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174-047
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 2 . Suspended El lb.Well Class: 20AAC 25.105 20AAC 25.110 Development 2 . Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14.Permit to Drill Number/ Sundry: Hilcorp Alaska,LLC Aband.•' 10/13/2016 ( 174-047 /3j(a—L 2l- 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 October 31, 1974 50-733-20167-01-00 4a.Location of Well(Governmental Section): «. 8. Date TD Reached: 16.Well Name and Number: Surface: 727'FSL, 141'FEL,Sec 17,T9N, R13W,SM,AK January 7, 1975 TBU K-10RD ' Top of Productive Interval: 9. Ref Elevations: KB: .4&5 r., 17.Field/Pog,�(g 9Artbur liver Fjglya, N/A GL:73 BF:52 IZl.S Hem oc Oil Po I"3- Total r U� Total Depth: 1'1 ( 10.Plug Back Depth MD/TVD: 18.Property Designation: „. j L 1206'F ,2427'FAL,Sec 19,T9N,R13W,SM,AK 8,445'/6,196' ADL 017594 k /8 4b. Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19.Land Use Permit: Surface: x- 213757 y- 2511791 Zone- 4 12,822'/9,739' N/A TPI: x- y- Zone- 12.SSSV Depth MDlTVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 206218 y- 2509053 Zone- 4 N/A N/A 5.Directional or Inclination Survey: Yes ['ached) No ❑✓ 13.Water Depth, if Offshore: 21.Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 73' (ft MSL) N/A 22. Logs Obtained: ROP DGR EWR-Phase4 ALD CTN MD, DGR EWR-Phase4 ALD CTN ND,Formation Mudlog 5in&2in MD&ND Formation,LWD Combo Log MD&ND,Gas Ratio Log and&ND, Driling Dynamics Log MD&ND,LWD Combo Log MD&ND RECEIVEDscope ar DEC 302016 AOGCC 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 24” Surface 384' Surface 384' Driven 13-3/8" 61/68# K-55 Surface 4,998' Surface 3,877' 18" 2255 sx 9-5/8" 47# N80/P110 Surface 8,898' Surface 6,439' 12-1/4" 700 sx 7" 29# N-80 8,532' 12,840' 6,260' 9,695' 8-1/2" 960 sx 24.Open to production or injection? Yes ❑ No 0 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom; Perforation Size SIZE DEPTH SET(MD) PACKER SET(MD/ND) and Number): 4-1/2" 11,966' 11,903'MD/10,793'ND p( 1>pa)Jl 26.ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes❑No El to /13)1 IP Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED L(.-- 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A N/A 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 Form 10-4 7 evised 11/ 015 CONTINUED O PAGE 2 Submit ORIGINIAL only 3/i/ 2 —2--?-17 Ae,7/7/J RBDMS L`' JAN 18 2016 28.CORE DATA Conventional Core(s): Yes ❑ No ❑✓ Sidewall Cores: Yes ❑ No ❑I If Yes,list formations and intervals cored(MDIfVD, 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 MC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? Yes ❑ No 0 Permafrost-Top N/A N/A If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base N/A N/A Attach separate pages to this form,if needed,and submit detailed test Top of Productive Interval information,including reports,per 20 MC 25.071. Formation at total depth: 31. List of Attachments: Wellbore Schematic,Daily Decompletion 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 MC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Cody Dinger Email: cdinger a<7hilcorp.com Printed Name: Cod Iter Title: Drilling Tech Signature: 41( Phone: 777-8389 Date: 12/30/2016 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item lb: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and ND for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 MC 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 MC 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 MC 25.071. Item 31: Pursuant to 20 MC 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 King Salmon Platform Trading Bay Unit • Schematic Well: K 10RD PTD: 174-047 H8t%4rp Alaska,LLC API: 50-733-20167-01 Casing & Tubing Size Type Wt Grade Thrd ID Top Btm Hole Cmt Cmt Top R1KB=34.40' 24" Conductor Surf 384' Driven s .. °? ! i E i 13-3/8" Surf Csg 61 K-55 • 12.515 Surf 1511' 655 Surf r, DV Collar 1511' 1514' 18" sx 355 fe returns I 13-3/8" Surf Csg 61 K-55 12.515 1514' 2500'± Calc @ 1300 2378' 16-1/2" (Calculated 13-3/8" Surf Csg 68 K-55 12.415 2500'± 4998' sx w/20%WO) t q N-80& 8830'TOW 12- 175sx 8435'CBL rtl 9-5/8" Prod Csg 47 Butt 8.681 Surf sqz@850perf5' Goods Bad s8755ass'-5755' ' V P-110 8830'-8898' 1/4" '-8758 'J Sp CI Butt 960 sxs 8964' 7" Liner 29 N-80 6.185 8532' 12,840' 8-1/2" +175sx lap CBL sqz TOW 8445' BOW' 8462' Jewelry Detail NO. Depth(MD1 Depth(TVD) ID OD Item C1BP 1 8,466 6,094' - CIBP(set for whipstock) 8,466' )-� 1 r 0 t;+; 11,903'MD 10,793' ? 2 11,857'ELM 10,747' 3.00" 5.968" BOT 47 B2 Model"FH"Retrievable Pkr w/30k shear ring '•'3 + +' Al i;: 11,935'MD 10,824' "X"Profile Nipple °- .j . 'S 3 11,896'ELM 10,786' 2.813 Note:Top of G5 perfs are 12'below Nipple. y 4 11,966'MD 10,855' 2.992 BOT Shear Sub/WLEG u jY� 11,929'ELM 10,818' U r ., 113-10 Perforation Details st 4 Top Btm Top Btm Est TOC t :Ail Zone (MD) (MD) (TVD) (TVD) Amt spf Comments 11,300' ���l.• , G-5 11,916' 11,978' 8,912' 8,965' 62' 4 9/10/94 w/2-1/8"SilverJet,0 phase G-5 11,934' 12,032' 8,927' 9,011' 98' 6 6/8/95 w/2-1/8"EnerJet,90 phase ► r ' i . . ,. G-5 11,970' 12,000' 8,958' 8,984' 30' 6 2/23/94 w/2-1/8"Strip,45 phase Ce a en0 tr r �. Vy G-5 12,010' 12,035' 8,992' 9,014' 25' 6 2/23/94 w/2-1/8"Strip,45 phase e11,800' ° T rt ,RI , 7/1/84 w/2-1/8"BarKone II,o phase:7/4/92 w/2-1/8" G-6/H0 12,107' 12,117' 9,076' 9,084' 10' 8 silverlet Top of 6x•- tubing *,; ,}-2 H1 12,153' 12,163' 9,115' 9,124' 10' 4 7/1/84 w/2-1/8"BarKone II,0 phase u,884' 3 G-5 H2 12,182' 12,202' 9,140' 9,156' 20' 4 7/1/84 w/2-1/8"BarKone II,0 phase x 4 Mr- 11,916' H2 12,198' 12,240' 9,154' 9,190' 42' 8 6/11/80 w/2-1/8"Enerjet:10/4/80 w/2-1/8"Enerjet L H2 12,200' 12,260' 9,156' 9,207' 60' 4 10/23/75 w/2"Hyperdome `12035'66/HO H2 12,200' 12,240' 9,156' 9,190' 40' 4 3/27/79 w/2-1/8"Enerjet 73 H2 12,202' 12,242' 9,157' 9,191' 40' 1 7/1/84 w/2-1/8"BarKone II,0 phase 0) H-I H2 12,245' 12,260' 9,194' 9,207' 15' 4 9/10/94 w/2-1/8"SilverJet,0 phase c to a 7/1/84 w/2-1/8"BarKone II,0 phase:9/10/94 w/2-1/8" 0) ' 7 x-z H3/4 12,285' 12,365' 9,228' 9,296' 80' 8 SilverJet E 11-3/a H3/4 12,289' 12,349' 9,232' 9,283' 60' 4 3/26/79 w/2-1/8"EnerJet CU ,! H-3 H3/4 12,289' 12,352' 9,232' 9,285' 63' 8 6/11/80 w/2-1/8"EnerJet:10/4/80 W/2-1/8"EnerJet (..) : _ H 3/4 H3 12,290' 12,320' 9,233' 9,258' 30' 4 10/23/75 w/2"Hyperdome y H3 12,290' 12,310' 9,233' 9,250' 20' 4 7/4/92 w/2-1/8"SilverJet,0 phase i»rul Tagged on 12,13/07 = H-4 H3/4 12,330' 12,350' 9,267' 9,284' 20' 4 7/4/92 w/2-1/8"silverlet,0 phase @ 12,478' H-s H4 12,375' 12,435' 9,305' 9,356' 60' 8 10/23/75 w/2"Hyperdome:3/25/79 w/2-1/8"Enerlet - H-6 H4 12,376' 12,391' 9,306' 9,318' 15' 1 7/1/84 w/2-1/8"BarKone II,0 phase x H4 12,377' 12,437' 9,307' 9,357' 60' 8 6/11/80 w/2-1/8"Enerlet:10/4/80 W/2-1/8"EnerJet ►f _H-6 H4 12,415' 12,435' 9,339' 9,356' 20' 6/20/78 w/DA 2"Guns TD=12,840' PBTD=12,580' H5 12,450' 12,491' 9,368' 9,403' 41' 8 1/27/75 w/DA 2"Slimhole:9/6/75 w/DA 2"Slimhole Max Deviation=55.1°@ 7100' H5 12,450' 12,475' 9,368' 9,389' 25' 4 9/10/94 w/2-1/8"SilverJet,0 phase H5 12,475' 12,494' 9,389' 9,405' 19' 4 10/4/80 w/2-1/8"EnerJet H6 12,520' 12,545' 9,427' 9,448' 25' 8 1/24/75 w/DA 2"Slimhole:9/6/75 w/DA 2"Slimhole H6 12,606' 12,611' 9,499' 9,503' 5' 4 1/20/75 w/DA 4"Casing Gun-SQUEEZED OFF 1/21/75 Updated by UD 12/30/16 Hilcorp Energy Company Composite Report Well Name: MRF K-10RD2 Field: McArthur River County/State: Cook Inlet Offshore,AK 1(LAT/LONG): evation(RKB): API#: 50-733-20167-02 Spud Date: Job Name: 1612388P K-10RD2 PreDrill Contractor AFE#: AFE$: Activity Date Ops Summary 9/24/2016 Inventory BOP bolts and clean up same,string out hoses for vac unit use,start removal of old lightwater plumbing from HPU units(bad),RU rigs test pump,cut opening in wall of centrifugal room for plumbing to upright tanks,modify legs of staircase to doghouse landing.,Cont removal of lightwater plumbing in HPU units, received stairs,ladders and assorted equipment off boat,install stairs and landing on electricians shop,RU mudline to rig cellar and tie into choke manifold for circulating,Lay out KatchKan floor mats on rig floor.,Cont RU circ hoses from choke manifold to flowline,inspect and repair steam leaks,cont setting rig floor matting,run pump#2 through bleeder(water),install ring gasket in choke line connection to choke manifold,hang ladder on mechanic shop to roof top,install stair case from production landing to pits.,Run pump#2 through choke manifold for 1 hr with no issues,60 spm-190 gpm.Shut down pump and line up on auto choke.Pump 2 would not start,found VFD fault,re-set same(twice)and ran pump at 37 spm-3000 psi-39%choke with no issues.Did have a drip from weep hole on pod#1 while under pressure.Shut down and lined up on pump#1.Ran pump 1 for 30 minutes on full open choke at 63 spm-119 gpm,with no issues.,Reduced pump rate to 13 spm,manual choke closed at 85%,2500 psi.Ran 5 minutes and shut down same.Lined up on auto choke and prep to run#1 pump under load.Welder installed staircase from production deck to pit access landing,installed ladder from upper pipedeck to production deck and modifying handrails around those.Crew laid out cable trays to be mounted on rig module.,,K-10RD2 wellhead pressures at 04:00:24"=20 psi, 13 3/8"=0 psi,9 5/8"=300 psi,Tbg=3 psi. 100%moved, 90%Rigged up. 9/25/2016 Troubleshoot autochoke/pump#1 issues.RU and transfer FIW into and load pits.Bled off pressure on well,RU to pressure test circ line to tree from rig,and return line from annulus to pig launcher.Welder working on handrails around new stairs/ladders.,CO low torque valve on tree,cont troubleshooting pump#1 (runs but won't pump),cont modifying handrails,install last 3 storm clamps on sub base,electrician troubleshooting VFD issues with pump#2,run pump 2 but still seeing faults at slow down or shut down,welder building brackets for cable trays.MWD and Canrig Reps on board.,Tear into pump#1 and inspect valves/seats. Replaced one bad valve spring.Assemble pump and run with no change(will not prime and pump).Remove swabs and inspect suction manifold.Checked swabs and tighten loose rod clamp.Assemble pump.,Start pump#1,caught prime immediately.Run at 60 spm-116 gpm-200+psi.Pinch back auto choke and run for 1 hour at 60 spm-110 gpm-2400 psi.Auto choke at 42 percent closed.Saw no more than 113 degrees temp on hydraulics.Pulsation dampener start 450 psi,at 60 spm-2400 psi dampener at 2200 psi.Found leak on mudline shock hose,shut down pump.,RU and blow down mudline,break mudline connection and inspect same.Replaced bad hammer union o-ring.Ran pump under load 15 min,no leaks,no pump issues.Shut down and repeat with no issues.Shut down and prep to test circ lines to wellhead room and pig launcher.RU hose to pits for FIW.,With rig test pump on annulus line to pig launcher,low tested at 100 psi then high test at 750 psi(good),lined up test pump to circ line to tbg,tested at 250 low and 2500 high(good).SIMOPS meeting with Production crew and decision made to wait until Production changeout to circ well to FIW.Hung cable trays on rig support module,fabricated threaded flange for charge pump room to upright tanks. 9/26/2016 Top off pits,sand trap and rig water tank with FIW for well kill,cont working on steam lines while wait on Production changeout.Troubleshoot and rectify the pump #2 VFD issue.Run pump 1 and verify ready to pump on well.Break circ pumping down tubing at 4 bpm-865 psi,taking returns from annulus to pig launcher.Start FIW into pits while pumping.,Pumped a total of 60 bbls getting oil and gas returns from annulus,then started getting gas with oil returns.With 450 bbls away started seeing water along with gas and oil.With 690 bbls away started seeing majority of water,with some trace of gas and oil.Pumped a total of 910 bbls FIW at 4 to 5 bpm and shut down.FCP tubing= 1613 psi,9 5/8"=555 psi.Shut down and shut in to monitor well.Bled well to zero.,Tubing pressure increased from 60 to 120 psi over an hour.Annulus pressure increased from 40 psi to 120 psi over an hour.,Lined up pump 1 on tubing and pumped a total of 50 bbls at 2.3 bpm- 675 psi.First 10 bbls had water with oil returns,by 20 bbls away had nothing but water returns.With 50 bbls away shut down,FCP tubing=620 psi,9 5/8"=700 psi.Bled well to zero.,Tubing pressure increased from 0 to 55 psi,annulus increased from 0 to 45 psi over 30 minutes.Bled well to zero psi and RD circ line to tree top.Wellhead Rep prepped BPV and spang tool.Slowly opened swab valve and fluid percolating in tree.Shut in well,decision made to pump another tubing volume.Notified Production to prep pipeline for circ.,RU circ line to tree top,test line at 250 low,2500 high,had to CO low torque valve due to leak,re-test circ line(good).,Pumped another 160 bbls down tubing,taking returns from annulus to pig launcher.Pumped at 4 bpm,FCP 1200 psi on tubing,530 psi on annulus. Had majority of water returns with trace oil/gas.Shut down and bled well to zero psi and monitored for one hour.Total FIW pumped to kill well=1120 bbls.,RD circ line to tree top,set BPV with no issues.Production reps started hardware removal from tree.Rig crew PU 2 jnts 4"DP and MU/racked back for tree removal. MU the two riser sections on upper deck.Welder working on mount brackets for hydraulic lines and building hole cover.,lnstalled saver sub on topdrive,installed XO on tree cap,MU XO's and installed stand of DP into tree cap,MU topdrive on stand.Removed grating around wellhead.Secured greylok clamps with tuggers and removed same.Lifted tree off wellhead with topdrive(no issues).Pulled tree through deck and set in sub.Removed DP stand from tree.Hanger threads look good.,Removed elevators from topdrive,MU slings and pulled rotary table,removed same from rig floor with crane.LD mousehole.Pulled tree to rig floor with slings and removed from rig floor with crane.Remove mudline in rig cellar to allow for trolly travel.Wellhead Tech installed blanking plug in hanger,pumped SSSV open and secured same in open position.Torque up riser connections on upper deck prior to PU. 9/27/2016 Cont torque up flanges on riser assembly,while on upper deck.Remove production valves and equipment from wellhead room.Installed variable rams in single gate,staged on upper deck.Welder installed"D"rings in v-door area.Held Environmental Compliance/Spud meeting with both crews,Production Reps and Drilling Team.,Clean up greylok clamps for wellhead.Cont torque up flange bolts on riser assembly.PU riser assembly and lower into wellhead room.Install greylok clamp.Install grating around wellhead.Welder built hatch cover for riser opening in main deck.Crane removed beaver slide,bridge and bridge stand.Set trolley on sub-base in prep for NU BOP's.,RU slings on topdrive,RU winch line and sheaves to pull trolley.Stage annular on trolley,pull into cellar and hang off same.Stage double gate on trolley,pull into cellar and MU on annular.Torque up same.Cont installing lightwater piping in HPU skids.Welder installed pad eyes over centrifuge,and built assorted brackets for PVC piping and lightwater piping.,Trolley in mudcross spool(with valves installed)and MU,trolley in single gate and MU.Drained rig water tank(FIW)to production,trolley in 2'spacer spool and MU,load rig water tank with fresh water,silicone seal foamed areas of shaker room and auger rooms.Cont installing PVC vac lines. 9/28/2016 Torque last of BOP spacer spool, MU choke and kill lines.Install dbl boot flange on top of hydril and set flow box in place.Stack ended up being to high because flow box boot set down on hydril boot and still was 4"from landing out.Pull flow box and dbl boot and send to welding shop to be modified.MU accumulator lines to BOPs.Seal up around auger building.Remove trolly and set catwalk stand to get pad eye,measurements.Pull catwalk stand back out and set by welding shop to install pad eyes.,Install 4"ball valve in 400 bbl tanks.Welders working on flow box,wire hanging posts,stairs and landings to front of sub.Install dual air boot flange back on hydril.Press up accumulator and function test BOPS f/rig floor and remote station.Work on light water plumbing.Production tested rig gas alarms and everything tested out.,Cont HPU firewater system installation,pressure test steam coil in OBM upright with air(good),pull ISO tanks from boat and offload into upright tank on deck(360 bbls),set flow box back in rotary for flowline fabrication,install guard on winch and spool line onto winch,welder installed pad eyes on bridge stand.,With crane,installed bridge stand on sub-base,installed catwalk onto bridge stand,installed anchor bolts onto beaver slide and installed same. Serviced koomey air pumps,finished PVC vac lines,RU BOP test manifold,re-worked rig floor matting,gathered up parts for panic line,Electrician working on gaitronic units. 9/29/2016 Weld chains to secure V-door.Get measurements for flow line and flow box flow line outlet.Have welders working on same.Build 3"panic line and install same. Test light water system to 215 psi for 2 hrs.Good test!Work on sealing up cracks around rig.Cont fabricating BOP test manifold. Weld 3"dike on riser/hatchcover.,Cont modifying flowbox outlet,tighten saver sub clamp on topdrive,stage floor valves on rig floor,stage test joint components on catwalk, welders finished flow line and installed same,installed flow riser in flowbox,welder fabricated staircase for pit level landing to rig sub.,Silicone seal around rotary table and cover plate,MU dart valve,TIW,pump in sub for pre-testing BOP's,CO grabber dies on topdrive,steel seal and paint handrails,troubleshoot vac unit (seized up),installed lightwater system sprinklers in pits and HPU skids.,Set test joint in wellhead and MU on blanking plug,flood riser and BOP stack with FIW from trip tank with no leaks,RU test manifold on rig floor,RU test hose and flood with water to purge air from lines.Prep to shell test riser and stack.Cont welding stair case to rig sub from pit level Ianding.,,K-10RD2 wellhead pressures at 04:00:24"=27 psi, 13 3/8"=8 psi,9 5/8"=50 psi 100%moved, 98%Rigged up. 9/30/2016 Shell test BOP stack to 2500 psi against annular w/4 1/2 test jt.Perform 250 low and 2500 psi high press on hydril. Test other BOP equip to 250 low and 3500 psi high.Had a upper ram door seal that leaked on about the fifth test.Tightened door and they tested again.Had welders working on Putting two 2"and two 3" fitting tie ins at the shaker possum belly.Also installed stairs and handrails to front of sub.,Perform accumulator test. Finish doing the rest of the tests on the 4 1/2.Pull test jt and lay dn same.Test blind rams.Packing started leaking on the HCR valve.Assist welders working on assorted welding projects and rig inspections and housekeeping.RU flow show.CO vac unit.,Tie in bleeder lines from rig floor and choke manifold to plumbing on shakers,repair steam leaks, replace stem packing on HCR valve,repair switch on rig air compressor.Steel seal various handrails for paint.Prep mounting plates for cellar and shaker room gas detectors.Install rotary table beam pins.Install swedge jets in gun lines of possum belly.,RU test equipment on kill line to re-test HCR valve.Sent crane crew to Granite Point Platform to offload ISO tanks from boat and stage on deck for loading OBM.Test HCR valve at 250/3500 psi f/5 minutes each(OK),install mounting plates for gas detectors in shaker room,work on centrifuge feed pump relay,clean up choke room and paint drilling alignment valves,cont housecleaning on all levels of the rig.,,K-10RD2 wellhead pressures at 04:00:24"=27 psi,13 3/8"=7 psi,9 5/8"=50 psi 100%moved, 99%Rigged up. 10/1/2016 Cont housekeeping throughout the rig,cont fabricating whipcheck clamps for 1"and 2"high pressure lines.Have meeting with the crew on what was left to be done before rig was accepted.Do a walk through w/the crew and point out the deficiencies and issues that still needed attention.Work on training and going over the 1st part of the well plan.Finish welding up grate over auger.,Put pad eyes and a turn buckle on the flow line by the auger.Remove old chains that were in the walkways.Work on remote controls for choke.Found plug that came undone and got gage calibrated to.Had fire drill at 15:30.Every mustered in galley and then went to there brucker.Had a MWD hand that did not respond because he thought they were testing alarms.All other personal responded.,Work on sealing up the rig floor better around the derrick legs.RU vacuum degasser vent line,reconfigure rig floor matting,fill possum belly with water and test airboot plug,service hopper air actuated valve,repair centrifuge feed pump relay,install mounting plate in cellar for LEL gas detector,add oil to koomey tank,welder finished fabricating 2"whipcheck brackets.,Cont sealing rig floor and derrick legs,perform derrick inspection,install 2"clamps on hydraulic lines,gathered up 6 x 8 150 flanges and valve for centrifugal room,drill mount holes on shaker dumps for pit liner,welders fabricating mounting brackets for mudline in upper and lower cellars. 10/2/2016 Install hydraulic elevators on topdrive,PU 4 1/2"test joint,RU and set up for first test against upper rams.Perform pre test to ensure we are ready for the state man.Work on welding projects and housekeeping while we were waiting for his arrival,State man[Jeff Jones]arrived on platform at 09:30.Went through orientation and did walk through on rig.Started testing BOP w/4 1/2 test jt at 10:00.Test all BOP equip except for the hydril to 250 low and 3500 psi high.Test all gas alarms w/production electrician.Perform accumulator test and recovery time was great[149 sec]but two of the air pumps wouldn't pump.Mech and TP worked on pumps.,Back out of blanking sub and PU to spacer jt.Lay dn 4 1/2 test jt and PU 3 1/2 test jt.Had issues getting stabbed back onto blanking sub. Finally got stabbed back on.RU and tested hydril on 3 1/2.Had to bleed pressure off twice and and tighten fittings on the test jt.Got test on the Hydril 250 low and 2500 psi high.Test upper and lower rams to 250 and 3500 psi.Test all the PVTs.Test manual and remote choke.,Remote choke was pressured up to 1000 psi and with pump down it bleed back to 0 psi within 3 min.Inspector wanted to see fire rating for kill and choke lines.Found cert for kill line hose,nothing for choke hose.Made arrangements to get choke hose from Monopod Platform along with unibolt flanges.Made arrangements to get DSA,ring gaskets and unibolt flange to heliport from warehouse.,Troubleshoot auto choke.Stem face had 4 small chips out of it,replaced stem piece,assembled and attempted to retest with same results,pressure dropping to 0 psi quick.Received choke hose from boat and other hardware from chopper.RD test equipment and test joint.Spotted Pollard e- line unit on upper pipe deck.,Shut in and drained Kuukpik choke hose,removed same,NU unibolt flanges to choke manifold and HCR valve,MU Hilcorp choke hose.Flood with water.Prep deck and rig to PU 4"DP and rack back.Test ran centrifuge and feed pump(ok).Attempt to test choke line several times,will not hold 3500 psi.Pump through choke line and manifold with fill up pump to eliminate any air.Attempt re-test with no luck.Strap 10 joints in,"V"door and start to MU stands in mousehole.Welder making cut in suction line in centrifugal room,to install flanges and valve.,,K-10RD2 wellhead pressures at 04:00:24"=28 psi,13 3/8"=8 psi,9 5/8"=50 psi 100%moved, 99.5%Rigged up. 10/3/2016 Cont to PU rack back 4"DP,Had a issue with the blocks dropping about 5'for no apparent reason.Driller shut down and notified the TP.Inspections were done and techs were contacted to see if they could tell if there were any issues.No issues were found. Worked on welding projects and testing 2"choke hose. Sent cert for 2"choke hose and test chart to Jeff Jones at AGOCC.Move BOP remote away V heliport.,Work block falling issues and keeping welders busy.Weld 6" flanges in centrifugal suction for isolating when we bring on OBM. Paint braces for blow down line.decision was made to PU DP and stand it back in the derrick with the driller that has experience running this rig. PU and stand back DP.,Cont PU rack back 4"DP in derrick.Had to pull mousehole and retrieve broken buffer spring from bottom of mousehole.Welder building whipcheck clamps for choke line.Received 3 ISO tanks from boat,RU trash pump and hoses and offload 2 1/2 ISO tanks OBM into 2nd upright.Received rig mat and placed on upper deck for dock space.Replaced hydraulic hose on tong line ram.,Installed light over auger deck,backside landing.Ran centrifuge and flushed with some FIW.Unit would not shut down.Electrician used breaker to shut down and found conveyor screw turning backwards.Electrician rectifying that.Install 4"hoses on upright tanks for suction line to centrifugal room.Paint handrails around support module. Housekeeping.Function tested vac degasser unit.,,K-10RD2 wellhead pressures at 04:00:24"=28 psi, 13 3/8"=8 psi,9 5/8"=50 psi 100%moved, 99.5%Rigged up. 10/4/2016 Cont servicing centrifuge and vac degasser in pits.Working on plumbing OBM hoses to tanks and starting to plumb base oil lines.,Had driller come in for training on chopper at 8:30.Started training new driller on rig running operations.Started PU DP and standing it back in the derrick.Got all 47 stds racked back.,Work on plumbing for hopper jet.Service rig.Work on monthly inspections.Go through centrifuge issues with SWACO tech.Offload work boat.Continue picking up drill pipe.,Continue picking up and standing back drill pipe.Rack back a total of 118 stands.Install steam heater in charge pump room. Work on plumbing base oil Iines.,K-10RD2 wellhead pressures at 04:00:24"=28 psi, 13 3/8"=8 psi,9 5/8"=52 psi 100%moved, 99.5%Rigged up. 10/5/2016 PU 4"XT 39 DP and stand it back in the derrick.We now have 142 stds in the derrick.About 9,000'of DP.,Service rig,Do a derrick inspection,Secure the V-door post.Replace derrick and drwks camera cable.Adjust pressure on MU tong line to make it more controllable.,Pull super choke apart and trouble shoot.Found out that main sleeve wasn't closing all the way.Replaced it with the old one.Tested it to 1000 psi for 10 min on a chart and it lost 70 psi.Good test for a choke. Send chart and explanation into AOGCC.Also left messages.Work on finishing up acceptance sheet.At 1600 hrs we got the ok from Jim Regg to proceed w/well work.,Get non-produced form approved and get equip ready to pump down tbg taking returns to production pipeline.Held PJSM w/production and rig crew.,Circulate 805 bbls FIW to production header at 3 BPM/850 psi.Annulus averaged 550 psi while circulating due to bucking pipeline psi.Shut down and bleed tubing and annulus to 0 psi.Monitor well 10 minutes(static).,Pull BPV.Fill hole and establish loss rate.Static.,Rig up landing joint and Pollard e-line.,Pollard run #1 3.84 GR to SSSV at 261'WLM without issue.Run#2 with hold-open sleeve and set same in SSSV.C/O elevators.Pull hanger off seat at 190K.Had to work+- 8 times to pull free.Pull up to 172K(6.4')and set slips.,Pollard run#3:2.75 jet cutter.Correlate on depth at 11,884'and cut tbg. Seen good indication of cut.POH with e-line.Well is still static.,K-10RD2 wellhead pressures at 04:00:24"=28 psi,13 3/8"=8 psi,9 5/8"=0 psi 100%moved, 100%Rigged up. 10/6/2016 Break dn and lay dn landing jt.Lay dn hanger on top of 1st jt of 4 1/2 tbg.Tbg is scaled up bad.Pull out a total of 5 jts with the hole swabbing,filling the tbg with a line off the trip tank.Scale getting worse and tbg started flowing over.,MU floor valve assem and screw in TD.Start circ at 2 BPM and work it up to 5 BPM[107 spm,343 psi]while reciprocating the pipe 30'.Getting a lot of scale back across the shakers.Shut down and monitor well.Well static.,Pull two more jts and LD SSSV.Continue POH laying dn tbg.Started getting less scale after SSSV and got a lot better after laying down about 380'of tbg.,Continue POOH laying down completion assembly to+-9100'.,POOH laying down completion assembly 9100'to 5300'.,K-10RD2 wellhead pressures at 04:00:24"=28 psi,13 3/8"=8 psi,9 5/8"=0 psi 10/7/2016 POOH laying down 4 1/2 completion string from 5300'to 3440".Break out 4 1/2 X 3 1/2 XO and RU 3 1/2 tbg tools.The last few jts of 4 1/2 tbg were 150 micro R/hr the rest of the 4 1/2 were between 50 and 80 micto r/hr.,Continue POH laying down 3 1/2 tbg.There were no pups on any of the GLM which made them time consuming to handle. Save 30 jts off to one side for running as a cmt stinger.Cut jt was 11.6,CIean and LD Weatherford tongs,slips,and elevators.,Clear floor and clean hand rails and walkways from rig floor to camp.,Change out elevators.Install wear bushing.,P/U M/U clean out BHA:bit,7"casing scraper,2 boot baskets,bit sub,XO=17.25,RIH with clean out assembly with stands out of derrick to+-3330'.Having to torque each connection on the trip in.,P/U 8 1/2"string mill and cross-overs.Break circulation at 4.5 BPM/220 psi. Continue RIH with stands out of derrick and torqueing each connection.,K-10RD2 wellhead pressures at 04:00:24"=30 psi, 13 3/8"=8 psi,9 5/8"=0 psi Fluid loss to well bore:0 bbls. 10/8/2016 RIH w/7"csg scraper and 8 1/2 string mill.Running DP out of the derrick,torqueing every connection to just above liner at 8480'. Break circ and check pressure before entering liner.#1 pump, 100 spm,400 psi.,Continue RIH out of derrick to 8979'.Didn't even see the liner top at 8532'.RU to PU 4"DP.Had safety meeting with crew and Hilcorp safety man Mark Tornai before crew went to work.,Continue RIH PU 4'DP.Had safety meeting with 2nd crew and Hilcorp safety man right after the got off work.Tag up at 11870'.MU topdrive and fill pipe.,Circ working pump rate up to 5.5 BPM,750 psi w/#1 pump.Minimal paraffin/residue over the shakers at bottoms up.,Change out elevators.Test ESD.Good test.,POOH to TOL at 8532'.,Circulate at 9.3 BPM/1425 psi with minimal residue over shakers.,POOH from 8532'to 4840'.,K-10RD2 wellhead pressures at 04:00:24"=30 psi, 13 3/8"=8 psi,9 5/8"=0 psi Fluid loss to well bore:0 bbls. 10/9016 POOH from 4840'to 5 1/2 taper mill.Lay do mill and finish POH.Lay do bit,csg scraper,and boot baskets.Recovered a coffee can of parifin from boot /baskets.,RU pollard E-line and RIH w/a 7"retainer.Set retainer at 11,800'.PU 50'off retainer and go back and tag. POH and RD E-Iine.,Rig up Weatherford ✓ V h] 1-r' tongs and equipment.,P/U cement stinger,XO's and 25 joints of 3 1/2"tubing=779.47.,Rig down Weatherford.Change elevators for running drill pipe.,RIH with cement stinger assembly to 11,745'. P/U 160 K, S/O 76 K.,Circulate down at 1 BPM and engage cement retainer at 11,762'.Recheck pipe on location.Pressure up to 3000 psi.Unable to inject.Bleed pressure off.,Stand back one stand.Make up pump in sub,TIW valve and pup joint.Rig up Schlumberger cementers.,K- 10RD2 wellhead pressures at 04:00:24"=33 psi, 13 3/8"= 10 psi,9 5/8"=0 psi Fluid loss to well bore:0 bbls. 10/10/2016 Rig up Schlumberger cementers.Hold PJSM.Pump 5 bbls water ahead.Test lines to 3500 psi.Batch up,pump 18.6 bbls of class g 15.8 ppg cmt,and displace with 112.5 bbls FIW.Held 250 to 300 psi back pressure w/choke.Shut down and bleed press off back side,RD cmt head,pull 12 stds.drop balls and circ a < complete circ.Got back a trace of cmt on bottoms up.,POH w/cmt stinger stand back 4"DP in derrick.,R/U Weatherford.POOH laying down 3 1/2"tubing and 1) cement stinger.Had a total of 25 joints of tubing.,Rig down Weatherford equipment.Hole is static.,Purge choke manifold.Test 7"x 9 5/8"casing and cement plug, ` /y at 2700 psi on chart for 30 minutes.Pressured up to 2720 psi and bled down to 2670 psi in 30 minutes.6.7 bbls to pressure up.13 3/8"annulus went from 8 to 10 1.' psi during test.Good test.Bleed down.,Rig up Pollard e-line.RIH with bridge plug.Correlate on depth.Set bridge plug at 8453'WLM.Pull 1500 lbs over to release setting tool.Retag to confirm setting depth.POOH.Shear screw looked good.Rig down Pollard e-line.,Slip and cut drill line.Service rig.Continue cleaning pits.,K-10RD2 wellhead pressures at 04:00:24"=30 psi,13 3/8"=10 psi,9 5/8"=0 psiIt Fluid loss to well bore:0 bbls. .5-,4- GI 6 r p c? L{5( 10/11/2016 Finish slip and cutting drilling line w/new crews.Set wt indicator.,Service rig.,Prep for picking up BHA.Clean shakers and shaker pits so we can do a couple welding projects.PU 1 jt of 4'HWDP and PU whip stock.mill assy and std back.,Pull wear ring,chase and seal rig floor leaks while continue and assisting with weld projects at shakers also assist crane crew w/boat.,Continue P/up BHA#3 BOT window master G2 whip stock w/torque master bottom trip anchor assy. Drift and pick up 21 joints of HWDP.,Test tools at 300 GPM/730 psi.Good test.,RIH with whip stock assembly with pipe out of derrick.SLM while running.,Hang off string with test plug at 4283'.Prepare to test BOPE.,K-10RD2 wellhead pressures at 04:00:24"=24 psi,13 3/8"=8 psi,9 5/8"=0 psi Fluid loss to well bore:0 bbls. 10/12/2016 Hang off string. M/U test joint.,Purge air and shell test w/top rams 250L and 3500 high good test.,State man Mr.Bob Noble on location and ok to proceed with r witness test.,Test BOPE on 4"test it as per regulations 250L and 3500 high w/annular high at 2500 psi w/one F/P annular high test function annular few times v- Vand re-test(ok)and one koomey air pump having blow by but still had good numbers on draw dn test(Mech went thru all three air pumps clean them and chg bad `G\ "0"ring on pump w/blow by),R/dn test equipment. Assist Mr.Clint Chanley on finish up of prep work of 9-5/8"pack-off LDS (have(2)LDS that we are unable to /\ back out).Remove test plug and lay down test joint.,Continue RIH w/BHA#3 as per BOT hand from 4240'to 8337'.,Establish parameters: 125 k P/U,68 k S/O. 5.5 BPM/780 psi.Orient to 47 L.Wash down and set whip stock at 8466'., Milling parameters with no pump:@ 20,50 and 80 RPM=13 K torque Milling parameters while pumping at 220 GPM/800 psi:@ 20,50 and 80 RPM= 13 K torque.,Lay down single DP.Blow down lines.Secure well.Welder finishing projects in shaker area,R/U lines to production and crew working on final foam sealing of areas before changing over to OBM.,K-10RD2 wellhead pressures at 04:00:24"=24 psi, 133/8"=8psi,95/8"=0psi Fluid loss to well bore:0 bbls. 10/13/2016 Continue finish weld projects and sealing cracks and gaps and prep for OBM chg over.,PJSM and chg over wellbore U OBM w/one MP dn hole w/OBM @ 3-5 bpm and one MP w/FIW to pipeline @ 3-5 bpm with 25 bbl spacer back 12 bbl early from calculated.,R/D clean pumping lines and clean pits.Prepare for OBM in pits.Pull blind flange out of MP suction line.Fill pits with OBM.,Obtain SPR's:#1 15 SPM/250 psi,30 SPM/370 psi. #2 15 SPM/260 psi,30 SPM/370 psi. Parameters:110 P/O,73 S/O,89 K rot wt at 80 RPM/8.5 K torque. 350 GPM/2460 psi MW 8.8 ppg.,Milling window 8443'to 8446'with previous parameters.Actual top of window will be 8445'and BOW will be_846_2'.,K-10RD2 wellhead pressures at 04:00:24"=32 psi, 13 3/8"=8 psi,9 5/8"=0 psi Fluid loss to well bore:0 bbls. ,{" r I 10/14/2016 Mill window from 8446'to 8458' at various parameters as per BOT hand w/ 7-14k torque and full stalls.,Continue Mill window f/8458'U 8462'@ 370 gpm @ 2350 psi @ 90 rpm @ 7-14k torque and full stalls and using various parameters.Recovered 312#metal. Also pumped around 25 bbl walnut sweep @ 20 ppb @ 8458'w/no change.,Circ btm/up while building dry job.,Monitor well(static).Pump dry job.,Service rig,repair TDS torque sensor and up max torque f/17.5k U 20k set torque.Chase TDS leak(gear box).,POOH with window milling assembly.Stand back HWDP.,Work BHA.Mill face 50%worn and 1/4"out of gauge.Upper and lower watermelon mills still in gauge.CIO for new 8 1/2"mill.M/U BHA.,RIH with window milling assembly BHA#4 to 1200'.,K-10RD2 wellhead pressures at 04:00:24"=32 psi, 13 3/8"=8 psi,9 5/8"=0 psi Fluid loss to well bore:0 bbls. Daily metal recovered:342 lbs Total:342 lbs 10/15/2016 RIH with window milling assembly from 1200'to 3317'.,Slip insert came out of slip body and fell down hole.Drain stack but did not locate insert.Consult with engineer about options.,POOH slowly from 3317'to+-800'without over pulls.Had some over pulls from 800'to tubing spool with upper watermelon mill.BHA hanging up with 20K over pulls at this point.,Attempt to fish slip insert off top of upper watermelon mill with magnet on T-bar without success.Work mills past tubing spool using various ideas by pumping and slight rotation,slacking off and picking up until finally able to pull to rig floor.Upper and lower mills were chipped and worn.Starter mill was 1/8"under gauge with broken cutters. No recovery of slip insert.,Consult with engineer.Lay down window mill BHA.Mobilize back-up starter mill,Pollard slick line unit(from Monopod)and personnel to fish with magnets.Organize and clean rig floor while waiting on equipment and personnel.Service equipment.,R/U pollard slick line unit. Run#1:4.5"magnet with 6 1/2"bow spring centralizer.Unable to pass 51'. Run#2:3.75 magnet with 6 1/2"centralizer.Unable to pass 51'. Run#3:2.25 LIB down to 900'without issue. Run#4:2.25 magnet with 6 1/2"centralizer to 8466'SLM.Minimal shavings recovery. Run#5:8.1 junk basket to 900'.Recovered sludge and minimal metal shavings.,K-10RD2 wellhead pressures at 04:00:24"=30 psi, 13 3/8"=10 psi,9 5/8"=0 psi Fluid loss to well bore:0 bbls. Daily metal recovered:5 lbs Total:347 lbs 10/16/2016 Pollard slick line run#6 w/9-5/8"junk bsk w/8.1"gauge btm U 8400'wlm w/no set dn. Pooh w/some metal shavings no slip die junk.r/dn slick line clean rig floor.,Rih w/Bha#5 w/all new window milling mills and tandem junk bsk a stand up from mills.,Service rig chg/out leaking man rider fittings,chk dwk mtr bolts, Tie up TD power cable service loop chk torque on TDS and confirm 20k setting inspect tds gear box leak confirm gear box vents are open chg/out adsorbents. Attempt to r/up double line on m/up tongs.,Continue rih f/683'V 2500'.,3.6 bbls to fill pipe brk circ and circ and warm mud©370 gpm ©1000 psi pump 144 bbls total.,Continue stage in hole f/2500'to 8435'.Fill pipe and warmed mud at 5000'and 7300'.,Establish parameters: 110 k P/U,73 K S/O,RT wt 85 K,9-15 K torque,9.1 BPM/1750 psi.,Mill window as per Baker rep.to 8462'.Work through window with and without pump and rotation.Drill 20'of new hole to 8482'.,Circulate and condition mud at 10.1 BPM/2100 psi until 8.7+ppg in and out.Had:40%cement,10%coal,40%carbonaceous sandstone,5%sand and 5% metal.,Pull 1 stand.Perform FIT to 12.5 ppg EMW.Bled back 3.1 bbls.Good test.No change on 13 3/8"annulus while testing.,Pump dry job.POOH with window milling assembly.,K-10RD2 wellhead pressures at 04:00:24"=35 psi,13 3/8"=10 psi,9 5/8"=0 psi Fluid loss to well bore:0 bbls. Daily metal recovered:19 lbs Total:366 lbs Assist production w/injection test of K-06 IIP ®g TB 0,14„. 1,7,---.A THE STATE Alaska Oil and Gas b.w Of Q c Conservation C®1'Y1n11sslOri rE 2 _ 333 West Seventh Avenue "eir _ C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS*P Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis Operations Manager Hilcorp Alaska, LLC SCANNED JAN 3 1 ZC17J 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock and Middle Kenai G Oil Pools, TBU K-10RD Permit to Drill Number: 174-047 Sundry Number: 316-427 Dear Mr. Golis: 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, // / 9)1,111A--- Cath '. Foerster Chair S1- DATED this 31 day of August, 2016. RBDMS SEP - 1 2016 RECEIVED STATE OF ALASKA AUG $2 �� ALASKA OIL AND GAS CONSERVATION COMMISSION ; .,1,,, APPLICATION FOR SUNDRY APPROVALS I 20 AAC 25.280 AOGCC 1.Type of Request:V Abandon 11 Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ f NJ'r'• Suspend CI Perforate C] Other Stimulate ID Pull Tubing ❑ Change Approved Program❑ q�, ti Plug for Redrill 0 - Perforate New Pool CI Re-enter Susp Well ❑ Alter Casing ❑ Other. CI2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. r Hilcorp Alaska,LLC Exploratory ❑ Development 0 • 174-047 ' 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic LI Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20167-01 , 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 Trading Bay Unit I K-10RD 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018777 McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools 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): • 12,840 9,695 ' • 12,575 . 9,473 2,540 psi WA N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 4,998' 13-3/8" 4,998' 3,877' 3,090 psi 1,540 psi Intermediate 8,898' 9-5/8" 8,898' 6,439' 6,870 psi 4,760 psi Production Liner 4,308' 7" 12,840' 9,695' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11,916-12,545 • 8,912-9,448 4-1/2"&3-1/2" 12.6#N-80&9.2#N-80 8,476&11,966 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker FH Packer&Camco TRB-6 SSSV • 11,903'(MD)8,901'(ND)&263'(MD)263'(TVD) 12.Attachments: Proposal Summary 0 Wellbore schematic 0 •13.Well Class after proposed work: Detailed Operations Program LI BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/15/2016 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended 0' 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 Dan Marlowe(907)283-1329 Email dmarlowe(aahilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature (.16-t,;, Phone (907)777-8356 Date g I(7 i E. Cti COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: `k 2-7 Plug Integrity ❑ BOP Test Mechanical� Integrity Test 1:1 Location Clearance ❑ Other: 'e V00 es. O$ ie 5f— Er SjOr�') - A tt. p l p t_- ` 'r'" L`{-1 -- ��. // Z, ) Post Initial Injection MIT Req'd? Yes ❑ No El ' ' 3( Spacing Exception Required? Yes ❑ No Subsequent Form Required: /6•- ci6 7- RBDMS ---SEP - 1 2016 /� APPROVED BY Approved by: elitt/'� ?0,..(4.4,(4,N.... COMMISSIONER THE CpOMMISSION Date: 8•3!/< 8 is f// /6 1 �J a '�/c' Submit Form and Form 10-403 Revised 11/2015 0 4 rolvet�'IOss1ld for 12 month rom the date of approval. Attachments in Duplicate Well Work Prognosis Well: K-10rd Hilcorp Alaska, LIS. 08/17/2016 Well Name: K-10rd API Number: 50-733-20167-01 Current Status: S/I Gas-Lift Producer Leg: Leg#4 (NW corner) Estimated Start Date: September 15, 2016 Rig: Kuukpik#5 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett(8332) Permit to Drill Number: 174-047 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904(M) Second Call Engineer: Monty Myers (907)777-8431 (0) (907) 538-1168 (M) Current Bottom Hole Pressure: 3,638 psi @ 9,450'TVD 0.384 lbs/ft(7.41 ppg)SIBHP 12/08/2006 Maximum Expected BHP: 3,638 psi @ 9,450'TVD 0.384 lbs/ft(7.41 ppg)SIBHP 12/08/2006 Maximum Potential Surface Pressure:2,540 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) This is a no-flow Well(01/21/2003) Brief Well Summary K-10rd is a shut-in comingled G-Zone / Hymlock gas-lifted producer. This workover will pull the current completion and plug the well for a sidetrack.Well has known 9-5/8" by 13-3/8 communication. Procedure: 1. Skid Rig into position above K-10rd. 2. Conduct AOGCC rig inspection prior to beginning plug bacjc. �ia.d 3. ND Wellhead, NU BOP and test to 250psi low/3760igh. (Fsi Note: Notify AOGCC 48 hours in .,,� advance of test to allow them to witness test).� ���, --krs• 4w e.11 s`q' /f,zy/' 4. Circulate hydrocarbons from well to production—Workover fluids will be FIW. ff 5. RIH w/E-Line and cut tubing at±9,009. L._. /474.1-4. 211144.-- .. 6. POOH laying down completion. (t 8'4'K 7. RIH with bit and string mill to top of liner at±8,532',circulate clean. POOH. 8. RIH with cement retainer and set at±8,520' a. We request a waiver to 20AAC25.112.a1c1d to set the retainer above the liner top. ?.5 ,' 1�0,7Z`' 9. RIH Stinging into cement retainer 03 10. RU cementing equipment and establish an injection rate with FIW. �" 11. Mix and pump±148 barrels Class G cement to isolate existing completion. -sting from retainer 0and circulate hole clean. POOH. � �. r--� ` 7 ( RP.ta ) zoJ p5c j 3 12 . . PU RTTS test casing starting at±8,500' working up the hole-to identify casing eak pressure testingLow fqS to 1,500 psig.The 9-5/8" repairs will be conducted as needed during drill and completion of the 30 sidetrack. 13. RU e-line and RIH w/CIBP to±8,400' ±CIBP 5' above casing connection. 14. RD e-line. 15. PU whipstock and mills and RIH to CIBP. 16. Orient whipstock and set at 45 degrees left of high side. ***Remaining Procedure to be included on the Permit to Drill Sundry for the sidetrack*** General sequence of operations pertaining to drilling procedure: (informational only) 17. Mill 8-1/2" window and 20' of new formation. POOH and LD mills. 18. PU directional BHA and TIH to window. 19. Swap well to 9.2 ppg oil based drilling mud r o of /0� C(00- lteeta deft.A P (At" Tti,s weir �r r4roty( q e r , 1 CO%cvr, • Pd t� x ?0 60Po w-Yti a 4 t4 Cvr- Of (NT,. P"f/"y Prod 0. 4c ,-*- /!�f‘av(d u/la, /1 inidved l� �,,1. )'/v/i flip n'e/, • • Well Work Prognosis Well: K-10rd Haror�)niaaka,�.u; Date: 08/17/2016 20. Drill and complete new production hole. 21. Conduct 9-5/8" casing repair as needed 22. Perforate per program 23. Run new completion Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form • • King Salmon Platform Trading Bay Unit . fliSCHEMATIC Well:K-10RD As Completed:01/27/75 eilcutp Alaska,LLC PTD: 174-047 API: 50-733-20167-01 Casing & Tubing Size Type ® Grade Thrd ID Top Btm Hole Cmt Cmt Top RKB=34.40' 24" Conductor _--_ Surf 384' Driven .,+ 13-3/8" Surf Csg 61 K-55 12.515 Surf 1511' 655 Surf 1 io DV Collar 1511' 1514' 18" 5x 355 ft'returns t s ~ 13-3/8" Surf Csg 61 K-55 12.515 1514' 2500'± Calc@ 1300 2378' 4 ,' 16-1/2" (Calculated %'i 13-3/8" Surf Csg1:111 K-55 12.415 2500'± 4998' SX w/20%WO) N-80& 8830'TOW 12- 1755x 8435'Cel o i^ 9-5/8" Prod Csg P_110 Butt 8.681 Surf 8830'-8898' 1/4" sqz perfs Bad 8455'-8755' AWy @ 8805' Good 8755'-8788' J sp Cl Butt 960 sxs r v a 7" Linerill N-80 6.185 8532' 12,840' 8-1/2" +175sxlap 8964' U i. I sqz F Tubing 34.40'RKBtoTbgHoar tfil , X44 4-1/2" 12.6 N-80 Butt 3.958 Surf 8476' , I "4, MB i' 3-1/2" 9.2 N-80 Butt 2.992 8476' 11,966' ,4 l x I?t'': 2-5 Jewelry Detail N0. Dssth ID OD Item 1 263' 2.813 5.917" Camco TRB-6 SSSV 2 2,795' 3.833" 7.031"x 5.625" GLM#1-4-1/2"Camco MMG w/R20 valve&RK Latch 'i' 3 5,243' 3.833" 7.031"x 5.625" GLM#2-4-1/2"Camco MMG w/R20 valve&RK Latch 4 7,195' 3.833" 7.031"x 5.625" GLMGLM)#3-4-1/2"Camco MMG w/R20 valve&RK Latch(Belly-up a m y i� ±'l 5 8,444' 3.833" 7.031"x 5.625" GLM#4-4-1/2"Camco MMG w/R20 valve&RK Latch 4 ': It 6 8,476' 2.992 Crossover,4-1/2"x 3-1/2" 2 i; i I`s i 7 9,254' 2.867" 5.390"x 4.155" GLM#5-3-1/2"Camco KBMG w/1"valve&BK Latch F 6 11.3P. 8 9,655' 2.867" 5.390"x 4.155" GLM#6-3-1/2"Camco KBMG w/1"valve&BK Latch i' 9 10,056' 2.867" 5.390"x 4.155" GLM#7-3-1/2"Camco KBMG w/1"valve&BK Latch 10 10,461' 2.867" 5.390"x 4.155" GLM#8-3-1/2"Camco KBMG w/1"valve&BK Latch k) 11 10,834' 2.867" 5.390"x 4.155" DIM#9-3-1/2"Camco KBMG w/1"valve&BK Latch I ♦ ', tT 66 12 11,178' 2.867" 5.390"x 4.155" GLM#10-3-1/2"Camco KBMG w/1"valve&BK Latch i �l 13 11,519' 2.867" 5.390"x 4.155" GLM#11-3-1/2"Camco KBMG w/1"valve&BK Latch 2 f5 14 11,864' 2.867" 5.390"x 4.155" GLM#12-3-1/2"Camco KBMG w/1"valve&BK Latch 11,903'MD , 15 3.00" 5.968" BOT 47 B2 Model"FH"Retrievable Pkr w/30k shear ring 11,857'ELM 1 � 16 11,935'MD 2.813 "X"Profile Nipple 4,4 7-14 111,896'ELM Note:Top of G5 perfs are 12'below Nipple. 17 11,966'MD 2.992 BOT Shear Sub/WLEG 11,929'ELM 4, ' Perforation Details i k a �� Top Btm Top Btm p �, � Zone (MD) (MD) (ND) (ND) Amt spf Comments OP c j /� G-5 11,916' 11,978' 8,912' 8,965' 62' 4 9/10/94 w/2-1/8"SilverJet,0 phase ;t s-. 0 -. G-5 11,934' 12,032' 8,927' 9,011' 98' 6 6/8/95 w/2-1/8"EnerJet,90 phase t" *1.- mG-5 11,970' 12,000' 8,958' 8,984' 30' 6 2/23/94 w/2-1/8"Strip,45 phase lam I 15 G-5 12,010' 12,035' 8,992' 9,014' 25' 6 2/23/94 w/2-1/8"Strip,45 phase Lk, igs d, G-6/HO 12,107' 12,117' 9,076' 9,084' 10' 8 7/1/84 w/2-1/8"BarKone II,o phase:7/4/92 w/2-1/8"silveriet f 17 �9ie H1 12,153' 12,163' 9,115' 9,124' 10' 4 7/1/84 w/2-1/8"BarKone II,0 phase SiH2 12,182' 12,202' 9,140' 9,156' 20' 4 7/1/84 w/2-1/8"BarKone II,0 phase 12035' H2 12,198' 12,240' 9,154' 9,190' 42' 8 6/11/80 w/2-1/8"Enerjet:10/4/80 w/2-1/8"Enerjet V G6/HO H2 12,200' 12,260' 9,156' 9,207' 60' 4 10/23/75 w/2"Hyperdome i H2 12,200' 12,240' 9,156' 9,190' 40' 4 3/27/79 w/2-1/8"Enerjet x-t H2 12,202' 12,242' 9,157' 9,191' 40' 1 7/1/84 w/2-1/8"BarKone II,0 phase iH2 12,245' 12,260' 9,194' 9,207' 15' 4 9/10/94 w/2-1/8"SilverJet,0 phase 4 11-2 7/1/84 w/2-1/8"BarKone II,0 phase:9/10/94 w/2-1/8" H-3/4 H3/4 12,285' 12,365' 9,228' 9,296' 80' 8 SilverJet T1 H3/4 12,289' 12,349' 9,232' 9,283' 60' 4 3/26/79 w/2-1/8"EnerJet '; x_3 H3/4 12,289' 12,352' 9,232' 9,285' 63' 8 6/11/80 w/2-1/8"EnerJet:10/4/80 W/2-1/8"EnerJet H-3/4H3 12,290' 12,320' 9,233' 9,258' 30' 4 10/23/75 w/2"Hyperdome 4.1 #I H3 12,290' 12,310' 9,233' 9,250' 20' 4 7/4/92 w/2-1/8"SilverJet,0 phase l Fill Tagged on 12/13/07e. 11-4 H3/4 12,330' 12,350' 9,267' 9,284' 20' 4 7/4/92 w/2-1/8"SilverJet,0 phase *12,478' H4 12,375' 12,435' 9,305' 9,356' 60' 8 10/23/75 w/2"Hyperdome:3/25/79 w/2-1/8"EnerJet Nzrsn ;•• / x-5 H4 12,376' 12,391' 9,306' 9,318' 15' 1 7/1/84 w/2-1/8"BarKone 11,0 phase '3(/`-4' H-6 H4 12,377' 12,437' 9,307' 9,357' 60' 8 6/11/80 w/2-1/8"EnerJet:10/4/80 W/2-1/8"Enerlet i,, H4 12,415' 12,435' 9,339' 9,356' 20' 6/20/78 w/DA 2"Guns 13-6 H5 12,450' 12,491' 9,368' 9,403' 41' 8 1/27/75 w/DA 2"Slimhole:9/6/75 w/DA 2"Slimhole TD=12,840' PBTD=12,580' H5 12,450' 12,475' 9,368' 9,389' 25' 4 9/10/94 w/2-1/8"SilverJet,0 phase Max Deviation=55.1°@ 7100' H5 12,475' 12,494' 9,389' 9,405' 19' 4 10/4/80 w/2-1/8"EnerJet H6 12,520' 12,545' 9,427' 9,448' 25' 8 1/24/75 w/DA 2"Slimhole:9/6/75 w/DA 2"Slimhole H6 12,606' 12,611' 9,499' 9,503' 5' 4 1/20/75 w/DA 4"Casing Gun-SQUEEZED OFF 1/21/75 Updated by iLL 08/03/16 • King Salmon Platform 1110 Trading Bay Unit . H PROPOSED Well: K-10RD As Completed: Future IliIcorp Alaska,LLC PTD: 174-047 API: 50-733-20167-01 Casing & Tubing Size Type Wt Grade Thrd ID Top Btm Hole Cmt Cmt Top RKB=34.40' 24" Conductor Surf 384' Driven f" .,.,, ,; 13-3/8" Surf Csg 61 K-55 12.515 Surf 1511' 655 Surf 00 t• DV Collar 1511' 1514' 18" SX 355 ft'returns 13-3/8" Surf Csg 61 K-55 12.515 1514' 2500'± Calc @ 2378' 11. 16-1/2" 1300 (Calculated 13-3/8" Surf Csg 68 K-55 12.415 2500'± 4998' SX w/20%WO) N-80& 8830'Tow 12- 175sx 8435'CBL a 9-5/8" Prod Csg 47 Butt 8.681 Surf sqz perfs Bad 8455'-8755' P-110 8830'-8898' 1/4" r @ 8805' Good 8755'-8788' ` Sp Cl Butt 960 sxs 8964' u = 7" Liner 29 N-80 6.185 8532' 12,840' 8-1/2" +1755x lap CBL sqz ' ` 4i'4 is- Tubing 34.40'RKB toTbg Hngr 2 ( 3-1/2" 9.2 1 N-80 1 Butt 2.992 1 ±9,000' 1 11,966' ii � T G 1 Jewelry Detail V c..c..;''''y'rNO. Depth(MD( Depth(TVD) ID OD Item 0` 1 ±8,400' i ±6,094' - - CIBP(set for whipstock) t oa _ I 2 ±8,520' ±6,175' Cement Retainer v ` .0 3 9,254' 8,194' 2.867" 5.390"x 4.155" GLM-3-1/2"Camco KBMG w/1"valve&BK Latch Cement Ret ner - ±+). ' .,�a_- 4 9,655' 8,559' 2.867" 5.390"x 4.155" GLM-3-1/2"Camco KBMG w/1"valve&BK Latch t8 520' t- it - r;2 5 10,056' 8,952' 2.867" 5.390"x 4.155" GLM-3-1/2"Camco KBMG w/1"valve&BK Latch 12 +' { '"^+' " 6 10461' _ 9,356' 2.867" 5.390"x 4.155" GLM-3-1/2"Camco KBMG w/1"valve&BK Latch ' I A G t 7(imj 'L- 7 10,834' 9,728' 2.867" 5.390"x 4.155" GLM-3-1/2"Camco KBMG w/1"valve&BK Latch m , ..�0 8 11,178' 10,071' 2.867" 5.390"x 4.155" GLM-3-1/2"Camco KBMG w/1"valve&BK Latch -`, 9 11,519' 10,410' 2.867" 5.390"x 4.155" GLM-3-1/2"Camco KBMG w/1"valve&BK Latch 1 - 10 11,864' 10,754' 2.867" 5.390"x 4.155" GLM-3-1/2"Camco KBMG w/1"valve&BK Latch c11,903'MD 10,793' 11 11 3.00" 5.968" BOT 47 B2 Model"FH"Retrievable Pkr w/30k shear ring k_/apt(2.- 11,857'ELM 10,747' 11,935'MD 10,824' "X"Profile Nipple 310 , 12 2.813 11,896'ELM 10,786' Note:Top of G5 perfs are 12'below Nipple. I 13 11,966'MD 10,855' 2.992 BOT Shear Sub/WLEG 11,929'ELM , 10,818' I ,. Perforation Details x 1_0.1_1 t Top Btm Top Btm a . - . m 11 Zone (MD) (MD) (ND) (ND) Amt spf Comments 12 I c-s G-5 11,916' 11,978' 8,912' 8,965' 62' 4 9/10/94 w/2-1/8"SilverJet,0 phase 13.11 11'916 G-5 11,934' 12,032' 8,927' 9,011' 98' 6 6/8/95 w/2-1/8"EnerJet,90 phase 12035' G-5 11,970' 12,000' 8,958' 8,984' 30' 6 2/23/94 w/2-1/8"Strip,45 phase .__.=?G6/110G-5 12,010' 12,035' 8,992' 9,014' 25' 6 2/23/94 w/2-1/8"Strip,45 phase ,� 7/1/84 w/2-1/8"BarKone II,o phase:7/4/92 w/2-1/8" H-1 G-6/HO 12,107' 12,117' 9,076' 9,084' 10' 8 silveriet H-2 H1 12,153' 12,163' 9,115' 9,124' 10' 4 7/1/84 w/2-1/8"BarKone II,0 phase to H2 12,182' 12,202' 9,140' 9,156' 20' 4 7/1/84 w/2-1/8"BarKone II,0 phase H-3/4 H2 12,198' 12,240' 9,154' 9,190' 42' 8 6/11/80 w/2-1/8"Enerjet:10/4/80 w/2-1/8"Enerjet • - 11-3 H2 12,200' 12,260' 9,156' 9,207' 60' 4 10/23/75 w/2"Hyperdome H-314 H2 12,200' 12,240' 9,156' 9,190' 40' 4 _ 3/27/79 w/2-1/8"Enerjet 73 H2 12,202' 12,242' 9,157' 9,191' 40' 1 7/1/84 w/2-1/8"BarKone II,0 phase Q) , iarsea on 1}43 07-H-4 H2 12,245' 12,260' 9,194' 9,207' 15' 4 9/10/94 w/2-1/8"SilverJet,0 phase +-,-� ru mi 12,478. C 2-r-. H-s 7/1/84 w/2-1/8"BarKone II,0 phase:9/10/94 w/2-1/8" QJ j k°�,,W„H.6 H3/4 12,285' 12,365' 9,228' 9,296' 80' 8 SilverJet E '...' =" H3/4 12,289' 12,349' 9,232' 9,283' 60' 4 3/26/79 w/2-1/8"EnerJet QJ '4 _H-6 H3/4 12,289' 12,352' 9,232' 9,285' 63' 8 6/11/80 w/2-1/8"EnerJet:10/4/80 W/2-1/8"EnerJet U 1D'12,840' PB I D=12,580' H3 12,290' 12,320' 9,233' 9,258' 30' 4 10/23/75 w/2"Hyperdome \lax Deviation=551° t,7100' H3 12,290' 12,310' 9,233' 9,250' 20' 4 7/4/92 w/2-1/8"SilverJet,0 phase .O. H3/4 12,330' 12,350' 9,267' 9,284' 20' 4 7/4/92 w/2-1/8"Silverlet,0 phase P L H4 12,375' 12,435' 9,305' 9,356' 60' 8 10/23/75 w/2"Hyperdome:3/25/79 w/2-1/8"EnerJet r 413' ( H4 12,376' 12,391' 9,306' 9,318' 15' 1 7/1/84 w/2-1/8"BarKone II,0 phase l 6G,✓ 1( ` H4 12,377' 12,437' 9,307' 9,357' 60' 8 6/11/80 w/2-1/8"Enerlet:10/4/80 W/2-1/8"EnerJet �l �7 01$1." H4 12,415' 12,435' 9,339' 9,356' 20' 6/20/78 w/DA 2"Guns 14 D H5 12,450' 12,491' 9,368' 9,403' 41' 8 1/27/75 w/DA 2"Slimhole:9/6/75 w/DA 2"Slimhole H5 12,450' 12,475' 9,368' 9,389' 25' 4 9/10/94 w/2-1/8"SilverJet,0 phase H5 12,475' 12,494' 9,389' 9,405' 19' 4 10/4/80 w/2-1/8"Enerlet H6 12,520' 12,545' 9,427' 9,448' 25' 8 1/24/75 w/DA 2"Slimhole:9/6/75 w/DA 2"Slimhole H6 12,606' 12,611' 9,499' 9,503' 5' 4 1/20/75 w/DA 4"Casing Gun-SQUEEZED OFF 1/21/75 Updated by JLL 08/03/16 0 • . liKing Salmon Platform K-1ORD Current 07/28/2014 I filrnrp:tbt.ka.1.1.1, King Salmon Tubing hanger,FMC-UH- K-10RD TC-1A-EN,13 5/8 5M X 4 A 24 X 13 3/8 X 9 5/8 X 4 1/2 IBT lift and susp,w/4"type IS BPV BHTA,B-11-A-0,4 1/16 5M FE R Valve,Swab,FMC-75, 011,40'-. 1f 4 1/16 5M FE,HWO,EE434 Valve,Wing,SSV, trim #,�1*� FMC-20,3 1/8 5M FE, ..�1:T.i.%. 13"Axelson oper, --- EE trim 0) \AN_ U � Valve,Master,FMC-75, ►1 6r. 4 1/16 5M FE,HWO,EE ;��� ,- it • trim leris.1-- Adapter,FMC-ASP,13 5/8 5M o ( API clamp X 4 1/16 5M,w/7" boI o � extended neck pocket \0 a 1=i► .i=1 1 1 Unihead,OCT type 3,13 5/8 5M API ' 1. I JJ �, hub top X 13 3/8 BTC casing bottom, 17 .1 � od. w/1-2 1/16 5M SSO on lower _, section,1-2 1/16 5M 550 on middle section,3-2 1/16 5M SSO on upper . section,IP internal lockpin assy ' ti� T All annular1SvalvesC20are l=I• Com' ::: 2 /16 M FM 1 C' 1 . Starting head,FMC, l- 21A2MX24' —± SOW, _ 1 i � 11 -- :- ' ' • w/1-3 1/8 2M EFO / \ 111.,, .11'I -, ,.j.. 124" 13 3/8" —I i4%95/8„ King Salmon Platform 2016 BOP Stack(Kuukpik) 06/22/2016 Mewl':Ilaeka.LU Rig Floor 16" Pipe I ■III'IiI'IlI. O 0 IU III Iii lii lii 111 lii 1�I 3'4' Shaffer 13 5/8 SM I fill rf i rffil ff Shaffer SI — 2 7/8.5.5 Variables 2.83' —1 ® _1 13 5/8 5M ,,...1111 '3_, Blind 2 1/16 5M i HCR valve 2 1/16 5M manual and HCR valve III in:': :4;o 176 ,lll . E1 I!1 I Ip r Shaffer1.44' 13 5 5 2 7/8-5.5 Variables •u 11 7-1l lIT til lel Drill deck 13.70' Riser 13 5/8 5M FE X 13 5/8 5M API hub ( ,� • • Choke Manifold Valves 2 " To Shaker 3" Panic To Gasbuster 3 1/8"1] 21/16"� � "I 0 2 1/16" a-•' II - f) (8 O 21/1 + 21/16" Z 3 1/8" H-,' ill 1/16" + 2 1/16" Manual Choke # Automatic Choke 2 1/16" Inlet Pressure Sensor 3" 5,000 PSI Choke Manifold Kuukpik Drilling Rig 5 RED = 3 1/18" 5,000 PSI VALVES AND LINES BLUE = 2 1/16" 5,000 PSI VALVES Kuukpik Drilling Rig 5 Choke Manifold C-2 #7 #11 #i0 • «3 #13 #1214 ......L b z8— #16 P al #2 .14. ilL Ci #1,5 _ Kuukpik Drilling Rig 5 Choke Manifold • E cd bA A • .9 vi of ei of °o • of• of 3 a 0ILi0iLdia 00101 O yi I l t l i w til i .7.i 1 1 1 it 1 al�1 al .1 I .� O N 91 Iyl i ..151 i A'! ';. 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NI !..9!P! i I 1 Si 1 1 1 I I I ►A III -...T) v I I I I I I I V" M N= A p,Ipi.rINiA mIr1Y,1 N N a .'N'N'N•I� N'N'N• U N 3 la I I I 12 1 1 1 4 I i i I% i i i N Ilr 4N N LIu y N _ ,Tr,- W J L J �_ _ a I I I 1 !1!1!1! 1 m0) .I•I•I�III� I1I °i J c ! �'' 1 1 1 1 1 1 1 1 1 N O :.-i21.61.ylyl21ail01dl 1 O LL W : • • Kuukpik 5 BOP Test Procedure ttaco.p Ai,Ake. Attachment#1 Attachment #1 Hilcorp Alaska LLC. Rolling BOP Test Procedure: Kuukpik 5 — Oil/Gas Producers, Water/Gas Injectors Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile & lift threads were deemed good, but still unable to get good tests 1) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Guy Schwartz (AOGCC-guy.schwartz@alaska.gov),Jim Regg (AOGCC-jim.regg@alaska.gov) and Michael Quick (AOGCC—Michael.quick@alaska.gov)via email explaining the wellhead situation prior to performing the rolling test. If on Federal land contact BLM representative Amanda Eagle (aeagle@blm.com) and Mutasim Elganzoory(melganzoory@blm.com). AOGCC and BLM may elect to send an inspector to witness.As outlined and approved in the sundry, proceed as follows: 2) With stack out of the test path, test choke manifold per standard procedure 3) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) Kill and choke line valve will also be tested during this time. 4) During these tests the test chart needs to be set to 60 min instead of 12 hours so chart shows a better graph. Need to station hands in cellar going over all connections on the BOPs looking for the slightest leak. Also need a man looking down the hole to confirm that the BOPS are not leaking. Test# 1=Annular, HCR Choke, and HCR Kill. Test#2=Upper Pipe Rams, HCR Choke, and HCR Kill. Test#3=Upper Pipe Rams, Manual Choke, and Manual Kill. Test#4=Lower Pipe Rams. 5) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. 6) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) 7) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 8) Pull hanger to surface. (Making tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid and sweep off any oil cap that may be present. 9) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE as per Kuukpik's standard test procedure. Or POOH laying down all the tubing and use the normal test plug to finish the tests that were not completed as per regulatory approval. • • . Kuukpik 5 BOP Test Procedure Hilcorp Alaska.Lit; Attachment#1 If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree and test. May have to tap out if scaled up or paraffined up if well is not dead may have to be done w/ pressure lubricator (diesel or acid could help) 2) If unsuccessful, or BPV profile is eroded and well is dead. Best practice is to have two barriers a. Fluid column b. Set wire line plug or tag fluid level with slick line to establish static fluid level or shoot fluid level with an echo meter gun. 3) Shoot off tubing very shallow( 300-500' most likely just under SSSV if applicable) 4) Spear hanger w/upside down cup provided by fishing company 5) Proceed to get best test we can achieve against cup and confirm no visual leaks on all flanges of BOPE 6) Notify Hilcorp Anchorage Operations Engineer and AOGCC of situation 7) Pull hanger and cut off stub 8) P/U test plug and set same. 9) Perform complete BOPE test as per Kuukpik's standard procedure . • • � o0 / :.-r. WC & O e c 2E 0oce / 2k ©\ a) «§ E -.- • . . . O � 2 = § 1lac R a < - 7 / ) CO m Y f �� - k �.§ 0- E k / ce) -0 e ■ Nrs_ 2 #CI 0 o ® 0.) / a) E/ 2J er as c @ o 0 £ Br. \ a Q) 1- 2 L O a. / U 14. CL o $ E£ & Y as \ § - CO ma k 20 2 C CD e E § ° 2 O 0 13 S .$ a Ea 2/ CD w O. \ k a) OS c § § b7 as .0)c c / . 2 Gp Co us > 2 CI 0 _ @ 2 § 0 2 ) 0oa ■ « / ) 0 . O. / o c0 E 0 a) 0 2 ■ o x u) .0) g 0 CO m . LC § m 0 2 0.I en S 7 2 it EL' ..CD ® _ . . 0 0 k ^ 2 $ U mC u o0 > .1 6 c C0 a) o / V @ m « # « a • ID Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon"or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work)the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. Ima~Project.Well History File Cove~ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Well History File' Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Diskettes, No. [] Other, No/Type -. [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other BY: BEVER[~~INCENT SHERYL MARIA WINDY Project Proofing BY: ~ROBIN VINCENT SHERYL MARIA WINDY Scanning Preparation )'" TOTAL PAGES BY: BEVERL~~/INCENT SHERYL MARIA WINDY · ~ Production Scanning / Stage 1 PAGE COUNT FROM SCANNED FILE: ~ O PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ['~ YES NO BEVERLY ROBIN VINCE~ARIA WINDY DATE/~/z~S/ IF NO IN STAGE t ~ PAGE(S) DISCREPANCIES WERE FOUND: .... YES NO ~OBIN VINCENT SHERYL MARIA WINDY DATE: BY: Stage 2 BY; (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: I$1 Quality Checked 12110102Rev3NOTScanned:wpd �.P: li//i/�� THE STATE Alaska 01'U' and Gas Ted Kramer QJ L GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 ..___. __.� ._...___"Fi�rc�•4fl7.2i 6.7542 Sr. Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pool, TBU K -LORD Sundry Number: 314-447 Dear Mr. Kramer: 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, Daniel T. Seamount, Jr. Commissioner DATED this 10 day of August, 2014 Encl. :► STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1 APPLICATION FOR SUNDRY APPROVALS 20 AAG 25,280 RF.DEIVED JUL 292014�,`I� 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑47k roved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate O , Pull Tubing E Time Extension ❑ Operations Shutdown ❑ Re-enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Convert to Infector 2. Operator Name: 4. Current Well Gass: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q ' Stratigraphic ❑ Service ❑ 174-047 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20167-01 , 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A, Will planned perforations require a spacing exception? Yes ❑ No Trading Bay Unit / K-10RD ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018777 • I McArthur River Field / Hemlock Oil & Middle Kenai G Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12,840' 9,696' 12,575' 9,473' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 4,998' 13-3/8" 4,998' 3,877' 3,090 psi 1,540 psi Intermediate 8,898' 9-5/8" 8,898' 6,439' 6,870 psi 4,760 psi Production Liner 4,308' 7" 12,840' 9,695' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 4-1/2" & 3-1/2" 12.6# N-80 & 9.2# N-80 8,476' & 8,476' -11,966 - Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker FH Packer & Camco TRB-6 SSSV 11,903' (MD) 8,901' (TVD) & 263' (MD) 263' (TVD) 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development ❑ Service El 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/15/2014 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ WI NJ 21 GINJ E]WAG ElAbandoned ElCommission 16. Verbal Approval: Date: Representative: GSTOR ElSPLUG El 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramer(&-hllcom.corn Printed Name Ted Kramer Title Sr. Operations Engineer G�Z_ Signature F Phone (907) 777-8420 Date 7/29/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission sothat a representative may witness Sundry Number: Plug Integrity El BOP Test 21 Mechanical Integrity Test Location Clearance ❑ Other: T Spacing Exception Required? Yes ❑ No LI Subsequent Form Required: 1 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ✓/ �J / v s i��Yn � Form 10-403 (Revised 10/20 ) Apprpvjd�p�c rrt�q�is�ir �2 months from_pe e date of approval. Submit Form and Attachments in Duplicate RSCMS AUG 18 20 1 Hilcorp Alaska, LLC Well Work Prognosis Well: K-10RD Application Date: 7/29/2014 Well Name: K-10RD API Number: 50-733-20167-01 Current Status: Oil Producer (SI) Leg: Leg #4 (NW corner), Slot #27 Estimated Start Date: September 15, 2014 Rig: Moncla Rig 404 Reg. Approval Req'd? 10-403 Date 10-403 submitted: 50-733-20167-00 Regulatory Contact: Juanita Lovett Permit to Drill Number: 174-047 First Call Engineer: Ted Kramer Office: (907) 777-8420 Cell: (985) 867-0665 Second Call Engineer: Dan Marlowe Office: (907) 283-1329 Cell: (907) 398-9904 Current Bottom Hole Pressure: 2,910 psi at 9,450' TVD Taken from a fluid level shot on 5/22/2014. Maximum Expected BHP: 2,910 psi @ 9,450' TVD Taken from a fluid level shot on 5/22/2014. Max. Anticipated Surface Pressure: 0 psi, Well will not flow based on an expected oil and water gradient of 0.437 psi/ft. Brief Well Summary: The K-10RD well is a Shut-in producer gas lifted producer. The work plan for this well involves performing the work necessary to convert this well to a water injector. Rig 404 will be placed on the well and a workover commenced to pull the existing completion and run an injection completion in the well. If for some reason the existing packer is difficult to pull, then we will cut and pull the tubing above the packer, and run a second packer with an overshot bowl to run over the existing tubing stub to repair casing to tubing integrity. AOR (Status of wells within % mile radius of infection zone): API WellNo Permit WellNumber Current Status Zonal Isolation (method) 150' of good cement above top perf @ 11,870' CBL 50-733-20167-00 169-002 K-10 abandoned 3/21/69 100' of good cement above top perf @ 11,916' CBL 50-733-20167-01 74-0047 K-10RD prod 1/24/75 Good cement from 101215- 10,345' 10,390-10,415' 50-733-20054-01 201-009 K-01RD2 prod 10,440-10,515' 1361 sx cement in 9 5/8" 50-733-20054-00 167-065 K-01 abandoned 12/8/67 Good cement from 121600- 50-733-20259-00 174-008 K-19 prod 11,910' CBL 5/30/74 Procedure: 1. MIRU Moncla 404 Pulling unit. 2. RU E -line unit, RIH with Tubing cutter to 11,850'(+/-) WLM. Cut tubing and POOH with E -line. 3. Circulate any hydrocarbon off the well to production. Insure well is static. 4. ND Wellhead, NU bop and test to 250 psi low / 2,500 psi high according to the attached BOP Test Procedure — Attachment #1 (Note: Notify AOGCC 24 hours prior to conducting BOP test to allow them the opportunity to witness). 5. POOH laying down Production String. ��vu� ��Q />U� W� � ��ao��ce�/ j �j,3 Weil O .� Can Cqv��. %' V''b � �uf �- l/ F ` 0 lU ' �^ Kr n'� y 14,s eil to ail '� cCfG3 701/�d I�^7P�0�� �CO✓P� �/i9 M 6 jo t, on, or l It t is e l d. e 0/11 Well Work Prognosis Well: K-10RD Hilmrp Alaska, LLC Application Date: 7/29/2014 6. PU RIH w/ over shot on 3-1/2" Workstring. Latch onto tubing stub and attempt to release Baker retrievable packer. If packer releases, go to step 13 (Completion Option # 1), otherwise, go to step #7. 7. Release off of packer and POH with work string. 8. PU outside cutter, RIH to TOF and engage and make cut at 11,860' (+/-). Pooh with production tubing and stuck fish inside of production tubing. 9. PU over shot, RIH to top of fish at 11,860' (+/-) and engage fish. ��. 10. RU E -line, RIH with Tubing cutter to 11,895' and make cut. POOH With production tubing. 11. PU RIH with RTTS type test PKR to 11,850'. Set Pkr. and pressure test casing to 1,500 psi. Chart same. POOH with test pkr. 12. PU up completion consisting of overshot bowl, nipple, injection packer, Polycore lined injection tubing. RIH with same and engage tubing stub with overshot bowel (Completion Option # 2). Run plug in seat nipple, pressure up and set hydraulics set injection packer. Go to step # 22. (l;6 -rc'2) 13. POOH with Same._ 14. PU 9-5/8" Casing Clean out assembly. RIH cleaning casing to the top of the 7" liner at 8,532'. POOH with same. 15. PU 7" casing clean out assembly. RIH cleaning out 7" 29# casing from 8,532 to PBTD @ 12,580'. Circ hole clean. POOH with clean out assembly. 16. RTTS packer, RIH to 11,580'. Set and pressure test casing to 1,500 psi. on chart for 30 min. POOH W/same. 17. RU Perforating Company. PU RIH with TCP perforating Guns as per latest Approved Perforation Request Form. 18. RU E -line and Run in tubing with GR, CCL and correlate TCP guns on depth. Fire Guns. 19. Pick up guns above perforations. Shut down (+/-) 1 hour monitoring well. ,LA .(a �Sa c Ps �Gjlt 20. Once the well is stable, POOH with TCP guns.�---� "I ` 21. MU RIH with injection packer on 4-1/2" Polycore lined injection tubing. Set packerr ae 11,552' 22. Hang off tubing. ND BOP, NU wellhead and test. 23. Turn Well over to production C. 24. RDMO Moncla 404 Pulling unit. Mf Tl - Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Current/ Proposed Wellhead Diagram 4. BOP Drawing l,✓.` ����Ss AE i -1►.q ALASKA DRILLING 1 ', 5 RKB =34.40' Max Deviation = 55.1° *, 7100' King Salmon Platform Trading Bay Unit Well K -LORD As Completed 01/27/75 Casing & Tubing Size T e Wt Grade Thrd ID Top Btm Hole Cmt Cmt To 24" Conductor Crossover, 4-1/2" x 3-1/2" C 11,903'MD 1 / 85TELM Surf 384' Driven D. 11,935'MD //,896'ELM 13-3/8" Surf Csg 61 K-55 11,966'MD /I 919'ELM 12.515 Surf 1511' G a s Surf DV Collar r e l I n f o r m a t i o n GLM #1 2795' 3.833" 7.031" x 5.625" 1511' 1514' 18" 655 sx 355 ft' returns 13-3/8" Surf Csg 61 K-55 7.031" x 5.625" 12.515 1514' 2500'± Calc @ 7.031" x 5.625" 2378' GLM #5 9254' 2.867" 5.390" x 4.155" 3-1/2" Camco KBMG w/ 1" valve & BK Latch GLM #6 9655' 2.867" 5.390" x 4.155" 16-1/2" 1300 sx (Calculated 13-3/8" Surf Csg 68 K-55 10,461' 12.415 2500'± 4998' GLM #9 10,834' 2.867" 5.390" x 4.155" 3-1/2" Carrico KBMG w/ 1" valve & BK Latch GLM #10 11,178' 2.867" .390" x 4.155" 3-1/2" Camco KBMG w/ I" valve & BK Latch GLM #11 11,519' 2.867" .390" x 4.155" w/20% WO GLM #12 11,864' 2.867" 5.390" x 4.155" N-80 & 8830'TOw 175sx 8435' CBL 9-5/8" Prod Csg 47 P 110 Butt 8.681 Surf gg30'-8898' 12-1/4" sqz perfs @ Bad 8455'-8755' 8805' Good 8755'-8788' 7" Liner 29 N-80 Sp Cl Butt 6.185 8532' 12,840' 8-1/2" 960 sxs 8964' +175sx lap sqz CBL Tubing 34.40' RKB to Tbg Hngr 12.6 N-80 Butt 3.958 Surf 8476' 9.2 N-80 Butt 2.992 1 8476' 1 11,966' - JEWELRY DETAIL NO. Depth ID OD Item A. 263' 2.813 5.917" Camco TRB-6 SSSV B. 8476' 2.992 Crossover, 4-1/2" x 3-1/2" C 11,903'MD 1 / 85TELM 3.00" 5.968" BOT 47 B2 Model ' FH" Retrievable Pkr w/ 30k shear ring D. 11,935'MD //,896'ELM 2'813 "X" Profile Nipple Note: To of GS erfs are 12' below Nipple. E 11,966'MD /I 919'ELM 2 992 BOT Shear Sub / WLEG G a s l i f t M a n d r e l I n f o r m a t i o n GLM #1 2795' 3.833" 7.031" x 5.625" 4-1/2" Cameo MMG w/ R20 valve & RK Latch GLM #2 5243' 3.833" 7.031" x 5.625" 4-1/2" Camco MMG w/ R20 valve & RK Latch GLM #3 7195' 3.833" 7.031" x 5.625" 4-1/2" Cameo MMG w/ R20 valve & RK Latch ell up GL GLM #4 8444' 3.833" 7.031" x 5.625" 4-1/2" Cameo MMG w/ R20 valve & RK Latch GLM #5 9254' 2.867" 5.390" x 4.155" 3-1/2" Camco KBMG w/ 1" valve & BK Latch GLM #6 9655' 2.867" 5.390" x 4.155" 3-1/2" Cameo KBMG w/ I" valve & BK Latch GLM #7 1 10,056' 2.867" .390" x 4.155" 3-1/2" Camco KBMG w/ I" valve & BK Latch GLM #8 10,461' 2.867" .390" x 4.155" 3-1/2" Camco KBMG w/ I" valve & BK Latch GLM #9 10,834' 2.867" 5.390" x 4.155" 3-1/2" Carrico KBMG w/ 1" valve & BK Latch GLM #10 11,178' 2.867" .390" x 4.155" 3-1/2" Camco KBMG w/ I" valve & BK Latch GLM #11 11,519' 2.867" .390" x 4.155" 3-1/2" Carrico KBMG w/ 1" valve & BK Latch GLM #12 11,864' 2.867" 5.390" x 4.155" 3-1/2" Camco KBMG w/ 1" valve & BK Latch Slickline/Fish/Fill Information: • 4/07/03 Found GLM # 12 pocket empty. Set new valve in same. possible GLV fish. • 12/13/07: 2.72" Gauge Ring to 12478' and tagged up. • Caliper Survey ran on 3/4/06 found no penetrations in tbg. Brief History & Info: • Spudded original K-10 on 1/13/69. TD @ 13,463' on 3/5/69. Completed & RR on 5/9/69. o Hole Section MWT: ■ 18" to 5025' 67 to 75 ppcft (9 to 10 ppg) ■ 12-1/4" to 10,663' 70 to 75 ppcft (9.4 to 10 ppg) o Approximate Rotating hrs: ■ 13-3/8" 270 hrs ■ 9-5/8" 180 hrs • WO 8/28/71 to 9/19/71 tbg CO. Recomplete G zone. • Redrill as K-IORD 11/1/74. TD @ 12,840' on 1/7/75. Completed & RR on 1/30/75 o Approximate Rotating hrs: ■ 9-5/8" 512 hrs K-IORD Schematic 1975-01-27 SLT Updated 2012-03-16 Page 1 of 2 REVISED: 3/16/2012 by TDF JALASKA 11 DRILLING 1 �3 King Salmon Platform Trading Bay Unit Well K -LORD As Completed 01/27/75 K-IORD Schematic 1975-01-27 SLT Updated 2012-03-16 Page 2 of 2 REVISED: 3/16/2012 by TDF PERFORATION HISTORY Zone Interval A=rn. Commnts Top Btm Amt spf G-5 11,916 11,978' 62' 4 9/10/94 w/ 2-1/8" SilverJet, 0 phase Cry 11,934' 12,032' 98' 6 6/8(95 W 2-1/6' EnerJet, 90 phase 2/23194 W 2-1/8" Strip, 45 phase Cry 11,970' 12,000' 30' 6 G-5 12,010' 12,036 25 6 2/23194 W 2-1/8" Strip, 45 phase G,6/H0 12,107' 12,117 10' 8 7/1/84 W 2-1/8" Baftrie II, o phase: 7/4/92 w/ 2-1/8" SilverJet H1 12,153 12,163 10' 4 7/1/84 W 2-1/9' BarKom II, 0 phase H2 12,182' 12,202' 20' 4 7/1/84 W 2-1/8" BarKone II, 0 phase H2 12,198' 12,240' 42' 8 6(11/80 W 2-1/8" Enerjet 10/4/80 w/ 2-1/8" Eneljet H2 12,200' 12,260' 60 4 10/23(75 w/ T FWerdorne H2 12,200' 12,240' 40 4 3(27/79 w/ 2-1/8" Enerjet H2 12,202' 12,242' 40 1 7/1/84 w/ 2-1/8" BarKone II, 0 phase H2 12,245 12,260' 15 4 9/10/94 W 2-1/8" SilverJet, 0 phase H3/4 12,286 12,366 80' 8 7/1/84 w/ 2-1/8" BarKone II, 0 phase: 9/10/94 W 2-1/8" SilverJet H314 12,289 12,349 60' 4 3/26x/9 w/ 2-1/8" EnerJet H3/4 12,289 12,352 63 8 6/11/80 w/ 2-1/8" EnerJet: 10/4/80 W/ 2-1/8" EnerJet H3 12,290' 12,320' 30 4 10/23(75 W T Hyperdorm H3 12,290' 12,310' 20 4 7/4/92 w/ 2-1/8" SilverJet, 0 phase H314 12,330' 12,350' 20 4 7/4/92 w/ 2-1/8" SilverJet, 0 phase H4 12,376 12,436 60' 8 10123175 w/ Z' Hy�e: 3(25(79 %V 2-1/9-i EnerJet H4 12,376 12,391' 15 1 7/1/84 w/ 2-1/8" Baftrie II, 0 phase H4 12,377 12,437 60' 8 6/11/80 w/ 2-1/8" EnerJet: 10/4/80 W/ 2-1/8" EnerJet H4 H5 H5 12,415' 12,435' 12,491' 12,475' 20' 41' 26 8 4 6/20/78 w/ DA 2" Guns 1/27/75 w/ DA 2" Slimhole: 9/6/75 w/ DA 2" Slimhole 9/10/94 w/ 2-1/8" SilverJet, 0 phase 12,450' 12,450' H5 12,476 12,494' 19 4 10/4/80 w/ 2-1/8" EnerJet 1/24/75 w/ DA 2" Slimhole: 9/6/75 w/ DA 2" Slin-hole 1/20/75 w/ DA 4" Casing Gun - SQUEEZED OFF 1/21/75 H6 H6 12,520' 12,545' 26 8 4 12,605 12,611' S K-IORD Schematic 1975-01-27 SLT Updated 2012-03-16 Page 2 of 2 REVISED: 3/16/2012 by TDF Hileorp Alaska, LLC RKB =34.40' Max Deviation = 55.1' 7100' PROPOSED -OPTION #1 Casing & Tubing King Salmon Platform Trading Bay Unit Well: K-10RD As Completed: 01/25/75 Size Type Wt Grade Thrd ID Top Btm Hole Cmt Cmt Top 24" Conductor I Surf 384' Driven ±11,532' WLEG 13-3/8" Surf Csg 61 K-55 12.5 Surf 1511' Surf 15 181, @, 655 sx 355 ft' returns DV Collar 1511' 1514' 13-3/8" Surf Csg 61 K-55 1514' 2500't 2378' 15.5 1�1 1300 sx (Calculated 13-3/8" Surf Csg 68 K-55 2500'± 4998' w/20% WO) 15'4 9-5/8" Prod Csg 47 N-80 & Butt 8.68 Surf 8830' Tow 12-1/4" 175sx sqz perfs @ 8435' CBL Bad 8455'-8755' P-110 1 8830,-8898, 8805' Good 8755'-8788' 7" Liner 29 N-80 Sp Cl Butt 6.18 8532' 12,840' 8-1/2" 960 sxs 8964' sqz CBL Tubing 34.40' RKB to Tbg Hngr 4-1/2" 12.6 L-80 TPL4040 3.40 Surf ±11,500' f Pol LinedI JEWELRY DETAIL NO. Depth ID OD Item 1 ±11,500' Nine Ener - Isolation Packer 2 ±11,531' "K" Profile Nipple 3 ±11,532' WLEG Brief History & Info: • Spudded original K-10 on 1/13/69. TD @ 13,463' on 3/5/69. Completed & RR on 5/9/69. o Hole Section MWT: ■ 18" to 5025' 67 to 75 ppcft (9 to 10 ppg) ■ 12-1/4" to 10,663' 70 to 75 ppcft (9.4 to 10 ppg) o Approximate Rotating hrs: ■ 13-3/8" 270 hrs • 9-5/8" 180 hrs • WO 8/28/71 to 9/19/71 tbg CO. Recomplete G zone. • Redrill as K -LORD 11/1/74. TD @ 12,840' on 1/7/75. Completed & RR on 1/30/75 o Approximate Rotating hrs: • 9-5/8" 512 hrs Updated: 07/22/14 by JILL Hilcorp Alaska, LLC PROPOSED -OPTION #1 Perforation Data King Salmon Platform Trading Bay Unit Well: K-10RD As Completed: 01/25/75 Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date G-1 ±11,602' ±11,614' ±8,645' ±8,655' ±12' Future G-1 ±11,625' ±11,644' ±8,664' ±8,680' ±19' Future G-1 ±11,662' ±11,669' ±8,696' ±8,702' ±7' Future G-2 ±11,704' ±11,721' ±8,731' ±8,746' ±17' Future G-4 ±11,774' ±11,870' ±8,791' ±8,873' ±96' Future G-5 11,916' 11,978' 8,912' 8,965' 62' 4 9/10/1994 G-5 ±11,921' ±11,959' ±8,916' ±8,949' ±38' Future G-5 11,934' 12,032' 8,927' 9,011' 98' 6 6/8/1995 G-5 ±11,970' ±11,997' ±8,958' ±8,981' ±27' Future G-5 11,970' 12,000' 8,958' 8,984' 30' 6 2/23/1994 G-5 12,010' 12,035' 8,992' 9,014' 25' 6 2/23/1994 G-5 ±12,012' ±12,033' ±8,994' ±9,012' ±21' Future G-6/HO 12,107' 12,117' 9,076' 9,084' 10' 8 7/1/1984 G-7 ±12,107' ±12,120' ±9,076' ±9,087' ±13' Future H1 12,153' 12,163' 9,115' 9,124' 10' 4 7/1/1984 H1 ±12,157' ±12,162' ±9,119' ±9,123' ±5' Future H2 12,182' 12,202' 9,140' 9,157' 20' 4 7/1/1984 H2 ±12,186' ±12,259' ±9,144' ±9,206' ±73' Future H2 12,198' 12,240' 9,154' 9,190' 42' 8 6/11/1980 H2 12,200' 12,260' 9,156' 9,207' 60' 4 10/23/1975 H2 12,200' 12,240' 9,156' 9,190' 40' 4 3/27/1979 H2 12,202' 12,242' 9,157' 9,191' 40' 1 7/1/1984 H2 12,245' 12,260' 9,194' 9,207' 15' 4 9/10/1994 H3/4 12,285' 12,365' 9,228' 9,296' 80' 8 7/1/1984 H3/4 12,289' 12,349' 9,232' 9,283' 60' 4 3/26/1979 H3/4 12,289' 12,352' 9,232' 9,285' 63' 8 6/11/1980 H3 12,290' 12,320' 9,233' 9,258' 30' 4 10/23/1975 H3 12,290' 12,310' 9,233' 9,250' 20' 4 7/4/1992 H3 ±12,290' ±12,338' ±9,233' ±9,273' ±48' Future H3/4 12,330' 12,350' 9,267' 9,284' 20' 4 7/4/1992 H4 ±12,343' ±12,389' ±9,278' ±9,317' ±46' Future H4 12,375' 12,435' 9,305' 9,356' 60' 8 10/23/1975 H4 12,376' 12,391' 9,306' 9,318' 15' 1 7/1/1984 H4 12,377' 12,437' 9,307' 9,357' 60' 8 6/11/1980 H4 ±12,398' ±12,435' ±9,324' ±9,356' ±37' Future H4 12,415' 12,435' 9,339' 9,356' 20' 6/20/1978 H5 12,450' 12,491' 9,368' 9,403' 41' 8 1/27/1975 H5 12,450' 12,475' 9,368' 9,389' 25' 4 9/10/1994 H5 ±12,453' ±12,494' ±9,371' ±9,405' ±41' Future H5 12,475' 12,494' 9,389' 9,405' 19' 4 10/4/1980 H6 12,520' 12,545' 9,427' 9,448' 25' 8 1/24/1975 H6 ±12,526' ±12,570' ±9,432' ±9,467' ±44' Future H6 12,606' 12,611' 9,499' 9,503' 5' 4 1/20/1975 Updated: 07/22/14 by 1LL King Salmon Platform PROPOSED - OPTION #2 Trading Bay Unit Well: K-10RD Hileorp Alaska, LLC As Completed: 01/25/75 Casing & Tubing RKB =34.40' G-5 0 11,916' G6/HO G-7 H-1 H-2 H-3/4 H-3 11-3/4 11-4 .' .' 4 i 11-6 rD= 12,840' PBTD= 12,580' Max Deviation = 55.1° (a, 7100' Size Type Wt Grade Third ID Top Btm Hole Cmt Cmt Top 24" Conductor Surf 384' Driven "X" Profile Nipple 5 13-3/8" Surf Csg 61 K-55 Surf 1511' Overshot Bowl 4 Surf 15 5.968" BOT 47 B2 Model "FH" Retrievable Pkr w/ 30K shear ring 5 18" 655 sx 355 ft' returns DV Collar 1511' 1514' 13-3/8" Surf Csg 61 K-55 5 1514' 2500'± 15 16-11/2' 2378 1300 sx (Calculated .120% Wo) 13-3/8" Surf Csg 68 K-55 4 2500'± 4998' 15 175sx 8435'CBL 9-5/8" Prod Csg 47 N-80 & Butt 8.68 Surf 8830' TOW 12-1/4" sqz perfs @ Bad 8455'-8755' P-110 1 8830'-8898' 88051 Good 8 755 8788'8' 7" Liner 29 N-80 Sp Cl Butt 6.18 8532' 12,840' 8-1/2" 960 sxs 8964' 5 +175sx lap sqz CBL Tubing 34.40' RKB to Tbg Hngr 12.6 H L- L- 80 TPL 4040 3.40 Surf Poly Lined 3-1/2" 9.2 1 N-80 I Butt 1 2.992 1 ±11,872' 1 11,966' JEW E L R Y D ETAI L NO. Depth ID OD Item 1 ±11,852' Nine Energy - Isolation Packer 2 ±11,862' "X" Profile Nipple 3 ±11,872' Overshot Bowl 4 11,903' 3.00" 5.968" BOT 47 B2 Model "FH" Retrievable Pkr w/ 30K shear ring 5 11,935' 2.813" 1 "X" Profile Nipple - Note: Top of G-5 perfs are 12' below nipple. 6 11,966' 2.992" 1 BOT Shear Sub / WLEG Brief History & Info: • Spudded original K-10 on 1/13/69. TO @ 13,463' on 3/5/69. Completed & RR on 5/9/69. o Hole Section WIT: • 18" to 5025' 67 to 75 ppcft (9 to 10 ppg) 12-1/4" to 10,663' 70 to 75 ppcft (9.4 to 10 ppg) o Approximate Rotating hrs: 13-3/8" 270 hrs 9-5/8" 180 hrs • WO 8/28/71 to 9/19/71 tbg CO. Recomplete G zone. • Redrill as K-10RD 11/1/74. TD @ 12,840' on 1/7/75. Completed & RR on 1/30/75 0 Approximate Rotating hrs: 9-5/8" 512 hrs Updated: 07/22/14 by JLL Ililcorp Alaska, LLC PROPOSED -OPTION #2 Perforation Data King Salmon Platform Trading Bay Unit Well: K-10RD As Completed: 01/25/75 Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date G-5 11,916' 11,978' 8,912' 8,965' 62' 4 9/10/1994 G-5 ±11,921' ±11,959' ±8,916' ±8,949' ±38' Future G-5 11,934' 12,032' 8,927' 9,011' 98' 6 6/8/1995 G-5 ±11,970' ±11,997' ±8,958' ±8,981' ±27' Future G-5 11,970' 12,000' 8,958' 8,984' 30' 6 2/23/1994 G-5 12,010' 12,035' 8,992' 9,014' 25' 6 2/23/1994 G-5 ±12,012' ±12,033' ±8,994' ±9,012' ±21' Future G-6/HO 12,107' 12,117' 9,076' 9,084' 10' 8 7/1/1984 G-7 ±12,107' ±12,120' ±9,076' ±9,087' ±13' Future H 1 12,153' 12,163' 9,115' 9,124' 10' 4 7/1/1984 H1 ±12,157' ±12,162' ±9,119' ±9,123' ±5' Future H2 12,182' 12,202' 9,140' 9,157' 20' 4 7/1/1984 H2 ±12,186' ±12,259' ±9,144' ±9,206' ±73' Future H2 12,198' 12,240' 9,154' 9,190' 42' 8 6/11/1980 H2 12,200' 12,260' 9,156' 9,207' 60' 4 10/23/1975 H2 12,200' 12,240' 9,156' 9,190' 40' 4 3/27/1979 H2 12,202' 12,242' 9,157' 9,191' 40' 1 7/1/1984 H2 12,245' 12,260' 9,194' 9,207' 15' 4 9/10/1994 H3/4 12,285' 12,365' 9,228' 9,296' 80' 8 7/1/1984 H3/4 12,289' 12,349' 9,232' 9,283' 60' 4 3/26/1979 H3/4 12,289' 12,352' 9,232' 9,285' 63' 8 6/11/1980 H3 12,290' 12,320' 9,233' 9,258' 30' 4 10/23/1975 H3 12,290' 12,310' 9,233' 9,250' 20' 4 7/4/1992 H3 ±12,290' ±12,338' ±9,233' ±9,273' ±48' Future H3/4 12,330' 12,350' 9,267' 9,284' 20' 4 7/4/1992 H4 ±12,343' ±12,389' ±9,278' ±9,317' ±46' Future H4 12,375' 12,435' 9,305' 9,356' 60' 8 10/23/1975 H4 12,376' 12,391' 9,306' 9,318' 15' 1 7/1/1984 H4 12,377' 12,437' 9,307' 9,357' 60' 8 6/11/1980 H4 ±12,398' ±12,435' ±9,324' ±9,356' ±37' Future H4 12,415' 12,435' 9,339' 9,356' 20' 6/20/1978 H5 12,450' 12,491' 9,368' 9,403' 41' 8 1/27/1975 H5 12,450' 12,475' 9,368' 9,389' 25' 4 9/10/1994 H5 ±12,453' ±12,494' ±9,371' ±9,405' ±41' Future H5 12,475' 12,494' 9,389' 9,405' 19' 4 10/4/1980 H6 12,520' 12,545' 9,427' 9,448' 25' 8 1/24/1975 H6 ±12,526' ±12,570' ±9,432' ±9,467' ±44' Future H6 12,606' 12,611' 9,499' 9,503' 5' 4 1/20/1975 Updated: 07/22/14 by JLL I H HiIM,rn Alnoka, U.0 King Salmon K-10RD 24X133/8X95/8X41/2 Valve, Swab, f 4 1/16 5M FE, trim Valve, Master, FI 4 1/16 5M FE, H� trim Unihead, OCT type 3, 13 5/8 5M API hub top X 13 3/8 BTC casing bottom, w/ 1- 2 1/16 5M SSO on lower section, 1- 21/16 51M SSO on middle section, 3- 2 1/16 SM SSO on upper section , IP internal lockpin asst' Starting head, FMC, 21 % 2M X 24" SOW, w/ 1- 3 1/8 2M EFO King Salmon Platform K -LORD Current 07/28/2014 Tubing hanger, FMC -UH - TC -1A -EN, 13 5/8 5M X 4 Y: IBT lift and susp, w/ 4" type IS BPV BHTA, B -11-A-0, 4 1/16 5M FE 5/8 SIM W/ 7" cket 411 annular valves are 2 1/16 5M FMC 20 I U HiLwmjr Ahtokn. LIA. King Salmon K -LORD 24 X 13 3/8 X 9 5/8 X 4 1/2 Valve, Swab, WI 4 1/16 5M FE, H' trim Valve, Master,WK 4 1/16 5M FE, HW trim Unihead, OCT type 3, 13 5/8 5M API hub top X 13 3/8 BTC casing bottom, w/ 1- 2 1/16 5M SSO on lower section, 1- 2 1/16 5M SSO on middle section, 3- 2 1/16 5M SSO on upper section , IP internal lockpin assy Starting head, FMC, 21 Y. 2M X 24" SOW, w/ 1- 3 1/8 2M EFO King Salmon Platform K -LORD Proposed 07/28/2014 Tubing hanger, FMC -UH - TC -IA -EN, 13 5/8 5M X 4 TC -2 lift and susp, w/ 4" type H BPV, Non cont control line port, 410 SS BHTA, Bowen, 4 1/16 5M FE X 7" SA Bowen top, FF trim SSV, 8 5M FE, r. FF trim ,/8 5M W/ 7" :et 411 annular valves are 2 1/16 5M FMC 20 HiLvvp Vnrks�. LL(, King Salmon Platform 2013 BOP Stack (Moncla) 09/19/2013 Hilrmp Alaska. H.0 Attachment #1 Moncla Rig 404 BOP Test Procedure Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, King Salmon WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2 -way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If BPV profile is eroded and/or corroded and BPV cannot be set with tree on, Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2 -way valve, or prepare lift -threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2 -way check valve by hand, or MU landing (test) joint to lift -threads d) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test, 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. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) Moncla Rig 404 BOP Test Procedure Hilrorp Alaska. LLC Attachment #1 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 wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests (i.e. Test Plug can be set in the Tubing -head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2 -way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C-1 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. d) Open C-1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves, to 250 psi low and 3,000 psi high, for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test, open same. Moncla Rig 404 BOP Test Procedure Hileorp Alaska, LLC Attachment #1 ii) Valves, 3, 4, 9. After test, open valves 3 & 4. Leave 9 closed. iii) Valves 5, 6, 9. After test, open valves 5 & 6, leave 9 closed. iv) Valves, 7, 8, 9. After test, open all valves. e) Close C-2. This is the HCR (the hydraulic controlled remote) valve just outside C-1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test, open HCR, close C-1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test K-1, K-2, and K-3 on the kill (pump -in) side by pressuring up on tubing. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW (or Lower Kelly Valve) and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be +/- 3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2"d set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre -charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/- 3,000 psi). Note: Make sure the electric pump is turned to "Auto", not "Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Moncla Rig 404 BOP Test Procedure Hilcorp Alaska, LLC Attachment #1 Diagram A-1: King Salmon BOP stack and Riser Arrangement — Typical for Single Completion 4 Hilcorp Alaska. LLC Diagram B: King Salmon Choke Manifold Moncla Rig 404 BOP Test Procedure Attachment #1 l~p From Bop Choke Line 2 1/16 5M Unibolt Flange Valve Type #1 National Ball Valve B3260, 3'/4" Ball port, 6000psi working pressure #2 National Ball Valve B3260, 3 '/4" Ball port, 6000psi working pressure #3 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #4 National Ball Valve 82650, 2 9/16" Ball port, 5000psi working pressure #5 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #6 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #7 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #8 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #9 National Ball Valve 83260, 3'/4" Ball port, 6000psi working pressure #10 National Ball Valve B1560, 1 '/2" Ball port, 6000psi working pressure Hileorp Alaska, LLC Moncla Rig 404 BOP Test Procedure Attachment #1 Hil¢orp Alaska, LLC Moncla Rig 404 BOP Test Procedure Attachment #1 Qg /JK V_ W z � J I C � U 1 s � � H Z J 7za Ol LIJ a z Q V j Vl Q I V z z 0 O H � � ---- o ao ¢QZU d < CD Q Q U M� O U L� :D W Z 0 0 0 m 0 Lj- d l- w w c = a Z) z Lz 1 'Q^ V z J D U U K-10RD Measured Distances Surface Location From: - Take from platform coordinates Top Middle Kenai G From - West Section Line 3357' - South Section Line 3990' Bottom Hole Location From - West Section Line 2840' - South Section Line 3853' Roby, David S (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Monday, August 04, 2014 2:S4 PM To: Roby, David S (DOA); Dan Marlowe Cc: Schwartz, Guy L (DOA); Bettis, Patricia K (DOA); Wallace, Chris D (DOA); Trudi Hallett; James Young Subject: RE: Sundry applications to convert wells TBU D-27 (PTD 175-024) and TBU K -LORD (PTD 174-047) to injectors Thanks Dave. We are looking into this and what is required. After we work through it here, I may be calling you for some clarification. Rest assured, we want to get it correct. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 From: Roby, David S (DOA) [mailto:dave.robyCa)alaska.gov] Sent: Monday, August 04, 2014 2:24 PM To: Ted Kramer; Dan Marlowe Cc: Schwartz, Guy L (DOA); Bettis, Patricia K (DOA); Wallace, Chris D (DOA) Subject: Sundry applications to convert wells TBU D-27 (PTD 175-024) and TBU K -LORD (PTD 174-047) to injectors Ted and Dan, Unless I am misreading your applications to convert the subject wells from long term shut in producers to injectors it appears that the wells will be setup for commingled injection into the Middle Kenai G and Hemlock Oil Pools. 20 AAC 25.215(c) prohibits commingled injection in a wellbore unless it has been authorized by order of the AOGCC. Therefore, in order to complete the wells as planned and conduct commingled injection you will need to apply for an order from the AOGCC, and such application is subject to public notice and hearing/comment. You can complete the proposed work, once the AOGCC approves your sundry applications that is, but would not be allowed to put the wells into commingled injection service until an order authorizing such is issued. If you have any questions on this matter please let me know. Regards, 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.robys`alaska.aov. ALA~I~k OIL A~D GAS CO~$1~RYATIO~ COMMISSIO~ January 31,2003 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dwight Johnson Cook Inlet Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99501 RE: No-Flow Well Status TBU Well K-10RD TBU Well K-25 PTD 174-O47 PTD 185-078 Dear Mr. Johnson: On December 30, 2002 AOGCC Petroleum Inspector Jeff Jones witnessed Safety Valve System (SVS) tests at UNOCAL's King Salmon Platform, Trading Bay Unit (TBU), McArthur River Field. The overall failure rate experienced was 16% (4 of 25 components). This performance requires that the SVS be re-tested in 90 days. The subsurface safety valves (SSSV) in wells K-10RD and K-25 failed the test and are of particular concern. Unocal personnel indicated the wells were considered "no-flow", however no records verifying authorization to remove the valves from service were provided. In addition, the Commission had no record that an Inspector had witnessed any "no-flow" test on these wells. Please explain why these wells were operating without operable SSSVs. Your response should be received by February 14, 2003. 20 AAC 25.265 (a) (2) requires that an offshore well capable of unassisted flow must be equipped with a fail-safe surface-controlled subsurface safety valve (SSSV). Removing or having an inoperative SSSV without prior authorization of the Commission is a violation of the regulation. Please provide the AOGCC a list of all offshore wells operating without SSSVs and the date of Commission approval by February 14, 2003. Inspector Jones subsequently witnessed "no-flow" tests on wells K-10RD and K-25 on January 20 - 21, 2003. No-flow tests are usually conducted at the Operator's request to seek approval to remove the sub-surface safety valve (SSSV). Over the course of the nearly 3 hour witnessed test periods, the performance of K-10RD (174-047) and K-25 (185-078) demonstrated that the wells are incapable of unassisted flow of hydrocarbons to the surface. During the observation periods, the wells produced Iow volumes of gas with less than 1 quad of liquids each. Based on these satisfactory test results, these wells need not be equipped with a commission approved fail-safe automatic surface-controlled subsurface safety valve. SCANNED FEB 0 4 2003 DwightJohnson Janua~ 31,2003 Page 2 0£2 However, these wells must continue to be equipped with fail-safe automatic surface safety valve ("SSV") and associated equipment capable of preventing uncontrolled flow, which must be maintained in proper working condition. If for any reason either of the wells becomes capable of unassisted flow of hydrocarbons, the SSSV must be returned to service. A copy of this letter should be maintained in the respective well files on board King Salmon. Please contact me at 793-1250 with any questions. Sincerely, Tom Maunder, PE ~ Sr. Petroleum Engineer SG/ NNED FEB 0 4 2003 MEMORANDUM TO: Mike Bill"~'~ Commissioner THRU: Tom Maunder ,~')~ ~ Petroleum Engineer~~ '~'[c~"'3'-~--""'% FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 21,2003 SUBJECT: No-Flow Test Unocal / King Salmon PLT Well K-10RD PTD:1740470 McArthur River Field / TBU January 21, 2003: I traveled to Unocal's King Salmon Platform to witness a No-Flow Test on well K-10RD in the McArthur River Field. Unocal representative Chuck Morse performed the test today in a safe and proficient manner. Well K-10RD was lined up from the wing valve through an Armor-Flow model # 3461-03T0 flow meter (180 SCFH to 1800 SCFH span) and a 1/2" hose terminating in an open top drum. The flow from the well was monitored for 3 hours with readings recorded every 30 minutes. Unassisted gas and liquid flow from the well did not exceed 900 SCF or 6.3 gals. hourly flow rate during the test. Well K-10RD meets the AOGCC requirements for a No-Flow status determination. Summary: I witnessed a successful No-Flow Test on Unocal's McArthur River Field well K-10RD on the King Salmon Platform in Cook Inlet, Attachments: Well completion schematic (1) CC; Dwight Johnson / Dave Condon (Unocal) Operator: Unocal Date 1/21/2003 Operator Rep: Chuck Morse AOGCC Rep: .left Jones Field/Unit/Pad MRF/TBU/Kin~ Salmon Well K-10RD PTD: 1740470 ~ Gas Liquid 10:00 AM 280 SCFH Gas Condensate droplets 10:30 AM 290 SCFH Gas Condensate droplets 11:00 AM 290 SCFH Gas Condensate droplets 11:30 AM 290 SCFH Gas Condensate droplets 12:00 PM 300 SCFH Gas Condensate droplets 12:30 PM 290 SCFH Gas Condensate droplets 1:00 PM 290 SCFH Gas Condensate droplets Produced to open top container through Armor-Flow meter model #3461-03T0. Flow meter calibrated by IISCO: 4/16/02 Total liquid produced: less than 1 quart. RJF 09/19/02 Page 1 of 1 NO-FLOW TBU King Salmon K-10RD 1-21-03 JJ.xls From: Jeff Jones 9077768850 To: Tom Maunder Date: 1/22/03 Time: 4:39:54 PM Page 3 of 3 Attach to file: NO-FLOW TBU King Salmon K-lORD 1-21-03 33.xls Unocal Corporation Oil & Gas Operations 909 West 9th Avenue, P.L~. D,~X 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOC. October 19, 1995 Alaska Mr. Russ Douglas, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Mr. Douglas: Re: King Salmon Platform Well K-10RD APl Number 50-733-20167-01 On June 8, 1995 the following intervals were reperforated in Well K-10RD: BENCH TOP (MD) BOTTOM (MD) FEET G5 11,934 12,032 98 TOTAL 98 Very truly yours, /... / Candace Williams Attachment OCT 2_ ~_, -~.~ Alaska 0il & Gas Cons, Commission Anchorage STATE OF ALASKA "-~" ALASKA OIL AND GAS CONSERVATION COIv,,.iSSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugg_~ Pull tubing m Afte'"'~ casing -- "~epair well 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE AK 99519 - 6247 5. Type of Well: Development Exploratory Stratigraphic Service Location of well at surface 727' FSL, 141' FEL, Sec. 17, T9N, R13W, SM At top of productive interval 1413' FNL, 2081' FEL, Sec. 19, T9N, R13W, SM At effective depth 12. At total depth 1515' FNL, 2424' FEL, Sec. 19, T9N, R13W, SM Present well condition summary Total depth: measured 12,822 true vertical 9,711 feet Plugs (measured) feet Perforate X Pull tubin~l Other 6. Datum elevation (DF or KB) 100' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number K-10RD 9. Permit number 74-0047-0 10. APl number 50-733-20167-01 11. Field/Pool McArthur River/Hemlock, G Effective depth: measured 12,575 feet Junk (measured) true vertical 9,503 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 4,998' 13-3/8" Yes 4,998' Intermediate 8,898' 9-5/8" Yes 8,898' 6,465' Production Liner 4,308' 7" Yes 8,532'-12,840' 6,205'-9,727' 13. 14. Perforation depth: measured 11934-12035; 12105-12115; 12153-12163; 12182-12260; 12285-12365; 12375-12437; 12450-12494; 12520-12545 true vertical 8958-9045; 9105-9114; 9147-9155; 9172-9238; 9259-9327; 9336-9388; 9399-9436; 9458-9478 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80 @ 8476' & 3-1/2" 9.2#, N-80 from 8476'-11966' Packers and SSSV (type and measured depth) Camco TRB-6 SSSV (~ 263', Baker FH packer (~ 11903' Stimulation or cement squeeze summary Intervals treated (measured) Gas Cons. Commission Anchorage Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Data Tubing Pressure Prior to well operation 6/8/95 260 158 871 1140 120 Subsequent to operation 6/15/95 250 14 998 1170 120 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oil X Gas Suspended Service 117'lherebycertifythatthef°re ' true, crrctt° ~best°fmykn°wledge'~ -~ LtAi Date {~ 'Z'~ Cl_~ Signed G. Russell Schmidt ~g~'~ 7~ ~ Drilling Manager SUBMIT IN DUP C E Form 10-404 Rev 06/15/88 Ralph P. Holman Engineer Technician Unocal P.O. Box 196247 Anchorage, Alaska 99519-6247 April 5, 1995 0Rt¢IN/ L Mr. Russ Douglas Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Douglas: ~L~' L~e'~ On September 10, 1994 the following intervals were perforated in well K-10RD (API 50-733-20167-01) in the McArthur River Field: BENCH TOP (MD) BOTTOM (MD) G5 11,916 11,978 62 H2 12,245 12,260 15 H3 & 4 12,285 12,365 80 H5 12,450 12,475 25 FEET TOTAL 182 Sincerely, Gas Cons. Oomm~io~ ~chom~ '~ ~-- STATE OF ALASKA -~ ALAS ~ OIL AND GAS CONSERVATION L VIMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing Alter casing Plugging __ Perforate X_ Repair well Pull tubing Other__ 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface Leg #4, Conductor #27, King platform 727' FSL, 141' FEL, T9N, R13W, SM At top of productive interval 1413' FNL, 2081' FEL, Sec. 19, T9N, R13W, SM At effective depth At total depth 1515' FNL, 2424' FEL, Sec. 19, T9N, R13W, SM 12. Present well condition summary Total depth: measured 12822 feet Plugs (measured) true vertical 9711 feet Effective depth: measured 12575 feet Junk (measured) true vertical 9503 feet 6. Datum elevation (DF or KB) KB: 100' 7. Unit or Property name Trading Bay Unit 8. Well number K-10RD feet 9. Permit number/approval number 74 -0047 -0 10. APl number 50-733-20167-01 11. Field/Pool McArthur River/Hemlock, G Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented Measured depth True vertical depth 4998' 13-3/8" Yes 4998' 3884' 8898' 9-5/8" Yes 8898' 6465' 4308' 7" Yes 8532'-12,840' 6205'-9727' 11916-12000,12010-12035,12105-12115,12153-12163,12182-12260, 12285-12365,12375-12437,12450-12494,12520-12545 true vertical 8936-9015, 9023-9045, 9105-9114, 9147-9155, 9172-9238, 9259-9327, 9336-9388, 9399-9436, 9458-9478 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80 @ 8476'; 3-1/2", 9.2#, N-80 from 8476'-11966' Packers and SSSV (type and measured depth) Camco TRB-6 SSSV @ 263', Baker FH pkr. @ 11903' 13. Stimulation or cement squeeze summary P, E6EIVED 14. Intervals treated (measured) Treatment description including volumes used and final pressure Representative Daily Average Production or I niection Data APR 2 0 199,5 Alaska Uil & Gas Cons. Anchora, ~ Prior to well operation Subsequent to operation OiI-Bbl 379 485 Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 99 1446 1140 100 143 1449 1140 150 15. Attachments Copies of Logs and Surveys run__ Daily Report of Well Operations __ 17. I hereby certify that the for. egoing is true a~nd LSigned .J(.'J'..[..~J~A~ ~~ Form 10-4~ Rev 06/15/~ 16. Status of well classification as: Oil X Gas Suspended __ ;orrect to the best of my knowledge. Service SUBMIT IN DUPLICATE Unocal North Americ;*~" Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region Ralph P. Holman Engineer Technician Unocal P.O. Box 196247 Anchorage, Alaska 99519-6247 August 16, 1994 Mr. Steve McMains Statistical Technician Alaska Oil & Gas COnservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 ORIGINAL Dear Mr. McMains: This is to inform you of Unoeal's intent, upon your approval, to perforate the following intervals in well K-10RD (A_PI # 50-733-20167-01) on the King platform. BENCH TOP (MD) BOTTOM (MD) FEET (35 11,916 11,978 62 HB2 12,245 12,260 15 HB3&4 12,285 12,365 80 HB5 12,450 12,475 25 TOTAL 182 Sincerely, oil & Gas Cons. c0mmissi0r~ Anchorage STATE OF ALASKA ALASKA L. AND GAS CONSERVATION COl ISSION APPLICA ION FOR SUNDRY APPROVALS 1. Type of request: Abandon __ Suspend __ Operations shutdown__ Re-enter suspended well__ Alter casing__ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate X_ Other 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. Location of well at surface Leg #4, Conductor #27 727' FSL, 141' FEL, T9N, R13W, Sec. 17, SM At top of productive interval At effective depth At total depth 5. Type of Well: Development X_ Exploratory __ Stmflgraphic __ R£¢£1V£D AUG 1 8 1994 0ii & Gas cons, commission Anch0r~ge 6. Datum elevation (DF or KB) KB: 100' 7. Unit or Property name Trading Bay Unit 8. Well number K-10RD 9. Permit number 74 -0047-0 10. APl number 50-733-20167-01 11. Field/Pool McArthur River/Hemlock feet 12. Present well condition summary Total depth: measured 12822 true vertical 9711 Effective depth: measured 12575 true vertical 9503 feet Plugs (measured) feet feet Junk (measured) feet Casing Length Structural Conductor Surface 4998' Intermediate 8898' Production Liner 4308' Perforation depth: measured true vertical Size Cemented Measured depth True vertical depth 13-3/8" Yes 4998' 3884' 9-5/8" Yes 8898' 6465' 7' Yes 8532'- 12840' 6205'-9727' 11970-12000, 12010-12035, 12105-12115, 12153-12163, 12182-12260, 12285-12365, 12375-12437, 12450-12494, 12520-12545, 9105-9114, 9147-9155, 9172-9238, 9259-9327, 9336-9388, 9399-9436, 9458-9478 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80 @ 8476' & 3-1/2", 9.2#, N-80 from 8476'-11966' Packers and SSSV (type and measured depth) Camco TRB-6 SSSV @ 263', Baker FH packer @ 11903' 13. Attachments Description summary of proposal m Detailed operations programX__ BOP sketch 14. Estimated date for commencing operation ~15. Status of well classification as: 16. If proposal was verbally approved Oil X_ Gas __ Name of approver Date approved Service Suspended~ 17. I hereb_y certify, that tl3p_foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Date ~,<~'- ~C~.~, (~' Conditions of approval: Notify Commission so representative may witness Plug Integrity _ BOP Test Location clearance Mechanical Integrity Testm S--'~bsequent form required 1'-~- ~c:) L~ Approved by the order of the Commission Original Signed By navid W. Johnston Commissioner Date '~/[~/~(--f, I SUBMIT Ih TRIPLICATE Form 10-403 Rev 06/15/88 Approved Copy Returned Unocal North America~ ~' Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region March 3, 1994 Mr. Steve McMains Statistical Technician Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. McMains: This is to inform you that on February 23, 1994 well K-10 on the King platform (API# 50-733-20167-01) was perforated in the following intervals: BENCH TOP-MD BOTTOM MD FEET G-5 11,970' 12,000' 30' G-5 12,010° 12,035' 25.__~' TOTAL: 55' Sincerel¥~ ~ Ralph P. Holman Engineer Technician RPH/rph -~'- STATE OF ALASKA -- ALASK/,, ,L AND GAS CONSERVATION CC ,IISSION REPORTOF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Pull tubing Alter casing__ 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. Location of well at surface 727' FSL, 141' FEL, Sec. 17 T9N, R13W, SM At top of productive interval 1413' FNL, 2081' FEL, Sec. 19, T9N, R13W, SM At effective depth At total depth 1515' FNL, 2424' FEL, Sec. 19, T9N, R13W, SM Stimulate __ Plugging __ Perforate X_ Repair well Pull tubing __ Other__ J5. Type of Well: Development X_ Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) KB' 100' 7. Unit or Property name Trading Bay Unit 8. Well number K-10RD ORIGIIVAL feet 9. Permit number/approval number 74 -0047-0 10. APl number 50-733-20167-01 11. Field/Pool McArthur River/Hemlock, G 12. Present well condition summary Total depth: measured true vertical 12,822 9711 feet Plugs (measured) feet Effective depth: measured 12,575 true vertical 9503 feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented Measured depth True vertical depth 4998' 13-3/8" Yes 4998' 3884' 8898' 9-5/8" Yes 8898' 6465' 4308' 7" Yes 8532'-12,840' 6205'-9727' 11970-12000,12010-12035,12105-12115,12153-12163,12182-12260,12285-12365, 12375-12437,12450-12494,12520-12545 truevertical 8989-9015,9023-9045,9105-9114,9147-9155,9172-9238, 9259-9327,9336-9388, 9399-9436,9458-9478, Tubing (size, grade, and measured depth) 4-1/2",12.6#,N-80@8476'& 3-1/2",9.2#,N-80from 8476'-11966' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Camco TRB-6 SSSV @ 263', Baker FH packer @ 11903' KI-LEIVEU Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 205 821 1080 Tubing Pressure 110 Subsequent to operation 477 1023 1080 110 15. Attachments Copies of Logs and Surveys run -- Daily Report of Well Operations X_ 16. Status of well classification as: Oil X_ Gas Suspended __ Service 17. I her~)y cer~fy that th.e f(~reg, oing is,,trj.{e and correct to the best of my knowledge. Signed . Title ~,~L~,,~. ~.,, ~ ~ C,.~ ~.~ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE STATE OF ALA~51<,A ALASK~"""L AND GAS CONSERVATION CO""~flSSION APPLIOA, ION FOR SUNDRY AF. OVALS 1. T~jpe of request: Abandon Suspend Operations shutdown Re-enter suspended well-- Alter casing Repair well Plugging Time extension Stimulate Change approved program Pull tubing Variance ~ Perforate X_ Other~ 2. Name of Operator Unocal 3. Address , P.O. Box 196247 Anchorage, Alaska 99519-6247 Location of well at surface Leg #4, Conductor #27 727' FSL, 141' FEL, T9N, R13W, Sec. 17, SM At top of productive interval At effective depth At total depth 5. Type of Well: Development X_ Exploratory Stmtigraphic __ RECEIVED 6. Datum elevation (DF or KB: 100' 7. Unit or Property name Trading Bay Unit 8. Well number K-10RD 9. Permit number 74 -0047 -0 10. APl number 50-733-20167-01 JAI'I 2 7 !994 Gas Cons. Commission Anchorage 11. Field/Pool McArthur River/Hemlock 12. Present well condition summary Total depth: measured 12822 true vertical 9711 Effective depth: measured 12575 true vertical 9503 Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical feet Plugs (measured) feet feet Junk (measured) feet Length Size Cemented Measured depth True vertical depth 4998' 13-3~" Yes 4998' 3884' 8898' 9-5/8' Yes 8898' 6465' 4308' 7" Yes 8532'-12840' 6205'-9727' 12105-12115,12153-12163,12182-12260,12285-12365,12375-12437,12450-12494, 12520-12545, 9105-9114,9147-9155,9172-9238,9259-9327,9336-9388,9399-9436,9458-9478 Tubing (size, grade, and measured depth) 4-1/2', 12.6#, N-80 @ 8476' & 3-1/2', 9.2#, N-80 from 8476'-11966' Packers and SSSV (type and measured depth) Camco TRB-6 SSSV @ 263', Baker FH packer @ 11903' 13. Attachments Description summary of proposal __ Detailed operations prograrr~__ BOP sketch __ 14. Estimated date for commencing operation ~15. February 2, 1994 16. If proposal was verbally approved Oil X__ Gas _ Name of approver Date approved Service 17. l he~'~lpy/CPrtffy,l?~j~the~o~go~ue and correct to .the best of my knowledge. FOR COMMISSION USE ONLY Status of well classirg:ation as: Suspended__ Conditions of approval: Notify Commission so representative may witness Plug Integrity _ BOP Test Location clearance Mechanical Integrity Test_ S--~bsequent form required 1--~- Approved by the order of the Commission Original Signe¢ 8y David W. Johnston [Approval. NO. ~,...~ Approved Copy Returned _ ,?.-r-~¥ _ Commissioner Date Y Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE January 26, 1994 Kine, Well K-10RD perforatin.a procedure 1. Hold safety meeting. 2. RU electric line unit. 3. Pressure test lubricator to 2500 psi for five minutes. 4. Shut down all welding and radio transmissions. 5. RIH and perforate intervals as instructed by Unocal (When gun is 200' below surface, welding and radio transmissions may resume.) 6. POOH. (When gun is 200' below surface, shut down all welding and radio transmissions.) 7. Repeat steps 5,6 and 7 as needed to perforate the following intervals: NOTE: A pump-in sub must be installed on lubricator. BENCH MEASURED TOTAL FEET G-5 11,970'-12,000' 30' G-5 12,010'-12,035' 25' TOTAL: 55' RECEIVED ,J A N '~ ~ -~. 7 i994 \ .,.(' /'", ~.,~, ;!,., Vii & 6as 0OHS. 6omrllission Anchora¢,s STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown ~ Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator UNOCAL Corporation (_ARCO Alaska. Inc. is sub-oDerator) 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory __ Stratigraphic Service ,, ,,, 4. Location of well at surface Leg #4, Cond. #27, 727' N & 141' W f/SE corner,Sec. 17, TgN, R13W, SM At top of productive interval 1121' S, 2047' W f/NE Comer, Sec. 17, TgN, R13W, SlVl At effective depth At total depth 1206' S~ 2427' W f/NE Comer~ Sec. 17~ TgN~ R13W~ SM 6. Datum elevation (DF or KB) RKB 100' Unit or Property name Trading Bay Unit feet 8. Well number K-10RD . 9. Permit number/approval number 10. APl number 50-733-20167-01 11. Field/Pool IvlcArthur River Hemlock 1 Z. Present well condition summary Total Depth: measured true vertical 12822' feet 9739' feet Plugs (measured) None Effective depth: measured 12575' feet Junk (measured) true vertical 9524' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 284' 24" Pile Driven 384' 384' Surface 4960' 13-3/8" 2255 sx Class G 4998' 3899' Intermediate Production 8860' 9-5/8" 700 sx Class G 8830' 6485' Liner 4308' 7" 960 sx Class G 8532'-12840' 6210'- 971 5' 13. Perforation depth: measured See attached well schematic Reperfed: 12105'-12115'~ 12288'-12308'~ 12328'-12348' (4 SPF~) true vertical See Attached well schematic Reperfed: 9135'-9143', 9291'-9308', 9325'-9342' Tubing (size, grade, and measured depth) 4-1/2", 12.6#/ft, N-80 @ 8476' MD; 3-1/2", 9.2#/ft, N-80 from 8476' - 11966' I~D Packers and SSSV (type and measured depth) RECEIVED Baker HYD FH packer @ 11 903' IvlD~ Camco SSSV TRB-6 @ 263' MD Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure N/A SE P 2 1 1992 Alaska Oil & Gas Cons. C0mmissi( Anchorage 14. Prior to well operation Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 202 331 819 1130 Tubing Pressure 80 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 299 300 1060 1130 110 16. Status of well classification as: Oil X Gas Suspended Service ___ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .C~-~ ~-~. ~[v~ Title F~m 10- Ee~15/80 Date ~ / I(~/~J P-... SUBMIT IN DUPLICATE ARCO Alaska, Inc. Trau,ng Bay Unit - King Salmon Pla,.urm Well K- 10RD AP1#:783-20167-O1 Spud Date: 11-16-74 Completion Dale: 1/23/75 Original RKB: 100' MD Hanger Type: OTC 12"X4-1/2" UH-K-1A-EN Top of Hemlock: 12107' Max Hole Angle: 54 deg @ 7200' MD Annulus Fluid:Sea water Last Revised: 06-23-92 All Depths are RKB MD to Top of Equipment. Well Type: Producer New J~J Wor. kover r'"J RKB to~--langer: 35' Angle at Perforations: 32° Reason: G R Data update Jewelry 1 263' 2 8476' 3 11903' 4 11935' 5 11966' Camco SSSV TRB-6 X-over 4-1/2" x 3-1/2" BTC Baker hydrostatic FH Otis 'X* 2.75" ID Baker shearsub tubing tail Casing and Tubing Size Weiaht Grade 13-3/8" 61# J-55 9-5/8" 47# N-80 BTC 7" 29# N-80 BTC 4-1/2" 12.6~ N-80 BTC 3-1/2" 9.2# N-80 BTC Gas Lift Information Depth Stn. TVD MandreJ 2795' 1 2329' Camco 5243' 2 4062' Camco 7195' 3 5365' Camco 84.4.4' 4 6148' Camco 9254' 5 6740' Camco 9655' 6 7060 Camco 10056' 7 7387' Camco 10461' 8 7718' Camco 10834' 9 8031' Camco 11178' 10 8319' Camco 11519' 11 8606' Camco 11864' 12 8902' Camco Perforation Data -DIL depths Zone Too-MD/SS Perf Interval FT SPF 0 12105'/9035' 12105-12115' 8 8 1 12143"/9067' 12153-12163' 10 8 2 12179'/9098' 12182-12260' 78 20 3 12285'/9188' 12285.12365' 80 24 4 12375'/9268' 12375-12437'62 24 5 12450'/9303" 12450-12494"44 18 6 12510'/9378' 12520-12545'25 18 12606-12611' 5 sqzd 7 Not peffed PBTD =12575' MD TD = 12822' MD Datum: 12357' MD (9250' SS, 9350 'A/D) 12495' MD (9350' SS, 9450' TVD) ToD Bottom Description 38' 4998' Casing 38" 8898' Window 8830'-8898" 8532' 12840' Uner 38' 8476' Tubing 8476" 11966' Tubing Size Tvoe Valve PortSz TRO PSC 4-1/2" MMG R-20 1/4 1180 1176 4-1/2" MMG R-20 1/4 1180 1142 4-1/2" MMG R-20 5/16 1220 1106 4-1/2" MMG R-20 5/16 1215 1081 3-1/2" KBMG BK 5/16 1205 1060 3-1/2" KBMG BK 5/16 1430 1039 3-1/2" KBMG BK 5/16 1420 1025 3-1/2" KBMG BK 5/16 1410 1010 3-1/2" KBMG BK 5/16 1400 996 3-1/2" KBMG BK 5/16 13gO 983 3-1/2" KBMG BK 5/16 1380 968 3-1/2" KBMG BK 5/16 orifice- Gauge Ring and Fill Level Data Date Size Depth Comments 1-23-75 2.75" 12575' PBTD after W/O 3-28-86 2.6" 12456' MD tagged fill 3-30-86 E-line 12511' ELM tagged fill 9-12-88 2.70" 12488' WLM tagged fill 1-8-90 2.70" 12168' WLM tagged fill 5-11-92 2.50" 12478' WLM tagged fill RECEIVED S E P ?_ 1 1992 Alaska Oil & Gas Cons. Commission Anchorage JLB 9/2/92 ,ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL IPBDT ~ -RAni'OR WELL SERVICE REPORT t 0(~55 0 ?0o 6'70[ 0%0 1/ /~1o Weather ReDort CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ! Alaska Oii & Gas Cons. ~ornmisslon ~.m. ]Slgn~,// ~,. ~..~ Anchorage REMARKS CONTINUED: DESCRIPTION DAILY ACCUM. TOTAL CAMCO OTIS ,. SCHLUMBERGER DRESSER-ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel Methanol Supervision Pre-Job Safety Meeting AFE AJaska Oil & Gas Cons~ gnnhnrag~ TOTAL FIELD ESTIMATE , ,, ,ARCO Alaska, Inc. ./ .... WELL SERVICE REPORT Subsidiary of Atlantic Richfield Company WELL REMARKS · IOPERATI<N~ AT REPORT TIME /o GO t ~/47 /.5-/o /~ ~o /~ ~o /¢o-<- ~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather I Temp. I Chill Factor l Visibility I Wind Vel. I Signed REMARKS CONTINUED: /' z~_~ ~,,vn -~ 0 ~5 . ~1~ ,~&~ n~ : ~,,'~4 _~.~~ d,~.- .~,,~ ~~ ) ~/I. , /~/:~ r~0 ~r~J 1o~/,~~ ~/~ '~r~, ~~;~ re~J~/,~q r~k ~ ~. /Sao DESCRIPTION DAILY ACCUM. TOTAL CAMCO OTIS SCHLUMBERGER DRESSER-ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel Methanol Supervision r~m Pre-Job Safety Meeting AFE SEP 2'" i992 / TOTAL FIELD ESTIMATE IISigned JUL 0~ '~ ~:~ UMUCNL NNCH UnoGai North Amerf(;an Oil & Gas Divi.ion Uno~al Corporation P,O, Box ] 90247 Ancl~orage, Alaska 99519-0247 Telephone (907) 276-7600 fer Fax Co~ln~ation Facsimile (SO7) 283-7884 UNOCAL Alaska Region PLEASE DELIVER THIS INFORMATION TO: Name: At the request of: [S4eder'~/ame], /~,__ pages (including this cover sheet), please call (907) 276-7600 and if you do not receive ask for: JUL o 2 1992 0il & 6as Cons. Commission Anchorage RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CON~RVATI~ CADMMISSiON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon_ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well_ Plugging _ Time extension _ Stimulate _ 2. Name of Operator UNOCAL Corporation (^R(~O Alaska. Inc. is sub-oDerator) 3. Address Change approved program _ Pull tubing _ 5. Type of Well: Development X Exploratory _ I Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Service _ 4. Location of well at surface Leg #4,Cond.#27, 727' N & 141' W f/SE corner Sec. 17, TgN, R13W SM Variance _ Perforate X Other _ 6. Datum elevation (DF or KB) RKB 100' 7. Unit or Property name Trading Bay Unit feet 8. Well number i<;-10RD At top of productive interval 1121' S & 2047' W f/ NE Corner Sec. 17, TgN, R13W SM At effective depth At total depth 1206' S & 2427' W f/ NE Comer Sec. 17, TgN, R13W SM 12. Present well condition summary Total Depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Uner Perforation depth: 12822 feet Plugs (measured) true vertical 9739 feet measured 12575 feet Junk (measured) true vertical 95 24 feet Length Size Cemented 284' 24" Pile Driven 4960' 1 3-3/8" 2255 sx Cl G g. Permit number 10. APl number S0-733-20167-01 11. Field/Pool McA rt h u r ~:liFa [,.,(I;[e,rrtl o,c I~ , Kt:,L !: I V, L) J U L - Alaska 0il & Gas Cons. Commission Measured depth/~le0r~e~cal depth 384' 384' 4998' 3899' 8860' 9-5/8" 700 sx Cl G 8830' 6485' 4308' 7" 960 sx CIG 8532'-12840' 6210'-9715' measured Current: See Attached Well Schematic Proposed= 12107'-12117', 12290'-12310', 12330'-12350' true vertical Current: See Attached Well Schematic Proposed: 9136'-9146', 9296'-9316', 9327'-9347' Tubing (size, grade, and measured depth 4-1/2", 12.6#/ft, N-80 @ 8476' MD; 3-1/2", 9.2#/ft, N-80 from 8476'- 11966' MD Packers and SSSV (type and measured depth) Baker HYD FH packer ~ 11903' MD, Camco SSSV TRB-6 ~ 263' MD 13. Attachments Description summary of proposal _ 14. Estimated date for commencing operation July, 1992 16. If proposal was verbally approved Name of approver Date approved Detailed operation program X BOP sketch 15. Status of well classification as: Oil X Gas _ Service _ Suspended 17. I hereby, certify that the foregoing is true and correct to the best of my knowledge. Signed('~ ~_-~C~-_~-,~, ~. (~ ~-~-~ FO~ Title COMI~ISSlON ~e_c~ ~ ~-<~. USE"'~ T-~%. ONLY ~--k ~-. ~ Date Conditions of ~t3proval: Notify Commission so representative may witness IApprovai.blo. Plug integrity_ BOP Test__ Location clearance m Mechanical Integrity Test Subsequent form require 10- Ho~ -~pproved CluF, y -- Returned Original Signed By - Approved by the order of the Commission David W, Johnston Commissioner Date '7 Form 10-403 Rev 5/03189 SUBMIT KING SALMON PLATFORM PERFORATING PROCEDURE WELLS K-10RD, K-21RDL, K-23 June 9, 1992 OBJECTIVE The purpose of this work is to increase the oil production rate and decrease the rate decline in wells K-10RD, K-21RDL, and K-23 by selectively re-perforating Hemlock intervals. 2-1/8" strip guns with 4 SPF and zero-degree phasing axe recommended. A list of equivalent peff guns from the various service companies is attached. WELL STATUS The current status, perforating depths, tubing restrictions, and gauge ring data are presented for each well on the accompanying Well Data Sheets. Individual well schematics are also attached. PROCEDURE 1. Obtain a representative 12-hour well test prior to perforating. 2. Conduct a safety meeting with all appropriate personnel. Obtain a diagram of the tool string prior to commencing E-line operations. e Rig-up E-line unit and lubricator. Make-up tool string of adequate weight bars, perforating guns, decentralizer and CCD Turn off platform radios, phones and elecmc welders and make the proper announcements before arming guns. These may be returned to service after the tool string is 500 feet below the wellhead. 4. Pressure test lubricator to 2500 psi. . RIH with well shut-m, and fie into CBL or CET as referenced in the Well Data Sheet Position gun below interval to be perforated. . Route well to test and/or swab separator. Unload well and produce for at least thirty minutes to establish adequate drawdown. e Raise gun to proper depth and fn~. Allow well to flow for 10 minutes to clean-up perforations. e Shut-off injection gas, close wing valve, and POOH. Turn off platform radios, phones and electric welders and make the proper announcements before reaching the SSSV. Cheek gun and record depths of any misfires. Repeat the gun mn if necessary. 9. Repeat steps 5 through 8 for the gun runs listed on the Well Data Sheets. NOTE: Well K-21RDL will be perforated in stages, with an intermediate 12 hour well test following the perforation of Bench 7. Benches 5 and 6 should not be repefforated until an ARCO engineer has had time to review the well tests results. 10. 11. 12. NOTE: Well K-23 will also be perforated in stages, with an intermediate 12 hour well test following the reperforation of Bench 3. Bench 1 should not be reperforated until an ARCO engineer has had time to review the well tests results. Rig-down electric line unit~ Rem well to production and obtain a stabilized 12-hour well test. Repeat steps 1 through 11 for ail wells. Murray O. Hamilton Cook Inlet Engineering Endorsed By~ WELL DATA ~HEET WELL K-10RD Ob_~e~tiv~ The purpose of this work is to increase oil production rate and decrease production decline by re- perforating Hemlock Benches 0 and 3. Status Well K-10RD is currently perforated in Benches i-6, with Bench 6 under fill. On 5/12/92 this well tested at 251 BOPD/1164 BFPD at 78.4% watercut and 2.3 MMSCFD lift gas. This well is not on the scale inhibition treatment program and does not show evidence of scale build-up. In recent months K-t0RD has shown steeper than usual decline in total fluid rate and oil ram. Near wellbore damage due to scale buildup or fines migration are possible causes. The latest PBU obtained on 4/12/89 showed a skin value of +4. The most recent stimulation work occurred on 7/1/84 and included the reperforation of Benches 2-4 and the addition of new perforations in Benches 0 and 1. This work resulted in an initial oil rate increase of approximately 100 BOPD. Perforation Data Tie-in Log: 1/14/74 Dresser Atlas CBL (CBL is 2' off depth with DIL; CBL = DIL - 2') Run No, Bench Interval (MD-t~BL) Interval (MD-DIL) Length SPF I 3 12328-12348 12330-12350 20 4 2 3 12288-12308 12290-12310 20 4 3 0 12105-12115 12107-12117 10 4 50' Gauge Ring Data: (5/11/92) 2.50" gauge ring tagged fill @ 12,478' WLM (12,513' MD) Minimum Tbg Restriction: Otis "X" nipple (ID = 2.750") @ 11,935' MD RECEIVED d U L - 1992 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, inc. Trading Bay Unit - King Salmon Well K- 10RD APhlk733-20167-01 Spud Dote: 11-1~74 Completion Dote: 1/23/75 Original RKB:100' MD Hedger Type: OTC 12'X4-1/2' UH-K-1A-EN Top of Hemlock: 12107' Max Hole Angle: 54 deg 13 7200" MD Annulus Fluid:Sea water Last Revised: 01-17-g0 All Depths are RKB MD to Top of Equipment. Well Type: Producer New (3q WorkOver E! RKB to~-langm: 3,5' Angle at Reason: Gauge Ring Data Jewelry 1 263' 2 8476' 3 11903' 4 11936' 5 11966' Cameo SSSV TRB-6 X-over 4-1/2' x 3-1/2' BTC Baker hydrostatic FH Oils 3(' 2.75' ID Baker shearsub tubing toll Ca, rig and Tubing 33-3/8" 6]~ J-55 38' 4998' 9-5/8' 47~ N-80 BTC 38" 8898' 7" 29~ N-80 BTC &532" 12840' 4-1t2' 12.6~ N-80 BTC 38' 8476' 3-1/2' 92~ N-80 BTC 8476' 11966' Casing Window 8830'-8898" Uner Tubing Tubing 2795' 1 2329 5243' 2 4062' 7195' 3 5365' 8444' 4 6148' 9254' 5 6740' 9666' 6 70g3 1__m6~__'7 7387' 10461' 8 7718' 10834~ 9 81331' 11178' 10 8319' 11519' 11 8606' 111~4' 12 ~ ~ W Type Valve Po~z Camco 4-1/2' MMG R-20 1/4 Camco 4-1/2' MMG R-20 1/4 Camco 4-1/2" MMG R-20 5/16 Camco 4-1/2" MMG R-20 5/16 Camco 3-112" KBMG BK 5116 Camco 3-112" KBMG BK 5116 Camco 3-1/2' KBMG BK 5116 Camco 3-112" KBMG BK 5116 Camco 3-112' KBMG BK 5116 Camco 3-1/2' KBMG BK 5116 Camco 3-1/2" KBMG BK 5/16 Camco 3-1/2" KBMG BK 5/16 1180 1176 1180 1142 1220 1105 1215 1081 12~ 10~ 1430 1039 1433 la25 1410 1010 orifice - ~ Dala - DIL depltm Zone 'Zsa~J.~. EtzLla~l]~ Fr ~!~ 0 12107'/9010' 121~-12115' 8 4 1 12143'/9041' 121,53-12163' 10 4 2 12179/9073' 12182-12260' 78 - 3 12286'/9165' 12285-12365' 83 - 4 1238gl9245' 12375-12437 ~Q - 5 12450'/~' 12450-12494 44 - 6 12510'/9356' 12520-1~ 25 - 12606-12611" 5 sqzd 7 Not perfed 1-23-75 2.75" 3-28-86 2.6' 3-30-86 E-line 9-12-88 2.70" 1-8-~0 2.70" · 12575' PBTD after W/O 12456' MD tagged ffi 1251¥ ELM tagged ffi 12488' WLM tagged 12168" WLM tagged PB1D =12575' MD TD = 12822' MD Dart,m: 12357' MD (9250' SS, 9350' 1VD) 12495' MD (9350' SS, 945(Y TVD) Unocat No~ttt Amef Oil & Gas Division UnocAl Corporation P.O. :3ox 190247 Anchorage. AlasKa 99519-0247 Teiepnone tg0,") 275-7600 AlasKa Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: .~ .. I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, G . Regional Drilling Manager GSB/lew KING SALMON PLATFORM FROM SE CORNER SEC. 17, TgN, R13W CONDUCTOR "Y" COOR. , "X" COOR. WELL #' LEG ~l: LEG #2' 9 l0 ll 12 13 14 15 16 _~G #3 17 18 19 20 21 22 23 24 Leg ~4' 25 26 27 28 29 3O 31 32 2,511,762 2,511,761 2,511,764 2,511,768 2,511,772 2,511,773 2,511,770 2,511,766 2,511,690 2,511,686 2,511,684 2,511,687 2,511,691 2,511,695 2,511,696 2,511,694 2,511,689 2,511,723 2,511,721 2,511,724 2,511,728 2,511,732 2,511,733 2,511,731 2,511,726 2,511,799 2,511,798 2,511,801 2,511,805 2,511,809 2,511,810 2,511,807 2,511,803 213,819 K-21 & RD 213,815 K-30 213,811 K-18 213,810 K-17 213,812 K-23 (23-19) 213,817 K-19 213,821 K-22 & RD 213,822 K-20 213,768 213,772 K-15 & RD 213,768 K-9 213,763 K-4 & RD 213,762 K-11 213,765 K-13 & RD 213,769 K-2 & RD 21 3,776 K-7 & RD 213,774 K-5 213,712 213,708 213,703 213,702 213,705 213,709 213,713 213,714 213,760 213,756 213,752 213,751 213,753 213,758 213,762 213,763 K-8 K-1 &RD K-lO &' RD K-16 K-12 & RD K-6 & 24 K-3 & RD FNL 688 687 690 694 698 699 696 692 611 610 613 617 621 622 619 615 725 724 727 731 735 736 729 FWL 74 78 82 83 81 76 72 71 121 126 130 131 128 124 120 ll9 133 135 141 142 140 135 130 .... -'- STATE OF ALASKA '-- ALASK 3,.-AND GAS CONSERVATION ,~..¢IlSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA 7. Permit No. 3. Address 8. APl Number PO BOX 6247, Anchorage, Alaska 99502 50- 755-20167-01 4. Location of Well Surface: 727' FSL, 141' FEL,T9N,R13W, SEC 17, SM King Salmon Platform, Cook Inlet 6. Lease Designation and Serial No. 5. Elevation in feet (indicate KB, DF, etc.) KB 100ft. 9. Unit or Lease Name Tr~din~ Bay Unit 10. Well Number E-10RD 11. Field and Pool McArthur River Field Hemlock Pool 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). The following Hemlock intervals were perforaCed on July 1,1984: Bench 0 Bench 1 Bench 2 Bench 3 Bench 4 12110-12118 ft. D1L ]2156-12166 ft. D1L 12185-12245 ft, D1L 12288-12368 ft. D1L 12379-12394 ft, D1L Note: D1L reference is 1/7/74 * ARCO Alaska, Inc. is sub-operator RECEIVED AUG 1 1984 Alaska Oil R ,. Gas Cons. Cot. mission Anchorage 14. i he y that rect to the best of my knowledge. ~r_~.~/~" ~1~,, ~~ Title DIST, DRLG, SUPER,. Signed ~. ~elow for Com_mission use C~ns of Approval, if any: Date 08/09/84 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL r-I COMPLETED WELL OTHER 2. Name of Operator Union Oil Company 3. Address P.O. Box 6247 Anchorage, AK 99502 4. Location of Well Surface: 727'FSL, 141'FEL, T9N, R13W, SEC 17 SM LEG #4, Conductor #27 King Salmon Platform, Cook Inlet 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 7. Permit No. 8. APl Number 50- 9. Unit or Lease Name Trading Bay Unit 10. Well Number K-lORD 11. Field and Pool McArthur River Field Hemlock Pool 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 p,oposed work, for Abandonment see 20 AAC 25.~05-1 701. We plan to reperforate the following intervals during October, 1983 in Well #K-10RD: Hemlock Perforation CBL (1-14-74) Bench DIL (1-7-74) Length 12376-12391' 12345-12365' 12325-12345' 12305-12325 12285-12305 12222-12242 12202-12222 12182-12202 12153-12163 12379-12394 12348-12368 12328-12348 12308-12328 12288-12308 12225-12245 12205-12225 12185-12205 12156-12166 TOTAL 15 20 20 20 20 20 20 20 10 165 ft. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Conditions of Approval, if any: , Approved Copy Returned Approved by By Order of COMMISSIONER the Commiss,on ~,,,,~, ln_~n'~ Submit "InTentions" m Triplicate Form 10-40.3 REV. 1-10-73 Submlt'°intentlons" in Tripllcate · & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS {Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) NAME OF OPERATOR * Union Oil Co. of CalifOrnia* ~ ADDRESS OF OPERATOR 909 W. Ninth Ave , .Anchorage, 4. LOCATION OF WELL At surface 5. APl NUMERICAL CODE 50-133-20167-01 6. LEASE DESIGNATION AND SERIAL NO. ADL 18777 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Tradinq, ,.Bay Unlt 9. WELL NO. K-10 (21-19) Redr~ll 10. FIELD AND POOL, OR WILDCAT McArthur River-Hemlock' 727' N & 14i' W Fr SE Cr Sec 17,.T9N~ R13W, SM ELEVATIONS (Show whether DF, RT, GR, et~) K.B. 100' above MLLW 14. NOTICE OF INTENTION TO: · TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT ' MULTIPLE COMPLETE . . SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Check Appropriate Box To Indicate Nature of Notice, Re : · 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 19, T9N, R13W, SM 12. PERMIT NO. ~ort, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF- ~ REPAIRING WELL FRACTURE TREATMENT ALTERING~ CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) Reperforate existing interval {NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) D~CRIBE PROPOSED OR COMPL~EUOPERATIONS {Clearly state ali pertinent details, and give pertinent dates, Including estimated ~te of starting any propo~d work. The following Hemlock 'intervals were reperforated on October 3 and 4- · 12198-12240- DIL 12289-12.352 DIL 12377'i2437-DIL 12475-12494 DIL *ARCO Oil & Gas Company, Suboperator 36. I hereby, c~rl'~,.¢~t ~h_e foregoing Is true and correct SIGNED .... C. H. Case ' TITLE... District Fnoineer DATE- ], ] -06-80 {This space for State office use) APPROVED BY..,.' ' . CONDITIONS OF APPROVAL, IF ANY: TITLE .DATE ~u~,'- In~trllnt|nn~ Cln RR~IP.r~R Ride F'orm 1 o.,~o3 ,REV. 1-10-73 Submit ** Intentions°' in Triplicate "Subsequent Reports'* in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to d rill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 5. APl NUMERICAL CODE 50-133-20167-01 6. LEASE DESIGNATION AND SERIAL NO. ADL 1877 ' 7. IF INDIAN, ALLOTTEE OR TRIBE NAME O,L I'k-1 GAS F-I WELLL-J WELL g--J OTHER NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Union· Oil Co. of California* Trading Bay Unit ADDRESS OF OPERATOR 9. WELL NO. 909 W. Ninth Ave. Anchorage, AK 9950'2 " K-10 (21-19) Redrill 4. LOCATION OF WELL At surface 727' N & 141' W Fr SE Cr SM 13. ELEVATIONS (Show whether DF, I~T, GR, etc.) · . Sec 17, T9N,. R'13W, Check Appropriam Box To Indicate Nature of Notice, Re .- · NOTICE OF INTENTION TO: ... TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE . SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Reperforate Existinq Interval 10. FIELD AND POOL, OR WILDCAT McArthur River-HemloCk 11. SEC.,T., R., M., (BOTTOM HOLE OE~JECTIVE) Sec 19, TgN, R13'W, SM 12.' PERMIT NO. )orr, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF F~ REPAIRING WELL FRACTURE TREATMENT I ALTERING, CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) DESCRIBE PROPOSED OR COMPLiED'OPERATIONS (Clearly state all pertinent detalls, and give pertinent dates, Including estimated date of ~.7. '~'F.- starting any proposed work. We propose to reperforate the following Hemlock 1249'4' - 12475' DIL 12377' - 12437' DIL 12'289' - 12352' DIL 12198' - 12240' DIL intervals: *ARCO Oil and Gas, . 'Suboperator 16. I hereby certify that Lhe foregoing Is true and correct ~:._- ,. District Engineer SIGNED~~' TITLE '- -C. 'H. Ca_go (This space for State office USe~ ..~ ~ /' :' ' ~. .~.e lnstru~-tions On Reverse Side 9/16/80' · DATE Dated ~t~/~ Fort0 10403 REV. 1-1(>,73 Submit "Intentions" in & "Subsequent Reports" in Duplicate STATE OF OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS {Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT-~' for such proposals.) 1. OIL ~ GAS ['-] WELL[.:.;.3 WELL OTHER 2. NAME OF OPERATOR Union Oil Co. of California* % ADDRESS OF' OPERATOR 909 W. Ninth Avenue, Anchorage, AK 4. LOCATION OF WELL Atsurface 727' N & 141' W Fr SE Cr.Sec 17., -R13W, SM . 99501 T9N,- - 13. ELEVATIONS (Show whether DF, ET. G'R, etc.) 14. Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: MULTIPLE COMPLETE ABANDON* CHANGE PLANS TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPA! R WELL 5. ,~UMERICAL CODE 50-133-20167-01 6'. LEASE DESIGNATION AND SERIAL NO. ADL 1877 7. IF INDIAN, ALLOTTEE ORTRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay [Tn~t_ 9. WELL NO. K-10 (21-19) Redrill 10. FIELD AND POOL, OR WILDCAT ' McArthur River-Hemlock I'~ I. SEC, T' , R ' , M'. (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. 3orr, or Other Data SUBSEQUENT REPORT WATER SHUT-OFF ' ~ REPAI RING WELL ~--~ FRACTURE TREATMENT ~ ALTERING CASING SHOOTiN¢ O. A¢iDiZING __j · ^BANDO MENT* (°ther~er~o~_te existing; interval~ (Other) (NOTE: Report results of multll31e completion on Well ComDletion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED'O~' (~OMPLETED OPERATIONS (Clearly state all pertinent ctetalls, and 9ive pertinent dates, including estimated date of starting any proposed work. The following Hemlock intervals were reperforated at 12377' - 12437' DIL 12289' - 12352' DIL 12198' - 12240' DIL During June, t.9'80[ 4 SPF *ARCO Oil and Gas, Suboperator 711 W. Eighth street, Anchorage, AK 99510 16. I hereby ~r~t the f(~regolng is true and correct SIGNED C. H. Case (This space for State office use) APPROVED BY ' CONDITIONS OF APPROVAl.. IF ANY: TITLE ..... DATE , See Instructions On Reverse Side ~orm i0-,~03 REV. 1-10-73 Submit"Intentions" in Triplicate & "Subsequent Repo~s" in Duplicate STATE OF A~S~ OIL AND GAS CONSERVATION COMMi~EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) ~' O,L I-g-! GAS r-] WELLL~l WELL OTHER 5. APl NUMERICAL CODE 50-133-20157-01 6. L~$E DESIGNATION AND SERIAL NO. ADL 1877 7. IF INDIAN, ALLOTTEE OR TRIBE NAME NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME UniOn Oil Co. of California* Trading Bay Unit 3. ADDRESS OF OPERATOR 909 W. Ninth Avenue, Anchorage, AK-- 99501 4. LOCATION OF WELL Atsurface 727 ' N & 141 ' T9N, R13W, SM W Fr SE Cr Sec 17, 13. ELEVATIONS (Show whether DF, RT, GR, etc.) Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING ~ ' FRACTURE TREAT ~ MULTIPLE COMPLETE ~.~ SHOOT OR ACIDIZE ~ ABANDON* ~ REPAIR WELL [ I CHANGE PLANS ~T~ (Other)Reperf°rate existinq intervallsNX K-10 (21-19) Redrill 10. FIELD AND POOL, OR WILDCAT McAruthur River-Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 19, TgN, R13W, SM 12. PERMIT NO. 3ort, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF' : REPAIRING WELL FRACTURE TREATMENT ALTERIN9 CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. We propose to reperforate the following Hemlock intervals: 12377' - 12437' DIL _ -, /.?, '~ :':; 12289' 12352' DIL ~ ';' 12198' - 12240' DIL ~,/::~ ......... '~, ' ...... *ARCO Oil and Gas, Suboperator 711 W. Eighth Street, Anchorage, AK 99510 16. I hereby certify that the foregoing is true and correct (Thts space for State offic.e~se) ~ [ -~ -' APPROVEDBY (~~~ ' '~q~~-" TITLE . DATE See Instructions On Reverse Side Union Oil and Gas Division' Western Region · Union Oil Company, : ~alifornia P.O. Box 6247, Anchorag,.e, Alaska 9957~ Telephone: (907) 279-768;1 -.. , . May ZO, 1975 '~-~' .;"~,.,~"'~- c ~ , Mr, Tom Marshall ~.i ~:e: f - D&~&s~o~ o~ OH & Ga~T.~: State o~ Ai~sA~ '~ 3001 ~o~cup&~e D~e A~cbo~ge, Alaska 9950~ RE: WELL HISTORIES KING SALMON PLATFORM Dear Mr. Marshall: Enclosed for your files are two (2) copies each of the Well Histories for TBUS K-1 WO, K-18, K-12 WO, K-10 Rd, K-4 Rd, and K-19, King Salmon Platform. Also enclosed are copies of the Directional Surveys for TBUS K-22, both the original and the redrill, and the Gyro Survey. Very truly yours, Jim R. Callender District Drlg. Supt. sk Encl. cc: Marathon Oil Co. Atlantic Richfield Co. Amoco Production Co. Phillips Petroleum Co. Skelly Oil Co. Standard Oil Co. USGS - Mr. Rodney Smith Union Oil Company '~'California unl ,n F'ebruary 26, 1975 Mr. Thomas Marshall Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 RE: TBUS G-22 TBUS K-10 Rd. Dear Mr. Marshall: Enclosed for your files and approval are three (3) copies of the Sundry Notice & Reports on Wells for Change of Plans for TBUS G-22, Grayling Platform and three (3) copies of the Well Completion Report (Form P-7) for TBUS K-10 Rd. Also enclosed is the directional survey for K-10 Rd. Very truly yours, Jim R. Callender District Drilling Supt. sk Enclosures (9) cc: M ar athon Atlantic Richfield Standard Amoco Production Phillips Skelly USGS .- Rodney Smith Pur'u t'- 7 · : SUBMIT IN DU STATE OF ALASKA 5. A}'I alL AND GAS CONSERVA'f'~ON COkA/d~TTEE 50-133-.203.67-01 b. TYPE OF COMPLE~ION: WELl, oVER ~J EN ~ B~CK RESVR. Other 2. NAME OF OPKRATt)I~ UNION 0IL COMPANY 0F CALIFORNIA ,~. AD[:RESS OF OPERATO~ 909 W, Ni~gh Avenue, Anchorage, AK 99501 Trading Bay Unit 9. ~V i~I.,L K-10 (2].-Z9) 10. FIELD ~ND POOL, O1{ McArthur River-ttem!oc} 17 , TDN , R13W, SM u. szc.. T.. ~., ~., ~X~'rTOM Sec 19,TDN~R13W,SM TDN ~R13W,SM 4. i,oc~.,'rms 0F WELL (Report location clearly and in accordance with any State requirt'ments)* At~urface 727' N & 141' W .fr SE er Sec At top prod. interval reported below 1,121' S & 2,047' W fr NE er Sec 19, At total depth 12.PEFLMIT NO. 1,206' S & 2,427' W fr NE er Sec 19, TDN,R13W,SM 74-47 I{O%%' !~L~N'Y' t{OTARY TOOLS ..... CABI.E TOOI 12,822'/9,739' [12,575'/9,524/ Single All 22. PJ{ODL~C1NG !r-F.UERV'AL(S). OF THISCO3IPI_2gTiON--TO-P, BOTTOM. NAS.IE (MD AND T%q))' LT WAS ) SUiIV]"Y MADE Hemlock 12,089' }/iD 99,~1' TVD (Top) I Yes 12~664' MD , 0' TVD (Bottom) 24. TYPE ELi::CTKIC AND OTHEi~ LOGS RUN Dual Induction-Laterolog, Borehole Compensated Sonic i Gyro Survey CASING ~ECORD ~set in weld (Ruport all strings ~-~'~61 & 68 [J-55 4,99"~" 118 '1 2255 sx (exis'ting~ ~Z~'7'~ [47 /N-80 s'830; 12-1/' 700 sx (e~tln2) J'----- 28. PEHFOI'{A'J'tONS OPeN TO PRODUC~ON tintcrv~l, size and nurnber) 29. ACID, Si:CT. ~'iDS.C'i CI~E, C!L.1LNI' SQL'El:fL2:. ETC. D~']]i IN'!~iV:~ IMD) / AMoUNF z'~'D Ix!ND O1;' MA'* ETZAL US~ Liner Liner L~p, . ......... i a , 30. PI{ODUCTION DATE OF T~ST, ~}i~U~{S qEs'r~ [CI1OXE SIZE ~ROD'N FO!, Oi~B!;L. - i~6~-r:~- lCAiU<m PRESSURE iCkl.c0~k~' Oi!~EBL. GA~F~ , C:°ss 3~. l,~s},t, slx'iox oF GAS tSold, used Jar]Nfl, t'cntcd, etc.)' Used for fuel t Louie Rennex' 32. I.I~T OF ATTACHMENT-'~ D'[L & BHC.<~-~onic lo6s. Directional Survey Report. ,,. _ ~ ~ ~ .... (ltttl nitltd f)~m t*] t%al]lll)]l rtct,rl:.~ --'~g'~l )',';'e~:t%]ffif~; Mutt the f0regoi~ a~at[a~ht.d i,,f,rmati,,n Is complet, and correct as , ,.t , '. :". /q ')~<</~./?/5.-/< . ....... "Dist. Drig. Supt. ..,..,, 2/26/75 *(See Instructions and Spaces for Additional Data on Reverse Side) iNSTRUCTiONS General: This form is designed for submitting a complete and correct well co~qpJetion repc:,rt 'and log on ail types of lands and leases in Alaska. J~m: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in other spaces on this form and in any attachme~ts. Items 20, ~n~ 22:: If this well is completed for separatc, production from more than one interval zone (multiple completion), so state in item 20, 8nd in iteq~ 22 show the ptcz{ucing interval, or intervals, top(s), bottom(s) end name (s) (if ~ny) for only 1he interv0J reported in item 30. Submit 8 separate report (page) on this form, adequately identificd, for e~ch additional interval to be seperateiy produced, show- ing the 8~itionel d~t8 pertinent to such interval. ' Item2&: "S~cks Cement": Attached supplemental records for this well shoul~ show the detaiis of 8ny mul- tiple stage cementing ~nd the Ioc~tion of the cementing tool. Item 28: Submit ~ separate completion re~rt on this form for each interval to be separately produc~. (~e instruction for items 20 ~nd 22 8bore). WATE~q. AND MUD NAME DST'd Hemlock Bench #6 perforations from 12,606-12,611' CBI G Marker t1,179' 8,343' measure. Recovered 13 BO, 142 BW & 3.3 BM. Recorded test Hemlock 12,089' 9,171' pressures at 12,529' were 4944 IH. 4015 I$I, 730 IF, West Foreland 12,664' 9,600' 4039 FF, 4039 FSI. BHT = i70°F craze DATA. Aa-racet rm~£?- DESCR,,PIT~O,WS' Ow' ntTll°LoG'~,. PoRosITY, FIiACTUR,~c~; APpAl:kLrq'T'r' ~N~ D~rECn'~) Suows o~'-om, G~S or~ · ,, AflanficRichfieldCompany Daily., ell History- Final Report lns~tr~=ti~.~a= Pre,are a~d submit the "Fhta~! Report" on ~e first Wednesday 'after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Fi~a~l P,e~:~rt" shouid be suOmitted also wheft operations are suspended for an indefinite or appreciable length of time. On workovers when an otficial test is not rec~ ~ comotetio~ reoort comptetJ<~ aad representative test da'~ in blocks provided. The "Final Report" form may be used for reporting the entir~ ©i-~c~ - .:.-.' C4;~nt¥ or Parish Slate · SOUTH &LASKA'_: .... ~ KENAI F~e~ Lease or Unit TR-~D_TNG BAT ~' -' ' -- TRADING BAY- UNIT Autm~ ~¢ '~.O. r~. Title '~ K-10 (21-19) REDRILL 19942? ~'' ..... , , .,,, ,, . . .... .._ ,. ©c~.-a~Or ~' ' ........................ ' ' .......... ~A.l ~Yotal number of wells (active or inactive) on this EF rELD CO'MPAN R.Co. w.~. Icost cemer prior ~o _._LAN~.C RTC _ · -~ 12.9% ........ .'-'-~2_'~. .___.,_~a, bandonment of this well I D~t~ ~d ~t~ Com~ ~r~ for each day m~ed ..... ..... .... .., - , .. ....... _ ........ ~-30-T5 ~BU:;K-~0 (~e4=i~) - C00[ [~LET - (T" ~i~e= ~ ~2,8h0') 12,822' TD .2~822~ TD,;~:!2,ST5~ PBD - Teste~ Hemlock Benches G~;'2h hrs~.'~;.r~e of 3098 BOPD w/no w~r 12 miani~ht;:?l'2T--?5. FINAL ~EPO~T. Accounting cost center code ALASKA jWell no. TBU K-10 on.- C~ ~ 13,h63' R~asad "rig MiDNiGHT Ch_.=smficafi~ns ioa, ~as, OIL ~AS,~ LiFT ~c~enti~ ~esi tala New TD Date i2,822' 1/27/75 PB Depth Kind of rig 12,575' Type completion (singte, dual, etc.) SINGLE Official reservoir name(s) HEMLOCK BENCHES #5 & #6 >il~°' t ~a~e ' Reservoir Producing Interv&l Oil or gas Test time Pr(~duci'i0n ! ..................... Oil on test' ['Ghs per day - K-'O I -- .--,2 t ~5 & ~6 12450'¢12545 OIL 24 2900 ...... ~ ~ v ;' , . ~--D ~..;9, SP,,t X length ~ Ohoke s~ze T.P. jC.P. Water % GOR ..... corrected ~ravityAl[owable Effective date .~ ........... ......... '1"' ....... G::.,; 7 VUTq .: 1-!/9" 190 n 140 0 SOUTH ALASKA DIST. DRLG. / - ~, ,.) ..... '~a~uat. Section i0, 87. SUPERVISOR INumber ali daily well history forms consecutively as they are prepared for each well. Page no. AtlanticRichfieldCompany Daily Well History-Interim This form is used during drilling or workover operations, if testing, coring, or perforating, show formation name in describing work performed. dfilt s~em tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets unfit final Rec, ort off~ciai or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days. or (2) Wec~'~es<say of the wee~ in which oil string is set. Submit weekly for workovers and follpwing setting of oil string until completion. District SOUTH ALASKA =ield 1-24-75 ~2,822 ' TD 1-27-75 _20_75 ICounty or Parish IKENAI ILease or Unit KING - TRADING BAY UNIT iState ALASKA no, TBU K-10 Comptete record for each day while drilling or workover in progress TBU K-10 (Redrill) - COOK INLET - (7" liner ~ 12,840') 12,822' TD, 12,575' PBD- Testing On GL FIH w/384 jts 4-1/2" x 3-1/2" GL compl assy as follows: Tail @ 11,966'; shear sub ~ 11,965'; Otis 3-1/2" X nipple ~ 11,933'; Baker 7" x 3-1/2" FH Hydrostatic pkr @ 11,895'; 8 Camco 3-1/2" KBMG GL mandrels w/BK vlvs @ 11,856'; 11,512'; 11,171'; '10,827'; 10,455'; 10,050';. 9648' & 9247'; 4-1/2" x 3-1/2" Butt XO ~ 8475'; 4 Camco 4-1/2" MMG GL mandrels w/R-20 vlvs ~ 8436', 7186', 5235" & 2787'; Camco 4-1/2" TRB-6 safety vlv ~ 251' & OCT tbg hgr @ 34' RKB. Ran .272 its 4-1/2" 12.6# N-80 Butt tbg & 112 jts 3-1/2" 9.2# N-80 Butt tbg. Landed tbg. ND BOPE. NU OCT tree w/4-1/2" straight run & 3-1/2" wing. Tested w/5000 psi. Set pkr w'/950# & sheared out ball w/2000#. RU & tstd lubricator w/2.500#. RIH w/DA 2" slim Di-Kone III perf gun. Tagged PBD ~ 12,551' WL/CBL measure. Unloaded well on GL to top GL vlv. Perfd Hemlock Bench #.6 w/4 JSPF f/12,520-12,545' · Cleaning up well on GL. TBU K-10 (Redrill) - COOK INLET - (7" liner @ 12,840') 12,822' TD, 12,575' PBD - Testing on GL Tstd Bench #6 perfs f/12520-12545' on GL ~ final rate of 2117 BPD w/0.25% BS&W ~ 170# FTP. Installed new 15,500' 9/16" sand line. Ran 14 hr static BHP survey.-FL ~ 2300' WLM (1920' TVD). BHP = 4190# ~ 12,500' WLM. Perfd Hemlock Bench #5 w/4 JSPF f/!2,450-12,491' w/DA's 2" slim Di-Kone III gun. Tstd Benchs #5 & 6 on GL 24 hrs ~ rate of 2900 BOPD w/no wtr ~ 190# FTP on 1-1/2" choke. TBU K-10 (Redri!l) - COOK INLET - (7" liner.~ 12,840') 12,822' TD, 12,575' PBD - Testing on GL - Tstd Benchs #5 & 6 24 hrs on GL ~ rate of 2920 BOPD w/no wtr ~ 120# FTP. TBU K-10 (Redrill) - COOK INLET - (7" liner @ 12,840') 12,822' TD, 12,575' PBD - Testing on GL - Produced 3067 BOPD w/no ~z'tr on 24 hr test of Hemlock Benches #5 & 6 ~ 150# FTP. IOate [Ti 7-7.C'-- ALASKA DIST. DRLG. SUPERVISOR Number all daily well history forms consecutively as they are prepared for each well. AtlanficRichfieldCompany Daily Well History-Interim Instructions: This ~orm is used during drilling or workover ooerations, if testing, coring, or perforating, show formation name in describing work performed. Number aJt drill stem rests se43uentially. Attach description of ail cores. Work performed by Producing Section will be reported on "Interim" sheets until final cocnoietion. Reoort otficiat o, representative test on "Finer' form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of t~e week i~ which oil string is set. ,Submit weekly for workovecs and following setting ot oil string until completion. CJstrict tC°unty or Parish I State SCUTH ALASKA KENAI ALASKA. F~e~d Lease Or Unit ~Well no. TRADi:[G BAY I KING - TRADING BAY UNIT I TBU K-10 Cate and ceotn rcomplete reco?d for each day while drilling or workover in progress as of 8:00 a.m. 1~20-75 . TBU K-10 (Redrill) - COOK INLET - (T" liner ~ 12,840') 12,822' TD 12,822' TD, 12,685' PBD - Testing - MW 10.2#, Vis 47 CO to !2,68~' PBD. Circ & cond mud. Tst csg & liner lap w/2500#. POH. Ran WSO w/2000' WS. Set pkr ~ 8332'. 0T for 1 hr flow period w/moderate blow decreasing to no blow in 8 mins. SI & POH to rise. R~covered 40' (0.7 bbls) mud. Recorded press ~ 8343': 3257 IH, 584 IF, 584 FF, 3257 FH. BHT = 155°F. Lap test dry. RU & test lubricator. Perfd Hemlock Bench #6 w/4 J~mbo Jet-SPF f/12,6G6~12,6il' 'CBL~jnaas..ure.~'w./DA'S '4' 'csg--gun. RIH w/7" DST tool on 5" DP. Rabitted DP & CO 10 drums of cmt. Tripped & rerabitted DP. Ran 2000' 'fresh WC. Set pkr @ 12,5'17' · OT @ 12:45 PM 1-19-75 for 1/2 hr IF w/heavy blow. Took 35 rain ISI. Reopened tool for 7 hr flow period w/gas to surface in 20 mins. Turned test to separator after 2 hrs. Flowing press would not buck 75# separator press. SI ~ 9:29 PM for final shut in. RO 10,337' net rise. Recovered 13 BO, 142 bbls salty wtr & 3.3 BM. 1-21-75 TBU K-10 (Redri!!) - COOK INLET - (7" liner ~ 12,840') 12,822' TD, 12,575' PBD - Circ - MW 10.1#, Vis 45 POH v/DST. Recorded press ~ 12,529': 4944 IH, 4015 ISI, 730 IF, 4039 FF, 4039 FSI. BHT = 170°F. RIH & set 7" ET. drill rtnr ~' 12,580' on DP. PU to 12,575'. Circ & cond mud. Set in rtnr & press to 5000#. Made several attemps & could not BD Bench #6 perfs f/!2,606-12,611' w/5000#. PU out of rtnr &circ thru stinger. Set back into rtnr & BD perfs w/4800#. Pumped into perfs ~ 1 BPM v/press decreasing to 3200#. SI w/immediate SI press of 2500#. PU. Pumped 20 BFW preflush & 100 sx "G" cmt w/l% CFR-2 & 0.2% HR-7 to spot. Set into rtnr & sqd perfs to 6000# w/60 sx. PU to 12,575' & dumped cmt on top of rtnr. RO XS cmt. Began reversing mud w/filtered Inlet wtr. 1-22-75 rBU K-10 (Redrill) - COOK INLET - (7" liner ~ 12,840') 12,822' TD, 12,575' PBD - LD DP - MW Diesel RO mud w/f. iltered Inlet wtr. RO wtr w/diesel. SOH. LD 5" DP. 1-23-75 TBU K-10 (Redri!l) - COOK INLET - (7" liner ~ 12,840') 12,822' TD, 12,575' PBD - PU Tbg - MW Diesel LD DP & dr!g tools. SIH w/3-1/2 x 4-1/2" tbg completion assy. A RS B -45~2 -A Number all daily well history forms consecutively IPage no. as they are prepared for each well. t ~ 3 · ( AtlanticRichfieldCompany Daily Well History-interim -,, Instructions: This form is-used during dritling or workover operations. If testing, coring, or perforating, show formation name in describing work performed, Number all drill stem tests seauentially. Attach description of all cores. Work performed by Producing Section wil be reported on "Interim" sheets until final completion. Re[}ort official or representative test on "Final" form. I) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or {2) on Wednesday of me week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish SOUTH ALASKA I KENAI Field ' ILeas'~ or Unit TRADING BAY I KING - TRADING BAY UNIT Date and dept~ ~Complete record for each day while drilling or workover in progress as of 8:00 a.m. .... I TBU K-10 (Redri11) - COOK INLET ALASKA ~TBU K-10 1-1k-75 12 , 822 ' TD 1-15-75 1-16-75 1-17-75 - (7" liner ~ 12,840') 12,822' TD, 12,685' PBD - POH w/Gyro - MW 10.1#, WL 4.6 RIH w/6" bit & 7" csg scraper. CO hard cmt in 7" liner f/8532-8599'. FIH to 12,633' & CO hard cmt f/12,633-12,685' PBD (Landing collar.~ 12,760'). Circ & cond mud. MOH. Ran DA cmt bond log w/GR & collar log f/12,660'-8400' WLM. Top of cmt indicated @ 8964' w/intermittent good to poor bonding thru out. PBD=12,667' WLM. Top of liner = 8519' WLM. Top of marke~ jt ~ 12,169' WLM. Ran Eastman Gyro survey f/7500'- 12,645'. · TBU K-10 (Redrill) - COOK INLET - (7" liner ~ 12,840') 12,822' TD,-12,685' PBD - Prep to Sq Lap - MW 10.2#,'Vis 47 Ran WSO test w/2009' wtr cushion. Set pkr .~ 8332'. OT for 1 hr flow period w/weak blow increasing to strong blow. SI for 1 hr final shut in period. Pul. led to rise. Recovered 1054' (18.6'bbl) muddy wtr rise w/2800-6300 ppm chlorides. RO & FOH. Recorded press ~ 8351': 3257 IH, 608 IF, 973 FF, 2623 FSI, 3257 FH. RIH & set RTTS ~ 8343'. Tst lap w/2500#. Press bled off to 2100# in 5 min. Tst lap w/3000#. Press bled off to 2500# in 5 min. Tst lap w/3500#. Press bled off to 2400# in 5 min. BD lap w/4000 psi ~ 1/2 BPM increasing to 3/4 BPM ~ 3600#. SD pump. Press bled to 2000# in 5 min. TBU K-10 (Redrill) - COOK INLET - (7" liner ~ 12,840') 12,822' TD, 12,685' PBD - WOC - MW 10.1#, Vis 49, WL 7.4 WOW 10 hrs. Boat unable to deliver cmt due to ice conds. Flew out cmt w/helicopter. BD lap w/4000# ~ 1 BPM w/pkr set ~ 8388'. Pumped 20 bbls caustic wtr followed w/40 bbls filtered Inlet wtr preflush. Mixed & pumped 200 sx. "G" neat cmt to spot. Sqd lap w/175 sx w,/3800# ~ 1 BPM increasing to 5000#. Held 5000# on sq for 30 mins. Bled off press - held OK. CIP ~ 10 PM 1-15-75. Pu to 8320 & RO 15 bb!s thick mud (no cmt). POH. RIH w/8-!/2" bit & 9-5/8" csg scraper to 7330'. Circ & cond mud. TBU K-10 (Redrill) - COOK INLET - (7" liner ~ 12,840') 12,822' TD, 12,685' PBD - Prep to Test Liner Lap - MW 10.1#, Vis 46, WL 7.6 GIH w/8-1/2" bit & 9-5/8" csg scraper. Tagged top of cmt @ 8~28'. Drld cmt f/8428-8534'. POH. GIH w76" bit & 7" csg scraper. Drld soft stringers of cmt f/8534-12,685'. The above is coffee; - / ~ / - /~ preparat-ion '~r',~. di~ribu.'.io~ see ~cedures Mammal ~ection 10 ~ng, Pages 85 and 87 Number all daily well history forms consecutively as they are prepared for each well Page no. 12 AtlanticRichfieldCompany Daily Well History-Interim Instructions: T~is form is used during drilling or wOrkover o~erations. If testing, coring, or Derforating, show formation name in describing work performed. Number ail ~dtt s.'.em tests sequentially. Attact~ descrilotion of ail cones. Work performed by Producing Section will be reported on "Interim" sheets un[il final co~nolet~on. Reoo~ offic=al or representative test on "Final" form. 1) Submit "interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wec~-=~-<3ay of the wee~ in which oil siring is se[. Submit weekly for workovers and following setting of oil string until completion. D~$zdct F~id Dz:e and as of 8:00 County or Parish ~~ ALASKA KENAI TRAD~ ~ =~ BAY KiNG - TRADING BAY UNIT Co~ptet~ ~¢~ 'for eac~ day ~bit~ drilling or workover in progress 1-8-75 12,82.2' TD IStaie ALASKA IWetl no. TBU K-lC 1-9-75 1-10-75 TBU K-10 (Redrill) - COOK INLET - (9-5/8" csg @ 8830') 12,822' TD - Circ - MW 10.2#, Vis 52, WL 4.8 Ran Scht DIL w/SP & GR-Sonic. Installed 7" rams. Tested BOPE w/3000# & Hydril w/1800#. RIH. Circ & cond mud. Made short trip. Hole cond good. Circ & cond hole for liner. TBU K-10 (Redril!i - COOK INLET - (9-5/8" csg ~ 8830') 12,822' TD (0') - RIH w/7" Liner - MW 10.2#, Vis 70, WL 4.8 SDotted 280 bbl of 70 vis mud pill on btm. PU 110 jts 7" -- 29# N-80 Butt liner w/BOT 'Type "V" FS, catcher sub ! jt above ' shoe & landing collar 2 jts above shoe. Total liner = 4309'. Ran 71 B&W duo turbin centralizers spaced on eve.ry jt on btm 27 &:i~-top7 jts & every second jt on remaining pipe. SIH w/liner -on 5" DP. Losing time thawing out ice plugs in DP. TBU K-10 (Redrill) - COOK INLET - (7" liner ~ 12,840') I2,822' TD - W0C - MW 10.2#, Vis 46, WL 6.5 FIH w/7" liner on 5" DP. Circ & cond mud. Set hanger. Pumped 20 BW oreflush. Cmt'd liner w/960 sx "G" w/l% CFR-2 & 0.2% HR-7 mixed @ 15.7 ppg. CIP ~ 8:28 PM 1-9-75. POH. Top of liner ~ 8532' 800' , shoe @ 12,840' landing collar ~ , catcher sub ~ 12, , ~ 12,760', 7" x 18' marker jt ~ 12,193-12,211'. (Note: Liner measurements are 18' deeper than DPM, will MIH to ck liner top.) TBU K-10 (Redrill) - COOK INLET - (7" liner ~ 12,840') 12,822' TD - PU 3-1/2" DP - MW 10.1#, Vis 46 MIH w/9-5/8" csg scraper & 8-1/2'' bit. CO cmt stringers f/78k6' to top of liner. No good cmt above liner. Circ & cond mud. MOH. No correction. Top of liner ~ 8532' DPM. Tst csg & lap. Pumped 5 BPM w/2500#. RIH & set 9-5/8" RTTS ~ 8343' Tst 9-5/8" csg w/2500#, OK. Tst lap w/2500# & pumped away ~ ~ BPM. Staged sqd w/100 sx "G" mixed w/l% CFR-2 & 0.2% HR-7 followed w/iO0 sx "G" neat. Sqd 160 sx below liner top w/2500#. CiP @ 1:25 AM 1-12-75. RIH w/bit & scraper. W0C 12 hrs. DO soft cmt f/83k3-8414'. WOC 4 hrs. Tst lap w/2500#. Bled off to 2150# in 20 mins. POH. IDate ' ITitle · ~ Z"-TS"-- ~'SOUTH ALASEA DZS?. DR;BO. SUPSR¥TSOR A R3B-459-2-A INumber all daily well history forms consecutively as they are prepared for each well. (~ AtlanticRichfieldCompany Daily Well History-Interim Instructions: This for~ is used during drilling or workove¢ operations. If testing, coring, or perforating, show formation name in describinq work performed, Number aH drill stem tests sequentially. Attach description of ail cores. Work ~erformed by Producing Section will be reported on "Interim" sheets until final completion. Reoort official or reoresentative test on "Final" form. I~ Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of [,ne -,eeek in whicl~ oil string is set. Submit weekly for workovers and following setting o! oil string until completion. District Field SOU'TH ALASKA County or Parish J Staie KENAI J ALASKA Lease or Unit KING - TRADING BAY UNIT JWell no. TBU K-10 Date and as of 8:00 a,m. 12-27-71~ 12-30-f~ 12-31-74 1-2-75 1-3-75 1-6-75 1-7-75 Complete record for each day while drilling or workover in progress TBU K-10 (Redri!!) - COOK INLET (9-.~/8" csg ~ 8830') 11,195' (120') - Drlg - MW 10#, Vis 51, WL 4.4 Dir dr!d 8-1/2" hole f/il ,075-11,195 ' · Hole cond good. 100 BM on trip ~ 11,083'. SurVey: 11,016' 32-1/2° S72W. Lost TBU K-10 (Redril!) - COOK INLET - (9-5/8" csg @ 8830') 11,837' (642') - RIH - MW 10.2#, Vis 54, WA 4.4 Dir dr!d 8-1/2" hole f/I1,195-11,837' w/wiper trips @ 11,204', 11,453', 11,837' & bit trip ~ 11,600'. Magna fluxed BHA & chgd out Mone! stb w/bad thd. Hole cond good. Surveys: 11,137' 32-1/4° S72W; 11,386' 32-1/2° S74W; 11,533' 32-1/4° S76W; 11,770' 31-1/4° S77W. TBU K-10 (Redril!) - COOK INLET - (9-5./8" csg (~ 8830') 12,135' (2~8') - Drlg - MW 10,2#, Vis 52, WL 4.4 Dir drld 8-1/2" hole f/11,600-12,135' w/wiper trip Hole cond good. 12,061 ' . TBU K-10 (Redrill) - COOK INLET - (9-5/8" csg ~ 8830') 12,294' (159') - GIH Wiper Trip - MW 10.1#, Vis 51, WL h.5 Drld 8-1/2" hole f/12,135-12,294'. Wiper trip ~ 12,294'. Down 7-1/2 hrs repairing monkey board & electrical short in rig power. Survey: 12,109' 30° S80W. TBU K-10 (Redril!) - COOK INLET - (9-5/8" csg ~ 8830') 12,401' (107') - GIH w/New Bit - MW 10.2#, Vis 52, WL 4.2 Drld 8-1/2" hole f/12,294-12,401'. Bit trip w/normal drag; hole slick. " TBU K-10 (Redrill) - COOK INLET - (9-5/8" csg ~ 8830') 12,759' (358') - Drlg - MW 10.2#, Vis 55, WL 4.4 Dir dr!d 8-1/2" hole f/12,401-12,759'. Normal torque & TBU K-10 (Redrill) - COOK INLET - (9-5/8" csg @ 8830') 12,822' (63') - Logging - MW 10.2#, Vis 54, WL 4.6 Dir dr!d 8-1/2" hole f/12,759-12,822'. Circ samples. wiper trip. Circ & cond hole for logs. Ran DIL w/SP TD 12,826' WLM. Survey: !2,780~ 33° S76W. drag. Made f/Schl J Dat~2:~ ' JTitle A R3 B-'459--2-A jNumber all daily well history forms consecutively as they are prepared for each well. j Page no. j 1o AtlanticRichfieldCompany ' Daily Well History-Interim Instn~ctions: This form is used during drilling or workover o~erations, tf testing, coring, or perforating, show formation name in describing work performed. Number ail dritl stem tests sequentially. Attach description of alt cores. Work performed by Producing Section wil be reported on "Interim" sheets until final comc~etion. Reoort official or representative test on "Final" form. 1} Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) cn W_,~onesca¥ of the ween in which oil string is set. Submit weekly for workovers and following selting of oil string until completion. D~stric~ ~County or Parish SOUTH ALASKA t KENAI F!eid JLaase or Unit TRADING BAY [ KING- TRADING Date =_nd ceotn Complete record for each day While dri'llir;'g o~' workove'r in progress as of 8:00 a.m. 12-18-74 12-19-74 12-20-74 12-23-74 12-24-74 ~2 26 74 IState BAY UNIT ALASKA BU K-10 , , TBU K-!0 (Redrilt) - COOK INLET - (9-5/8" csg ~ 8830') 9933'-(34.2') - Drlg - MW 10.2#, Vis 54, WL 4.4 Dir dr!d 8-1/2" hole f/9591-9933' w/wiper trips every 12 hrs.- Survey: 9680' 35-1/4° SS~W. ~BU K-10 (Redri!l') - COOK INLET - (9-5/8" csg ~ 8830' ) 9996' (63') - RIH w/TD #6 - MW 10.2#, Vis 52, WL 4.4 Dir drld 8-1/2" hole f/9933-9964'. Tripped for TD #5 f/9964-9996'. Survey: 9964 ' 34-3/4° S86W. TBU K-10 (Redril!) - COOK INLET - (9-5/8" csg @ 8830') 10,070' (74') -Orlg- MW 10.2#, Vis 56, WL 4.5 Drld £/9996-10,036' w/TD #6. Tripped for BHA. Rmd 120' to btm. Dir drld 8-1/2" hole f/10,036-10,070'. Normal torque & drag. Hole cond good. & drld TBU K-10 (Redrill) lo,540' (~70') - Dir drld 8-1/2" w/high torque & 10,279' on short 10,540'. Surveys: - COOK INLET - (9-5/8" csg ~ 8830') RIH w/TD #7 - MW 10,2#, Vis 54, WL 4.8 f/10,070-10,540'. Rmd tight hole f/9956-10,266' drag on trip ~ 10,266'. CO bridge f/10,264- trip. Normal drag on trip out of hole @ 10,213' 36° S79W; 10,473' 31-1/4° S82W. TBU K-10 (Redrill) - COOK INLET - (9-5/8" csg @ 8830') 10,581' (41') - Tripping - MW 10.2#, Vis 51, WL 4.6 Dir drld 8-1/2" hole w/TD #7 f/10,540-10,581'. Normal drag & torque w/exception for tight hole @ 9393' on trip out. Tested BOPE w/3000# & Hydril w/1800#. SIH w/BHA. Survey: 10,543' 32° S78W. TBU K-10 (Redri!l) - COOK INLET - (9-5/8" csg ~ 8830' ) 11,075' (494') - Drlg - MW 10.2#, Vis 53, WL 4.3 Dir dr!d 8-1/2" hole f/10,581-11,075'. Lost 75 BM on wire trip ~ 10,885' . Hole cond good. Surveys: 10,649' 32-3/4° S72W; 10,818' 32-3/4° ,is correc[ ~ S73W. ,~Title SOUTH ALASKA DIST. DRLG. SUPERVISOR AP3 8-~459-2-A Number all daily well history forms consecutively as they are prepared for each well. IPag~no. . AtlanticRichfieldCompany Daily Well History-Interim Instructions: Thi~ fo~.., is uSed during drilling or workover operations, tf testing, coring, or perforating, show formation name in describing work performed. Number a;l dnil sze~ teszs se<3uentiaityo Attach description of ali cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Re,oct cff~ciat or ~-epresentative test on "Final'" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on WednesCa~ pt ~e ~,ee~ in w~ich oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field ~T~ SO~_ ALASKA - ICountyor Parish tState KENAI ALASKA L~'as~' or ur;i'i I",v~. no. KING - TRADING BAY UNIT fBU K-10 TRADING BAY Date and Ceom as of 8:00 a.m. t2-!0-Th ~3,~'6~' _ ~ ~ ~D !2-1!-7h 12-12-74 12-13-7h 12-!6-7L 12 * 7 7L Complete record for each day while drilling or workover in progress TBU K-10 (Redrill) - COOK INLET - (T" liner ~ 13,415') 13,463' TD, 9002' Est PBD - Circ - MW 9.6#, Vis 98 Rmd f/8854-8879' w/Servco "K" Mill #4. Recur 2' window f/8879-8881'. Milled 17' windown in 9-5/8" csg f/8881- 8898' in 9 hrs. Est. 75% mill cuttings to surface. Cut total 68' window-:~ f/8830-8898' in 38 hrs. Circ. RIH w/305' 3-1/2" Butt tbg tail to 8993' (top of 9-5/8" stub @ 8898'). Reversing out mill cuttings.~ TBU K-10 (Redrill) - COOK INLET - (7" liner ~ 13,415') 13,463' TD, 9002' Est PBD - Circ & Cond Mud - MW 9.5 Vis 48, WL 7.8 RO mill cuttings ~ 8993'. Pumped 5 BW followed, w~20'bb~s caustic wtr & 5 BW preflush. Spotted Kick off plug @ 8993' w/160 sx densified "G" w/1~ ~ CFR-2 mixed @ 17.0 ppg. CIP ~ 8:12 AM 12-10-74. PU to 8714' & RO 40 cf cmt w/ball of mill cuttings. POH. Tested BOP w/3000#. Replaced Hydril bag & tested to 1800# OK. RIH w/bit. TBU K-10 (Redrill) - COOK INLET - (9-5/8" csg ~ 8830') 8852' (17') - Drlg w/TD #1 - MW 9.5#, Vis 53, WL 6.0 Circ & cond mud @ 8500'. WOC total 24 hrs. Tagged top cmt ~ 8714' DO' hard cmt f/8714-8835' (5' below top of window ~ 8830'i. Circ hole clean. RIH w/Turbodrill #1. Oriented w/Sperry Sun steering tool. Sidetracked old hole & drld 8-1/2" hole f/KOP 8835-8852'. TBU K-10 (Redrill) - COOK INLET - (9-5/8" csg ~ 8830' ) 8893' (41') - RIH TD #3 - MW 10.1#, Vis 58, WL 5.8 Drld 8-1/2" dir hole w/TD #1 & mill tooth bit f/8852- 8878'. Drld w/TD #2 & Dia bit f/8878-8893'. TBU K-10 (Redrill) - COOK INLET - (9-5/8" csg ~ 8830')' 9440' (547') - Drlg - MW 10.2#, Vis 57, WL 4.6 Dir dr!d 8-1/2" hole w/TD #3 f/8893-8916'. Tripped for BHA. Rmd f/8834-8916'. Drld f/8916-9440'. Surveys: 9022' 40° S82W; 9206' 38-1/2° S83W. TBU K-10 (R'Sdrill) - COOK INLET - (9-5/8" csg 09 8830' ) 9591' (151') - Drlg - MW 10.2#, Vis 53, WL 4.5 'Dir drld 8-1/2" hole f/94~0-9591'. Tested BOPE w/3000# &. Hydri! ~z/t800#. Hole cond good. Survey: 9416' 37° S84W. ~,..~ Ti.tlg0 U.TH __7__.7 ALASKA DIST. DRLG. SUPERVISOR A R3 3-4,59,-_-A INumber all daily well history forms consecutively as they are prepared for-each well. . no, 8 AtlanticRichfieldCompany Daily Well History-Interim This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Numoe~r ~! drill stem tests sequentially. Attach description of alt cores. Work performed .by Producing Section will be reported on "Interim" sheets until final comt34~en~n~ Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not tess lrequently than every 30 days, or (2) c~ wec_..-.,~3a¥ oi ~.he week in which oil string is set. Submit weekly for' workovers and following setting of oil string until completion· ~0~Tm=,.,._2 ALASKA- ,, , TRAD~.'~G BAY 12-k-74 ~ h63' TD 12-5-7h 12-6-7h 2-9-7 h County or Parish KENAI Lease or Unit KING - TRADING BAY UNIT ALASKA INVell no. ' ~BU K-10 Complete record for each day while drilling or workover m progress TBU K-10 (Redrill) - COOK INLET - (7" liner @ 13,h15') 13,463' TD,' 9030' PBD - DO rtnr - MW 9.8#, Vis 94, WL 6.0 Recovered rtnr setting tool w/overshot. Tagged top of fish ~ 8752' DPM w/btm ~ 8763' DPM. RIH w/stinger on 5" DP. Circ btm up. Set into rtnr. Press DP to 100 psi & circ annulus. Press annulus to 100 psi &circ DP. Made several unsuccessful attemps to get =tnr to hold. Press DP & annulus w/2000#. Could' not pump into perfs @ 8805'. RIH w/bit to drl cmt rtnr ~ · 8764'DPM = 8765' WLM. TBU K-10 (Redri!l) - CO0~ INLET - (7" liner ~ 13,415') 13,463' TD, 9026' PBD - Prep to SQ - MW 9.8#, Vis 105 DO rtnr @ 8764' & pushed to btm ~ 9026' DPM. Circ& cond mud. Recovered 1/2 gal rtnr pcs in junk basket. RIH w/9-5/8" csg scraper open ended & reverse hole clean ~ 3000' 5000' 6500', 8000' , & 8990'. Recovered approx 1 gal mill cuttings rbr & coal on each circ. POH. Press up csg to ck pump in rate thru sq perfs @ 8805'. BD w/1200 psi & pumped 12 bbls into perfs @ 3 BPM w/t400 psi. RIH & set Baker retrievamatic pkr ¢ 8620' DPM. Found 1/4" hole in DP 1" below weld on box end. Tube cracked 1/2 circumference. TBU K-10 (Redriil) - COOK INLET - (7" liner ~ 13,4].5") 13,463' TD, 9026' PBD - DO Cat - MW 9.8#, Vis 105 · Tested sq pkr, OK. BD fmtn w/1200 psi & pumped 12 BM into perfs ~ 8805' WLM ~ 2.5 BPM w/1600 psi. Pumped 10 BW preflush & -mixed 200 sx "G" w/l% CFR-2 ~ 15.1-16 ppg. Pumped 5 BW flush &circ cmt to spot holding 900# back press on annulus. Closed bypass & press annulus to 1000#. Staged sqd to 2600# W/175 sx thru perfs. CIP ~ 12 noon 12-5-7~. POH. RIH w/bit to top of cmt ~ 8623'. Circ& cond mud. Press tested csg . w/2200# for 15 min OK. W0C total 1~ hrs. DO hard cmt f/8623'- 8783' & f%rm to soft cmt f/8783'-8811'. TBU K-10 (Redrill) - COOK INLET - (7" liner ~ 13,415') 13,463* TD, 9002' Est PBD - RIH w/Mill #4 - MW 9.7#, Vis 115 CO soft cmt f/8811-9002'. Circ& cond mud. Tested csg & sq per~s ~ 8805' w/2200#. Ran DA CBL-VDL f/9000-8000'. No cmt indicated below 8800' WLM. Indication of good csg & ftmn bonding f/8755-8788'. & f/8435-8455'. Cmt indicated f/8455- 8755~ w/no fmtn bonding. Cut 51' windown in 9-5/8" csg f/8830-8881' in 29 hrs w/Servho "K" Mill #3. Mill worn to 9-1/8" OD. DRLG. SUPERVISOR INumber all daily well history forms consecutively as they are prepared for each well. J Pag~.no. AtlanticRichfieidCompany Daily Well History-interim L. Instructions: .T:.,~is form ;s used during drilling or workover operaticns, if testing, coring, or perforating, snow formation name in describing work performed. Humi~er ail driill szerrt '.es[s sequentially. Attach description o~ all cores. Work performed by Producing Section will be reported on "Interim" sheets until final comDletioO. Re¢or[ off~ciat or reoresentative test on "Final" form. t) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wecinesc, a~r 3t ;ne week ir~ which oil strir~ is set. Suomit weekly for workovers and following setting of oil string until completion. jCounty or Parish ms,ri=,SO.l''' ~''~ ~= AL ASKA .J~ KENAI {haase or. Unit KING - TRADING BAY UNIT 'Complete r~o~d for eac~ day while drilling or workover in progress Field TRADT_NG~ BAY Date and ceptn as of 8:00 , i2-2-?~ 13,h63' TD Ist,t% LA S KA Well no. ,.[,,T BU K-10 circ or rotate. Worked 11 hrs to get DiaLog free pt indicator down. Pipe stuck at bumper sub ~ 9229' WLM. Attempted to jar loose w/20" x 300 gr/ft string shot f/9229'-9249' w/400,O00# straight pull. RIH w/DiaLog back off shot. Put in 3 rounds left hand torque & fish backed off ~ 9247' DPM w/o shot. Ok~kd backoff w/collar log. POH. Tightened all corms. Recovered bumper sub. LD fishing tools. RIH w/0EDP. Tagged top of fish @ 9247' DPM. Reverse circ hole clean. R0 4 gals mill cutting up to 2" long w/no rubber or coal. Ran DA Gamma Ray & cmt bond log f/top of fish @ 9246' WLM to 7700' No bonding indicated. Recorded max temp of 122°F ~ 924~' MD (8 hfs since -¢'~k~). Plugged back w/Baker-9-5/8" "K" rtnr set ~ 9200'~LM. Fish left in hole: #3 Top 9247', Btm 9354', LIH 107' (X0 - 7'""~"$~'t"bskt - X0 - 8-1/8" boot bskt - 3 jts (93') 8-1/8" WP - 8-3/8" WO shoe); #2 Top 9~26'~ Btm 9672' LIG 46' (X0 - jars - BS - screw in sub - 6-1/4 DC/ ; #1 Top 9~72', Btm 9702', LIH 30' (6-1/4" DC - Bit sub - Bit). Perfd 9-5/8" csg for lower block sq ~ 9080' w./4 Jumbo Jet SPF. Set Baker "K" rtnr ~ 9030' on DP. PU. Broke circ & stung into rtnr. Could not BD fmtn w/3000 psi. PU & broke circ. Stung into rtnr. Press annulus to 2000 psi & DP to 5000 psi w/no bleed off. POH. Perfd 4 JSPF ~ 8805' for upper block sq. RIH w/Baker retrievamatic pkr 1! stds. Attempted to set pkr for tool ck. Could not set pkr, POH. RIH & set new pkr ~ 8780'. Pkr leaking to annulus w/1200# DP press. Released DP press. Press annulus to 2000# w/o press on DP. Held OK. BD fmtn & pumped into perfs ~ 2 BPM w,/1400 psi. P0H w/pkr. Set Baker "K" rtnr ~ 8750'. PU. Broke circ& stung into rtnr. Press DP to 600 psi &circ annulus. Press annulus to 600 psi &circ DP. Rtnr !e~ing. Press DP & annulus to 1600 psi & pumped into fmtn ~ 2-1/2 BPM. POH w/stinger. Stinger OK - no damage. SIH w/bit to DO rtnr. ... TBU K-!O (Redrill) - COOK INLET - (7" liner ~ 13,415') !3,h63' TD, 9030' PBD - RIH w/overshot - MW 9.6#~ Vis 95 DO rtnr in 35 mins & pushed to btm ~ 9030'. Circ. POH. Set. Baker rtnr ¢ 8764' on DA WL. Could not pull rtnr WL setting to~l w/normal pull. Worked WL & pulled up to 5500# to pull out of rope socket. Pulled setting tool loose & SOH. Collar log working to 7000'. WL pulled out of rope socket. P0H w/WL. Left setting tool in hole. Tested Hydrill to 2500 psi & BOPE & choke manifold to 3000 psi. SIH w/overshot to recover setting tool. DRLG. SUPERVISOR A a 3 B-4,C-~2-A JNumber ail dally well history forms consecutively as they are prepared for each well. IP~ge no. AtlanticRichfieldCompany Daily Well History-Interim tnstm~=f~3~s: This form is used during drilling or workover operations. ~f testing, coring, or perforating, show formation name in describing work performed. Num,>er a;l dri;I stem ;ests sequentially. Attach descriotion of ati cores. Work performed by Producing Section will be reported on "Interim" sheets until final com~e{~a. Reoor[ ofhcia} or representative test on "FinaF' form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on WeOnesday ~ ~.~e week in which oil string is set, Submit weekly for workovers and following setting of oil string until completion, . . , District Field Date and as of ~:00 County or Parish ~ .1- ~ c,~?~ ~ .~AS KA KENAi Lease or Unit TP.A~T-~__,~ BAY KING = TRADING BAY UNIT , Complete record for each day while drilling or workover in progress !1-25-T4 13, a~3 ' TD ii-26-T4 11-27-74 State IALASKA IWell no. TBU K-10 TBU K-10 (Redriil) - COOK INLET - (T" liner ~ 13,415') 13,463' TD, 9721' Est PBD - Fishing - MW 9.6#, Vis 55, WL 7.8 FIH w/5"'DP & fish'g tools. Screwed in fish ~ 9589' , failed. to jar lose. Backed off @ #2 DC above bit (@ 9618') & Jarred #2 fish up hole_to 9597'. Failed to circ w/2500#, oil jars failed. Ran string shot & BO ~ free pt ~ top of oil jars ~ 9552'. #1 Fish: TOP 9618' BTM 9647', LIH 29' #2 Fish: TOP 9552' BTM 9597' LIH 45' , , TBU K-lO (Redrill) - COOK INLET - (7" liner @ 13,415') 13,463' TD, 9721' Est PBD - Washing over fish - MW 9.5#, Vis 71, WL 7.4 Backed off fish #2. PU l0 stds. Circ & cond mud. POH. Tightened all conn. Tested BOPE w/3000 psi, Hydril w/2500 psi & manifold w/5000 psi. RIH w/2 jts (65') 8-1/8" washpipe & 8--3/8" scallop W0 shoe #1. Circ in hole f/9052' to top of fill ~ 9545'. CO fill to top of fish #2 ~ 9551' DPM. TBU K-10 (Redrill) - COOK INLET - (7" liner ~ 13,415') 13,463' TD, 9721' Est PBD - Jarring on Fish - MW 9.6#~ Vis ll0 WO fish f/9551'-9614' in 3 hrs. Circ hole cln. Recovered mill cuttings, pcs of DP rubbers & coal. SOH w/washpipe. Pulled to 9.570' w/no drag. Could not circ ~ 9570'. Pulled to 9285' w/excessive drag (jars stroked). Broke circ ~ 9285' &circ hole cln. POH. Pipe drug to 9250' w/no drag up hole. WO shoe #i 100% worn & cracked. Recovered mill cuttings, 4 pins & 2 pcs metal reenforcement f/DP rubbers in boot basket. RIH w/overshot, jars & B. Sub. Washed down f/9453' to top of Fish #2 ~ 9571' (no fill). Engaged fish w/OS. Fish #2: TOP ~ 9571', BTM ~ 9617', LI-H 46' Fish #1: TOP ~ 9618', BTM @ 9647', LIH 29'. !2-2-~4 TBU K-J0 (Redrill) - COOK INLET - ( 7" liner ~ 13,415 ' ) 13,463' TD, 9030' PBD - RIH - MW 9.6#, Vis 115, WL 6.2 Jarred on fish 3 hrs w/400,000# gross. Released overshot & cir. RIH w/3 jts (93') 8-1/8" washpipe w/8-3/8" scallop shoe #2'. Removed all DP rubbers. Circ on top of fish ~ 9571'. WO fish f/9571'-9647~ in 4-3/4 hrs. Fish moved down hole 55' to 9702'. Circ 2-1/2 hrs ~ 9702' until no cuttings or junk over shaker. Circ out 15 gals DP rubber pcs w/some mill cuttings to 4" long. SOH. Tools dragging to 60,000# over wt. PU Kelly. Circ w/1200 psi & plugged off to 2500 psi while working pipe. Could not circ. Stuck washpipe ~ 9354'. Attempted to jar down w/no surface indication that bumper sub was working. Jarred & worked fish to 400,000# gross. Could not ([[~~f~jJ[:~[r~'~:~m'"~'°" ) , -,, ,~--7~7 SOUTH ALASKA DIST. DRLO. SUPERV~Saa A RSB-,.~69--2-.~ I Number all daily well history forms consecutively as they are prepared for each well. no. ', AtlanticRichfieidCompany L Daily Well History-Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Numoer all dritl siam ;ests sequentially. Atlach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Reoort official cc representative test on "Final" form. 1) SuDmit "Interim" sheets when filled out but not less frequently than every 30 days, or (2} on Wednesc~ay of the w~.mek in ;~hic,~ oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Da~e and depm as of 8:00 , J County or Parish SOU~=__ :~.~ASKA KENAI r~, ~ '--~ 7'?]'-... ~ ^ . jLease or Unit _.'R:4~__ ~- ~.~Y KING -.TRADING BAY UNIT Complete record for each day w.ite drilling or workover in progress 11-18- f 4 13,h63' "-'T~ 1t-~9 -74 11-20-74 11-22-74 JState ALASKA jWell no. TBU K-10 TBU K-10 (Redrill) - COOK INLET - (7" liner @ 13,415') 13,463' TD, 9833' PBD - Circ &cond mud - MW 10.1, Vis 110 Tagged cm% top ~ 9833' PBD. Circ &cond mud. Tested 9-5/8" csg w/2500 psi. POH. MIH w/Servco K mill. Cut 15' window .. in 9-5/8" csg f/97!2-9727' w/Mill #1 in 12-1/4 hrs. TripPed for mill. Cut 42' window" f/9727'-9769' w/Mill #2 in 22 hrs. Milled total 57~ window f/9712-9769' in 34-1/4 hrs. Circ · out mill cuttings. POH. RIH w/400'± 3-1/2" butt tbg stinger' on 3-1/2" DP to spot kickoff plug. TBU K-10 (Redri!l) - COOK INLET - (7" liner ~ 13,415') 13,463' TD, 9579' PBD - WOC- MW 9.8#, Vis 53 Circ& cond mud ~ 9833'. Started mixing cmt. Cmt surge tank ruptured w/25 psi. R0 cmt. Shut down 7 hrs & repaired tank. Pumped 20 bbls caustic wtr flush mixed w/10# caustic per bbl followed w/5 bbl fresh wtr. Spotted kick off plug ~ 9833' w/150 sx densified "G" w/l% CFR-2 mixed @ 17.0 ppg. PU to 9579' & RO 3 bbl cmt cut mud. CIP @ 8:30 PM 11-18-74. POH. TBU K-10 (Redrill) - COOK INLET - (7" liner @ 13,415') 13,463' TD, 9721' Est'd PBD - Work'g stuck DP - MW 9.5# Vis 65, WL 7.0 RiH w/bit. Rep' rig brakes. WOC total 25 hrs. Washed f/9462' to top of cmt ~ 9664'. Drld soft'cmt f/9664-9699' & hard cmt f/9699-9715'. Btm of cmt ~ 9715'. Washed to 9721' PU for conn. Worked tight hole f/9721'-9712' & 9679'-966~' (Top of window ~ 9712'). Pipe draging. Stuck pipe ~ 9647' in 9-5/8" csg w/25% returns. Spotted 50 bbt Mica-Gel pill. Plugged off in annulus & pumped into fmtn ~ 3200# w/o returns. TBU K-10 (Redritl) - COOK INLET - (7" liner ~ 13,415') 13,463' TD, 9721' Est PBD - Fishing - MW 9.6#, Vis 55, WL 7.0 Worked stuck DP while waiting on fishing tools. Ran DiaLog free pt. DC's free ~ 9589' DPM = 9548' WLM. Free pt tools failed. Unable to determine deeper free pt reading. Ran back off shot & backed off ~ 9589' DPM. POH. LD 3-1/2" DP. TBU K-10 (Redri!l) - COOK INLET - (7" liner ¢ 13,415') 13,~63' TD, 9721' Est PBD (Btm of fish 9647') - Fishing - MW 9.7, Vis 58, WL 7 0 Finished LD 3-1/2" DP. Found DC's backoff ~ string shot point; #2 DC above bit ~ 9589'. SIH w/screw in sub, oil & bumper jars~ 6 - 6-t/4" DC's while picking up 5" DP. Fish: TOP: 9589'; BTM: 9647'; LIH: 58'; REC: 0 Date JTitle ~__~-.-~--~-~SOUTH[ ~/ ALASKA DIST. DRLG. SUPERVISOR AR3B-459-2-A JNumber all daily well history forms consecutively as they are prepared for each well. JPage no. AtlanticRichfieidCompany Daily Well History-interim ;ns/ructions: This form is used during drilling or workover operations. !f testing, coring, or perforating, show formation name ~n describing work performed. Numoer all drill stem tests sec!uentially. Attach description o{ ali cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report officiat or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. ~Jstr~Ct SOUTH ALASKA Field *~^~V~G BAY Cate and cep,n as of 8:00 11-13 -74 !3,1~6~-. =' TD 11-i4-74 11-15-7'4 ICounty or Parish KENAI L~ase or O~it ' KING - TRADING BAY UNIT istate ALAS KA lWell no. Complete record for each eay while drilling or workover in progress TBU K-10 (Redrill) - COOK INLET - (T" liner ~ 13,415') 13,463' TD,' 11,461' PBD - Circ &cond mud- MW 9.7#, Vis 44 Finished LD fishing .tools. Set Baker retainer on WL ~ 11,878' CBL measure.- RIH w/stinger on 3-1/2" DP. Broke circ. Stung into retainer & BD fmtn w/3000 psi. Pumped 10 bbls into ftmn ~ final rate 1-3/4 BPM w/2600 psi w/no communication w/upper perfs. PU & mixed 185 sx "G" cmt w/l% CFR-2 & 0.2% HR-7. Set back into retainer & sqd 110 sx below retainer. Sq press increased f/1800 psi @ 2 BPM to 2900 psi ~ 1-1/2 BPM. Pulled out of retainer & spotted 75 sx (417'). Plug f/1!,461'-11,878' across "G" zone perfs. PU to 10,943' & RO 20 bbl cmt cut mud. CIP ~ 7 PM-11-12-74. POH. RIH w/bit & 9-5/8" csg scraper to top 7" liner- ~ 10,407'. -. TBU.K-10 (Redrill) - COOK INLET - (T" liner @ 13,415') 13,463' TD,' 9'833' PBD - RIH w/sq pkr - MW 9.8#, Vis 52 Circ & P0H w/9-5/8" csg scraper. Ran DA CC1 f/9400'-9950'. Perfd for block sq ~ 9901' w/4 Jumbojet shots. Set Baker "K" rtnr ~ 985Q' on 5" DP. PU & broke circ. Set into rtnr & BD fmtn w/2400 psi. Pumped into fmtn ~ i BPM w/2200 psi. PU & mixed 200 sx "G" cmt w/l% CFR-2 & 0.2 HR-7 ~ 15.8 ppg. Set back into rtnr & sqd i94 sx below rtnr. Sq press increased f/1600 psi @ 2 BPM to 3200 psi ~ 1.5 BPM. PU 20' & spotted 6 sx cmt on top of rtnr. Top of cmt @ 9833'. R0 l0 bbl cmt cut mud. CIP @ 6 PM 11-13-74. POH. WOC total of 9.5 hrs. Perfd for block sq ~ 9601' w/4 Jumbojet shots. TB~'K-!0 (Redrill) - COOK INLET - (7" liner ~ 13,415') 13,463' TD, 9833' PBD - Circ & cond mud. Prep to mill window MW 9.8#, Vis 58 Set sq pkr ~ 9562' on 3-1/2" DP. BD perfs ~ 9601' w/2800# & pumped 8 bbls @ 1.5 BPM w/2400#. Mixed'200 sx "G" w/l% CFR-2 & 0.2% HR-7. Blocked sqd w/1600# @ i BPM increased · to 2800# ~ 3/4 BPM. PU to 9378' & R0 15 bbls cmt cut mud. CIP-~ 8:30 AM 11-14-74. POH. Realigned derrick. RIH w/bit & 9-5/8" csg scraper to top of cmt ~ 9569' DPM. W0C total 14 hrs. DO firm cmt f/9569'-9579' DPM. RIH to 9800'. DIST. DRILLING SUPERVISOR A R3-B-45~-2-A Number all daily well history for~s consecutively las they are prepared for each well. AtlanticRichfieldCompany L)aily Well History-Interim l~struct~a~ ,'~.:.,$ form is used ourim~ drilling or workover operations, if testing, coring, or perforating, show formation name in describing work performed. Numoer ~t ddtt s~ecm :es[s sc-~uentially. Attach deScription of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final comc~e[i(~. Reoort otiic~al or reorese~iatiwe test on "Final" form. I) Submit "lnte~rim" sheets when filled out but not less frequently than every 30 days, or (2) c~1 Weds'remedy c,f Lhe ~ee¢ tn '~hich oit s/~ing is set. Submit weekly for worKovers and following setting of oil strin§ until completion. Distric~ SOUT~ ALAS F~& Yieid , ii-o8-74 fl-fi-Th JCounty or Parish KENAI Istate ALASKA ILease or Unit ~ I KING - TRADING BAY UNIT ! Compiete reCord for eac~ day while drilling or workover in progress no. w~BU K-10 TBU K-10 (Redri!l) - COOK INLET (7' liner ~ 13,415') 13,463' TD, 12,930' PBD - Ran free point - MW 9.6#,Vis 51,WL 7..8 FIH w/OS. Jarred on fish 1-1/2 hrs ~ 270,000#. No movement. RU DA. WiH w/35' sinker bar & jars. Worked tools f/12,170'- 12,370'. RD DA. RU Otis. WIH w/30' Otis 1-1/2" sinker bar & jars. Could not get below 12,370. RU DA. Ran Dialog free point ~ndicator. Tbg free ~ 11,921' and stuck ~ 11,953' ~reparing to back off tbg ~ 11,92t'. TBU K-10 (Redrill) - COOK INLET - (7" liner ~ 13,415') 13,363' TD, 12,930' PBD - POH - MW 10.1#, Vis 51, WL 6.8 Backed off tbg ~ 11,921'. POH w/fish. WIH w/3 jts wash pipe- & overshot. Washed over tbg f/11,921'-12,009' . Engaged fish. Jarred off fish. P0H w/Wash pipe. WIH w~redressed 4-1/h" overshot. Engaged fish. Jar to 270,000# - no movement.. Ran free point - una~'te to get below 11,985'. Preparing to run sinker bar & jars on DA line. TBU K-10 (Redrilli - COOK INLET - (7" liner ~ 13,415') 13,463' TD, !2 ,930 PBD - Washing over fish ~ 12,110' MW 9.7#, Vis 4h, WL 7.8 Jar on fish w/270,000#. Ran 35' sinker bar to 12,370'. Worked thru bridge ~ 11,985'. Ran free point. Tbg free ~ 12,021'. Ran 2 string shots in attempt to back off ~ 12,0lb'. Backed off ~ 11,985'. P0H w/2 jts tbg (63.05'). RIH w/3 jts 6" OD Tri-state wash pipe. Washed over f/12,009'- 12,015' ~/high drag & torque. P0H w/wash pipe. RIH w/3 jts wash pipe & redressed shoe. Washed f/12,017 ' -12,070 ' · (H~rd fill to 12,065'. Soft fill f/12,065'-12,070'.) Backed off fish ~ 12,014'. POH w/1 perf jt of tbg. RIH w/3 its · wash pipe. TBU K-10 (Redrill) - COOK INLET - (7" liner ~ 13,415') 13,463' TD, 12,930' PBD - LD fishing tools - Mw 9.7#, Vis 43 Washed over tbg w/W0 Shoe #3 f/12,070'-12,095' w/o rotating. Circ& cond mud. WO f.12,095'-12,099' w/o rotating & engaged fish. Fish backed off w/10 rds torque w/o backoff shot. POH. Tightened all DP jts. Recovered 3-1/2" 'Butt collar. LD washpipe. RIH w/5-3/4" x 3-1/2" OS. Engaged fish @ 12 ,001'DPM= 12,015' WLM. Torqued DP for backoff ~ 12,093'+-. DP backed off 8 stds f/surface w/o backoff shot. Screwed into fish & POH. Recovered 14' 3-1/2" tbg. twisted off on btm end. 'Btm 2'+_ of fish was half shaved off, split & twisted. Top of fish ~ 12,015' DPM = 12,029' WLM. Thawed out choke & kill lines. Tested upper & lower Kelly Cock, stand pipe & Mud lines to 5000 psi w/clear wtr. Tested BOP & wing vlvs w/°000, ~ os~. Tested Hydril to 2500 psi. Displaced manifold % ...... ~ '; ~' ~'E .~-.r /~_'!. -,~-r,~l ~.~.~- ~ SOUTH AK. DIST. DRILLING SUPERVISOR I Number ail daily well history forms consecutively as they are prepared for each well. AtlanticRichfieidCom pany Daily Well History-Initial Report Instructions: Pr~oare and submit the "Initial Rel>ort" on the first Wednesday after a well is spudded or workover operations are started. Daily wor~ prior to spudding should be summarized, on the form giving inclusive dates- only. District SOUTH 'ALASKA TRADING BAY Auth. or W.O. no. County or Parish - - KENAI Lease or Unit KING-- TRADING'gAY UNiT Title .. K-lO (21-19) REDRiLL Operator . ATLANTIC RICHFIELD COMPANY4''' sp~d~;~'o~W. 01 ~g~". 'i~ ~ 10/31/74 .. ,, , ,., . , ~.,. , .~ ii-0i-74 11-04-74 l!-05-T4 11-06-74 IHour 3 PM JStat6 ,, ALASKA IA.R.Co's W.I. 12.9% Prior statu~ i'i a W.O. ..,.. :: . ... TBUi[K-iO (Redrill) -COOK INLET- (7" liner @ 13,415') ,-13,463' TD, .12,930' PBD Perf tbg - MW 9.5#, Vis 60, WL ~i :~ii~i::Began moving rig f/K-12 ; 6 PM 10-30-74. Move completed ]iii('~'./10:30 10-30-74. ~RU & mixed..-fresh wtr gel mud. 'Commenced '.j~..operations~:.~?(~3 PM 10-31-74. Installed & tested lubricator . !--!."7:w/5000 psi+-PUlled'-.ball vlv." Bled off tbg & csg press. ' TBU:E-!0 (Redrill) -COOK INLET - (7" liner @ 13,415') ~ -]ji'~13.,463' TD,~-12,930' PBD- POH.w/compl assy- MW 9.5#, Vis 51 '.Perf gun'-.differentially stuck after perfg tbg ~ 11,630'. Equalized.press on annulus w/gas. POH w/gun. Killed well. ND -~.:~tree. NU BOPE. Pulled tbg hgr. Attempted to pull compl assy. /~:~';/~kr stuck..~/Worked pkr to 285,000~ gross (141,000~ net) while :~J/~'~iting on~"~free Point indicator. 3-1/2" tbg butt pin ~arted '~'~[~.:62' below'~ Surface. Engaged fish w/overshot on 3-1/2 DP. RIH w/free .point & collar locator. Tools stopped ~ 6711' WLM. POH. RIH w/collar .locator & sinker bar to 12,190'. Worked too s t ru 0. 00' free pt & collar locator w/additional 15' sinker bars .to 11,730'. Free pt indicated top pkr partially stuck ~ 11,645' & tbg partially stuck ~ 11,725'. ~0H. Released .~-.:~overshot & ~POH w/3-1/2" DP. Reran overshot on 3-1/2" tbg. :/~Engaged fish.~. RIH w/3-1/2" jet tbg cutter & cut tbg '~ 11,659' WLM. (14' below top pkr). Pulled 2 its & LD overshot. Circ btms up. SOH w/30,000~ net drag. TB~ K-10 (Redrill) - COOK INLET -.(7" liner ~ 13,415') · .~_!3',463' TD,..12~930' PBD - RIH w/Globe Basket - MW 9.5~, ///Vis, 5[, WL ~T.5 -POH w/WL -left sinker bar, collar locator & tbg cutter in hole (8'-). P0H & LD 3.77 jts 3-1/2" tbg, SV, 10GLV & Otis RH pkr w/!4' tbg tail. (Top 3-1/2" tbg fish ~ 11,659'). Visual inspection of tbg showed no scale inside. Tested BOPE (Rams w/3000 psi - Hydril w/2000 psi). GIH w/5-3,/8" Globe Basket (dressed for 1-11/16" inside catch w/8' 'extension on 3-1/2" DP) to recover collar locator. TBU K-10 (Redrill) - COOK INLET - (7" liner ~ 13,415') i3,463' TD, 12,930' PBD -GIH w/3-1/2" OS - MW 9.6#, Vis 51 WL 7.5 Circ & cond mud. Tagged top of fish ~ 11,646'. POH. No recovery. RIH w/3-1/2" ID overshot w,/8' extension. Dressed off too of fish. Latched onto fish. Slipped off fish. POH. -- Redressed overshot. RIH w/3-1./2" ID overshot. Tj:~,--~ove is correct ' ' / -' A R31~-459-1-B ..-... JNumber all daily well history ~orms consecuti, vely Page no. '~' ':~ r Ias they are prepared f°r each well' I 1 ' JOB No ~,~ ,11-11-74 DATE REPORT 'and PLAN of. SUB-SURFACE SURVEY ) King K-10 (Redrill) O P, I F, I N A 1,,-22,r75 .......... COMPLETiON'REPORT ...................................... ATLANTIC RICHFIELD OI-~-CO. -- TRADING BAY MAGNETIC S/SHOT SURVEY BY ADDCO K B ELEv'_ 100 FT, TANGENTIAL_METHOD-OF COHpu~AT]ON_'BYF-. UNZT -10 .EDRXLL ...................................... ........ DECLiNAT~ON-_~i'24__DEGREEs~ M. LINDSEY $ ASSOC. RECORD OF SURVEY .... -ALL -~AI~UL-ATZONS PERFORMED BY. Z B M ELEcTRONIC--coMPUTER~ HE~-~---~R-iF~-.-VERT[CAL __ SUB__ DRIFT ...... TOTAL cOOR-D[N~ATEs~ ........ ~ I~--0--$-'~'~--E-'-~_- ....... ~EVER[T% ...... SECTION_ DEPTH ANGLE .... DEPTH ....... SEA _.. DIREC ............................... DISTANCE _ ANGLE.. DEG/~OOE~_ ...... DISTANCE ......... D ..... ~ .................................. DEGe ....................................................... D .... M _~ 8835. 45.~0 6417,14 6~17,14 S 87 ~ 1519,60 $ 5415,46 W 562~.63 S 74 19 ~2_W .... _..9022__~0_ 0 6560.39 6460.39. S 82 W 1536.33 S 553~,49 W 5763,77 S~ 74 29 920&~37 ~5. 6705,87 6605.87 S 84 W 1548.11S 5646.52 W 585~.90 S 7~ 40._ 9~16 37__0 6873,59 6773,59 S 8~ W 1561,32 S 5772,21W 5979.6~ S 74 5I_51.W 9680 ~5 15 7089.18 6989.18 $ 86 W 1571.95 S 592~,21 W 6129.21 S 7~ 8 21 W 9964 ~ 45 7~22,5B 7222,5~ S 86 ~ ~58~,2~ S 6085,6~ W 6288,27 S 75 25 2_~ 10055_~4 0 7~97,97 7297.97 $ 82 W 1590,~2 S 61~6,08 W 6~B8.82 S 75 Z8 ~2 W 10213 B&._ 0 7525,80 7425,80 S 79 W 1608,04 S 6227.25 W 6~B1.52 S 75 B1 15 W 10473' 31 15 7748,07 7648,07 S 82 W 1626.81S 6~60,81~W- 6565,55 S 75 ~9~15 106~ 32 45 7896,10 7796.10 S 72 W 1656,2~ S 6451,37 W 6660.57 $ 75 ~6 5 W 10818_ 32 ~5 8038,23 7938e23 S 73 W 1682.97 S 6538,80 ~ 6751,91 S 75.33-58 11016 ~2 30 8205,22 8105,22 S 72 W. 1715,8~ S 66~9,97 W 6858,09 S 75 30-~9 W ..... 11137 ~2 15 8~07,56 8207,56 $ 72 W 17~5,79 $ 6701.38 W 6922.54 $ 75 28 ~2 11386 ~2 30 8517,56 8417,56 S 7~ W 1772,67 S 6829,99 W _ 7056,28 S 75 27- 1153~..32 15 8642,73 8542,73 S 76 ~__ 1791,78 S 6906,62_~.. 7135,25 S 75 27 23 ~ .... 11770 31 15. 88~4.49 874~.~9 S 77 W 1819,32 $ 7025,91W 7257.6~ S 75 28 56 12109 30 0 9138,07 90~8,07 $ 80 W 18~8,75 S 7192,8~ W 7~26,62 S 75 3~_ 1233~ 31 30 9329.91 9229.91 S 80 W 1869.16 $ 7~08.61W 75~.84 S 75 ~9 15 W- . 12822 33 0 97~9,19 96~9,19 S 76 W 193~,46 S 7566,50 W 7809.62 S 75 ~g 57 5560.12.. ~.454 ...... 5742.55_ 1.400 ...... 585~,01 0,35~ ..... 5979.05_ 0.799 .... 0.176 _ 6288'2~- 2.61~__ 6338.7B~ ~.670 ....... 1,935 ..... 6565.55- 3.126 --- 6660.5~- 0,320 .... 0.300 ....... 6858.06- 0.207 -- 6922.50. ~0,4~2 ...... 7056.23- 0.74~ ...... 7135.20. 0.479--- 7257~6~_ 0.582 ........... 7~26.62- 0.667 ....... 0.534 ....... 7809.62 iNTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CEOSURES FOR GIVEN DEPTH~ .................................. TRUE CODE ....... MEASURED-. VERTICAL ...... TOTAL COORDINATES .......... C L O $ U R E ............. SUB' NAME DEPTH ...... DEPTH ..................... DISTANCE ...... ANGLE ...... SEA- ...................... D ......... HEASURED TRUE ..................... VERTiCA~ ~UB , HD-TVD_ DEff~H DE~_H~SE~_ _D [ F~.ERENCE ..... _C~RRE C TZON .......... TOTAL_ COORD [NATES 27 15~7.63_ S 56~1.99~ ...... !199 6700 .___6600 ,_ _ ~2~99 ............ 9_~8 ............... 6900~ _6~00 · 25~8 9571 7000. 6900~ .... 257k 9693 ..................... 7100 ~_.._~000, 2593 ................... ........... !8_15 7200. 7100~_~_.'261! ........... 9937 10058. 10181__ 7500. .... 7400._ 10300__ 7600. .... 10417 ........ 7.700. 7600._. 1053f ....... 1065½ __ __7900,_.7800._ 10773 8000.__.7900. 10891 ........... 8100._ 8000, ___.llOl~ 8200. 8100. 11128 8300, 8200. 11247 8400. 8300. 11365__ 8500, 8400. ......... 11483. 8600, 8500, 11601 8700. 8600. 11718 8800, 8700. 11834~ 8900, 8800. 11950 9000. 8900. 12065 ..... 9100, 9000. 12182 9200. 9100. 12299-- ........... 9300. 9200. 22 1582.15_$_ _ 6070.10_~ 2681 ............... 23 ............... 160~.47 & 6208.84--~ 2700 .............. 19 1614.~1 $ 6271,83___W_ 2717~ ....... : ........... 17.___ 1622.75 $.._ 6331.92_~-- 2735 .............. 18 ............ 16~7.15 $ 6392.58_~ 275~ ............... 19 .............. 1656,97 2773 .................. 19 ................ 1675.77 & 6515028._~ 2791 .............. 18 ............... 1695.12 $ 6576.22__~_ 2810 ............... 19 ................. 171~,81 $ 6636.81 2828 .............. 18-- 17~.~a 28~7 ............. 19 .............. 1752.03 2865 18- 176~.59 S--- 6819.2~-~ 2883 .... 18 ............... 1785.25 $ ..... 6880.~5-~ 2901 ............... 18___' ....... 1799.59_.$_ 2918 ................. 1[_. 1813.2~ 293~._ 16 ............ 182~.88 S._. 7057.~7._W~ 2950 ' 16 ........... 1834.91 2965 ............. 15 ............... 184~,93 2982 .............. 17 ........... 1855.34 S 7230.20 '2999 .......... 17 ............. 1865.98 7300,__7200,___2637__ 7400, .... 7300e~._2658 iNTERPOLATED VALUES FOR EVEN lOOO FEET OF MEASURED DEPTHi .... MEASURED ..... VERTICAL _.. SUB ......... DEPTH---- DEPTH ..... SEA--- TOTAL COORDINATES ......... 9000 ......... 6543. 6443. ..... 153~.37 $ 5520.~9 ........... 10000 ........ 7352. 7252. t586.0~ S 6105.63 ......... 11000 .......... 8191. 809I. _ _ 1713e18 $ 6631.80 ....... 12000 ....... 9063.~ 89~3. 1839.29 $ 7139.16 HORIZONTAL VIEW SCALE 1"=50Qt- '' ATLANTIC RICHFIELD COMPANY-- TRADING BAY UNIT K-lO, REDRILL~ TANGENTIAL METHOD - T.V.D.: 9,739 ...... ~ T.M.D.: 12,822 ....... ~ , ,% ,, ~"',,j: , , ,., , J ,, ~ . ~ , ,. ~ , . ~ % ~ ,' . '. ~ ~. ' . , . . ~ '.~ i : . ~ , . , .~ , . , ~ ~ ~ ' :'- i',. :'~.j. ' .... : : VERTICAL SECTION , ) ,' ' , ' : ' : J N , : . , t ', . J . ' _' ~ ~ ~. '. ~J SCALE : I : I000 ' ' :: * ' ' ', ~-'-~ :-'N-: :.-:" ~-~'-~-~"-~ .... ~-I--~-,~' -i ....... '~ ~,~,.,~ ~,~,~,~'~o~,~ --. ~.-'~'.. . . m.~~d .I_:_.'/i.N , . . ', ' ' . , , . ~~~~ ~' ,~, ~' ~ , , . ~ .... i', ~~ -',~ ~ , ', , ~~ - ~ ~' ~ ' : , ~ ' , r : ~j .... F' .. . , . , . . ~ ' ' ' '* ' n I ' " ' ~ ' ' : ~'" ' ' ' J ' ' 600 , ~ , I ' , I I ' ~ ' I,' ' ' I ' ~ ' J ' ' ) 8400 ' , J , , ' ~, i, i ~ ' , ,, ~ ' , 8800 - ~-~ '~1 .....~ .... ~ ......... ' ": ': - ' ......... ~ ' ' 9000 _COMPLETION REPORT ........................... JANUARY 15~1975 ATLANTIC RICHFIELD OIL CO~ TRADING BAY.UNIT K-10 REDRILL ,MAGNETIC S/SHOT SURYEY BY ADDCO .............. *" -. -K B ELEV, 100 FTc ........................................... DECLINATION 24 DEGREES -RADIUS OF CURVATURE METHOD OF COMPUTATION BY F, M, LINDSEY $ A$$OCe ....................... ...... ALL '~ECU~iiON$ PERFORMED BY ~.B M ELECiRONI¢ COMPUTER .......................... ....... - ........................................................ ' - DOG LEG TRUE -NEAS.-DRIFT VERTICAL ~ -PTH ANGLE DEPTH SU-~ .... -~-~-D-~-~ ..... /~-OTAL COORDINATES --C L 0 $ U R E $ ---SEVERITY .... SECTIO:. SEA ., DIREC ........................... DISTANCE ~.ANGLE ..... DEG/~OOFT ....... DISTAN' ........................................ D H- -S S 5~51,~6 W 5562,02 S 7~ 10 ~9 W ' 1520,19 $ 5~15e8~ W - -5625e15 $~ 7~ 19 15 W 1532e35 S 5542e10 W 5750e0~ $ 74-32 ~9 W t5~6,42 S 5656e7I W 5864e28 S 7~ 42 ~6 W 1559e74 $ 5783,49 W 5990e12 S 7~ 5~ 25 W 157~,31 $ -59~8,52 W 6l~e~O S 75 9 40 W 1584e67 S 6101,02 W 630~,46 S 75 26 2~ W 1590e04 S 6152ell W 6354,26 S 75 30 31W 160~e99 S 62~1.~7 W. 6~4~e5~ S 75 3~ 43 1628,75 S 6~8~,~2 W 6587e93 S 75 ~1 10 W 16~9,70 S 6~74e18 W 6681e05 S 75 42 16 W -1677~19. S 6561e~7 W 6772e~4 S 75 ~9 40 W 1709,29 S 666~,18 W 6878,92 $ 75 3~ 4~ W 1729e~1 S 6724e79 W 694~e59 $ 75 ~4 ~2 W 1768~29 S 6852e29 W 7076,78 S 75 B1 47 W t788~80 $ 6928,85 W 7156e02 S 75 ~1 26 W 1817e79 S 70~9,59 W ~--7280e18 S 75 ~2 26 W 1852,22 S 7218,79 W .7~52,63-$ 79 ~6 ~3 W 1872,19 S 7~32~08 W 7~67,~3 S 75 ~0 ~ W 1926e~2 $ 75~6~7~ W 7827e47 $ 7~ 45 11W ~-8835 45 90 6416~71 6916,71 $87,00W ---9022 40 0 655~e98 6453,98 S82,00W ,,9206 ~7 ~5 6697e22 6597e22 S~,OOW ..... 9~16 ~7 0--686~e10 676~e10 $84,00W ---9680 35 15 7077e33 6977e33 566,00W -- 9964 9~ 45 7~09e97 7209e97 SSSeOOW 10055 3~ 0 7385,08 7285,08 582,00W ~10213 36-0 ...10473 3~ 15 7730,93 7630,93 ..106~9 32 ~5 7880,Z9 7780,Z9 572~00W _10818 32 ~5 8022,32 7922,32 $73eOOW ~1~0~6 32 30 8189,08 8089,08 572~00W -'~137 32 15 8291,27 8~9~,27 572,00W ~ ~386 32 30 8~0~,57 8~0~,57 574,00W -1153~ 32 15 8626e56 8526e56 S76eOOW -11770 31 15 8627,2~ 8727e24 $77e00~ -12109 30 0 9116,95 9018e95 $80eOOW 12934 ~1 ~0 9312e31 9212e31 SSOeOOW -12822 ~? 0 9725e02 9625,02 -BOTTOM HOLE CLOSURE 7827,~7 FEET AT $ 75 45 ii W OEO00 -5559e9 3~362 ___57NSe7 ...1,~8~ ........... 5863~3 ..... 0,357 ........ 5989,~ .... 0e789 ..... 61~3e¢ O~lT& .... 6303,~ 2,570 ..... 6354,2 W --le706 ..... ..... legll ......... 6587,9 3e252 ...... 6681,0 ~-.0e320 .... 6772.3 ---0,298 .- 6878*9 0,207 ---69~3,5 0,738 ........ ~155,9 -0e667 ..... 7567,3 0~550 -- MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF $U8 SEA DEPTH. ....................................... TRUE .................................................... NEASURED .... VERTICAL' SUB-- 'MD-TVD- DEPTH .......... DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES .............. .... 8950 ~ 6500* 6400 .......... 908~ ......... 6600, 6500 ....... 9209-- 6700, 6600 ......... 9335 ............ 6800, 6700 ........... 9461 6900. 6800 ......... 9585 .......... 7000, 6900 ......... 9708 ............. 7100, 7000 9830 ............. 7200. 7100 9952 -7300.-- 7200 10073 7400, - 7300 ..... 10195 .......... ~ 7500* 7~00 10317 ......... 10437 .... 7700, .7600 ......... 10554 ....... 7800, 7700 ........ 10672 ............ 7900, 7800 -- ...... 10791 ....... 8000, 7900 ...... 10910 ........ 8100, 8000 ........ 11029 .......... 8200, ~ 8100 ......... 1114~ ......... 8300,_ _8200_ 1126& .... 8400, 8300 11384 8500*_ 8~00- 11502 .......... 8600, 8500 11621 ....... 8700, - 11738 -8800, 11855-- 8900, 1'1971 9000. 1208~ .... 12203 9200,.. 12319 9300, 12~37 9400, - 2411 ' 2411 1519.26 5 2450 .......... 39 -- 1526e-~8--'S 8600- 8700 8800 8900 ~000- 9100 9200 2482 .............. 32 -. ...... 1537,44 $ 2509 ........... 27 ............ 1546.61S 2535 ........... 26 ....... 1554.63 S 2561 ........... 26 .......... 1562,48 5- 2585 .......... 24 ....... 1569.12 S 2608 ........... 23 ....... 1574.42 S 2630 .......... 22 ............. 1579.32 S 2652 ............... 22 ............... 158~,19 S 2673 ............ 21 .............. 1591.~7 2695'- "' - -22 ......... 1603,02 2717 ............~--- -22--?:-: .... 2737 .......... . .... 20 ......... '1626.07 S 2754 ................. 17 .............. 1636,34 2772 .............. 18 ........ 1653,53 S 2791 .............. 19 ......... 1672,90 2810 ........... 19 ......... 1691.91 5 2829 ............. 19 .......... 1711,~ 5 28~7 ............... 18 1730,96 2865 ...... I8 ............ 1749.97 288~ 19 ......... 1768,00 2902 ............... ~8 ............... 1784,60 5- 2921 ...................19 .............. 1799,79 5 .... 2938 1~ .......... 1814,05 S 2955 ............. 17 .................1827,38 2971 ............ 16 -.~: ~--- 1839.47 S- 2987 ............. 16--.--m~...: ......_ 1850,30 3002 ........... 1~ ........... 1860,46 5- 3019 ........... 17 1870,84 5 3037 ............. 18 ............ 1881,98 $ 3054 ............. 17 ........... 1894.26 $_ 3073 ............. 19 ........... 1907,74'S-- 3092 .... 19 .... 1922e43 9300- ........ 12555 ................. 9500, .... 9~00 ..... 12673 ......... 9600.-- 9500-- ....... 12792 ........ 9700. 9600 5398.79 5~95.48 5579,87- 5658,54 5810.25 5883.39 5954.48 6094mll 6162,10 6~31,11 6300.47 6364,60 6425,16 6486,01 6547,41 6608.83 6669.79 6729e87 6?90.3'9' 6851e26-~ 6912,27 6973.51-~ 7033,~4 7150,59 7207.99 7265,51 7324.38 7385.25 7508,~-W 7570,89 I N T E R P 0 L.A T E D i~AL-UE-S--FO R--E V-EN_-i °"~- FEE-T' ........ ~EAsURE{~ ..... VERTICAL SUB :_'_-___' .... 'DEP_TH___"_':_-.-_'-_'._:__ DEP. TH L.-:_,_-_,:'___ SEA:..._.~ 10000 ........... 7339, 7239,_ 1586.38 S 11000 .8175, .... 8075e ........... 1706,64 S ............. 12000 ............ 9024. 89~. .... 184a,26 S 5528,00 W ....................................................... 6121,39 W ......... : ...................... 716~+,87, W 'VERTICAL SECTION SCALE: I"= IO00' ATLANTIC RICHFIE:LD COMPANY ' TRADING BAY UNIT K-lO, RE:DRILL RADIUS OF CURVATURE ME:THOD too 9,725 , ~ - : , .'" _~ .~- HORIZONTAL VIEW _ ' ........ _" -_ ...... ....... . ...... ........" y" -~"'.-~ ' SCALE I =500 - : .... '- ATLANTIC RICHFIELD COMPANY _ . ' ' ' -' i- ; TRADING BAY UNIT K-lO, REDRILL T.V.D.= 9,725 j' '-: - ._._~ ...... ; ..... ; ................. ORIGIN'AL REPORT of SUB-SURFACE DIRECTIONAL SURVEY ATLANTIO R I~T-1T~ TET.TI COMPANY TRADING BAY K-lO REDRILL WELL NAME COOK INLET LOCATION JOB NUMBER AM0175 G-01 'I'Y, PE OF SURVEY DATE January 14, 1 ~. SURVEY BY Jack Henderson OFRCE Alaska COMPLETION REPORT FOR TRAD]NG:-OA~ _TANGENTIAL_COMPUT~TIO~ .__6¥R05C0~IC SUEVEY ............................. ~-': ...................K B ELEV._.IO0_ F~ ~ RECORD-OF '6URVEY ~ -' ~)-'- ...... ALL-Ci-LCUL~Ti'ON$'-_:PERFORMED BY I B Fi ELECTRONic coMPuf'~R_- ---:- TRuE DOG_ LEG_ :-~-ETA~;--'_-~RI#'J'-__-VERTIC,~:~-.:-:__.'-_--,~B .... DRIFT ....... TOTAL-~OORDIN~A:TETs ...... C L 0 S_U R.E $ SEVERITY ...... SECT_I_ON_ DEPTH ANGLE DEP,T.H~ .... ~_EA~ ._.. DZREC .................................... DISTANCE ...... ANGLE __~500_~6 _30._6185.36.. 6085.3.6 .... ___8600__~__0__.6256.07_ 6~6.07___S__85_~ . ..8700_~5~_0 .... 6326.78 6226~78 .... 5..86 __.8800_~ ~.0__639?.~9._ 629~.~9 ._ 5_82 .... 8900_62_0_ 6~71,81 6371,81 'S 82_~ .... 9000_~0 0 65~8.~1 6~8.~1_._S 85 .... 910~_39 30 6625.57 6525,57_S 9200 38 30._6703,83 6603.83 _$ 83_~ ..... 9300__38' 30 6782,10 .... 6682,10 ..... __.9~00_.3!_0 _6861,96_.6761,96 ._$ 87_~ _. 9500__t7__0_'69~1,82._ 68~1,8~ 960~ 36__0_. 7022.72 6922.72 . S 86 _ 9800 35_15___ ?~86.0~_..?086.05__$ 9900.35. O_ .7267.97. 10000 36 15_ 7348.61 10100 38_ 0 _.7427.&1 7327.ql 10200 38 15 7505,95 7~05695 10300 36 O_ 7586,85 7486.85 10~00 32 30_ 7671,19 7571,19 10500 32_45. 7755,29.._7655,29. 10600 3~ 15_ 7838.92 77~8.92 7167.97_ S 83.~ 72~8.61_ S 82 ~ S 80g $ 80W S 79._W $71~ 1636,11 S 1642,27 16~7,20 1657,0~ S 1666,36 1671,96 $ 1679,71 S 1687.30 $ 1693.80_S 1696.95 S 1701,15 $ 1705,25 1709.28 1711,29 1718,28 5 1726,51 $ 1737,20 S 1747,95'$ 1767,57 S 1782,~8 S 1800.3~ S 51~1,38 W 5395,~3 5.72 20 _51_W 1,772 ...... 5392,76 5211,82 W _ 5~6~,~4 $_72~30 36_~ ...... 1,50~ ...... 5~62.~Q 5282,~6 W _ 5533,23 S_72~0.51_~,_ 0,707__ ..... 5531,A~ 5352,38 W 5603,01 S 72 ~7 52.W ...... 2.828____ 5601,~ 5418,6~ W 5669,08 S 72 5~ 21_.~ .... 3,000 .... 5667 ~ 5482,67 W 5731,9~ S 73' 2_26 W 2,806 ....... 5736 554~.81N 579~.60 S 73 8 58_W_~.. 1.3.7~ .... 5795t7~ 560?.60 W_ 5855.95 S ?3 15 13_~ .... 1.000 __ 5855.2i 5669.51W 5917..12 S 73 21, 57. W ..... 0.623 ........ 5916.56. 5729.61_W_ _ 59?5.62 S 73 30_ ~ W_ _ _2.37! ...... 5975.2~ 5789.6~ W .... 603~.39 S 73 37 32_~ ...... 0.602 ..... 603~.1~ 58~8.28 5905.85 5963.53.W 6020.46 6079.01 6139,65 6200.61 6258.31 6311.38 6363.38 6415.23 6091,82 S 73 ~ 39_W .... 1,000 61~8.23 S 73 51 30. W .... 0,750 .... 620~,21 $ 73 59 lg_W ..... 1,15~ 6260,8.7 S.7~ 4 15 W 6319.4~ S 7~ 8 ~1W_._ 6380.68 $ 7~ 12 6 W 6~2.28 S 7~ 15 2½ W 6500.86 S 7~ 17 58 W 6554.23 S 7~ 21 16 W _ 6608.32 S 7~ 21 5 W 6663.06 $ 7~ 19 26 W 6091,6~ __620~e_18. 2,887 .... 6260,8~ 1,379 ...... 6319,6~ 2,126 ..... 6380.68_ 0,250__ 6~2,2~ 2,329 ....... 3'676 ...... 3,781 ........ 6608.2& 1,709 ..... RECORD OF SURVEY ...... ~ ALL CALCULATZONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE DOG LEG MEAS. DRIFT VERTICAL ..... SUB DR-iFT ..... T-0TA~.-co0RD~-t~Es_L___ c L O $ U R '~ S~- .... sEVERITY ........ SECTION_ DEPTH ANGLE .... DEPTH' SEA .... DiREC ................................. DISTANCE ..... ANGLE ._ DEG/iOOFT---- DISTANCI ~ D_M .... DEG. ........... DJ M--5 -10800-~.. 0 8006.~7_ 7906,~7. S 72 ~ ~8~.30 S 6519,81.-W-- 6772.66 S 74 ~7.-40--~ ..... 0.7~2-- --6772,6~ 10900 33 15 8089,80 7989.80 S 71W 1851.15 $ 11000-33- 0 8173,67 8073,67-S 72 W 1867.98 S 11100 33-,0- 8257.54-8157.54-- S 74 W_ 1883,00 S 11200 33-_ 0 8341*40 8241,40- S 74 W ~- 1898,01 $ 11300 33-O 8425,27- 8325,27- $ 72 W 191~,84 S 11400 32.15_ 8509,84- 8409,84 5 72 W 1931,33 S 11500 32. 0 8594*65 11600 31-45- 8679.68 ..11700 31 45. 8764.72 11800 31 45 8849.75 .11900 31 30 8935,02 12000 31 15 9020,51 12100 30 15_ 9106,89 8~94.65 8579.68._S 72 W 8664,72 ~ S 72 W-- 8749,75 $ 71W 8835.02 S 75 W 8920.51- $ 75 W 9006.89 .S 76 W S 72 W __ 19~7,70 S 1963,96 $ 1980,23 S 1997,36 S 2010*88 S 202~,31S 2036m~9 S 6571.65 W 6827.~0 S 74 l& 5 W .-- 0,601 ....... 6827,38- 6623,45 W 6881,82 S 74 15---0 W ........ 0,601 ........ 6881,89 6675,80 W .... 6936*28 S 74 14 53 W ...... 1.089 ..... 6936*27 6728,15 W 6779,95 W 6830.70 W 6881,10 W 6931.15 W. 720~.02 S 74 10 46 W--- 0,250--- 6981,19 W -7256.61 $ 7~ 9 50 W --- 0.000 7030,9~ W 7309,15 S 74 8 28 W___ 0.526 ?08i,~2 W_ _ 7361,39 S 74-8 50.-W .... 2,112 7131,53 W 7~1~,27 $ 74- 9 11W - 0.250 7180,~1 W_ 7463,62 $ 74 g 56 W._ 1.123 6990.74 $ 74 14 46 W~, 0.000 ....... 6990*73- 7045,17 $ 74 13-43 W -- 1,089-----70~5.16- ?098.49 $ 74 12.43 7151.~ S 74 11 ~4 W 0.250 ...... 7151,~ 12200 31_.0. 9192,61 9092.61__.S 76 12300 31_30__9277.87_ 9177,87 .... S 74 W_ 12400 32. O_ 9362,68._. 9262,68. S 12500 33-15---9446,3l_ 9346,31 S 73 W -12600-33--0--9530,17- 9430,17- S 12645 33 0--9567,91 9467.91- S 73 12685 33___0 9601,46 9501.46 S 73 W 7204,02- 725~ ~ 730~.I~ --7361*3~ --7413,2~ 7463,6~ _BOTTOM HOLE CLOSURE 2048,95 $. 7230,38 W_ 2063,36_S 2077,96 S_ 2093,99 S 2110,82 S 2117,99 S 212~,36 S 7515,09 S 74 10_41_W .... 0,750---- _7280,61. W . 7567,34 S--74 10 37_W__ 1,152___ 7331,55 W 7620.34 S 7~ 10 32_W .... 0,500 7383.98 W 7675,15 $ 7~ 10-- 2-W .... 1,361---- 7435e78 W --7729.58 S 74 .... 9--.7-W ....... 0.601 7459,22 W 7754,08 S 74 8 54 W .... 1,210 7480,05 W 7775,86 S 74 8 ~2 W _ 0.000--- 7515,0~ .7567,3~ 7620,3.3- 7675,1~ -7729,5~ 775&.08~ 7775,86- 7775,86 FEET AT S 74 8 42 W ................................................ .... ~-i~-T-~R'~-(~EA-;rE~-~-~Ru~- ~/-ERT ! ~:~,~'--DEP 1~$; -~oRD~ NA~'E-5 A~D CLO~R~-5 ~OR-'G [vEN DEPTH5 TRUE NAME ~ DE?TH ......... DE~TH ..................... DISTANCE ..... ANGLE_ SEX NEASUR~-'D-DEPTH AI~)-~-T-~E-~"~.-~A-~'OR--E.'~-E~-~'-EvE-I~-'loo FEET OF ,SUB SEA DEPTHe ................................... TRUE .................................................. _~. MEASURED ..... VERTICAL' SUB .... MD-TVD ...... VERTICAL ......... DEPTH DEPTH SEA DIFFERENCE ..... CORRECTION ......... TOTAL COORDINATES- 8521 ............. 6200.. __ ........ .......... 8662 .............. 6300. 6200, 8803 .... =--. 6400, 6300, 8937 ....... 6500, 6400, 9067 ...... 6600, 6500, 9195 ......... 6700, 6600, 9322 ......... 6800, 6700,. 9448 ......... 6900, 6800,. 9572 .............. ?000, 6900, 9695 ....... 7100. 7000, 9817 _.. 7200, 7100, 9940 ....... 7300. 7200, 10065 10192 10316 10434 10553 10673 10793 ....... lO91Z 11031 1115! 2362 ................ 41 2403 ......... 41 243Z ......... 2467 2495 2522 ............. 27 2548 2572 259'5 2617 2640 7400._ _7300,__ 2665 7500,_.7400, 2692 7600, 7500, 2716 7700, 7600, 2734 7800, '7700. 2753 7900, 7800, 2773 8000, 7900,__.2793 8100.._ 8000,_..2812 8200. 8100, 2831 8300,_ 8200,_._2851 ........ 11270 .............. 8400, 8300, 2870 11388 ........ 8500. 8400. 2888 11506 8600,- 8500,- 2906 11624 ...... 8700._ 8600, 2924 11741 ...... 8800, 8700, 2941 11859.__ 8900. 8800, 2959 11978_. ' 9000, 8900, 2976 12092 ....... 9100, 9000, 2992 12209 ....... 9200, 9100. 3009 12326._. 9300. 9200, 3026 12445 .... 9400, 9300, 3045 12564 ....... 9500. 9400. 306~ 24 23 22 25 20 ...... 20_ .19 19 20_ 19 18 1'8 18 17 18 17 16 17 17 19 19 1615,33 1657.36 1668.42 1677,14 1686,92 1694.51 1698.95 1704,10 1709,06 1712.48 1721,55 '1733,48 1747,14 1760.48 1772,68 1792,03 1812,15 1832.06 1853,20 1872.70 1890,60 1909,77 1929,41 1948e73 1967,85 1987.33 2005,33 2021,09 2035.52 2050.20 2067~17 2085.12 210~.77 $ $ S S $. $ $ 5255,63_~- 5354.61 5442.20 5604.56 5682.98~ 5758.20 5831.80 5902.75 5973.22 6043.7~ 6118.55N_ - 6196,00 6266.59 6329,19 6391.10 W 6453,88_~ 6515,99_~ 6577.94~_W_ 6639,88__~___ 6702.30_N_ 6764,34. 6824,79 6884,25 6943.10 W~__ 7001,83 7060,69_W 7119,50 7176,50 7234.73 W__ 7293.89 735~.94 W 7417,14 .W ............... ..TRUE .............................................. . ~SU~E~ ......... ~ERTICAL SUB DEPTH ..... DEPTH .... -~-:. SEA ......... ]OTAL '-cOORDINAtES .......... 11000 ........... 8173. 8073._ 1867.98 12000 ........... 9020..,. 8920.. 2024.31 VERTICAL SECTION SCALE I' = 10OO' ATLANTfC RICHFIELD COMPANY TRADING BAY UNIT K-lO, REORILI. 'TANGENTAL METHOD - ! HORIZONTAl VIEW SCALE I'~= 500' ATLANTIC RICHFIELD COMPANY TRADING BAY UNIT K-IO~ REDRILL TA.GE.T,AL MET.OD Document Transmittal I. Jnion C)~l Comp~n¥ ()~ C~I unl®n No. DATE SUE~MITTED $ACCOUNTING MONT[t To Harry ~vv. Kugler Oil & Gas Division R~ C. Warthen 'z"~ 3001 Porcupine Drive ~P.O. Box ~47 ~nchorag%AK 99S0~-- ~n chorage~ ~K 99S02 TELEPHON~ NO. TRANSMITTING THE FOLLOWINO: Arco TBU K- 10~Final Logs: .... 2II i 5II DIL 1 Sepia and 1 Bluelire of ea~ 2" 5" i Sonic 1 Sepia and i ; , FORM 369 IREV 2 70) PRINTED IN U.S.A. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DIJP. LICA'I~ MONTHLY RE!PORT OF DRILLING AND WORKOVER OPERATIONS 1. wI~LL W~,LL OTHER NAME OF OPE~ATOR *UNION OIL COMPANY OF CALIFORNIA AbDRESS OF OPI~,~ATOR 909 W. NINTH AVENUE, ANCHORAGE~ AK ~01 LOCATION OF WFA.,L King Salmon Platform: 727' N & 141' W fr SE cr Sec 17, T9N, R13W, SM ~ API NU,AiERICAL CODE 50-133-20167-© i LEASE DESiGI'~A'FION AND SEHIAL NO ADL- 1877 IF INDIA],I[ ALOT'/-EE O]~ TlqlBE NAME 8. L,~IT FAi~2A OR LEASE TRADING BAY UNIT 9 WELL K-10 (21-19) Redrill FIF, LD Z%.N'D POOl,. Oil %VILDCAT McArthur River-Hemlock SEC . T.. R. M (BO'I~TOM HOLE Se%~,W~T9N, R13W, SM 12 PF~GViIT I~O 74-47 13. REI:~ORT TOTAL DEPTH AT END OF MONT~. CYIA~N'C;ES IN HOLE SIZE, CASING A~) C~MENTING JOBS INCLUDING DEPTH SET ~ VOL~ USED, p~O~TIONS, ~TS ~ ~SULTS FISHING JO~ JI~K ~ HO~ AND SIDE-~.ACKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ HO~ CO~ITIONS January 1975 12,822' TD; 12,575' PBD - Drilled 8-1/2" directional hole f/12,294 to TD ~ 12,822' DPM. Ran DIL and Gamma Ray Sonic logs f/TD to 9-5/8" casing shoe ~ 8830'. Ran 110 joints (4308') 7" liner f/8532-12,840' by casing measurement. (Note: casing measurement 18' deeper than DPM. ) Cemented liner with 960 sacks "G" cement w/l% CFR-2 & 0.2% HR-7 ~xed ~ 15.7 PPg. C$-eaned out to top of liner @ 8532' Tested & pumped into liner lap 5 BPM w/2500#. Squeezed lap with 165 sx cement. Cleaned out to 8532'. Retested liner lap with 2500#. Bled off to 2150# in 20 minutes. Cleaned out cement to 12,685' PBD. Ran GR-CBL w/CCi f/12,660-8400' . Ran Gyro survey f/12,645-7500'. Ran WSO test. Recovered 18.6 barrels muddy water. Resqueezed lap to 5000 psi with 175 sacks "G" cement. Cleaned out to 12,685' PBD. Reran WS0 test. Recovered 0.7 barrel rat hole mud. Lap test dry. Perforated Hemlock Bench 6 with 4 JSPF f/12,606-12,61______1' CBL measure. Ran DST~-~& ............... re'covered~' ..... ? .............. 13~' ........ BO,~"~'~" '~'~1~2~'~'"'"- ..... ~'~WB & 3.3 BM . Recorded test pressures 12,529' were: 4944 IH, 4015 ISI, 730 IF, 4039 FF, 4039 FSI. Set retainer at 12,580' · Squeezed perforations f/12,606-12,611' to 6000 psi with 60 sacks "G" cement. Displaced hole with diesel. Ran 4-1/2" x 3-1/2" gas lift completion assembly. Set packer ~ 11,895' w/bubing bottomed ~ 11,966' & NU &~tested tree to 5000 psi. P.erforated Bench 6 thru tubing with 4 JSPF f/12,520-12,545'. Ran static BHP survey. BHP = 4190 psi ~ 12,500' WLM. T est$~ ~-~5~ ~--~n gas lift at rate of 2117 BPD w/0.25% BS&W. Perforated 'Bench 5 w/4 JSPF f/1.2,4 0-12 491'. Tested Benches 5 & 6 on gas lift at maximum rate of 3098 BOPD w/no water. Released rig at 12 MIDNIGHT 1-27-75. FINAL REPORT. Tested BOPE w/3000 psi and Hydril w/1800 psi on 1-1-75 & 1-8-75. *ATLANTIC RICHFIELD COMPANY - Sub-operator Fo~r~ No. P.--4 R.,%'V. ~- I-?O STATE OF ALASKA OIL AND GAS CONSERVATION COMMrI-I'EE SUBMIT IN DUPLICATE MONTHLY RE!PORT O'F DRILLING AND WORKOVER OPERATIONS -5 API NUA.{ERICAL CODE 50--133--20167- LEASE DESIG~ATiON AXD SEHIAL NO ADL-1877 7 IF INDiART. ALO'~'T~,E OR TRIBE NANIE 1. OIL W~LL ~. N~E OF OP~TOR 8. L~IT FA~I OR LEASE NA_ME Union 0il Co. of California w Trading Bay Unit 3. ADDRESS OF oPhiR 9 WELL NO K-10 (21-19) Redrill 909 W. Ninth Ave., Anchorage, AM 99501 4LOCA~ONOFWF-J~ King Platform: 727'N & 141'W from SE Cor, Sec 17, T9N, R13W, SM 10 FIELD AND POOl,. OR WII.DCAT McArthur River - Hemlock Il SEC. T.. R 1%{ (BOTTOM HOLE OB,rScr., ~ Sec 19, T9N, R13W, SM 1~. PERMIT 74-47 13. REPORT TOTAL DEPi~H AT END OF MONTH. CHA~NGF, S IN HOLE SIZE, CASING AND CEMF~TT!NG JOBS INCLUDING DEPTH SET A~ VOL~ USED, p~O~TIONS, ~TS ~ ~SULTS FISHING JO~ J[~K ~ HOLE AND SIDE-~.ACKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~q HOI~ ~ITIONS December, 1974: DO retainer and pused to bottom ~ 9030' and circulated. Set Baker "K" retainer ~ 8764' on DA WL, but could not pull retainer WL setting tool with normal pull. Pulled setting tool loose and SOH. P0H with WL and left setting tool in hole 12-3-74. Recovered retainer setting tool with overshot on 12-4-74 and tagged top of fish ~ 8752' DPM with bottom ~ 8763' DPM. Drilled out retainer ~ 8764' and pushed to bottom ~ 9026' DPM. Circulated and recovered 1/2 gallon retainer peices in junk basket. RIH with 9-5/8" casing scraper open ended and reverse hole clean ~ 3000', 5000', 6500', 8000' and 8990'. Recovered approximately 1 gallon mill cuttings, rubber, and coal on each circulation. POH. Pressure up casing to check pump in rate thru squeezed perforations ~ 8805'. Break down with 1200 psi and pumped 12 barrles, into perforations ~ 3 BPM with 1400 psi. RIH and set Baker retrievamatic pakker ~ 8620' DPM. Break down formation with 1200 psi and pumped 12 BM into perforations ~ 8805' WLM ~ 2.5 BPM with 1600 psi. Pumped 10 BW preflushe and mixed 200 sacks "G" cement with 1% CFR-2 ~ 15.1-16 ppg. Pumped 5 BW flush and circulated cement to spot holding 900# back pressure on annulus. Closed bypass and press annulus to 1000#. Staged squeezed to 2600# with 175 sacks thru perforations. CIP ~ 12 NOON 12-5-74. Drilled out hard cement from 8623-8783' and firm to soft cement from 8783-8811'. RIH with mill and clean out soft cement from 8811-9002' (est PBD). Tested casing squeeze perforations @ 8805' with 2000#. Ran DA CBL-VOL from 9000- 8,000'. No cement indicated below 8800' WLM. Indication of casing and formation bonding from 8755-8788'and 8435-8455'. Cement indicated from 8455-8755',with no formation bonding. Cut 68' windown in 9-5/8" casing from 8830-8898'. with Servco "K" mill. Estimated 75% mill cuttings to surface. Pumped 5 BW followed with 20 bbls caustic water and 5 BW preflush. Spotted kick off plug ~ 17.0 ppg. CIP ~ 8:12 AM 12-10-74. PU to ~714 and reversed out 40 cf cement with hul~ of mill cuttings. Circulate and cond mud f/8714-8835'. Circulate hole clean. RIH with Turbodrill and sidetracked old hole and started directional drilling 8-1/2" hole from KOP 8835'-12,~94o (As of Dec. 31, 1974) *ATLANTIC RICHFIELD IS SUB Tested12~ll_74;BOPE12_17_74;with 300© and psi 12-24-74. and H~drill with 1800 psi on Form 1~o. P--4 l'~gV, ~- I-?0 STATE OF ALASKA Sv.MrT ]:N DU!?LICAT~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~'~;LL 2. NAME OF OP~%ATOR Union Oil Co. 909 W. Ninth Ave. ~ King Platform: 727' SEC of California* Anchorage: AK N & 141' W fr SE CR, 17, T9N, R13W, SM ~Pl NLT~[ERICAL CODE 50-133-20167 .... L~$E DESIGNA~ON AND S~IAL NO, ADL 18777 IF INDiA~I~ A'LA)T/-EE O]~ TRIBE NAME 8 'L.~IT FARA{ OR LEASE NAME Trading Bay Unit 9 W~L NO K-10 (21-19) Redrill 10 FIFJ.O AND POOL. OR %VILDCAT McArthur River - Hemlock 11 SEC. T., R. 1~{ (BO~TOM HOL~, O ~LrP, CT, rv~) Sec 19, T9N, R13W, SM 13. REPORT TOTAL DEPTH AT F_~ND OF MONTH. CHANGES IN HOLE SIZE. CASING AND CEMF~NTING JOBS INCLI:DING DEPTH SET A/WI) VOLLrMES USED. PERFORATIONS, 'I-~TS A/xrD F~FULTS FISHING JOB~M Jb~"iqK LN HOLE AND SIDE-/q~.AC'KED HOLE AND ANY OTHER SIGNIFICANT CH.A~GF~S IN HOL.$ CONDITIONS November 1974: Commenced operations ~ 3 PM 10.31-74. mud. Could not pull packer. Cut off & recovered tubing Fished 11 days & recovered 3-1/2" tubing assembly to 1 WLM. Top of tubing ~ 12,015' DPM. Bottom of tubing ~ 1 547' 3-1/2" completion assembly in hole & plugged back Set retainer ~ 11,878' WLM & squeezed below retainer w cement w/l% CFR-2 & 0.2% HR-7. Spotted 75 sacks (417') 11,878' across top of "G" zone perforations ~ 11,690'. Set retainer ~ 9850' & blocked squeezed w/200 sacks "G & 0.2% HR-7. Spotted cement on top of retainer to 9833 9601' & squeezed w/200 sacks cement as above. Cleaned out to 9833' PBD. Milled 57' window f/9712-9769' in 9-5/8" casing. Spotted kick off plug ~ 9833' w/150 sacks densified "G" cement w/l% CFR-2 mixed ~ 17 ppg. Cleaned out to 9721' Stuck drill pipe. Fished 11 days. Left fish in hole w/top of fish ~ 92~7' & bottom of fish ~ 9702'. Plugged back w/retainer set at 9200' WLM. Ran cement bond log f/9246-7700'. Perforated at 9080' and set retainer at 9030' for block squeeze. Could not break down. ~erforating w/5000 psi. Perforated at 8805' for block squeeze. Killed well w/9.5 ppg completion to 11,659'. 2,015' DPM = 12,029' 2,562'. Cemented as follows: /110 sacks "G" cement plug f/ll,461'- Perforated ~ 9901'. " cement w/l% CFR-2 '. Perforated ~ Tested BOPE w/3000 psi & Hydrill w/1800 psi on 11-2-74, 11-5-74, 11-11-74, 11-25-74. :~* Atlantic Richfield is sub-operator 14. 1 hereby cer~y ~t the ~oregJ~j~g i.~j~e arui correct smwn~ Dist Drlg~ _S~p~_~ ,~ 11/17/74 N~Report on this form is required for each calendar ~nthT regardless of th~- ItotuS of operations, and must ~ filed tn duplicate with th · oil and gas conlirvofion commiflie byfht 15~ of the iuGcNding mon~)unle~ ofherwile ~recfed. Form 10-403 REV. 1-10.73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 2. NAME OF OPERATOR Union 0il Company of California* 3. ADDRESS OF OPERATOR 909 W. Ninth Avenue~ 4. LOCATION OF WELL Atsurface King Platform 727' N & 141' W fr SE SM Anchorage, AK 99501 cr, Sec 17, T9N, R13W, 8. UNIT, FARMOR LEASENAME Trading Bay Unit 5. APl NUMERICAL CODE 50-133-20167 6. LEASE DESIGNATION AND SERIAL-NO. 18777 ~ ....... l1 - 9. WELL NO. K-10 (21-19) Redrill 10. FIELD AND POOL, OR WILDCAT! . ~..- . McArthur River - Heml:~.~k---- 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 19, TgN, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RKB 100' above MLLW 14. CheCk Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ FRACTURE TREAT SHOOT ORACIDIZE REPAIR WELL (Other) Plugged back PULL OR ALTER CASING 12. PERMIT NO. 74-47 )orr, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF REPAIRING WELL MULTIPLE COMPLETE ABANDON* CHANGE PLANS FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) ALTERING CASING ABANDONMENT* (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Ori$inal Proposal- Pull tubing completion assembly. Set cement retainer between "G" perforations f/11,690-12,474' and HemlOck perforations f/12,535-12,930'. Squeezed perforations and plug back to 9800'~. Cut window in 9-5/8" casing at 9700-9770'. Sidetrack and redrill. Supplemental Report - Commenced operat[nns on November 1, 1974. Fished 11 days to recover 3-1/2" tubing completion assembly. Top of fish ~ 12,015'. Bottom of fish ~ 12,562'. Permanent packer ~ 12,520'. Change in Plans - (As verbally approved by Mr. Homer Burrell on November 11, 1974 in telephone conversation with Mr. J. D. Keasler.) Cement fish in hole and plug back for redrill. Work was accomplished as follows: Set retainer ~ 11,878'. Squeezed below retainer with 110 sacks "G" cement. Spott d 75 sacks (417')cement plug from 11,~'~ 11,878' across top of "G perforations Remainder of program will be as originally approved. *Atlantic Richfield Company is sub-operator 16. I hereby ~ that the foregoing is true and correct SIGNED *'*~"/'~ -~,ITLE Dist. Drlg. Supt. DATE 11/25/74 (This Sl~ce for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE See Instructions On Reverse Side DATE ~pproved Cop~/ Retumed ~o. $-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMI1WEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS of California* 1. 0IL ~ GA~ ~ OTI~ER W~-LL W~-LL 2. NAME OF OPEI~.A. TOR Union 0il Company 3. ADbRESS OF OPERATOR . 909 4 ~cA~O~ o~ w~ At surface: 727' N & 141' SUBMIT IN DUPLICATE King Platform W fr SE cr, Sec 17, T9N, R13W, SM r~API NU3/IERICAL CODE 50_133_20167 LEASE DESiGI',I'A?ION AND SElqlAL NO. ADL 18777 7 IF INI)IA~. AI_,OTI~EE OR TRIBE NAME 8 UNIT FAI~{ OR LEASE BIAME Trading Bay Unit 9 W~,LL K-10 (21-19) Redrill lO FIELD A~TD POOl,. OR XVIL1DCPtT McArthur River-Hemlock SEC, T.. R. M (BOT~rOM HOI~ Sec icj, ,TS}N, Ri~W, SM PI~JVl IT NO 13. REPORT TOTAL DE~TH AT END OF MONT'H. CH.A~NGES IN HOLE SIZE. CASING AND C~---'~VtF~NTING JOBS INCLUDING DEPTH SET AND VOLU1VrE~ USED. PERi~'ORATIONS. TESTS AND RESULTS FISPII~NTG JOBlg JL%-NK IN PIOL~ AND SIDE-'I~ACKED HOLE AND ANY OTHER SIGNIFICANT CPLA~GES IN HOLtil CONDITIONS October, 1974 Commenced operations at 1500 hfs, October 31, 1974. Preparing to kill well. *Atlant/~ Richfield is su~-ona~n.*.n_~ ,, 14. I hereb~ e4z'ti~ t~t the ~ore~o~g~t~e ~ ~ - sm~ ~ ~-~~~~' ~ Dist. Drlg. ,_~upt. D~ 11/10/74 ,, // dl~ ~- (,2.11~mOo~ ,i .... , ......... ~ , ,11 ~OTE ~Reporf on thle form is required for eoch colendor ~nfhT regQrdlees of the afo~ue of o~erofioas, ond ~s~ filed in dupllcole with the oil o.d go~ conltrvolion commi~ee by the I~ of the &u~c~din~ mon~. u. le~ Ofherwiaa ~rected. ~tober 21~ 1974 Trading Bay Unit K-10 (21-19) RD Union Oil Co. of Calif., Operator Peri% ~o. 74-47 Mr. Robert, ~knderson Union 0il Company of California 909 ~q. 9~ Avenue Anchorage, Alaska 99501 ~ar Sir ~ Enclosed is t~ approve<] ~plication for permit to drill the above referen~d well., on or about October 15, 1974 at a location from the King Platfo~. Well .samples, core chaps are ~t required. A directional survey is re~irea. Pollution of any waters of the State is prohobited by AS 46, Chapter 03, Article 7 and ~gulations promulgated thereunder (Title 18, Alaska ~--~dmmnlstrative Co~e, Chapter 70) and by the Federal Water Pollution ContrOl ~t, as amended. Prior to commencing operations you may be contacted by a ~pr~-sentative of the Department of Environmental Conse~ation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska. Depar-t~.~nt of Labor is 'being notified of the issuance of this permit to ~ili. Very truly yours, .,,"~ / I/ .:,'..z~/ .' I~~ ' .,"' ,x"'< ,i,, . ...)~.~. ~omas R. ~rshall, Jr.. ExeCutive Secreta~ Alaska Oil and Gas Conse~ation C~ittee Enclosure cc: ~partment of Fish and Game, Habitat Section w/o encl. ~part~nt of ~nvirOr~entaI Conservation w/o encl. ~partment of Labor, Supervisor, L~r Law ComDliance DiVision w/o encl. Fo~m P--1 REV. 9-30-~ SUBMIT IN TRII (Other instructions on reverse side) STATE O,F ALASKA OIL AND GAS CONSERVATION ,COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK la. TYPIB OF WORK RE DRILL [] o,,~[] o,s I-1 .INGL,[] 2. NAME OF OPERATOR Union 0il Company of California* 3. ADDRESS ~ DEEPEN [] PLUG BACK MU I,TIPI,E ZONE 909 W. 9th Ave., Anchorage, AK 99501 4.LOCATION OF WELL At surface 727' N & lhl' W fr SE er, See 17, T9N, At proposed prod. zone 1150' S & ~po0' w. e~ ww .~ Sec l~, T9~, 13. DISTANCE IN MILES AI~D DIRECT!ON F_IOM NEARI~ST T6-W~q~JR I~O'S~ OFFICE 24 Miles NW of Kenai R1BW, SM R1SW, SM API #50-133-20167-01 8. UNIT~ FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. K-10 (21-19) Redrill I0. FIELD AND P()OL, OR WILDCAT McArthur River-Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 19, T9N, R13W, SM 14. BOND INFORMATION: TYPES t at ew i desurety and/or No. Fe de r al 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) Insurance Co. 1200' fr TBU Boundary I l0. NO. OF ACRES IN LEASE 1902 19. PROPOSED DEPTH 12800'+ 18. DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. lOGO' fr ~u K-i (he-lg) 21. ELEVATIONS (Show whether DF, RT, C-R, etc.) 100' RKB above MLLW 23. E X i S 13 1 n g: ~m'X)X~X:ASING AND .~EMENTING PROGRAM # 8011-34- hO _~o--.~ $100,000.00 17. NO. ACRES ASSIGNED TO THiS WELL 20. ROTARY OR CABLE TOOLS Rotary 2,2. APPROX. DATE WORK WILL START* October 15, 197h SIZE OF HOLE SIZE OF CASING} WEIGHT PER FOOT GRAI)E SETTING DEPTH QUANTITY OF C~MEN~ · 18 13-~/8 61 & 68 J-55 h,998 2255 sx 12-l/4 9-5/8 47 N-80 10,616 700 sx j (, ' '~- _ 8-1/2 7" liner 29 N-80 lq_.hl5 570 ax Pro ~osed: 8-1/2 7" liner 29 N-'80 l~.'/~O0'+ 4~0 gx Minimllm Present Status: The K-10 well was originally drilled to 13,463' TD w/7" liner cemented ~ 13,415' (see casing program above), and plugged back to 12,930' PBD. The "G" and Hemlqck. zones are open thru perfs between Proposed Program: (See Attached Sheet) ("" : *Atlantic Richfield Company is sub-operator. ""7. ' IN ABOV~ SlmAC~ D~C'R/BE FROPOSETO PI~OGRA_NI: If proposal is to deepen or plug back, give data on present produ~6t~iv, e zone and proposed new productive zone. If proposal is to drill or deepen direct[onall¥,, give pertinen~ data on subsurface location~ '~uid rneasu~d aha true vertical depths. Give blow. ut preventer pix)gram. 24, I hereby certify that ~h~regoing is True an& C~frect TmmDistrict Land Yzmager (This space /or State office use) coNDITIONS OF APPROVAL, IF ANY: SAMPLES AND CORE CHIPS REQUL~.I~D [] YES ,l~N'o j DIRECTIONAL SURVEY REQ~ ~ YES [] NO OTHER REQU~S: SEE TRANSMITTAL LETTER A.P.I. NlrMERICAL CODN .5-0-- /~,- 2o16,'7-o/ rm~r ~o_ r! ~ . qL r[ AP,',~ov~ D^~. October 21, 1974 f ~'~ tj ~/~~ ~/,.~- l ., f ~ Ar~o~.~'/ t~, . w,:. Exequtive Secretary OA~ October 21, *~e Inmu~o.. ~ Reve~ Side 1974 Application f Permit to Drill, Deepen, J' Plug Back P age 2 Well K-10 (21-19)Redrill Proposed Program: Cement squeeze existing Hemlock & "G" perfs & plug back to kickoff point ~ 9,600'+. Cut window in 9-5/8" casing & sidetrack well ~ 9,600'+. Directionally drill 8-1/2" hole to ...... ~ 12,800'+--MD to a new Hemlock location approx. ii' 1000' east of the present location. The Hemlock is not productive at the present lo- cation & the "G" produces only 900 BFPD w/a 52~water cut. Redrilling K-10 to the pro- posed location will increase ultimate oil recovery and rate f/the Hemlock. A 1B-B/8" ~--'-~ 3D00 psi BOP & Hydril will be installed & ~'~:- tested weekly. I¢c ~,A'T ~U ~ S'r TDI3 AtlanticRichfieldCompany O, _. I I I I I I IIII IIIII II Iii WELL LOCATION MAP TRADING BAY UNIT K-lO (21-19) REDRILL __ iii iii i II I I III III IIII IIII , 2. 3. 4. 5, 6', 7. 8. CHECK LIST FOR NEW WELL PERMITS -... Lease & Well N°. Yes No Remarks Is well to be located in a defined pool ................. ~3~ Do statewide rules apply ........................ Is a registered survey plat attached .................. Is well located proper distance from property line., .......... ~ ,, Is well located proper distance from other wells Is sufficient undedicated acreage available in this pool ........ _ Is well to be'deviated ......................... AJ~e?~_ _ Is operator the only affected party ................... ~_~,o£_ Q Can pen~it be approved before ten-day wait ...... ; ........ m~,,?c __ _ 10. Does operator have a bond in force ................... /,.:.'.~.~ ~ ll. Is conductor string provided ...................... 12. Is enough cement used to circulate on conductor and surface ...... 13. Will cement tie in surface and intermediate or production strings . . . 14~ $,lill cement cover ail possible productive horizons ........... 15. Will surface casing cover all fresh water zones ............ 16. Will surface csg. internal burst equal .5 psi/ft, to next string .... 17. Will all casing give adequate safety in collapse and tension ...... ,~ . 18. Does BOPE have sufficient pressure rating ............... ~:~ ~roval Recommended' ........ ~-KLV ,]AL -- ~.<..Z,. _ HWK .,..: -.., ?'. LCS _~ ... .1
