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201-141
RECEIVED III 0 STATE OF ALASKA JUN 1 5 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AlAQQAC 1a.Well Status: Oil❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑✓ Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Developmept L Exploratory 1:1GINJ ❑ WINJ El WAGE WDSPL EJ No.of Completions: Service [Z .jlb Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: iA- Hilcorp Alaska, LLC Aband.: 3/18/2017 /' 201-141/,'/3((Q- (p 3.Address: 7. Date Spudded: 15.API Nu er:✓ 3800 Centerpoint Drive,Suite 1400 Anchorage,AK 99503 September 1,2001 50-733-20330-02-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number Surface: 733'FSL, 133'FEL,Sec 17,T9N, R13W,SM,AK September 24,2001 TBU K-24RD2 • Top of Productive Interval: 9. Ref Elevations: KB: 49' 17. Field/Pool(s):McArthur River Field GL:73' BF:45.7' Hemlock Oil/Mid Kenai G Oil Pools Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 742'FNL,361'FWL,Sec 27,T9N, R13W,SM,AK 7,691'MD/5,496'TVD ADL018730 4b.Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 213766 y- 2411797 Zone- 4 14,200'MD/9,999'TVD N/A TPI: x- y- Zone- 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 219319 y- 2504750 Zone- 4 N/A N/A 5. Directional or Inclination Survey: Yes U (attached) No 0 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: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry, and perforation record. Acronyms may be used.Attach a separate page if necessary N/A SCANNED NOV 0 3 2U17, 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. TOP BOTTOM TOP BOTTOM PULLED 24" Surface 330' Surface 330' Driven Driven 18-5/8" 96.5# K-55 Surface 409' Surface 409' 24" 548 sx 13-3/8" 72/68# N-80 Surface 5,712' Surface 4,165' 17-1/2" 2412 sx 9-5/8" 47# S-95 Surface 7,691' Surface 5,496' 12-1/4" 1050 sx 24.Open to production or injection? Yes ❑ No Q 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number; Date Perfd): 3-1/2" Cut @ 7,897'MD 12,518'/8,748' .FF O©N� (Abandoned) 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. )4,,TE: Was hydraulic fracturing used during completion? Yes ❑ No Q "✓7(sit--4.- Per 20 AAC 25.283(i)(2)attach electronic and printed information '/F:IFiED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED Lc_ 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period .. 10. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate =.4,- Form Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 RBDMS JUN 2 2 2017 Submit ORIGINIAL only/ 043 i0/007-- g3vdie Vroj- , 17 �� • • • 28.CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No Ei If Yes, list formations and intervals cored(MD/TVD, From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Q Permafrost-Top If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval information, including reports,per 20 AAC 25.071. N/A Formation at total depth: 31. List of Attachments: Wellbore Schematic, Decomplete reports Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name:Paul Mazzolini Contact Name: Cody Dinger Authorized Title: Drilling Manager Contact Email: cdinger@hilcorp.corn Authorizeditiop C -7.7 °1 /i J Contact Phone: 777-8389 Signature: Date: / ! 7 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 19: Report the Division of Oil&Gas/Division of Mining Land and Water: Plan of Operations(LO/Region YY-123), Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions, core chips, photographs,and all subsequent laboratory analytical results, including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only McArthur River Unit 11 • • Well: K-24rd2 P&A'd Schematic PTD: 201-141 API:50-733-20330-02 llilcorp Alaska,LLC CASING DETAIL SIZE WT I GRADE CONN _ ID TOP BOTTOM 24" Driven Conductor Surf. 330' 18-5/8" 96.5 K-55 BTC Surf. 409' L , 72 N-80 BTC 12.347" Surf. 591' L , 13-3/8" 68 K-55 BTC 12.415" 591' 4,218' 72 N-80 BTC 12.347" 4,218' 5,712' 47 N-80 BTC 8.681" Surf. 1,798' 9-5/8" 47 S-95 BTC 8.681" 1,798' 2,765' 47 S-95 8rnd 8.681" 2,765' 10,793' 7" 29 L-80 KC Buttress 6.184" 7,962' 14,199' Tubing Detail 3-1/2" 9.2 L-80 IMP Butt SC 2.992" 7,897' 12,599' A 1 L. JEWELRY DETAIL h No DMph h kph ID OD Description 1 7,691' Top of Window 2 7,712' CIBP aBP7,712'-- .", 3 7,893' CIBP 1� 3a 8,486' 6,040' 2.992" 5.810" GLM#5 SFO-2 w/R-2 valve and RK latch 2/3 k ',0' *; J,,, 4 9,324' 6,547' 2.992" 5.810" GLM#6 SFO-2 w/R-2 valve and RK latch -- - CIBP 7,893' 5 10,137' 7,051' 2.992" 5.810" GLM#7 SFO-2 w/R-2 valve and RK latch 6 10,788' 7,484' 2.992" 5.810" GLM#8 SFO-2 w/R-2 valve and RK latch 7"liner 7 11,375' 7,888' 2.992" 5.810" GLM#9 SFO-2 w/R-2 valve and RK latch top @ 1 , 3a 8 11,936 8,304' 2.992" 5.810" GLM#10 SFO-2 w/R-2 valve and RK latch 7962' 9 12,438' 8,688' 2.992" 5.810" GLM#11 SFO-2 w/R-2 valve and RK latch-Orifice 4 10 12,518' 8,748' 3.250" 5.997" Baker Model 84 SAB 40x32 Hydraulic Permanent with K-22 Anchor type seal Assembly 11 12,565' 8,784' 2.813" 4.270" X-Nipple 5 12 12,599' 8,810' 2.992" 3.850" Baker''cut WLEG i 6 7 PERFORATION DETAIL L 8 , ZONE Interval(MD) Interval(TVD) Feet SPF DATE Status 9-5/8 G-1 12,680' 12,710' 8,871' 8,894' 30' 6 12/5/2002 window 9 6-2 12,750' 12,790' 8,925' 8,956' 40' 6 12/5/2002 @ 10793' 6-3 12,860' 12,890' 9,009' 9,032' 30' 6 12/5/2002 10 6-4 12,910' 12,980' 9,047' 9,101' 70' 6 12/5/2002 G-5 13,070' 13,160' 9,168' 9,234' 90' 6 12/4/2002 11 HB-1 13,370' 13,400' 9,384' 9,406' 30' 6 10/17/2001 HB-2 13,445' 13,460' 9,437' 9,448' 15' 6 10/29/2001 Cemented 12 HB-2 13,510' 13,520' 9,484' 9,491' 10' 6 10/29/2001 HB-2 13,570' 13,580' 9,526' 9,534' 10' 6 10/29/2001 HB-3 13,618' 13,633' 9,561' 9,572' 15' 6 10/28/2001 HB-3 13,640' 13,670' 9,577' 9,599' 30' 6 10/27/2001 HB-4 13,688' 13,733' 9,612' 9,644' 45' 6 10/25/2001 HB-4 13,767' 13,787' 9,670' 9,684' 20' 6 10/27/2001 4,;c4.* 141t- :�'t1 HB-5 13,857' 13,882' 9,737' 9,755' 25' 6 10/21/2001 TD=14,200'MD/9999'TVD PBTD=14,157' Max angle=57°@4800' Hole Angle=40°@ TD' Updated By:CJD 6/15/17 • • • Hilcorp Energy Company Composite Report Well Name: MRF K-24RD3 Field: County/State: Cook Inlet Offshore,Alaska (LAT/LONG): ovation(RKB): API#: Spud Date: Job Name: 1613470P K-24RD3 PreDrill Contractor AFE#: AFE$: 2/26/2017 Change adapter spool on riser. Pump 15 more bbls dn tbg before we caught pressure. 100 psi.Shut down and bleed slight blow off back side.Pressure bled to o psi on both sides..Production rigged dn water flood line to tree.Got wellhead hand and Weatherford BOP repair hand out on the boat.Test hanger to 4000 psi and it held.,Check pressure on accumulator bottles.Install rubber on shakers.Clean BOP bolts.,Set BPV and nipple dn tree.Pull tree wellhead room to rig floor. Remove 2 sections of old flow line and one valve from wellhead room for production. Have Weatherford hand changing hinge pin and seals on upper pipe ram door.Clean up hanger and change out bad LDS.Screw test sub into hanger.Nipple up riser.Set BOPs on top of riser.,Nipple up BOP.Charge accumulator. Function test all components. Install flow box.Change out all air boots.Modify bell nipple to fit.Nipple up kill line.,Nipple up choke line and mud manifold. Torque all bolts.Install drain pan,rotary table and flow line.Seal rotary table and rig floor.,Make up 3 1/2"test joint.,Wellhead pressures:24"=2 psi, 13 3/8"= 75 psi,9 5/8"=0 psi,tbg=0 psi. 2/27/2017 Make up 4 1/2"test joint. Pressure up to test and had a leak on the choke line.Tightened up choke line flange. Make 1st 5 tests.Had gas alarm in shipping pump room. Everybody muster in galley.All non-responding personal counted for.Finish testing everything but the bag and the blinds w/4 1/2.Test 250 and 3500 psi. Had 2 FP. Had to re-tighten graylock clamp&choke line. LD 4 1/2 test jt&MU 3 1/2 test jt.,Test w/3 1/2.Test annular to 250 and 2500 psi.Test Upper rams,lower rams,and blind rams to 250 and 3500 psi.Test both manual and remote chokes.Test PVT and gas alarms.RD test equip.,Pull BPV and make up landing jt. RU to circ. Back out LDS and pull hanger off seat with 35k. PU 3'more w/50k up wt.,Bring on mud pump and stage it up to 3 BPM. Pumped 24 bbls and got returns back at the shakers,w/no pump press. Pump 30 bbls and shut pump down.Pull hanger above floor checking for holes. Everything looked good.Cir one full circ w/no losses.,Lay down landing jt and hanger.RU to LD 4 1/2"tubing.,POOH laying down 4 1/2"tbg kill string.,Rig down Weatherford.Clear and clean rig floor. Organize pipe deck.Install wear bushing. Back load work boat.Monitor well(<1 BPH loss).,Make up BHA#1: Shoe,bushing,OS bowl,bushing,12 ea.8 1/8"washpipe,boot basket,float sub, BS/OJ,XO,6 ea.6"DC's,XO,6 1/4"accelerator,XO=574.61.,Wellhead pressures:24"=3 psi,13 3/8"=72 psi,9 5/8"=0 psi. 2/28/2017 Pick up BHA#1:Shoe,bushing,OS bowl,bushing, 12 ea.8 1/8"washpipe,boot basket,float sub, BS/OJ,XO,6 ea.6"DC's,XO,6 1/4"accelerator,XO= 614.77.,Pick up remaining BHA#1 as per Baker fishing tool hand.,RIH with BHA#1 picking up 4 1/2"drill pipe to 2382'.,Service blocks,top drive and rig equipment.,RIH picking up 4 1/2"drill pipe from 2382'to 4866'.,POOH rack back 7 STDS to 4450'.,RIH picking up 4 1/2"drill pipe 4866'.,Break circulation- pump drill pipe and washover pipe volumes 7 bpm @ 530 psi.Set TD torque limits to 9K.,Record parameters:UP wt.73K/DN wt.46K/Rot wt 54K/5.5K torque @ 30 rpm.Wash from 4866'-tag @ 4896'with 4K-pressure increase 100 psi.Continue washing to 5224'tag with 6K. Rotary 40 rpm @ 9k torque / 4.5 bpm @ 110 psi-reaming/wash down to 5228'.Continue wash to 5243'as Baker rep.,Wellhead pressures:24"=4 psi, 13 3/8"=70 psi,9 5/8"=0 psi. Fluid loss to well today:30.7 bbls Total:54.7 bbls 3/1/2017 Continue washing from 5242'to 5265'. 200 GPM/350 psi.Began having torque stalls at 9.5 K. Pick up with 8 K extra weight.,Blow down top drive.Monitor well (<1 BPH loss rate).,POOH from 5265'to 3843'.Drawworks hydraulic motor failed.,Remove and replace Raineer hydraulic motor.,POOH with BHA#1 from 3843'to 1610'.Replaced drawworks motor blew a seal.,Replace seal(o-ring).Tighten bolts.Replace hydraulic flow indicator.,POOH from 1610'to 1176'. Trouble shooting-monitor case drain flow rates while operating drawworks in all gears. Due to high volumes,decision to shut down and wait on motor.,Remove motor,circulate/filter hydraulic system. Inspect poppet valves.Raineer motor arrived King @ 2350 hrs.Completed inspection and install motor.Test drawwork. Monitor well(<1 BPH lose rate).,Wellhead pressures:24"=4 psi,13 318"=70 psi,9 5/8"=0 psi. Fluid loss to well today:38.3 bbls. Total:93 bbls. Code 8: 16.0 hrs Today, 18.0 Total hrs. Metal recovered: 13.9 lbs. Total:41.1 lbs. 3/2/2017 Finish test drawworks motors and hydraulic functions.Monitor well(1/2 BPH loss rate).,POOH from 1176'to 561'.,Lay down BHA with exception of wash pipe.,Lay down wash pipe and 308.67'of 4 1/2"tubing fish, 1 GLM and 2 wireline tools.Photos in o-drive.New TOF+-5277'. (1/2 BPH loss rate).,Clear and clean rig floor-Service rig.,Pick up BHA#2:Shoe,T-DOG overshot,4 ea.8 1/8"washpipe,boot basket,float sub, BS/OJ,XO,4 ea.6 1/2"DC's,XO,6 1/4" accelerator,XO=298.15'.(1/4 BPH lose rate),P/U 20 joints of 4 1/2"drill pipe to 917'-rabbit pipe.,RIH with BHA#2 from 917'to 5115'.,Record parameters: UP wt.76K/DN wt.54K/Rot wt 62K I 5K torque @ 30 rpm and set TD torque @ 2K over to Baker requirement. Break circulation 6 BPM @ 250 psi.,Wash from 5115'-tag @ 5269'with 4K-no pressure increase-put wraps in sting,weight fell off.Continue wash to 5280'tag with 5K several times.Rotate 40 rpm and stalled @ 7K. P/U to 5270'could not get pass 5272'-set 8-10K.No over pull.,Wellhead pressures:24"=4 psi, 13 3/8"=70 psi,9 5/8"=0 psi. Fluid loss to well today:6.8 bbls. Total:99.8 bbls. Code 8: 1.0 hrs Today, 19.0 Total hrs. Metal recovered: 8.3 lbs. Total:49.4 lbs. 3/3/2017 Unable to work past 5272'with wash pipe assembly,BHA#2.,Monitor well.<1 BPH loss rate.Fill trip tank. Install wiping rubber.,POOH with BHA#2 from 5272'to 360'.,Service rig.Check drawworks bolts and adjust drill line roller on ODS.<1 BPH loss rate.,Work BHA#2. Lay down 21.65'of spiraled 4 1/2"tubing. New TOF=5281'. Photos in o-drive.,Pick up BHA#3:8 1/2"shoe,T-dog OS,12 joints 8 1/2"wash pipe,boot basket,float sub,BS/OJ,XO,4 ea.6 1/2"DC's, XO,Accelerator,XO=550.40'.,RIH with BHA#3 to 1170'.,Slip and cut 189'of drill line.Service rig.,Continue RIH from 1170'to 5205'.,Establish parameters: Circulate 6 bpm @ 250 psi-UP wt.84K/DN wt.48K 1 Rot wt 62K/4.5K torque @ 30 rpm-set TD torque @7K.,Wellhead pressures:24"=4 psi, 13 3/8"_ 70 psi,9 5/8"=0 psi. Fluid loss to well today:4.8 bbls. Total:104.6 bbls. Code 8: 0.0 hrs Today, 19.0 Total hrs. Metal recovered: 25 lbs. Total:74.4 lbs. • • 3/4/2017 POOH from 5665'to BHA#3.<1 BPH loss rate.,Work BHA and lay down 581.64'of fish(pin down).New TOF @ 5863'with collar looking up-Photos in o- drive.,Clear floor of handling equipment and service rig.,Change out Reenier drawworks hydraulic motor(ODS top).Drain and inspect poppet valves.Test system for proper operation,(<1 BPH loss rate).,P/U BHA#4:8 1/2"shoe,T-DOG O/S, 12 joints 8 1/2"wash pipe,boot basket,float sub, BS/OJ,XO,4 ea.6 1/2"DC's,XO,Accelerator,XO=550.40'.,Wellhead pressures:24"=4 psi,13 3/8"=70 psi,9 5/8"=0 psi. Fluid loss to well today:4.8 bbls. Total:109.4 bbls. Code 8: 5.0 hrs Today, 24.0 Total hrs. Metal recovered: 39 lbs. Total: 113.4 lbs. 3/5/2017 RIH with BHA#4:8 1/2"shoe,T-DOG O/S, 12 joints 8 1/2"wash pipe,boot basket,float sub, BS/OJ,XO,4 ea.6 1/2"DC's,XO,Accelerator,XO=550.40'to 5637'.,Circulate bottoms up at 215 GPM/200 psi.Establish parameters:S/O 55 K, P/U 94 K without pump.S/O 53 K, P/U 90 K with pump.30 RPM/5 K torque,64 K.,Wash down from 5637 to 6247.Saw slight bobbles at TOF 5870',5979',6004',and 6210'. Circulate bottoms up.P/U on string and had free travel at 114 K.Pull up to 170 K and broke free.Appears trash above wash pipe basket.,Work string/fish until free travel while circulating an additional bottoms up due to possibility of gas from moving GLM at 6609'.,Pump out of hole from 6247'to 5878'.Monitor well with zero loss.Pick up and swabbing.Pump out of hole from 5878'to 4892'.,Continue POOH on elevators from 4892'to 385'BHA(wash pipe)with pipe displacement and slight losses.,L/D Baker 8 1/8"wash pipe and 4 1/2"fish.Photos in o-drive.,Wellhead pressures:24"=4 psi,13 3/8"=70 psi,9 5/8"=0 psi. Fluid loss to well today:7.2 bbls. Total: 116.6 bbls. Code 8: 0.0 hrs Today, 24.0 Total hrs. Metal recovered: 26.6 lbs. Total:140.0 lbs. Fire Control System is 50%completed with HPU fire suppression equipment. 3/6/2017 POOH laying down BHA#4 wash pipe and fish. Recovered 492.75'.New TOF+/-6355'.,Clear/clean rig floor.Drain stack and pull wear bushing.,Make up BHA #5:8 1/2"shoe,T-DOG O/S,12 joints 8 1/2"wash pipe,boot basket,float sub, BS/OJ,XO,4 ea.6 1/2"DC's,XO,Accelerator,XO=550.40'.,RIH with BHA #5 to 3960'.,M/U and land test plug, Baker shoe©4008'. Fill stack and choke with water.Shell test.,Test BOPE 250/3500 psi for 5 mins.each with 4 1/2"drill pipe.Components:Variable rams(2),choke manifold,stack choke and kill valves,floor valves,top drive except blind rams and annular.UD 4 1/2"test joint. Choke HRC valve failed.,Test blind rams 250/3500 psi.P/U 3 1/2"test joint and change out choke HRC valve. Perform accumulator draw down test.Shell test. Continue testing with 3 1/2"tubular:Variable rams(2),HCR 250/3500 psi.and Annular 250/2500 psi.,Wellhead pressures:24"=4 psi, 13 3/8"=70 psi,9 5/8" =0 psi. Fluid loss to well today:9.5 bbls. Total: 126.1 bbls. Code 8: 0.0 hrs Today, 24.0 Total hrs. Metal recovered: 39.0 lbs. Total: 179.0 lbs. Fire Control System is 75%completed with HPU fire suppression equipment. 3/7/2017 Pull test plug,and lay down test joint.,Run in hole with BHA#5 from 3960'to 6253'.,Circulate a surface to surface volume at 226 GPM,290 PSI,establish parameters, UW 100K,DW 53K with pumps,UW 108K,DW 58K without pumps.30 RPM,TQ 6-7K.,Wash down over fish from 6253'to 6637'at 240 GPM, 310 PSI without issue,set down 6 K on top of GLM#9(#3 on schematic).,Circulate 2 bottoms up at 440 GPM, 1040 PSI while adding 2 drums of CON DET to system,at bottoms up,had approximately 5 gallons of scale granules.,Shut down pumps,pick up to 96K free travel,pull out of hole with BHA#5,from 6637,no over pulls observed,and no swabbing issues encountered.,Work BHA#5,rack back 6 1/4"drill collars lay down bumper sub,and oil jar,service boot basket recovered 28#of scale,break out and lay down 12 joints of wash pipe with no fish recovered. Inspected T-dog overshot and found 2 of the 3 teeth that engaged under a coupling were missing,causing the failed run. Note:teeth were left in hole.,Clean and clear rig floor prep to pick up BHA#6.,Pick up BHA#6 consisting of 8.5"x 6.75"flat bottom shoe,8.125"rolling dog overshot,(9)joints 8.125"wash pipe,wash over boot basket,float sub,6.25"bumper sub,6.25"oil jar,XO sub 4.5"H90 x 4.5"IF,(4)6.5"drill collars,XO sub 4.5"IF x 4.5"H90,6.25"accelerator,and XO sub CDS 40 x 4.5 IF. Total BHA length 457.98'.,Continue to trip in the hole with BHA#6 picking up 10 singles off deck and remaining pipe out of derrick to 4635'.,Wellhead pressures:24"=4 psi,13 3/8"=70 psi,9 5/8"=0 psi. Fluid loss to well today: 14.5 bbls. Total: 140.6 bbls. Code 8: 0.0 hrs Today, 24.0 Total hrs. Metal recovered: 13.6 lbs. Total:192.6 lbs. Fire Control System is 90%completed with HPU fire suppression equipment, 3/8/2017 Run in hole with BHA#6 from 4635'to 6107'.,Obtain parameters, UW 89K,DW 64K without pump.UW 85K, DW 59K with pump.71K ROT at 4K torque,220 GPM 200 PSI.,Wash over fish,down to top of GLM at 6638'without issue.,Pick up to 92K free travel,maximum gas 45 units.,Pull out of hole with BHA#6 to 5749'.,Rig Service:Service top drive,draw works,crown,and replace link tilt cylinder.,Rig Service: Service top drive,rig tongs and slips.,Rig Repair: Link tilt cylinder ODS leaking,change out both link tilt cylinders and adjust same to clear monkey board fingers.,Pull out of hole with BHA#6 from 5749'to 4407',link tilt bracket ODS broke at top drive.,Rig repair: Repair link tilt bracket with TESCO upgrade kit. Losses to wellbore less than 1 BPH.,Continue to trip out of hole with BHA#6 from 4407'to BHA.,Work BHA,lay down accelerator,cross overs,stand back(2)stands of drill collars,oil jars,and bumper sub. Lay down and service boot basket recovered 31#of scale. Break and pick up top joint of wash pipe and found fish were it was anticipated,cut tubing and laid down same, continue to lay down fish.,Wellhead pressures:24"=4 psi,13 3/8"=70 psi,9 5/8"=0 psi. Fluid loss to well today: 14.5 bbls. Total: 140.6 bbls. Code 8: 9.0 hrs Today, 33.0 Total hrs. Metal recovered: 13.6 lbs. Total: 192.6 lbs. Fire Control System is 99%completed with HPU fire suppression equipment. 3/9/2017 Pull out of hole laying down BHA#6 fish.Recovered 442.07': one GLM and 5 joints 4 1/2"tubing below GLM.,Clear and clean rig floor,service rig.,Make up BHA#7: 8 1/2"x 6 1/2"flat bottom shoe,8 1/8"T-dog overshot,(12)joints wash pipe,wash over boot basket,float sub,bumper sub,oil jar,XO,(4)6 1/2"drill collars,XO,6 1/4"accelerator,XO=550.83.,Run in hole with BHA#7,picking up 20 joints of CDS40 drill pipe,continue to run in hole to 6691'with pipe out of derrick.,Circulate 2 bottoms up,had a max of 479 units of gas and approximately 3 gallons of fine scale.,Establish parameters,90K UW,69K DW,pumps off, 87K UW,63K DW,74K ROT,pumps on 231 GPM,310 PSI. Slacked off and washed down to top of fish at 6799'set down 2K,picked up and put 2 wraps in pipe set back down and seen overshot swallow top of fish,continue to wash down to 7183'tagging on no-go.,Circulate bottoms up at 400 GPM rate 837 PSI had 540 units max gas.,Pick up to 118K, pipe parted falling back to 110K,continue to pull out of hole to 6799',UW 101K,looks like 10-11K additional weight. Continue to trip out of hole to 6591',hole taking correct fill.,Wellhead pressures:24"=4 psi, 13 3/8"=23 psi,9 5/8"=0 psi. Fluid loss to well today: 14.5 bbls. Total: 140.6 bbls. Code 8: 0.0 hrs Today, 33.0 Total hrs. Metal recovered: 13.6 lbs. Total: 192.6 lbs. Fire Control System is 99%completed with HPU fire suppression equipment. 0 •• 3/10/2017 Pull out of hole with BHA#7 from 6591'to BHA,standing back collars.,Work BHA#7,serviced boot basket and recovered 28#of scale, lay down wash pipe and fish,recovered 491.46'of fish,our new top of fish is at 7290',with a coupling looking up.,Clean and clear rig floor perform rig service.,Inspect T-Dog prior to running back in hole,found the lost tooth from T-Dog,failed run#5,wedged in tool,removed same and verified integrity.,Pick up BHA#8,consisting of 8.5" x 6.5"flat bottom shoe,8.125"T-Dog overshot,(12)joints 8.125"wash pipe,wash over boot basket,float sub,6.250"bumper sub,6.250"oil jars,XO sub,(4) 6.50"drill collars,XO sub,6.250"accelerator,and XO sub back to CDS40 drill pipe.,Pick up 20 singles off deck and continue running in hole with pipe out of the derrick to 7210'.,Wellhead pressures:24"=4 psi,13 3/8"=23 psi,9 5/8"=0 psi. Fluid loss to well today:14.5 bbls. Total: 140.6 bbls. Code 8: 0.0 hrs Today, 33.0 Total hrs. Metal recovered: 17.0 lbs. Total:209.6 lbs. Fire Control System is 100%completed with HPU fire suppression equipment. 3/11/2017 Circulate at 10 BPM,870 PSI to clean hole,added Condet to system,max gas 549 units at bottoms up,with less than 1 BPH fluid loss. Establish parameters: UW 90K,DW 64K,with pump, UW 94K, DW 69K without pump,30 RPM,4K torque,75K ROT.,Tag top of fish at 7920'had to rotate over top,wash over fish from 7290'to 7674'without issue,no go out with 3K down. Circulated an additional 100 bbls at 10 BPM, 1000 PSI on each kelly down to clean hole.,Circulate 1 1/2 times bottoms up at 10 BPM, 1000 PSI.Max gas at bottoms up 140 units.,Pick up to 10k over string weight and tubing parted with 6K extra weight. Trip out of hole with fishing BHA#8 from 7674 to BHA,with no issues.,Work BHA racking back 2 stands of drill collars,serviced boot basket and recovered 28#of scale. Break down wash pipe laying down fish and wash pipe,recovered 485.37'of fish including GLM#4 and still pulling fish.,Wellhead pressures:24"=4 psi, 13 3/8"=23 psi,9 5/8"=0 psi. Fluid loss to well today: 14.5 bbls. Total:140.6 bbls. Code 8: 0.0 hrs Today, 33.0 Total hrs. Metal recovered: 17.0 lbs. Total:209.6 lbs. Fire Control System is 100%completed with HPU fire suppression equipment. 3/12/2017 Continued to lay down 4.5"tubing fish, XO,and 3.5"collar total recovered 608.75',estimated top of fish at 7899'. Their was no wire line tools recovered,and pipe condition remains the same,with no norm detected above back ground.,Serviced draw works,top drive,inspect tongs,slips and elevators,while discussing recovery with town,decision made to terminate fishing operations.,Clean and clear rig floor,lay down all fishing tools monitor well.,Continue to monitor well while strapping and measuring tools. Note:well static with slight seepage.,Pick up clean out BHA#9 consisting of,8.5"RR bit with open jets,(2) boot baskets,9.625"casing scraper,string magnet,float sub with ported float,bumper sub,oil jars,XO,(4)6.5"drill collars,XO,accelerator jar,and a XO= 190.20'.,Run in hole slowly with clean out BHA#9,from 190'to 2049'.,Crew change and had a rig service.,Continue to run in hole slow with BHA#9 from 2049' to 6641',break circulation and pump 50 BBLS.,Cut and slip 200'of drilling line while monitoring well. Note:well static with no losses. Clean and clear rig floor.,Continue to run in hole slow with BHA#9 from 6641'to top of fish,tagging up at 7897',while washing last joint down.,Circulate the hole clean,pumped 1.5 bottoms up,at 420 GPM,715 PSI,had approximately 3 gallons of fine scale with no gas above background.,Performed injectivity test,pumping at 1 BPM rate,pumped a total of 7.8 BBL to a max pressure of 1500 PSI on casing,with no break over observed,at 1500 PSI pumps were shut down and casing pressure was monitored,with casing pressure falling to 750 PSI in 5 minutes.While performing injectivity test outer annuluses were monitored with no additional pressure increase noted.,Pump rate 1BPM:,2 BBL=560 PSI,3 BBL=850 PSI,4 BBL=1080 PSI,5 BBL=1250 PSI,6 BBL=1360 PSI,7 BBL=1447 PSI,7.8 BBL=1500 PSI Pressure bleed off:,30 SEC=1360 PSI,1 MIN=1234 PSI,90 SEC=1134 PSI,2 MIN=1051 PSI,3 MIN=921 PSI,4 MIN=823 PSI,5 MIN=750 PSI.,Trip out of hole with clean out BHA#9 from 7897'to BHA.,Lay down clean out BHA#9.,Wellhead pressures:24"=4 psi,13 3/8"=23 psi,9 5/8"=0 psi. Fluid loss to well today:2.3 bbls. Total:142.9 bbls. Code 8: 0.0 hrs Today, 33.0 Total hrs. Metal recovered: 22.5 lbs. Total:232.1 lbs. Fire Control System is 100%completed with HPU fire suppression equipment. 3/13/2017 Continued to lay down BHA#9,serviced boot basket and string magnet,recovered 5#of metal off magnet and minimal fine scale out of boot baskets.,Clean and clear rig floor,move all Baker equipment off floor and stage on pipe deck.,Rig up Pollard e-line,and conduct a PJSM.,E-line run#1,run in hole with Halliburton 40 arm 9.625"casing caliper to 500'WLM and encountered telemetry issues with tool,trouble shoot same,could not resolve,pulled out of hole,to change tools.,E-line run#2,run in hole with Halliburton 40 arm 9.625"casing caliper to 6540'WLM were it appeared that tools were sitting down picked up and passed through with no issue,continue in hole to 7850,WLM pick up logging at 35 FPM to surface. At surface found bottom half of spring missing from logging tool.,E-line run#3,run in hole with 8.35"gauge ring and junk basket,sifting down at 7890'WLM,pull out of hole,at+-1350'WLM pulled out of rope socket,leaving a 1.437"OD cable head looking up,continue to pull out of hole and rig down e-line.,Pick up,strap and drift 581'of CDS40 HWDP,drain stack, make up test plug and land in wellhead. Make up 4.5"test joint and screw into test plug. Fill stack,and test equipment with water,work air out and shell test.,Make up 4.5"test joint and screw into test plug. Fill stack,and test equipment with water,work air out and shell test to 2000 PSI.,Test BOPE on 4.5" pipe, per AOGCC regulations,annular 250 PSI low,2500 PSI high 5 minutes each,all other components 250 PSI low and 3500 PSI high 5 minutes each. Perform accumulator draw down test,all good. Note AOGCC Mr.Jim Regg waived BOPE test witness 03-12-2017.,Rig down testing equipment,break and laydown test joint,pull test plug and lay it down,pull and rack back 9 stands HWDP.,Rig up Pollard's slick line unit,run in hole with a rope socket,10'of 1 3/4" stem,knuckle joint,oil jar,spang jars,GSU adapter 4.5 baited sub with overshot with 4 12"bell guide baited with a 1 7/16"grapple.,Wellhead pressures:24"= 4 psi, 13 3/8"=23 psi,9 5/8"=0 psi. Fluid loss to well today:2.3 bbls. Total: 142.9 bbls. Code 8: 0.0 hrs Today, 33.0 Total hrs. Metal recovered: 22.5 lbs. Total:232.1 lbs. Fire Control System is 100%completed with HPU fire suppression equipment 3/14/2017 Complete running in hole with a rope socket,10'of 1 3/4"stem,knuckle joint,oil jar,spang jars,GSU adapter 4.5 baited sub with overshot with 4 12"bell guide ited with a 1 7/16"grapple,to 7887'set down on fish and beat down to 7888,and pull out of hole. At surface we had 100%fish recovery including bow spring off of caliper. Rig down slick Iine.,Riq up a-line,run in hole with 9.625"CIBP tapped top of fish and picked up setting top of CIBP at 7883.5 WLM. c ' ? POOH and rig down e-Iine.,Clean and clear rig floor.,Rig up Weatherford tongs and elevators strap 4.5"tubing,pick up and drift tubing out"V of door,run a total of 305'of tubing,rig down Weatherford tongs.,Trip in hole with cement stinger from 305'to 7893'DPM tagging top of CIBP,stood back stand and picked g up 20"of pups to space out for GYRO logging run.,Circulate bottoms up at 450 GPM 680 PSI.,Reposition 5"pup below single for proper space out,run in hole 1 and tag CIBP at 7893'. Rig up a-line with Scientific/Halliburton GYRO tool.,Run in hole with GYRO tool to 7860 WLM'logging in and out at 150 FPM, r j'2.recalibrating tool every 15 degree change. Rig down e-Iine.,Make up pump in sub with floor safety valve and a low torque on outlet,spot and rig up cement �J( manifold on rig floor,string out 2"HP hoses for cementing,and prep for cement job.,Waiting on weather,prepping for cement job,and prepping to seal rotary table.,Wellhead pressures:24"=4 psi,13 3/8"=23 psi,9 5/8"=0 psi. Fluid loss to well today:2.3 bbls. Total: 142.9 bbls. Code 8: 0.0 hrs Today, 33.0 Total hrs. Metal recovered: lbs. Total:232.1 lbs. Fire Control System is 100%completed with HPU fire suppression equipment • • 3/15/2017 Rig down cement lines,pump in subs, FOSV and 15'pup,drain stack and pull stand,make up test plug less seals,land work string out on test plug&rack back(1)stand.,Waiting on weather,pull rotary table clean and seal flow box along with rotary table flange,install extension on flow box in preparation of OBM. Clean pits,steam and heat fresh water tank and OBM tanks,continue with rig house keeping and maintenance with a focus on finishing up welding projects.,Schlumberger on board hands orientated,cementers rigging up equipment,pulled test plug and laid down same,positioned end of stinger at 7888' de up pump in sub,FOSV,and made up hoses while waiting on Schlumberger,Conduct PJSM with all parties,purge lines,verify data acquisition,perform Agw pressure test to 275 PSI and high pressure at 3000 PSI,pump 18 BBL fresh water,batch cement to 15.8 PPG and pump 2.8 BBL down hole was unable vt•-o to transfer sufficient dry cement to maintain 15.8 PPG slurry,after 45 minutes decision made to abort job and circulate pipe clean.,Circulate surface to surface Cr with rig pump catching cement in cuttings tote, pumped bad cement from unit to tote,Conducted another PJSM to ensure all parties were aligned,blew down Schlumberger's hard line,staged additional tankage for cleanup,pump 18 BBLS fresh water,batch up 15.8 PPG cement with,D046 antifoam.2%BWOC, D065 dispersant.3%BWOC, D255 fluid loss.35%BWOC, D177 retarder.035 gal/sk.and pump 12 bbls at 2 BPM rate followed by 5 BBL of fresh water,Start to displace with 97 BBL of FIW with the rig.,Wellhead pressures:24"=4 psi, 13 3/8"=zi psi,v-sus =U psi. Fluid loss to well today:2.3 bbls. Total: 142.9 bbls. Code 8: 0.0 hrs Today, 33.0 Total hrs. Metal recovered: 0.0 lbs. Total:232.1 lbs. Fire Control System is 100%completed with HPU fire suppression equipment 3/16/2017 Finish spotting cement plug,displaced with 97 BBL FIW with rig pump at 6 BPM slowing to 2 BPM at 93 BBL away,shut down drill pipe on slight vac.,Break out cement equipment and pull 6 stands at 10-15 FPM to 7504',to minimize cement stringing out.,Drop wiper plug(nerf foot ball),and circulate a surface to surface volume at 10 BPM,560 PSI.seen a trace of cement at bottoms up. Blow down and clear cement lines while circulating.,Break out cement assembly subs. Blow down top drive and mud lines. Pull out of hole standing back drill pipe to 4 1/2 tubing.,Break out XOs and rig up tubing equipment,lay down 10 joints of 4 1/2 tubing,and rig down tubing equipment.,Change grabber dyes and service rig.,Clear floor and pick up BHA#10,consisting of,8.5"mill tooth bit, 9.625"casing scraper,bit sub,flex joint,8.5"upper string mill,XO sub,(1)HWDP,XO sub,float sub,6.25"bumper sub,6.25"oil jar,XO sub,(18) syr HWDP.,Run in hole with clean out assembly,to 7523,wash down with 300 GPM to 7722'set down 5K,picked up and rotated down to 7740'taking 5K WOB, picked up and set 12K down with no rotation and 300 GPM(hard cement). Looks like 153'of cement.,Circulate bottoms up at 448 GPM,860 PSI.,Perform '-=sing tos+„r ' h 97nn PSI ctahili7ori of 9876 PSI and hold for 10 minutes,glow down top drive and choke,trip out of hole with clean out assembly from 7740'to 5350',Wellhead pressures:24"=4 psi, 13 3/8"=23 psi,9 5/8"=0 psi. Fluid loss to well today:2.3 bbls. Total:142.9 bbls. Code 8: 0.0 hrs Today, 33.0 Total hrs. Metal recovered: 0.0 lbs. Total:232.1 lbs. 3/17/2017 Pull out of hole with clean out BHA from 5355'to BHA.,Lay down BHA#10,no damage to bit or string mill,picked up window mill,lower string mill,flex joint, upper string mill.XO.and(1)ioint of HWDP,and stood back in the derrick.,Clean and clear rig floor of tools.,Rig up Pollard e-line,make up Baker CIBP,run in hole,correlate and set CIBP with too at 7706'WLM Pull out of hole,rig down e-line,worked on sealing pan under rotary while wirelining,pulled back floor plate,installed 4"drain,put strong back under drip pan and secured it with a chain,silicone and re-install back floor plate.,Hold PJSM for picking up whipstock A with all hands,pick up mill assembly scribe same,pick up 9 5/8 generation 2 whipstock with bottom trip anchor,attach mills to whipstock with 47k shear bolt. i +1 Continue to run in hole with,float sub,DM collar,TM collar and scribe same(Note;Directional offset 40.29),continue to run in hole with(3)flex collars,XO,and one std of HWDP.,Shallow test MWD tools,appeared to have good signal.,Trip in hole with remainder of HWDP and continue in on CDS40 drill pipe too Y 7636',Orientate whipstock face to 68R,run in hole and tag CIBP at 7712'set 8K weight down,and tripped anchor,setting same,picked up 5 K over up weigh,t (o' and verified anchor was set,set down 26K below down weight,and sheared mill attachment bolt,picked up and had free travel. TOW©7691, BOW @ 7708',Prep to change over to OBM.,Wellhead pressures:24"=4 psi, 13 3/8"=23 psi,9 5/8"=0 psi. Fluid loss to well today:2.3 bbls. Total: 142.9 bbls. Code 8: 0.0 hrs Today, 33.0 Total hrs. Metal recovered: 0.0 lbs. Total:0 lbs. 3/18/2017 Prepare to change well over to OBM,shipping FIW to TBPF production pipe line. Installed blind in#2 pump suction,install 1/2"bleeder valve on pipeline pig launcher,conduct PJSM.ensure hoses and lines are secured,tested all lines to 1000 PSI.,Pump 22.4 BBL spacer down drill pipe with#2 mud pump,followed by 541 BBL of OBM taking FIW returns to active pit system. Pumped FIW from active pits to pipeline with pump#1,at 4 BPM on both pumps. Pumped 560 ✓ v.%BBL FIW down pipeline and 541 BBL OBM to displace well. Shut down and blow down FIW line to production.,Clean under shakers,pit#1 and#5,transfer •?''/OBM from uprights to mud pits. Having issues getting OBM below 100 BBL in,#2 400 BBL upright storage tank,rig up and pump 75 BBL from ISO,leaving ,� �) t') 1 10 unrecoverable BBLS. (Note; All the OBM tanks have been setting for over 30 days.) We have attempted to roll the uprights but apparently the OBM has v) channeled in the#2 upright storage tanks.,Break circulation with a short system,centrifuge running to cut mud weight back,current mud weight 9.2+. Bring pumps up to 400 GPM,2050 PSI,could not reach 80 RPM in low gear had to shift to high,with 6K TQ, putting maximum torque at 12 TQ. Tagged top of whipstock at 7689'while rotating.attempted to start milling window,had stalling issues due to low torque from being in high gear.,Perform rig service,lube tongs and top drive,change oil in HPU's,troubleshoot PLC for TD rotary RPM issues.,Rig repair;Troubleshoot PLC for top drive rotary RPM issues. Contacted ART,diagnose and fix problem by downloading PLC upgrade.,Mill window per Baker Oil Tool from 7691'to 7723'with 400 GPM, 1820 PSI,80-95 RPM,7-12K TQ,2-10K WOB.had a torque spike to 17K and started to stall but broke free,with a free rotating torque of 6.5K attempt to continue milling with no success, applied additional bit weight up to 16K with no additional torque,and pump pressure remained constant.,Pump dry job and trip out of hole for new mill from 7723'to 5380'.,Wellhead pressures:24"=4 psi,13 3/8"=23 psi,9 5/8"=0 psi. Fluid loss to well today:2.3 bbls. Total: 142.9 bbls. Code 8: 1.5 hrs Today, 34.5 Total hrs. Metal recovered: 213.0 lbs. Total:213.0 lbs. V ~ • 3/19/2017 Pull out of hole with Baker oil tool window milling assem to BHA.,Stand back HWDP,lay down one flex collar,and rack back 1 stand of flex collars,lay down TM and DM collars. Pull mill through floor,and inspect same,starting mill was 1/16 under gauge,and both string mills were in gauge,with no wear. Remove flex joint,and make up mills back to back,run in hole and set slips on HWDP.,Clean and clear rig floor,while making call to town,decision made to run insert bit,instead of starter mill, appears it was formation that stopped us.,While waiting on bit,back flushing#2 400 bbl upright storage tank and recovered 65 BBLS of OBM. Changed hoses on draw works that were identified as being reversed by Sawyer Hydraulics Engineer,test run draw works,everything good. Rigged up new line for transferring OBM from ISOs using rig mix pump,emptied ISO in 20 minutes compared to 3 hours it had been taking with trash pump. Bit arrived at 1400 hrs.,Break out starting mill and make up 8 1/2"button bit. (Note;bit 1/8"under gauge) Run BHA#12 consisting of,8.5"RR bit,8 3/8"lower string mill,8 1/2"upper string mill,XO,(1)joint HWDP,XO,float sub,(2)ea 6 3/4"flex collars,XO,18 jts of HWDP=667.27'.,Run in hole with window milling BHA#12 to 7677'.,Establish parameters, UW 95K,DW 69K, RW 76K,TQ 6K,350 GPM,1335 PSI,wash down to 7719'set down 5K,wash and ream to 7723'with 3-4K WOB,drill to 7728 with 7-15K WOB. Picked up and polished BOW at 7708'with 8.5"upper mill,picking up to 7709'bit depth keeping bit below BOW. Drift window with pumps on and off observed maximum of 2-3K drag through window.,Note top of window 7691'bottom of window 7708'.,Pick up to 7674',circulate and condition mud to even out at 9.1 PPG.,Perform FIT to 12.6 PPG MWE, (9.1 PPG mud,5506'TVD, 1010 PSI applied pressure=12.6 PPG MWE).,Pump slug and trip out of hole from 7674'BHA,laying it down,Wellhead pressures:24"=4 psi, 13 3/8"=23 psi,9 5/8"=0 psi. Fluid loss to well today:0 bbls. Total:0 bbls. Code 8: 0.0 hrs Today, 34.5 Total hrs. Metal recovered: 167.0 lbs. Total:380.0 lbs. 10 OF Tye S \��\�yyy��� THE STATE Alaska Oil and Gas 7 of LAsKA Conservation Commission 1 }E__ 333 West Seventh Avenue 1, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Off'ALAS ' Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manager �ElYla � , Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 suruse Anchorage,AK 99503 Re: McArthur River Field,Hemlock and Middle Kenai G Oil Pools, TBU K-24RD2 Permit to Drill Number: 201-141 Sundry Number: 316-586 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, Cathy P. oerster Chair ud DATED this Z day of November, 2016. RBDMS LA-/ u i t 8 2818 • STATE OF ALASKA NO 1 5 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALSAOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate 0 Pull Tubing ❑ Change Approved Program❑ Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other. 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0 201-141 • 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic 0 Service 0 , 6.API Number. Anchorage,AK 99503 50-733-20330-02-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes 0 No 0 Trading Bay Unit/K-24RD2 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018730 • 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): 14,200 . ' 9,998 • 14,157 • 9,965 2,720 psi 14,157 N/A Casing Length Size MD TVD Burst Collapse Structural 330' 24" 330' 330' Conductor 409' 18-5/8" 409' 409' Surface 5,712' 13-3/8" 5,712' 4,165' 3,450 psi 1,950 psi Intermediate 10,793' 9-5/8" 10,793' 7,487' 6,870 psi 4,760 psi Production 6,237' 7" 14,199' 9,992' 8,160 psi 7,020 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12,680-13,882 • 8,871 -9,755 4-1/2" 12.6#/L-80 7,879 3-1/2" 9.2#/L-80 12,599 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker SAB lnj Pkr • 12,518'(MD)8,748'(TVD) 12.Attachments: Proposal Summary Q Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory ❑ Stratigraphic 0 Development 0 Service l 14.Estimated Date for 15.Well Status after proposed work: 12/1/2016 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended El 16.Verbal Approval: Date: GAS 0 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©hilcorp.com Printed Name Stan W.Golis // Title Operations Manager Signature 413 irtr.; Phone (907)777-8356 Date w1 1 r''4 1 i (. `J COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number:- - $ Le Plug Integrity 0 BOP Test i Mechanical Integrity Test 0 Location Clearance ❑ LJ� Other: / 3500 .5. (' i esf 14/-fere ` 10C,-. e(�.c...w.� Teo,��, Z r4r4� S. IIZC�� Post Initial Injection MIT Req'd? Yes 0 No 0 � I 1 1-1--11 b Spacing Exception Required? Yes ❑ No V Subsequent Form Required: ' O ..LI 0"7 RBDMS (,v NOV 2 8 2010 APPROVED BY // Approved by: /`+'�" COMMISSIONER THE COMMISSION Date: -22-1 fief/7 11/744 /i.L.i./4, Submit Form and Form 10-403 Revised 11/2015 0 lPGidP\IiI: .t::s valid for 12 Yths from the date of approval. Attachments in Duplicate • 4110 Well Work Prognosis Well: K-24rd2 E{iieor���1a ka 1,1,C PTD:201-141 Date: 10/11/2016 Well Name: K-24rd2 API Number: 50-733-20330-02 Current Status: Shut-in Injector Leg: Leg#4 (NW corner) Estimated Start Date: December 01, 2016 Rig: Kuukpik#5 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett(8332) Permit to Drill Number: 201-141 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: 3,607 psi @ 8,871'TVD 0.407 lbs/ft(7.82 ppg)based on 2001 SIBP Maximum Expected BHP: 3,607 psi @ 8,871'TVD 0.407 lbs/ft(7.82 ppg)based on 2001 SIBP Maximum Potential Surface Pressure:2,720 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary K-24rd2 is a shut-in well that used to inject into the G and Hemlock sands. It was shut in in 2012 due to tubing integrity. A workover was attempted in,2012 with CUDD and was halted due to rotten tubing resulting in slow progress de-completing the well. Last Casing Test: N/A Procedure: 1. Skid Rig into position above K-24rd2. 2. ND Wellhead, NU BOP and test to 250psi low/3,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 3. Circulate hydrocarbons from well to production through kill string—Workover fluids will be '8.5ppg FIW. •j 4. POOH with kill string. 5. Fish tubing to±7,950'.1/ 6. RIH with bit and scraper to±7,950', circulate clean. POOH. 7. RIH with cement retainer and set at±7,950' • We request a variance to 20AAC25.112(c)(1)to set the retainer>500' above top perforation. 8. RIH and sting into cement retainer. 9. RU cementing equipment and establish an injection rate with FIW. • If able to pump into well- Mix and pump±212 barrels cement to isolate existing completion. Un-sting from retainer and circulate hole clean. • If unable to pump into well unsting from retainer and spot a >100' balanced plug bbls on top of the retainer. • POOH w/workstring \\ j 10. Pressure Test casing to 1,500 psig for 30 minutes and chart. tv 11. RU e-line and RIH w/CIBP to±7,800', ±5' above casing connection. 12. RD a-line. 13. PU whipstock and mills and RIH to CIBP. 14. Orient and set whipstock. ***Remaining Procedure to be included on the Permit to Drill Sundry for the sidetrack*** • 41) II Well Work Prognosis Well: K-24rd2 PTD: 201-141 Hilcorp Alaska,LLC Date: 10/11/2016 General sequence of operations pertaining to drilling procedure: (informational only) 15. Mill 8-1/2" window and 20' of new formation. POOH and LD mills. 16. PU directional BHA and TIH to window. 17. Swap well to drilling fluid 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 ' 0 S II McArthur River Unit SCHEMATIC Well: K-24rd2 Last Completed: 2012-08-24 Hilcorp Alaska,LLC PTD: 201-141 API: 50-733-20330-02 RKB to TBG Hanger=34.85 CASING DETAIL SIZE WT GRADE CONN ID TOP BOTTOM 24" Driven Conductor Surf. 330' 18-5/8" 96.5 K-55 BTC Surf. 409' 72 N-80 BTC 12.347" Surf. 591' L 1 , 13-3/8" 68 K-55 BTC 12.415" 591' 4,218' L72 N-80 BTC 12.347" 4,218' 5,712' V`�, '1 47 N-80 BTC 8.681" Surf. 1,798' 7 9-5/8" 47 S-95 BTC 8.681" 1,798' 2,765' 47 S-95 8rnd 8.681" 2,765' 10,793'(TOW) 2 , 7" 29 L-80 KC Buttress 6.184" 7,962' 14,199' Ll Tubing Detail 3 4-1/2" 12.6 L-80 IMP Butt SC 3.958" Surf. 4,838 4-1/2" 12.6 L-80 IMP Butt SC 3.958" 4,884' 7,879' 4 (91,0„.b, i.21;"` 3-1/2" 9.2 L-80 IMP Butt SC 2.992" 7,879' 12,599' /- .,-a ` JEWELRY DETAIL 7" liner 5 Depth Depth top @ No MD TVD ID OD Description 7962' 6 FMC-UHA-1A-EN Hanger TCII w/4"type H BPV profile 1 4,838' 3,703' 4.250" 4.875" BTC Collar w/45 degree bevel 2 5,169' 3,894' 3.958" 6.810" GLM#2 SFO-2 wl R-2 valve and RK latch 3 6,618' 4,813' 3.958" 6.810" GLM#3 SFO-2 w/R-2 valve and RK latch 4 7,744' 5,539' 3.958" 6.810" GLM#4 SFO-2 wl R-2 valve and RK latch i 8 5 7,879' 5,624' 2.992" 4.950" 4-1/2"x 3-1/2"Crossover 6 8,486' 6,040' 2.992" 5.810" GLM#5 SFO-2 w/R-2 valve and RK latch __ 7 9,324' 6,547' 2.992" 5.810" GLM#6 SFO-2 w/R-2 valve and RK latch 9 8 10,137' 7,051' 2.992" 5.810" GLM#7 SFO-2 w/R-2 valve and RK latch 9 10,788' 7,484' 2.992" 5.810" GLM#8 SFO-2 w/R-2 valve and RK latch 10 11,375' 7,888' 2.992" 5.810" GLM#9 SFO-2 w/R-2 valve and RK latch 9 5/8 1 11 11,936' 8,304' 2.992" 5.810" GLM#10 SFO-2 w/R-2 valve and RK latch window L , 11 , 12 12,438' 8,688' 2.992" 5.810" GLM#11 SFO-2 w/R-2 valve and RK latch-Orifice @ 10793' Baker Model 84 SAB 40x32 Hydraulic Permanent with K- 13 12,518' 8,748' 3.250" 5.997" 12 22 Anchor type seal Assembly 14 12,565' 8,784' 2.813" 4.270" X-Nipple 13 15 12,599' 8,810' 2.992" 3.850" Baker'Y2 cut WLEG PERFORATION DETAIL 14 ZONE Interval(MD) Interval(TVD) Feet SPF DATE Status G-1 12,680' 12,710' 8,871' 8,894' 30' 6 12/5/2002 15 G-2 12,750' 12,790' 8,925' 8,956' 40' 6 12/5/2002 it, G-3 12,860' 12,890' 9,009' 9,032' 30' 6 12/5/2002 b �e G-4 12,910' 12,980' 9,047' 9,101' 70' 6 12/5/2002 '�+ ' t° G-5 13,070' 13,160' 9,168' 9,234' 90' 6 12/4/2002 ��''� 3')" HB-1 13,370' 13,400' 9,384' 9,406' 30' 6 10/17/2001 HB-2 13,445' 13,460' 9,437' 9,448' 15' 6 10/29/2001 1, HB-2 13,510' 13,520' 9,484' 9,491' 10' 6 10/29/2001 .11 , rte 45' b. FIB-2 13,570' 13,580' 9,526' 9,534' 10' 6 10/29/2001 HB-3 13,618' 13,633' 9,561' 9,572' 15' 6 10/28/2001 HB-3 13,640' 13,670' 9,577' 9,599' 30' 6 10/27/2001 TD=14,200' MD/9999'TVD HB-4 13,688' 13,733' 9,612' 9,644' 45' 6 10/25/2001 PBTD= 14,157' HB-4 13,767' 13,787' 9,670' 9,684' 20' 6 10/27/2001 HB-5 13,857' 13,882' 9,737' 9,755' 25' 6 10/21/2001 Max angle=57° @ 4800' Hole Angle=40° @ TD' Revised: 10/14/16 By: DEM McArthur River Unit - in • • Well: K-24rd2 PROPOSED Last Completed: FUTURE PTD:201-141 API:50-733-20330-02 Hileorp Alaska,LLC RIM to TBG Hanger=34,85 CASING DETAIL SIZE WT GRADE CONN ID TOP BOTTOM LI I 24" 18-5/8" 96.5 Driven Conductor Surf. 330' K-55 BTC Surf. 409' 72 N-80 BTC 12.347" Surf. 591' L , 13-3/8" 68 K-55 BTC 12.415" 591' 4,218' 72 N-80 BTC 12.347" 4,218' 5,712' 47 N-80 BTC 8.681" Surf. 1,798' 9-5/8" 47 S-95 BTC 8.681" 1,798' 2,765' 47 S-95 8rnd 8.681" 2,765' 10,793'(TOW) 7" 29 L-80 KC Buttress 6.184" 7,962' 14,199' Tubing Detail 3-1/2" 9.2 L-80 IMP Butt SC 2.992" ±7,950' 12,599' L JEWELRY DETAIL ? th ..,,� No Depth De�D ID OD Description �t ` 1 ±7,800' CIBP(set for Whipstock) th 11-4 nO2 2 ±7,950' Cement Retainer ,,. CIBP±7,800' 11-4 l •1 2 Retai -r @ 3 8,486' 6,040' 2.992" 5.810" GLM#5 SFO-2 w/R-2 valve and RK latch ±7,950' 4 9,324' 6,547' 2.992" 5.810" GLM#6 SFO-2 w/R-2 valve and RK latch 7"liner top @ I ro. 3 5 10,137' 7,051' 2.992" 5.810" GLM#7 SFO-2 w/R-2 valve and RK latch 7962' 6 10,788' 7,484' 2.992" 5.810" GLM#8 SFO-2 w/R-2 valve and RK latch 7 11,375' 7,888' 2.992" 5.810" GLM#9 SFO-2 w/R-2 valve and RK latch 4 8 11,936' 8,304' 2.992" 5.810" GLM#10 SFO-2 w/R-2 valve and RK latch ' 9 12,438' 8,688' 2.992" 5.810" GLM#11 SFO-2 w/R-2 valve and RK latch-Orifice 1 hi 5 Baker Model 84 SAB 40x32 Hydraulic Permanent 10 12,518' 8,748' 3.250" 5.997" with K-22 Anchor type seal Assembly I to 6 11 12,565' 8,784' 2.813" 4.270" X-Nipple . 12 12,599' 8,810' 2.992" 3.850" Baker'A cut WLEG I III 7 L t w 8 9-5/8" 013 L windowro @ 10793' `:;. -- 9 �iL G 10 PERFORATION DETAIL ZONE Interval(MD) Interval(TVD) Feet SPF DATE Status 11 G 1 12,680' 12,710' 8,871' 8,894' 30' 6 12/5/2002 G-2 12,750' 12,790' 8,925' 8,956' 40' 6 12/5/2002 12 G-3 12,860' 12,890' 9,009' 9,032' 30' 6 12/5/2002 G-4 12,910' 12,980' 9,047' 9,101' 70' 6 12/5/2002 G-5 13,070' 13,160' 9,168' 9,234' 90' 6 12/4/2002 'K.t ,^t '`- HB-1 13,370' 13,400' 9,384' 9,406' 30' 6 10/17/2001 « , i HB-2 13,445' 13,460' 9,437' 9,448' 15' 6 10/29/2001 Cemented ,� HB-2 13,510' 13,520' 9,484' 9,491' 10' 6 10/29/2001 "' "'' '1\ HB-2 13,570' 13,580' 9,526' 9,534' 10' 6 10/29/2001 TD=14,200 MD/9999 TVD HB-3 13,618' 13,633' 9,561' 9,572' 15' 6 10/28/2001 PBTD-14157 HB-3 13,640' 13,670' 9,577' 9,599' 30' 6 10/27/2001 HB-4 13,688' 13,733' 9,612' 9,644' 45' 6 10/25/2001 Max angle=57°@ 4800' HB-4 13,767' 13,787' 9,670' 9,684' 20' 6 10/27/2001 Hole Angle=40°@TD' HB-5 13,857' 13,882' 9,737' 9,755' 25' 6 10/21/2001 Updated By:JLL 11/08/16 King Salmon Platform * ti K-24RD2 Current 10/19/2016 ITdrarp 11a.ka.I.Td. King Salmon Tubing hanger,FMC-UH- K-24RD2 TC-IA-EN,13 5/8 5M X 4'1 24 X 13 3/8 X 9 5/8 X 4 1/2 TC-2 lift and susp,w/4" type H BPV,410ss material BHTA,B-11-A-0,4 1/16 SM FE `(� R Y 111111111111..11111101 1111101 I.0 ; Valve,Swab,OCT-75, �`'' 4 1/16 5M FE,HWO,EE �.,e 1��1 trim # -L 1i.-Ti• \... _„% / N _Mk: Valve,Master,OCT-75, 41/16 5M FE,HWO,EE y�� ie 0' ''.1 trim , v :11.K.-- Adapter,FMC-ASP,13 5/8 5M 'i'" API clamp X41/16SM,w/7" {0i • �`�. • • iextended neck pocket •Thw. •ix . if 0 „,,.. I ...„ Unihead,OCT type 3,13 5/8 5M API hub top X 13 3/8 BTC casing bottom, 7� w/1-2 1/16 5M SSO on lower [__i►I�� �I ' ` ?' [121 section,1-2 1/16 5M SSO on middle .. 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P !minis. . , 0 „,sepo tic? ° •-t Pa H • • Kuukpik 5 BOP Test Procedure Hilcorp Alaska,LLC 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 Hileorp 11aRka.IAAAttachment#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 • • 0 ca It13 /. g �2 0 6 0 73 c 7 7 (90 co t 2 �� § f « E 0 . 2 = § i 0. >`..-41 a I a < '• 70 2 m '4-0 0 7 13 ' .E 0. a g7 § ; n -0 a) ■ R % Nt ■ 2 0 0 $ % t � CO as CL S � 0 CI 77 0 a. 2 ° O ka a)La. ct o.Y o.f a) as L§ ascU C.) Z "0 0 ■ C) a) ■ E m ° 2 8. a a I- E. a L. Ca c Z12' E a) co kp c LU t 2 as g ca@ @ § � a ici o 47. / 0. / 0 .o cd 0. 4 2 k � t 0 Qcn S 0 $ ® ,-12 x m ,g C.) § C $ \ O. $ g A S ) £ u) ;« it 00Q % , % ¢ & e " EQ § , & : 0 'v cx V k k9. .� < 1 2 . 1 • • • Roby, David S (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent! Wednesday. November 16, 7016 4:1 S PM To: Roby, David S (DOA) Subject: Re: Sundry application for TRU K-24RD7 (PTD 201-141) It will be a West forland sand producer Thanks. Dan On Wed, Nov 16,2016 at 2:45 PM-0900, "Roby, David S(DOA)" <dave.roby@alaska.gov<mailto:dave.roby@alaska.gov»wrote: Dan, Quick question on this application. What is the plan for the sidetrack that will be drilled? Will it be a replacement service well to restore injection in the portion of the pool(s)that the existing well used to inject into? Is it tapping a different portion of the pool(s)for either production or injection service? Thanks in advance. Regards, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907)793-1232 CONFIDFNTIAI ITV NOTICE:This e-mail messageincluding 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 %/inJate state or federal Iain, If Vr)li are an ?unintended recinient of this e-mail nlpace 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 rnh,rnal;aska nnvyrmailto•d ave rnhv a(alaska any-, • • 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 z "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 Ge logist 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. WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. dol / Lf/ Well History File # Digital Data Added to LaserFiche File 0 CD's - # 0 DVD's - # 0 Diskettes - # - 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No Oversized Material Added to LaserFiche File 0 Maps # - 0 Mud Logs # - 0 Other # - 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No General Notes or Comments about this file. If any ofthe information listed above is not available in the LaserFiche file you may contact the Alaska Oil & Gas Conservation Commission to request copies. Please call Robin Deason at (907) 793-1225 if you have any questions or information requests regarding this file. UNSCANNED, OVERSIZED MATERIALS AVAILABLE: ~0/ /~/ FILE # c~~ i'~/ U~ 6 ~ 9 S .vs:~.h- ~ °~J To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ~ 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 Fax (907) 276-7542 RECEIVED STATE OF ALASKA SEP 2 5 2012 Ail OIL AND GAS CONSERVATION COMM SION REPORT OF SUNDRY WELL OPERATIONS AOGCO 1. Operations Abandon ❑ Repair Well El Plug Perforations ❑ Perforate ❑ Other' ❑ Performed: Alter Casing ❑ Pull Tubing 0 Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WeII❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development ❑ Exploratory ❑ 201 - 141 3. Address: 3800 Centerpoint Drive, Suite 100 StratigraphiC❑ Service El 6. API Number: Anchorage, AK 99503 50- 733 - 20330 -02 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018730 Trading Bay Unit / K -24RD2 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A McArthur River Field / Hemlock Oil and Middle Kenai G Oil Pools 11. Present Well Condition Summary: Total Depth measured 14,200 feet Plugs measured 14,157 feet true vertical 9,998 feet Junk measured None feet Effective Depth measured 14,157 feet Packer measured 12,518 feet true vertical 9,965 feet true vertical 8,748 feet Casing Length Size MD TVD Burst Collapse Structural 330' 24" 330' 330' Conductor 409' 18 -5/8" 409' 409' Surface 5,712' 13 -3/8" 5,712' 4,165' 3,450 psi 1,950 psi Intermediate 10,793' 9 -5/8" 10,793' 7,487' 6,870 psi 4,760 psi Production 6,237' 7" 14,199' 9,992' 8,160 psi 7,020 psi Liner SCANNED JAN 2 8 2013 Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4 -1/2" 12.6# L -80 7,879' (MD) 5,624' (TVD) Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.# L -80 __ 12,599' (MD) 8,810' (TVD) 12,518' (MD) Packers and SSSV (type, measured and true vertical depth) Baker SAB Inj. Packer 8,748' (TVD) TRSSSV N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 20 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑ Service El Stratigraphic ❑ Daily Report of Well Operations x 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ E WAG ❑ GINJ ❑ SUSP SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -170 Contact Ted Kramer Printed Name Ted Kramer Title Sr. Operations Engineer e------------ Signature . "72— Phone (907) 777 -8420 Date 9/25/2012 4 ,____, Reams SEP 2 6 7n �Z• L Form 10 -404 Revised 11/2011 Submit Original Only . , • • 11 Trading Bay Unit 1 King Salmon Platform S CHEMATIC Well # K -24RD2 Injector Hilcor p Al Actual 1202 (G-Zone Perf Add) Alaska, LLC RKB to TBG Hanger = 34.85 Casing Detail SIZE WT GRADE CONN TOP BOTTOM i [ 24" 1 8 5/8" 101 H-40 Driven Surf. 330' 409' 13-3/8" 72/68 N80/K55 Surf. 5,712' . 9 -5/8" 47 N- 80/S -95 N- 80/S -95 Surf. 10,793' L . �' 6 7" 29 L -80 KC Buttress 7,962' 14,199' Tubing Detail ..��' 2 4 -1/2" 12.6 L -80 Buttress Surf. 4,838 II 4 -1/2" 12.6 L -80 Buttress 4,884' 7,879' 1 3 3 -1/2" 9.3 L -80 Buttress 7,879' 12,599' Jewelry Detail i 4 No Depth Description 1 4,838 Kill String 5 2 5,169' 4 -1/2" SFO -2 GLM with R -2 valve and RK latch 7" liner 3 6,618' 4 - 1/2" SFO -2 GLM with R -2 valve and RK latch top @ 4 7,744' 4 -1/2" SFO -2 GLM with R -2 valve and RK latch 6 7962' 5 7,879' Xover, 4 -1/2" x 3 -1/2" buttress 6 8,486' 3 -1/2" SFO -2 GLM with R -2 valve and RK latch 7 9,324' 3 - 1/2" SFO - GLM with R -2 valve and RK latch 7 8 10,137' 3 - 1/2" SFO - GLM with R -2 valve and RK latch 9 10,788' 3 - 1/2" SFO - GLM with R -2 valve and RK latch «mow 0 8 10 11,375' 3 - 1/2" SFO - GLM with R -2 valve and RK latch • 11 11,936' 3 - 1/2" SFO - 2 GLM with R - valve and RK latch 9 12 12,438' 3 -1/2" SFO -2 GLM with Orifice valve and RK latch 13 12,518' Baker SAB 3 -1/2' x 7" injection packer 14 12,565' 3 -1/2" "X" nipple w/2.813" ID 10 15 12,599' Tubing tail L AMMO 0 11 , 9 -5/8" Perforation Detail M I window ZONE Interval (MD) Interval (ND) SPF DATE .� " 12 @ 10793' G -1 12,680' 12,710' 8,871' 8,894' 6 12/5/2002 G -2 12,750' 12,790' 8,925' 8,956' 6 12/5/2002 13 G -3 12,860' 12,890' 9,009' 9,032' 6 12/5/2002 G -4 12,910' 12,980' 9,047' 91,001' 6 12/5/2002 G-5 13,070' 13,160' 9,168' 9,234' 6 12/4/2002 14 HB -1 13,370' 13,400' 9,384' 9,406' 6 10/17/2001 HB -2 13,445' 13,460' 9,437' 9,448' 6 10/29/2001 15 HB -2 13,510' 13,520' 9,484' 9,491' 6 10/29/2001 HB -2 13,570' 13,580' 9,526' 9,534' 6 10/29/2001 HB -3 13,618' 13,633' 9,561' 9,572' 6 10/28/2001 - HB -3 13,640' 13,670' 9,577' 9,599' 6 10/27/2001 1/27/10: 2- HB -4 13,688' 13,733' 9,612' 9,644' 6 10/25/2001 - 1/2" swedge HB -4 13,767' 13,787' 9,670' 9,684' 6 10/27/2001 tagged at ---10. HB -5 13,857' 13,882' 9,737' 9,755' 6 10/21/2001 13,965' TD = 14,200' MD/9999' ND PBTD = 14,157' Max angle = 57 @ 4800' Hole Angle = 40 @ TD' Revised: 9/25/2012 By: TDF . . Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date K -24RD 50- 733 - 20330 -01 7/2/12 8/25/12 Daily Operations: ©'+ I`t' 7/2/2012 - Monday Set BOP W/ Crane, NU BOP ; LD and MU flowback and Circ lines. 07/04/2012 - Wednesday NU lines to BOP. Test BOP: 250 psi low / 4,000 psi high. MI Injector head spotting and spot lubricator stand. Stabbing pipe into Injector Head. PU injector head. NU Lubricators and MU Baker BHA #1. NU Lubricator to BOP and test all surface iron to 3,000 psi. 07/05/2012 - Thursday RIH with BHA and tag fish @ 4,354'. POOH to 304' and stop. The safety valve feels partially shut. Unable to pull through. MIRU Braided line unit. MU tools to fish cutter bars. MU lubricators. RIH w/ BHA stopped at 280' (Safety Valve).Tried several times but was unable to continue through. RIH with 2 -7/8" OD Lead Impression Block. Shows indention. Sent pictures to a -line. RIH with 3.68" Lead Impression Block and sent picture to a -line. 07/06/2012 - Friday MIRU E -Line Unit and prepare for camera run. RIH w/ camera. Video shows damage to flapper w/ 1 side of hinge separated and flapper off -side. Decide to shut down project. RDMI all Wire -line and CT equipment. RD CTU and Braided line unit. Prep to demobilize all equipment. 08/11/2012 - Saturday Function test BOP's 250 psi low/ 2,500 psi high. AOGCC witness waived By Jim Regg @ 4:00 pm on 8- 11 -12. 08/12/2012 - Sunday Preform running test on blinds, fill hole with 32 bbls FIW, close blinds Pump 5 bpm 200 psi, check for Teaks, none. Pull BPV and R/U a -line. RIH t/ 295' tag up, cut above SSSV. Make a -line cut @ 280' and POOH. R/D e-line. P/U handling tools & spot power pack for tubing tools. M/U Spear BHA w/ 4.010 grapple. Engage grapple into hanger, pull working wt up t/ 40k, pull up wt fell t/ 34k, POOH t/ window no fish. RIH with 4.010 grapple, engage t/ hanger pull on hanger grapple came free from hanger. POOH and inspect, looks like only engaging 3" & wedge shaped from btm. Change out grapple to 3.947. RIH engage @ same depth, snub down w/ no movement, .ull free • 1000 .si.,POOH and inspect grapple, same indication s rom ast run. Round up 4" taper mill, get to heliport. R/U rotary & function, secure hyd connections, unload mill f/ helicopter. 08/13/2012 - Monday P/U M/U tapered mill BHA. RIH 4 L/D sczaws, start rnt 301m4q 500 -600 and continue milling hanger profile. POOH L/D BHA. C/O weight indicator, drain stack inspect hanger mill not in profile. P/U M/U BHA w/3.947 grapple. RIH and engage grapple to hanger. POOH with hanger & 1 collar. L/D fish & BHA. Prep to continue BOP test. M/U & test w /4" & 4 -1/2" test jts and set test plug.Test BOPE 250 psi low / 2,500 psi high. AOGCC witness waived By Jim Regg @ 4:00 pm On 8 -11- 12. C/O test jt. t/ 4 -1/2 ". Pull test plug, I/d test jt, set wear ring, P/U overshot BHA. 08/14/2012 - Tuesday Cont. prep & p/u overshot BHA. RIH slow, p/u drill pipe t/ 98.76' tag fish. POOH till overshot in window. L/D BHA. C/O handling tools f/ tubing. Pull & L/D 243' of 4 -1/2" tubing, including cut jt. Tubing has holes & pin ends in bad shape. C/O handling eq. Prep. next BHA. P/U overshot BHA, TIH t/ 342' tag fish. R/U circ lines & kelly. Mill over cut jt. POOH and L/D BHA. L/D 4 -1/2" tubing fish. Swap out handling tools & break down overshot & re- dress. Break down crossovers needed f/ next BHA. C/O handling tools f/ tubing. • Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date K -24RD 50- 733 - 20330 -01 193 -129 7/2/12 8/25/12 Daily Operations: 08/15/12 - Wednesday M/U BHA on drill deck. RIH with overshot BHA. P/U tubing to TOF @ 2,066'. Set down 4K and engage fish. Attempt to pick up to 15K for tension for cutting tubing. Weight fell off and fish had parted. POOH racking back tubing. Break and lay down fish and BHA. Redress overshot. M/U BHA. RIH with 4 -1/2" 563 tubing and overshot BHA to 2,141'. While making up last joint before engaging fish tubing tongs came in contact with weight indicator resulting in it becoming inoperable. Waiting on replacement weight indicator. 08/16/12 - Thursday Install weight indicator. Function test same. P/U 1 joint and engage TOF @ 2,155'. Set down 4K and swallow fish. P/U 20K over and fish parted. POOH with fish. Lay down 14 joints of fish. Redress overshot and M/U BHA. RIH with overshot BHA to 2,531'. R/U wireline unit. M/U radial torch cutter. Engage TOF with overshot @ 2,546'. Took several attempts to engage. RIH with 2.5" radial torch cutter. Make cut @ 2,634'. POOH with wireline. R/D same. POOH with fish. 08/17/12 - Friday POOH with fish to overshot BHA. Lay down 4 joints and GLM fish. Redress overshot and M/U BHA. RIH to TOF @ 2,732' and engage fish. Make several attempts to rotate for better swallow. P/U to 46K and fish is free. POOH with fish racking back stands to overshot BHA. Lay down 17 joints of 4 -1/2" BTC fish. Redress overshot and M/U BHA. RIH to TOF @ 3,246' and engage fish with 4K set down weight. Pick up to 41K and fish pulled free. POOH with fish racking back stands of 4 -1/2" 563 and BTC tubing workstring. 08/18/12 - Saturday POOH with fish racking back stands of 4 -1/2" 563 and BTC workstring to overshot BHA. Lay down 14 joints of 4 -1/2" BTC fish. Redress overshot (4 -1/2" grapple). Clean dies and slips for trip. Change out winch line cable. RIH to TOF @ 3,688' and engage fish with 8 - 10 k set down. POOH to BHA. Redress overshot and add 3' extension. RIH with overshot (4 -1/2 ") to TOF @ 3,688'. Engage fish with 7 - 10K set down while pumping @ 2 BPM /100 psi. POOH to BHA. Redress overshot with 4 -3/8" grapple. Install dies in traveler slips. RIH with 4 -3/8" grapple. 08/19/12 - Sunday RIH with 4 -3/8" grapple overshot to TOF @ 3,688'. Engage fish with 7 - 10K set down weight while circulating @ 3 BPM /100 psi. Work over fish several times and attempt to P/U to 10K over pull. Fish came free with 4K over. POOH with fish to BHA. Lay down 10 joints of 4 -1/2" BTC fish. Remove /cut 4 -3/8" grapple from fish. Redress overshot with 4 -1/2" grapple. RIH with 4 -1/2" grapple overshot to top of fish @ 3,988'. Engage fish with 7 - 10K set down while circulating @ 3 BPM /100 psi. Work over fish several times and attempt to P/U to 15K over pull. Fish came free with 12K overpull. POOH with fish to BHA. Lay down 6 joints 4 -1/2" BTC fish. Remove 4 -1/2" grapple from fish. Redress overshot with 4 -1/2" grapple. RIH with 4 -1/2" grapple overshot. 08/20/12 - Monday RIH with 4 -1/2" overshot to TOF @ 4,130'. Engage fish with 7 - 10K set down weight while circulating @ 3 BPM /150 psi. Work over fish several times and attempt to P/U to 10K over pull. Fish came free with 6K over pull. POOH to BHA. Break and lay down fish. Redress overshot with 4 -7/8" grapple. RIH with 4 -7/8" overshot to 4,483' tagged fill /obstruction (TOF @ 4,532'). Circulate and wash down to 4,518' @ 4 BPM /200 psi. Close bag. Reverse circulate @ 4 BPM /200 psi. Set down 6K at 4,518' and not able to go further. Decide to POOH and see what we have. • tit Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date K -24RD 50- 733 - 20330 -01 193 -129 7/2/12 8/25/12 Daily Operations: 08/21/12 - Tuesday POOH to BHA. Break and lay down fish. Pull wear bushing. M/U 4 -1/2" test joint. Fill stack. Test BOPE at 250 psi low / 2,500 psi high. Pull test plug. Set wear bushing. M/U overshot with 4 -7/8" grapple. RIH to 4,816'. Tagged obstruction. Wash down while reverse circulating from 4,816' - 4,835'. 4 BPM /200 psi. Open bag and work down to 4,842'. Continue reverse circulating with earlier parameters and washing down 4,835' - 4,844'. Expected TOF @ 4,852'. 08/22/12 - Wednesday Wash over fish @ 4,852'. Engage same with 4 -6K set down weight. P/U to 14K over and fish came free. POOH to BHA. Lay down fish. Redress overshot with 4 -7/8" grapple. RIH to 4,870' and tagged obstruction. Reverse circulate @ 6 BPM /400 psi while working down to TOF @ 4,886'. Work string up to 14K over, P/U weight at which time the fish came free. POOH to BHA. M/U 4 -1/2" grapple in overshot and P/U same. RIH with 4 -1/2" overshot to 4,871' (no tag). Expected TOF @ 4,886'. Circulate at 3 BPM /100 psi down tubing and wash down 4,871' to 4,890'. Set down 6K and engage fish. P/U to 72K and fish came free. Work back over fish without circulating and attempt to re- engage. P/U weight to 80K. Stage circulation up to 3 BPM /100 psi. Work fish up @ 58 - 60K P/U weight. Shut down pump. POOH. 08/23/12 - Thursday POOH to BHA laying down 4 -1/2" 563 tubing. Lay down overshot and 1 joint of fish. Estimated TOF = 4,884'. R/U Hawkjaw and break down IF connections on overshot. Pull wear bushing. M/U muleshoe. RIH with 4 -1/2" IBT tubing to 4,838'. M/U tubing hanger in work window with two -way check valve installed. Land tubing hanger. Run in lock down screws. Lay down landing joints. Tubing tail set at 4,838'. R/D flow line, bell nipple and bleed down accumulator /disconnect hoses. N/D BOPE. 08/24/12 - Friday Y N/D BOPE. N/U tree - test hgr and tree 5000 #. R/D power packs and cont R/D unit. L/D tong arm and gin pole. 08/25/12 - Saturday Move gin pole off deck. R/D basket and remove riser. Continue R/D equip. Return to production. 1 • • o „, „ AL/ [0) SEAN PARNELL, GOVERNOR ALASKA OII, AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Ted E. Kramer g � � j _ Senior Operations Engineer 1 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur /Hemlock River Field, Middle Kenai G Oil Pool, K -24RD2 Sundry Number: 312 -170 Dear Mr. Kramer: 4 MAY 2 2 all 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 Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy /P. Foerster Chair DATED this 2I day of May, 2012. Encl. � .�,/R ECE I V ED 1 } s .ti STATE OF ALASKA MAY 0 20 ALASKA OIL AND GAS CONSERVATION COMMISSION DTI 6 J z( /+ L. APPLICATION FOR SUNDRY APPROVALS AOGGC 20 MC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing 0 Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Development ❑ Exploratory ❑ 201 -141 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number. 3800 Centerpoint Drive, STE 100, Anchorage, AK 99503 50- 733 - 20330 -02 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number property line where ownership or landownership cianges: Spacing Exception Required? Yes ❑ No El K -24RD2 9. Property Designation (Lease Number): 10. Field / Pool(s): Trading Bay Unit ADL0018730 McArthur River /Hemlock & 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): 14,200 9,999 14,157 9,965 14,157' none Casing Length Size MD TVD Burst Collapse Structural 330' 24" 330' 330' Conductor 409' 18 5/8" 409' 409' Surface 5,712' 13 3/8" 5,712' 4,165' 3,450 psi 1,950 psi Intermediate 10,793' 9 5/8" 10,793' 7,487' 6,870 psi 4,760 psi Production 6,237' 7" 14,199' 9,992' 8,160 psi 7,020 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Various 12,680' - 13,160' / Various 8,871' - 9,234' / 4 1/2" & 3 1/2" 12.6# L -80 & 9.3# L -80 7,879' & 12,599' Various 13,370' - 13,882' Various 9,384' - 9,760' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 3 1/2'x7" Baker SAB Injection Packer / 4 1/2" TRSSSV Baker SAB Injection Pkr 12,518' (MD) & 8,748 (TVD) / TRSSSV 297' (MD) & 297 (TVD) 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch O Exploratory ❑ Development ❑ Service S 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/1/2012 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ El GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Printed Name Title E. Kramer Title Sr. Operations Engineer Signature 1,/ , Phone (907) 777 -8420 Date 5/2/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 12, l -) 6 Plug Integrity ❑ BOP Test V Mechanical Integrity Test M Location Clearance ❑ Other: 5(,7p / rs/ 2 /' --I3 N',t / fv ,'n /7 l e. tr `l 5. / . 0 �/.,��a 1 d Subsequent Form Required: /0 — 40¢ / 2 -- °,��/ APPROVED BY _ Approved by: / - ' COMMI SSIONER THE COMMISSION Date: � _ al _. 8 Di1AS 7 MAY 2 2 2012 /�� �� ORIGINAL �� ,c � ✓ ,,,,,. FoIrm 10 -403 Revised 1/2010 V Lf" Submit in Duplicate 4 • • McArthur River Field K -24RD2 May 19, 2012 Hilcorp Alaska, LLC OBJECTIVE: • To Repair the tubing to casing leak in well K -24RD2 on the King Salmon Platform Current BHPinj: 4435 psi @ 9,312' TVD Max Downhole Pressure: 4435 psi @ 9,312' TVD (Based on Hydrostatic calculation using specific gravity of sea water plus the injecting tubing pressure) MASP: 0 psi. The tubing pressure drops to zero within 24 hrs.of shutting in well. PROCEDURE SUMMARY: 1.) MIRU Cudd Hydraulic Work Over Unit (HWOU). 2.) ND Wellhead. 3.) NU and test BOP Stack to 250 psi. low / 2500 psi. high. (Notify AOGCC 48 hours in advance of BOP test). 4.) RIH with tubing punch on E -line to 12,500'. Punch Tubing. 5.) Reverse circulate one tubing volume to circulate any oil on tubing string. 6.) Monitor fluid loss in tubing. Pump graded rock salt pill down tubing in FIW to adjust fluid loss to acceptable rate. 7.) RIH with Jet cutter to 12,513' ( + / -). Cut and pull 4 -1/2" X 3 -1/2" injection tubing from well. 8.) PU new 4 -1/2" X 7" hydraulic set packer with a 4 -1/2" X 3 -1/2" reducerover shot on bottom. 9.) RIH with pkr. assemblyand over shot on 4 -1/2" tubing to 12,500 ( + / -) Note: Over shot on tubing tail will swallow tubing stub of 3 -1/2 "tubing looking up. Note: Packer set depth must be within 200 feet of top pelf. (topperf = 12.680'). 10.) RIH with plug and set in XN nipple on bottom of the packer. 11.) Circulate pkr. fluid down back side. 12.) Set hydraulic pkr. s t c) ('! rt 13.) RD BOP, RU Well Head 14.) Turn over well to production to perform MIT. 3o kv) , ` 5` p s t C 1<r�, ✓ t 15.) Return to Injection. 16.) RDMO well. w:1-hesS N(( 44 ..f��,- s itt3 -E � N U Well Identifier REVISEDBY: Initials MM -DD -YYYY McArthur River Field K -24RD2 May 19, 2012 Hilcorp Alaska, LLC Trading Bap Unit King Salmon Platform Wells K -24RD2 Injector Actual 1202 (G -Zone Perf Add) REB t3 :'BG Hh u_=er= 34.55 C-ASINGANID TLBLNG DETAIL SIZE UT GRADE CONN TOP BOTTOM 2s Driven 330' 18 -5 8" 131 H.40 0' 409' 13 -3 8" - 2 68 1+780 K55 0' 5 l ' 9 -5 8" 4" N -80 S-95 0' 10 J _ '" 29 L -80 KC Burnes s 7 962' 14199' Tubing: 4 -12 124 L -80 Buttress 0' 7 8'9' J 3-1 2" 93 L -33 Buttzzss - 8 - 9' 12599' Gas Lift Mandrels: J 1 2590' 4 -1 2" SFO -2 01.11 with R -2 valve and RK lath 2 5169' 4 -1 2" 8FO -2 GLM with R -2 valve and RK lath 3 6618' 4 -1 2" SFO.2 C-LM with R -2 valve and RK lath J 4 " 4 -1 2" 70 -2 GLM with R -2 valve and RK lath 5 8486' 3 -1'2" SFO -2 GLM with R -2 valve and RK lath 6 9324' •_,- : e"r0 -2 GLM with R -2 valve and RK lath — - • -itt " 101. -' ' : SFO -2 GLMwith R -2 calve and RK lath J top 2 8 1: • - : '".CFO -2 GLM with R -2 valve and RR lath 952- 9 :.. 7O -2 GLM with R -2 valve and RK Iath 10 11936' 3- SFO-2 GLM with R -2 valve and RK lath J 11 12438' 5 : SFO 2GLM with OriSce valve and RKlatch JEWELRY DETAIL NO. Depth Item 1 29 "SSSV.4 -12" J 2 - 8 - 9' X4Te1.4 -1 2"x 3 -1 2 buttzm 3 12518' Baker S.AB 3 -1 2' x -" injectionpar_kec J 4 12565' 3 -1 2" i "nipplew 2 813-1D 5 12599' Inbinetail -- J a 9-5 8" window J 1 10793' PERFORATION DATA X X' _ TOP BTM ZONE SPF DATE COILNSENTS /\ 12680 12 - 13 G -i 5 4 12 12 G-2 6 _ . -- 12860 12393 0-3 6 12 ' 2: 12910 12981 C= 6 12: :: _ 130'0 13160 0-5 6 12 = :: 133 13400 H3 -1 6 10 : - 0: — 13445 13460 HB-2 6 10 := :1 _ 13510 13520 H3-2 6 10 2: ... 3; 3_: ._ i — 135 13580 1-S-2 6 10 :2 :1 -:: %es 13618 13633 HB -3 6 1 :_ :: 13640 136 - 0 HB-3 6 12 : - :: TD = 1!,200' MDi9999' TVD 13688 13 "33 E3 r 6 13 :' l 13 1373 HB-t 5 1 :- l 2370 = 1415" 1385" 13882 H3 -5 6 10 : : 0: Max angle = 61' g !S00' Hole Angle =40' g TD' Well Tdentifier REVISEDBY: Initials MM- DD -YYYY . , • • , , 1 H i lcorp Alaska Cudd Snubbing 13 %" 5M HWO Stack E A ((,) ,13-5/8 11 HYDRIL05111.tv pi, e H 0 '' ' P ri S HEIGHT] 54-1/8' INCHE, WEIGHTI 13,800 LBS NATURAL Maki AVOID OIL BASE MX) L IOW TEMP FlurDs x x REN elk I n n ent I en 0 s 110 l" It ILI 'r 0 yr a" NJ Lit II.F ni. V SA O Pipe Mike Freeman 713-252-1944 _ _____ Houston, Tx. L C O 1 D Vinci/Shear rooster Bonnets Instd. 11 • Cap 11 ......- LI im t i ----- - A - _ -- L II I ___ Lur ur - , "...,- i 13-5/8' 5M t:1 IllrA I . 1 ar0 7 DRILLING v) li 111041114111 1 t SPOOL ■ 3> I t NI "• 5M VALV 1 4-1/W 5N 4-1/16' 5N -X- -X- 2-1/16* 314 2-1/16' 5N RSA. RSA • XS lUr CP' P res8239 L..... 0 j c — C_ 11 111111111 1 4 . ., • 4 ..._ . • • King Salmon Platform K -24RD2 Current 03/19/2012 I$.i.... t1.4.., 11-1 King Salmon Tubing hanger, FMC -UH- K-24 TC- 1A -EN. 13 5/8 5M X 24X133/8X9518X4112 4' /EUE8rdlift and susp, w14 ' type H BPV, Alloy material BHTA, B- 11 -A-0, 4� 1/16 SM FE ,� y t 1• 1 I. 1 .. ogre. Valve, Swab, VG -200, 4,4 41 /165M FE, HWO, A , EE trim 1iii.> 1.11.1 f.11II r III, 171 Valve, Swab, OCT -75, " 4 1/16 5M FE, HWO, 6'7,1',* 4I„ EE trim - lJy . 1. 1 : i 1 ; . -,--- - 'O... L Valve, Master, OCT -75, 4 1/16 5M FE, HWO, EE r'i trim !" Lf ,v 1e ' "' "- Adapter, FMC ASP, 13 5/8 Voic test g..c 1.__ -__ 5M API clamp X 4 1/16 5M, 25015000psi \ w/ 7" extended neck pocket co 19/201 ' 0\ ,, r_ , J Unihead, OCT type 3, 13 5/8 5M - .. 4 API hub top X 13 3/8 BTC casing i I 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 = ( 4'., SSO on upper section , IP i intemal lockpin assy 4J re All annular valves are 2 1/16 5M OCT -20 - .1 . c i'1 i ridi4 - :s _ _ tra ,.... .,.,__ I ,41 Starting head, FMC, I , t # :,P 21 "' 2MX24" 4 • +. .ti ) ' SOW, w/1- 31/82M EFO Il 24" � 13 3/8" g • • • Trading Bay Unit K -24RD2 05/01/12 Hilcorp Alaska, LLC OBJECTIVE: • • To Repair the tubing to casing leak in well K -24RD2 on the King Salmon Platform Current BHPinj: 4435 psi @ 9,312' TVD Max Down hole Pressure: 4435 psi @ 9,312' TVD (Based on Hydrostatic calculation using specific gravity of sea water plus the injecting tubing pressure) MASP: 0 psi. The tubing pressure drops to zero within 24 hrs. of shutting in well. PROCEDURE SUMMARY: 1) MIRU Cudd Hydraulic Work Over Unit (HWOU). 2) ND Wellhead. 3) NU and test BOP Stack to 250 psi. low / 2500 psi. high. (Notify AOGCC 48 hours in advance of BOP test). 4) Pump 150 bbls of FIW down tubing and monitor well to insure that it is balanced. qt/r4 5) Cut and pull 4 -1/2" X 3 -1/2" injection tubing from well. 6) PU new 4 -1/2" X 7" hydraulic set packer with a 4 -1/2" X 3 -1/2" reducer over shot on bottom. 7) RIH with pkr. assembly on 4 -1/2" tubing to within 50 ft of 3 -1/2" tubing stub. 8) Circulate pkr. fluid down back side. 9) Engage over shot over 3 -1/2" tubing stub. 10) Set hydraulic pkr. — 11) Perform MIT. 3cJfro+v; /2,5 vU /25 ( 11 a✓* 12) Return to Injection. K -24RD2 REVISED BY: TEK 05 -01 -2012 II • • Trading Bay Unit K -24RD2 05/01/12 Hilcorp Alaska, LLC UNOCAL 7G Trading S t m a Unit Ivne Salmon Platform Well 4 K- 24RD:Injector. Actual 1202 (C -Zone Perf Add) RILE to TBG Hanger - 34.85 CASING .4...ND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM - ::::% i...r. 33'0' 18 -5 r 101 H.40 0' 409' - l - 13 -3 r '2 68 N80 K55 0' 5'12' . 9 -5 r 4' N -80 3- 95 0' 10'93' (window) J A _ 29 L -S'3 1{0 B^m:es '962' 14199' Tubing: 4 -1 2 12 6 L -80 Buttress 0' 7 8'9' J 3 -1 2" 9 3 L -80 Buttsees '8'9' 12599' Gas Lift Mandrels: J 1 2593' 4 -1 2" SFO -2 GLM with R -2 valve and RX lath 2 5169' 4 -1 SF0 -2 GL?+t with R -2 valve and RX lath 3 6618' 4 -1 2" SFO -2 GLM with R -2 valve and RK lath J 4 " 4 -1 2" SFO -2 GLM with R -2 valve and RK lath - 5 8486' 3 -1 2" SFO -2 GLM with R -2 valve and RK lath 1 - 6 9324' 3 -1 2" SF0 -2 GLM with R-2 valve and RX lath -- — - ' liter 1013' 3 -1 2" SFO -2 GLMwith R -2 valve and RX lath J ' 8 10'8S' 3- 12 "SFO -2 GUI with R-2 valve and RKlath `62 * 9 113 "5' 3 -1 2" SFO -2 GUI with R -2 valve and RK lath 10 11936' 3 -1 2" SF0 -2 GLM with R -2 valve and RK lath J 11 12433. 3-1 2" SFO 2 GLM with Orifice valve and RX latch JEWELRY DETAIL J 7 O. Des Ilea 1 29'' TRSSSV.: - J 2 '8"9' x41.4.4 -1 2 " x 3 -1 2 " buttress 3 12518' Baker SAB 3 -1 2' x ' "injectionpacker J 4 12565' 3 -1 2 X" nipple w 2 813 5 12599' Tubingtail J 9 -5 ..' indow ' J 10'93' PERFORATION DATA X X 3 TOP BTM ZONE SPF DATE CONL‘iEN - TS /\ 12 1: - 1: G -1 6 12 -50 12 G -2 6 : :: ' 2 12860 12890 0 -3 6 . _ _ :2 12910 12980 0-4 6 130'0 13169 0 -5 6 1: 4 :2 133'0 13499 HB-1 6 10 : - 31 13445 13460 HB-2 6 10 29 01 13510 13529 HB-2 6 10'2901 :.-.1 ms 135"0 13580 HB -2 6 1029 01 et Iris • L 13618 13633 HB-3 6 10 :1 01 13640 136'0 HB-3 6 10 :: 31 TD = 14.200' MD 9999' TIT 13"33 HB-4 6 I :: :1 13'6" 13"8' 11114 11114 6 14 - 31 PRIM = 1415" 1385' 13882 HB -5 6 10:.: 31 Max angle = 516 g 4800' Hole Angle = 40• g TD' K -24RD2 REVISED BY: TEK 05 -01 -2012 • Ferguson, Victoria L (DOA) From: Ferguson, Victoria L (DOA) Sent: Wednesday, May 16, 2012 11:06 AM To: 'Ted Kramer' Cc: Schwartz, Guy L (DOA) Subject: RE: K -24RD2 Ted, The procedure for this well is lacking: 1. How are you fluid packing the well to balance the IA /tubing? 2. At what depth are you cutting the tubing? 3. Where is the packer set? 4. Rig down BOPs /NU tree Please resubmit a procedure. Thanx, Victoria From: Ferguson, Victoria L (DOA) Sent: Wednesday, May 16, 2012 9:38 AM To: 'Ted Kramer' Cc: Schwartz, Guy L (DOA) Subject: K -24RD2 Ted, We have the outstanding request on K -24RD2 as outlined below: Please provide a schematic of the well post - workover. A hand drawn sketch is fine. We have the following questions which could be addressed with a schematic: 1. Do you plan to rerun the SSSV or a profile? 2. At what depth is the new packer going to be set? The packer depth relative to the perforations must meet 20 AAC 25.412 — "The packer must be placed within 200 feet measured depth above the top of the perforations, unless the commission approves a different placement depth as the commission considers appropriate given the thickness and depth of the confining zone." Thanx, Victoria From: Ted Kramer fmailto:tkramer ©hilcorp.coml Sent: Wednesday, May 16, 2012 6:29 AM To: Ferguson, Victoria L (DOA); Tom Fouts - (C) Cc: Larry Greenstein; Juanita Lovett; Schwartz, Guy L (DOA) Subject: RE: Format for Sundry Applications - RWO Victoria, 1 • Thank you for the clarification. We will do our best to comply with these requirements on future submittals. However, for the applications that have already reached your desk, how do you propose that we complete those? For example, what do you need to complete the 12 RD? We are currently rigging up on this well, and need to get the permit completed. I believe we all realize that this is a transition period for several of us. Now that we have this clarification, the process should smooth out considerably. Please call if you would like to discuss? Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC Office Phone 907 - 777 -8420 Cell Phone 985 - 867 -0665 From: Ferguson, Victoria L (DOA) f mailto :victoria.ferquson(aalaska.govl Sent: Tuesday, May 15, 2012 10:01 AM To: Tom Fouts - (C); Ted Kramer Cc: Larry Greenstein; Juanita Lovett; Schwartz, Guy L (DOA) Subject: Format for Sundry Applications - RWO All, Please find a standardized format for rig workover (RWO) sundry applications(10 -403). This outlines all the needed information and will reduce time in processing the application. Please refer to this as you prepare future sundry applications. Thank you in advance, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson a(�alaska.gov 2 • • II Trading Bay Unit King Salmon Platform Well # K -24RD2 Injector Hilrnrp Alaska, L1,1, t, I Proposed Schematic RKB to TBG Hanger = 34.85 CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 24" Driven 330' 18 -5/8" 101 H -40 0' 409' 13 -3/8" 72/68 N80/K55 0' 5712' L , 9 -5/8" 47 N- 80/S -95 0' 10793' (window) L , 7" 29 L -80 KC Buttress 7962' 14199' Tubing: 4 -1/2" 12.6 L -80 Buttress 0' 7879' 1 9 1 T -R(1 Biittrecc 7R79' 17599' JEWELRY DETAIL NO. Depth Item 1 +/- 12,518' 4 -1/2" Tubing 2 +/- 12,518' 4 -1/2' x 7" injection packer 3 +1- 12,599' Tubing tail, Nipple & WLEG 1 PERFORATION DATA 7" liner top @ ZONE TOP(MD) BTM(MD) TOPITVD) BTM(TVD) SPF DATE COMMENTS 7962' 0-1 12,680 12,710 8,871 8,894 6 12/5/2002 G-2 12,750 12,790 8,925 8,956 6 12/5/2002 G-3 12,860 12,890 9,009 9,032 6 12/5/2002 G-4 12,910 12,980 9,047 9,100 6 12/5/2002 G-5 13,070 13,160 9,168 9,234 6 12/4/2002 HB -1 13,370 13,400 9,384 9,406 6 10/17/2001 HB -2 13,445 13,460 9,437 9,448 6 10/29/2001 HB -2 13,510 13,520 9,484 9,491 6 10/29/2001 HB-2 13,570 13,580 9,526 9,534 6 10/29/2001 Z. , 9 - 5/8" HB-3 13,618 13,633 9,561 9,572 6 10/28/2001 window HB -3 13,640 13,670 9,577 9,599 6 10/27/2001 @ 10793' HB-4 13,688 13,733 9,612 9,644 6 10/25/2001 HB-4 13,767 13,787 9,670 9,670 6 10/27/2001 2 HB-5 13,857 13,882 9,737 9,755 6 10/21/2001 3 1/27/10: 2-1/2 swedge tagged ----.0, MAY 3 Y 2 3 ZQ1Z at 13965'. L TD = 14,200' MD/9999' TVD PBTD = 14157' Max angle = 57° @ 4800' a Hole Angle = 40° @ TD' O:\ NAU \MCBMAlaska\Depts \CI_oil_Ops\ Fields \TBU\ King \Wells\Injectors\K- 24\K- 24RD2\ Schematics \K- 24RD2ActSchem1202.doc Revised by: TDF 5 -21 -2012 P� 2-6 I t 4- ( 0 Regg, James B (DOA) From: Ted Kramer [tkramer @hilcorp.com] Sent: Wednesday, April 25, 2012 11:13 AM � 4( ZI tv To: Regg, James B (DOA) 1( Cc: Schwartz, Guy L (DOA); Larry Greenstein Subject: K -24RD2 and G -5RD updates Jim, I wanted to write a note and give you an update on the above two wells. IJDJUN 0 5 2012 K -24RD2 We attempted to run a camera in this well to confirm or deny the parted tubing (4,438 feet) issue to help get this well ready for repair. We ran the camera and made it to 4,468 feet (no part in the tubing observed) became stuck (Heavy buildup on the tubing walls observed). Attempts to free the camera resulted in pulling out of the rope socket leaving the camera in the well. We then rigged up slickline to retrieve the tool. We latched onto the camera with slickline but could not pull it free. We then had to cut the slick line leaving those tools in the well also. Plan forward is to mobilize Coil tubing to the King platform to rig up on this well to fish out the camera and to clean the tubing in advance of the CUDD unit. We need to tubing clear and relatively clean in order to get a cutter down the well to cut the tubing for removal. The coil tubing unit just came off of the Dolly platform. The vendor has some repairs to perform on the unit this week and then we will take it to the King Salmon for this well. The CUDD unit is scheduled to be here May 6` If the K -24RD2 is not ready in time, we will go to the Dolly Platform with it for a conversion and then back to King as soon as this well is ready. G5RD Attempts to remove the plug from the tubing after the jug test were unsuccessful. We ran into the well with e-line to see where the plug was. The thought was that if the plug was located below the packer we might be able to shoot off the tubing tail to restore the well to injection. Unfortunately, the plug was confirmed by e-line to be stuck above the packer so this is not possible. Therefore, we have placed this well on the workover list for when a workover rig is placed on the grayling platform. We anticipate that a rig will be there around June 15 Please let me know if Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC Office Phone 907 - 777 -8420 Cell Phone 985 - 867 -0665 1 • • -ck r— z z._ Regg, James B (DOA) PMT � (4-t0 From: Regg, James B (DOA) Sent: Thursday, April 05, 2012 1:08 PM \ \ � ®,q To: 'Ted Kramer'; Larry Greenstein 1 Cc: Schwartz, Guy L (DOA) Subject: RE: K -24RD2 Upcoming Workover and King Salmon Waterflood Injection Ted and Larry - Thank you for coming in to discuss the strategy Hilcorp has for restoring temporary injection in TBU K -24RD2 (PTD 2011410) to facilitate diagnostics that will be used to repair this important water injector on the King Salmon platform. During today's meeting you reiterated the plan as described below; that plan is acceptable to the AOGCC. You may recommence temporary water injection into K -24RD2 without completing the temperature survey that was required in January 2012; annuli pressures reported to the AOGCC as a condition of administrative approval A10 5.010 confirm the production casing has integrity; previous temperature surveys show injected water is exiting the wellbore through the perforations as intended. The other approval conditions of A10 5.010 still apply. If there is a significant delay in the planned start of the TBU K -24RD2 rig workover (beyond June 2012) please contact us for additional discussion. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 > APP 21) '7 Anchorage, AK 99501 907 - 793 -1236 From: Ted Kramer [mailto:tkramer©hilcorp.com] Sent: Tuesday, April 03, 2012 6:45 AM To: Regg, James B (DOA) Cc: Larry Greenstein Subject: K -24RD2 Upcoming Workover and King Salmon Waterflood Injection Jim, As you are aware, water flood injection is currently down on the King Salmon Platform in the Cook Inlet due to the lack of operable water injection wells to inject the minimum capacity rate (20,000 BWPD) of pressurized injection water from the platform injection pumps. When K -24RD2 injection well went off line, the minimum injection rate could no longer be maintained. K24RD2 went off line because we could not get down to perform a compliance temp survey when it became due. Therefore, Hilcorp shut the well, and consequently, platform injection in. It is the intention of Hilcorp Energy to repair this injector. To that end, the Cudd Hydraulic Workover Unit has been mobilized for this repair and will be rigged up on this well by the third week of May. In preparation for that work over, Larry Greenstein and I would like to meet with you discuss the possibility of placing this well back on injection and starting up the water flood so that we can: 1 i • 1. Get clean, clear fluid going into this well so that a camera can be run to determine the severity of the obstruction (tubing part /collaspe or scale). This information will greatly aid the repair planning and design for K- 24RD2. 2. Pressurize the reservoir in the local vicinity of this well so that the well can be back flowed during the work over process. This will allow solids to be circulated out of the well during the execution of the work over Please let me know if and when your schedule would permit this discussion. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC Office Phone 907 - 777 -8420 CeII Phone 985 - 867 -0665 2 . , . 1 ?PI) Z61- 141 ) Ulan_ , ,--1 Unit ' UNOCAL.. n saintaa Platform WO* 1(0.941WA14.4940t Axtus11202, (eriaie pettAitio RAM 16 TG r9485 4N U'cD WE '''SvT altADE COV TO , . VT4 g ±- 4- f- 24" Driven 330' „ 18-5/8” tifi it* 13-3/8" 72/68 149940, if put 5 3E0 1 i 3 1 ;„ ; .e. 1 b "on 47 N410/045 19)1D 6 870/ -- . 00000 SI 1' KCB. Ss 7962 " 14199* Z, 29 L40 K 6 .s. TtthitiV , 4-1/2* 124 L40 BUR:rest 0' 7879" S4 3ops; (7 9.,„)... )- ■ 4- 34/" 9.3 L40 BUR** 7879' 1099' /0, 1 6 c• - '` r Re_54-tc4-tix. 40 Lift blorkelst (io 540,,, 0 r ) 1 2.199' 4-1/.2-701,14 witiriti.v*eli4t000, /Moo' - I- 700' / 2 . 5169' 4-1/2 Si02 GI* vidiatia *ye ISARE kW* -iitkii-- Lti i r 40 1 461 41-11 4 7744* 4-112" 810-204**1419,4,41va 104 RN, 44th 5 8486' 3-1/2" SR04 crat ‘Wit1B-Zittlito*OAKA100 2 :6 9124 3-1/2”5102 431.24 wliik•ivithwairl Mita t lino} 7 10137' 3-112” SF0•213U4 *46,R4,9rdvitAiritRK Nick , , 01 8 107W 3-1/2” ST0-20144*161114100:0411X.1144 j 11 /962' 9 lials' 34/2" Sf0-2 GL/i4w110,t4 A* . WO 10 1193.6' i-1/2" sit0.2 Mu with JO veivearvitt 1et0 , j It 1242 j-iir 004 Oilitwitti-00Tice wave 4904004/11 J novutylottAk. j NO .,.; xtesi 1 . Attfiti;*ttr J. 2" 7819 Xevq, 4-1(2" x342' *cos * tkit *timedi****7 c37 41 4 1 4:- 9-5/8** 4 12565* 34/2r 4 1'**1 'OAS" TO 5 12599' 1*16110411 ' 1: ii4o4vw i 4#/, 109at P OMR 1#914 DAtitt, _ 44 ToR trot ion BO , ' H,No$Iilacr$ . noso Ivo 0-1 6 2 • ' - it* 1090 0-2 6 122 ' = 00 I • t ,4M 6 O 0 04 . 5 • 12010 12980 04 6 124102 ▪ 13070 13160 0-5 6 'WW2 • 13310 13400 H-1 6 107101 • 13445 13460 1i 6 10129* • 13510 135:00 19B-2 6 tetztvot • ono taw 1: -2 6 10/29/01 „ M.... • 13018 13633 HB-3 6 10,2sidi . 4 Path k> TagSedi1319 4. • 13640 13670 1111-3 6 10/27/01 • 13688 13733 ''.: -4 6 10/25101 i TD*14,2410* 011}111999i TVD • 1376/ 13* H134 6 idev/91 , TIM r•-- 141$7* ' 13857 1102 11134 6 10/21/01 A* 1 411 1 4 s Sr lit, 1104 Am* = 40° r" TD' 0:001100ErsoldenlAKirOW404*-24%-24REG‘Scher44604%2411132ANScheral2024oc \ - DRAWN BY DIM • • of 1/ Z / Z,f4 ( Plot Pressure & Rate vs Time - Well K -24RD2 2500 — I kr e . 10000 •9 5/8" I 2000 - 13 3/8" 26" Tubing —Vol 8000 1500 z /_— a, 6000n m E m a` 1000 4000 500 - - 2000 0 -, i ...1r111111■04. L ..........4--...p.— o N N M N N co N R O O N O O O 0 . • .,'1 til i 'i' jSi l /i\ Plot Pressure & Rate vs Time - Well K -24RD2 ,... _ .,,. - 12000 2500 __ rr - 10000 -9 5/8" - 8000 13 3/8" 26" 1500 Tubing a Vol K -24 v 6000 N a) Cr. 1000 — — - - 1 - 4000 500 k - 2000 \ O \ p M N N 0,3- 1 O th M n M V 0 c0 o 0 fl {� O {'f O 0 • • tot s( p_ ; /3 / /t( Plot Pressure & Rate vs Time - Well K -24R02 2500 — P ro■ —P. A ■Jrnlw — i m illi.—_ . 10000 2000 — I PvP"' f 11 4 — 5/8" 13 3/8" 8000 26" Tubing —Vol K -24GL 1500 — — — - — v 6000 N ■3 J G! m O: 1000 — — - 4000 500 0 2000 A i 1 0 0 0 0 0 O N N co N co co N_ N N CV CO 01 0 ,- O O O 0 • • 4 (1,i - 9( Plot Pressure & Rate vs Time - Well K -24RD2 3000 .. ° 12000 \-4111"1111111 ill 2500 , AI I 10000 -9 5/8" 13 3/8" 2000 26" 8000 1 ■� +•Tubing -Vol v tg 1500 -- --- 6000 r a 1000 4000 500 2000 I 0 ... _ 0 _o _o o_ 0 0 0 0 ` \ \ N N O O 7 to co co W o n n n o 0 0 0 • l O/ b 7- 3 / 3 j/r9 Plot Pressure & Rate vs Time - Well K -24RD2 r _ _au% ------) 4 — I � _ I 10000 ) 0111.40,.......... 2500 . - ir •9 5/8 8000 2000 - -- 13 3/8" -- 26" Tubing —Vol E 1500 - - -- J _ __ _— 6000 0 vl m y m a` 1000 4000 I 4 i 500 - - 2000 0 0 0 m 0 rn o 0 0 0 0 0 0 0 o rn a> w n rn CO 07 N N N N N M O ,- . O O O SUS O Pr f) MI f "f) 201 -1 • (Chevron I Well:IK -24RD2 I FieId:IKing Salmon 101 -27 -10 I Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 0 — Pressure - Temperature Profile I 1 Going in hole TVD �� 2. Well Shut In 1000 All '� _ Iii 2000 - -- - - - -_- — - -- - 2 3000 t tt 4000 C CD 111111 -- 5000 F 6000 k 46k F 7000 - 11 - 1 8000 — - - -- 1 , 9000 lb 1 I 10000 i , Q CLCk-Cr 6 Z(� �� ' 30 40 50 60 70 80 90 100 110 120 130 140 Temperature (De9. F) 1 -27 -10 Pressure — Perfs A GLM 13 3/8 9 5/8 7 — TBG •1 - 27 - 10 Temp - 12 -21 -07 Temp • • Chevron John Zager Union Oil Company of California General Manager, Alaska 3800 Centerpoint Drive, Suite 100 MidContinent/Alaska SBU Anchorage, AK 99503 Tel 907 263 7815 ■%\--Q60 Mobile 907 223 0128 Fax 907 263 7897 Email jzager @chevron.com b k %O Ca- -OSL 1 -�3 V r� t bps -(3V`S ECEivE November 16, 2011 `— ‘ A \M NOV 3 7 ?O' UIC Manager 9�S Thor Cutler, OCE -082 VA— v lQ% i ' c)(0\---\ ` °flCP or U.S. Environmental Protection Agency, Region 10 1200 Sixth Ave., Suite 900 , } t� c it `! Seattle, WA 98101 . Re: Amended Request for Permit Transfer: Underground Injection Control (UIC) Permit No. AK- 1I006 -A by Union Oil Company of California ( "Union ") to Hilcorp Alaska, LLC Dear UIC Manager: Please replace my letter dated November 15, 2011 requesting permit transfer of Underground Injection Control (UIC) Permit No. AK- 1I006 -A by Union Oil Company of California ( "Union ") to Hilcorp Alaska, LLC. Union Oil Company of California ( "Union ") has entered into an Asset Sale and Purchase Agreement dated July 1, 2011 to sell its interests in the Cook Inlet Area to Hilcorp Alaska, LLC, ( "Hilcorp ") with an anticipated closing scheduled on or about December 15, 2011, assuming certain regulatory approvals are received by December 1, and all other Closing conditions are met. The actual closing date may vary depending on how quickly certain regulatory approvals are processed. The transfer of Union's interest to Hilcorp is conditioned on the completion of the transaction ( "Closing ") pursuant to the Asset Sale and Purchase Agreement by and between Union and Hilcorp. Union and Hilcorp will advise you upon Closing that the transfer has become effective, and Hilcorp has taken over Union's interest and operations, including the above referenced UIC Permit No. AK- 1I006 -A. Should the Closing for any reason not occur, Union will advise you that it has retained its interest. Environmental Protection Agency (EPA) Form 7520 -7, Application to Transfer Permit, is enclosed. Eight wells are permitted as candidate wells for Class I operation under this permit. These eight wells are: Dolly Varden Platform wells D -9RD and D- 15RD2, Grayling Platform wells G -5RD and G -16, King Salmon wells K -11 and K- 24RD2, and Steelhead Platform wells M -27 and M -30. Currently, only D -9RD has received written authori7atinn from EPA Region 10 to commence Class I infection. An agreement memorializing the transfer of UIC Permit No. AK- 1I006 -A from Union to Hilcorp is also enclosed. 1 of 2 • UIC Manager US Environmental Protection Agency November 16, 2011 Page 2 We appreciate your attention to this request and apologize for the inconvenience. Should you have any questions, please do not hesitate to contact Faye Sullivan at FayeSullivarachevron.com or 263 -7685. Regards `✓L� John ager Enclosures: US EPA Form 7520 -7 Agreement to Transfer UIC Permit No. AK- 1I006 -A cc: John A. Barnes, Hilcorp Alaska, LLC Marc Bentley, ADEC Cathy Foerster, AOGCC 2 of 2 • • OMB No. 2040 -0042 Approval Expires 1213112011 United States Environmental Protection Agency co 1% Washington, DC 20460 C Application To Transfer Permit Name and Address of Existing Permittee Name and Address of Surface Owner Union Oil Company of California; P.O. Box 196247 State of Alaska, Department of Natural Resources Anchorage, AK 99519 -6247 550 West 7th Avenue, Ste. 800; Anchorage, AK 99501 State County Permit Number Locate Well and Outline Unit on Alaska NA -State waters offshore AK- 11006 -A Section Plat • 640 Acres N Surface Location Description t ill l I ' I , Sc 1/4 of tie 1/4 of SW 1/4 of SW 1/4 of Section j Township 8n Range 13w -4-1--4- _ 4 - I. 4 _ j Locate well in two directions from nearest lines of quarter section and drilling unit I I ( I Surface 7 r7 7�r7 t :-.4-1-4- ^ 4 -1- 4 - I Location 754 ft. frm (N/S) S Line of quarter section t 1 I I ( I I L and i i lat. from (E/W) w Line of quarter section. W I 1 1 I I I i 1 Well Activity Well Status Type of Permit - - r' - - -, - -- Class I X Operating , Individual I I I I 1 I Class H Area MoModification/Conversion -- Conversion � % I t , Brine Disposal Number of Wells _ - - k` - ^ " r I _— Enhanced Recovery ir Proposed I I I I I I ( , Hydrocarbon Storage S ^ Class III Other Lease Number See Attached Well Number See Attached Name(s) and Address(es) of New Owner(s) Name and Address of New Operator Hilcorp Alaska, LLC; 3800 Centerpoint Drive Suite 100; Hilcorp Alaska, LLC; 3800 Centerpoint Drive, Suite 100; Anchorage, AK 99503 -5826 Anchorage, AK 99503 Attach to this application a written agreement between the existing and new permittee containing a specific date for transfer of permit responsibility, coverage, and liability between them. The new permittee must show evidence of financial responsibility by the submission of a surety bond, or other adequate assurance, such as financial statements or other materials acceptable to the Director. Certification I certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those Individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. (Ref. 40 CFR 144.32) Name and Official Title (Please type or print) Signature Date Signed John "Lager, General Manager 11/15/2011 EPA Form 7620 -7 (Rev. 12 -06) • • Attachment to Form 7520 -7, Application to Transfer Permit One well is fully authorized for operation as a Class I well. An additional 7 wells are proposed candidate wells, but are not fully authorized for operation as Class I wells. The location map and surface well location shown on the front page of EPA Form 7520 -7 illustrates the location of the 1 authorized and operating Class I well. Well information for each of the 8 permitted wells is included on this page. Well API No. Lease Feet from Section Seward Meridian Line (Surface location) Sec Twp Range Authorized Well D -9R0 ' 50- 733 - 20131 -01 -00 ADL 018729 756 FSL/ 1138 FWL 6 8N 13W Permitted wells M -27 50 -733- 20423 -00 -00 ADL 018730 974 FNL/ 531 FWL 33 9N 13W M -30 50- 733 - 20430 -00 -00 ADL 017594 967 FNL/ 520 FWL 33 9N 13W G -5RD 50- 733 - 20162 -01 -00 ADL 018730 1838 FNL/ 1487 FEL 29 9N 13W G -16 50- 733 - 20060 -00 -00 ADL 017594 1879 FSL/ 1381 FEL 29 9N 13W K -11 50- 733 - 20148 -00 -00 ADL 017594 617 FSL/ 131 FEL 17 9N 13W K -24 RD2 50- 733 - 20330 -01 -00 ADL 018730 733 FSL/ 131 FEL 17 9N 13W 0-15 RD2 50- 733 - 20159 -02 -00 ADL 018729 754 FSL/ 1130 FWL 6 8N 13W FSL = Feet from south line of quarter section (feet south section line) FNL= Feet from north line of quarter section FWL= Feet from west line of quarter section FEL= Feet from east line of quarter section Agreement to Transfer UIC Permit No. AK- 1I006 -A This Agreement to Transfer UIC Permit No. AK- 11006 -A ( "Agreement ") is made the 15 day of November, 2011 between Union Oil Company of California, a California corporation ( "Union "), and Hilcorp Alaska, LLC., a Delaware limited liability company ( "Hilcorp "), collectively referred to as the "Parties," or individually as a "Party." RECITALS WHEREAS, Union and Hilcorp have executed an Asset Sale and Purchase Agreement dated effective as of July 1, 2011, ( "ASPA ") whereby Union agreed to sell its therein described interests in the Cook Inlet Area to Hilcorp; and WHEREAS, Union's interests in the Cook Inlet Area include UIC Permit No. AK- 1I006 -A; and WHEREAS, Union wishes to effect the transfer of that permit to Hilcorp as authorized by regulation promulgated by the Environmental Protection Agency ( "EPA ") at 40 CFR § 144.38(b); and WHEREAS, the EPA requires a written agreement between Union and Hilcorp containing the specific date for transfer of permit responsibility, coverage and liability between them. Agreement to Transfer UIC Permit No. AK -I I006 -A • • AGREEMENT NOW, THEREFORE, in consideration of each Party's intent to consummate the dosing of the ASPA, and for such other consideration the receipt and sufficiency of which is hereby acknowledged, the Parties agree as follows: 1. In the absence of notification to the Parties by the Director of EPA of the Director's intent to modify or revoke and reissue the permit, then effective as of the date of closing of the transaction contemplated by the aforementioned ASPA (the "Closing "), which Closing is projected to occur on or about December 15, 2011, subject to certain regulatory approvals being received by December 1, 2011 and all other Closing conditions being met, Union transfers and assigns to Hilcorp, and Hilcorp agrees to accept and assume, all of Union's rights, responsibilities, and liabilities under UIC Permit No. AK- 11006 -A. The specific date for transfer of permit responsibility from Union to Hilcorp for this permit will be on the actual Closing date, which is anticipated on December 15, 2011, but may be later depending on when Closing actually occurs. 2. Should the Closing not occur for whatever reason, the Parties agree that Union shall retain all of its rights, responsibilities, and liabilities under UIC Permit No. AK- 11006 -A, and Hilcorp shall have no rights, responsibilities, or liabilities under the permit. 3. In the event that the Director of EPA notifies the Parties of the Director's intent to modify or revoke and reissue the permit, then, assuming the Closing will nevertheless occur, Union shall undertake commercially reasonable efforts to cooperate with Hilcorp should it 2 Agreement to Transfer UIC Permit No. AK- 1I006 -A ! • choose to engage with EPA while the Director works to modify or revoke and reissue the permit. 4. Notices shall be made as follows: Union: Steve Wright Asset Development Manager 3800 Centerpoint, Dr., Suite 100 Anchorage, AK 99503 (907) 263 -7865 sswr @chevron.com Hilcorp: John Barnes Senior Vice President Exploration and Production - Alaska 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 (907) 263-7739 5. This Agreement may only be amended by written agreement signed by a duly authorized representative of each Party. 6. Except as set forth herein, this Agreement shall be binding only upon, and inure only to the benefit of, the Parties and their respective successors and assigns. No Party shall assign its rights or benefits under this Agreement without the prior written consent of the other Party. 7. This Agreement shall be governed by the laws of the state of Texas. 3 Agreement to Transfer UIC Permit No. AK- 11006 -A • • 8. The Parties have jointly drafted this Agreement, and this Agreement shall not be interpreted against or in favor of either of the Parties on the ground that any Party participated in drafting this Agreement. 9. This Agreement constitutes the entire agreement and understanding of the Parties with respect to the matters addressed herein. 10. In the event that there is any conflict between terms and conditions of this Agreement and the ASPA, the terms and conditions of the ASPA shall prevail. 11. No Party or representative, agent, or attorney for a Party has made any representation or warranty to influence the execution of this Agreement that is not expressly contained in this Agreement. 12. This Agreement may be executed in counterparts, all of which together shall constitute one and the same instrument. 13. By execution of this Agreement, each of the Parties hereto represents and warrants that they have the corporate power and authority to execute and deliver this Agreement and that each of the Parties has the power and authority to make and carry out its obligations hereunder. WHEREFORE, this Agreement shall become fully enforceable and effective in all respects on the latter of the two dates appearing below. 4 Agreement to Transfer U1C Permit No. AK- 1I006 -A • • Union Oil Company of California, Hilcorp Alaska, L1.C, a a California corporation Delaware limited liability company By: ..."111.1411 By: Name: J " Zt r i^ t Name: -.la L-■ 4 f A* Its: t-�y °rr Its: V 1 Date: Nmod, � act( Date: it i � 2 o 11 5 Agreement to Transfer UIC Permit No. AK-1 1006-A • • ~hevr~l~ FranCI5C0 Castro Chevron North America Exploration and Production s Technical Assistant 3800 Centerpoint Dr. Suite 100 ~~;~a ~;, Anchorage, AK 99503 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com .,~ - DATE Tune 28, 2010 -... ~.' .a', v To: AOGCC Mahnken, Christine R re , rj~ ~~ 333 W. 7t" Ave. Ste# 100 N~ji°w~~v'~wn+ AU ~ " .~ ,.._. . Anchorage, AK 99501 ' '~' - ~ ~ "'" " °" ~~ ~ ~ ~ ~ ~ Transmitted herewith is one DVD containing the following data. • D-48L1 • Formation evaluation logs -LAS • Gamma ray logs -LAS • K-12RD2 • K-12RD2_Final_Survey.xls • K-12RD2_Tops.xlsx • MPR-Gamma ray logs -LAS, CGM, PDF • K-18RD • K-18RD_Final_Survey.doc • Density Neutron logs -LAS • K-18RDPB1 ' • UBI log -LAS, PDS, DLIS • survey.xls • K-24RD2 • Density Neutron logs -LAS l~i~i 0~ l C7~~' 6s~( ~p~s ~~ ~ ~vl -/t~ -b!- /`~ ~~~-i~a ~~~ ~ ~ ~d~ l ~i ~~~ l9~~~ J ~ ~a i~~b~ /9 ~,o • Final Mudlog Report -LAS, DOC c~0~ -l~ ~ ! 9 ~!/ • M-06 • Final logs; Depth, Formation Evaluation, Realtime, Time -LAS, PDS, DLIS M-10 ~p~ -/(o ~ `~ ~lc7 • M-lOTops.xlsx • USIT log -PDS ~U~ -d 5' 3 !~ ~~ • Final logs; Depth, Formation Evaluation, Realtime, Time -LAS, PDS, DLIS • M-10PB1 • Final logs; Depth, Formation Evaluation, Realtime, Time -LAS, PDS, DLIS • M-16RD_Tops.xlsx • Final logs; Cement Bond Log, Completion Record -PDS • M-17 • M-17_Tops.xlsx • M17_MWD_Survey.pdf • Final Mudlog Report -LAS, DOC, DBF, MDX, PDF, DAT • Final logs; Depth, Formation Evaluation, Cement Bond, Plug Setting, Perforation - LAS, PDS, DLIS, TIFF Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: Date: 1~ • • Page 1 of 1 Maunder, Thomas E (DOA) From: KRAMER, TED E [TED.KRAMER@chevron.com] Sent: Friday, February 19, 2010 9:10 AM To: Maunder, Thomas E (DOA) Subject: FW: King Salmon Platform Well No. K-24RD2 Injector Administrative Approval AIO 5.010 - Compliance Temperature Survey Attachments: K-24RD2 Temp Survey 1-27-10 vs 12-21-07.zip Tom, My apologies for not including you on this. Larry straightened me out. Ted E. Kramer Petroleum Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7960 ~~~~~~ IV/~r~ i `~ ~~~~' Cell 907-382-0059 Fax 907 263 7847 ted.kramer@chevron.com From: KRAMER, TED E Sent: Thursday, February 18, 2010 4:43 PM To: Regg, James B (DOA); Aubert, Winton G (DOA) Cc: Greenstein, Larry P Subject: King Salmon Platform Well No. K-24RD2 Injector Administrative Approval AIO 5.010 -Compliance Temperature Survey Jim and Winton, A compliance Survey was conducted for King Salmon well K-24RD2 AIO 5 (PTD 201-141) on 1/27/10. The previous survey was conducted on 1-21-07. The attached temp plots (MD and TVD) contains over lays of these last two surveys. The two surveys closely resemble each other in signature and the latest survey confirms that the injected water is going below the packer (12,518') into the perforations (top perf @ 12,680'). Ted E. Kramer Petroleum Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7960 Cell 907-382-0059 Fax 907 263 7847 ted.kramer@chevron.com 3/11/2010 Chevron Well: K-24RD2 Field: King Salmon 01-27-10 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 0 ~ i r -i 1000 2000 .~. .~ 3000 D H t ~ 4000 5000 6000 7000 8000 9000 10000 ! ' I ' i ' I ' 1 I' i I ~ I 30 40 50 60 70 80 90 100 110 120 130 140 Temperature ~Deg• F) -1-27-10 Pressure - Perfs ~ GLM - 1 3 3/8 9 5/8 7 -TBG 1-27-10 Temp 12-21-07 Temp S,tRT~ ~F t~l~~,S#~n r~LASK1-, ~a~_ ~~t`~ G~`~S COI*ISER~Ir1TIf~~E `,C:~!~NE~~S, ..;~ ~~~C)~~' ~F ~t~fi~~3~tY V41~~.~ ~~~~~~~~ FHB ~ '~ 2.QQ8 [1 (1Nrrr~~tict~.s> 'i.bnncitin i f~ecairl~`weif (__; Plttgt'er`nratir~ns ~SGn~u'sate; ~ r ;' ~,~5 ~~ -r;an;ed: %,itar C_,s;n~ ' ~ ~'u!E ~u~1:ng ~~' ~ ~erforafe Ne+i'r Pc3ci r ] 'w^lalv~r~ 'i-ie~e e:x',~n~Et~n [ ~91C tJf~1~8 ; # ~an~.;e>:t(1 ru~:e3 f'r~grasr ' '?~e;a,. Shuircrvara~~ ~ f'ertorat~ `J1 - ~e-enearSus, ended Vlei_~ € _ I ? ~Jt:~eraiW r :~inifln C)if Cn.npany of Caii4ptnia ~U~C~L} _ 4. ~u> rent :^J~l[ ~ lass. ~ S. ~~rm~;t ±o fir [f )vat^~~;: ~~ ~damr~- C3~aelapmen# ~~ EXtaatatilry 1 `~01-;=9t ~3 rt:fe.ress: 900 S+~i.:~th .~n~~i,aragi~, ttlaska 09501 _ ~ Stratigraphlc~~ oerv:ue~~ ( 6..~,R Riua~~;-er: - ~- 50-7~3 24~',',W~-u? ' ~ 7 Kf3 E}t J~riv; t ;t?. 9. 'vl+eli Name aFid tVun~b~r: i ~ ~ j - a~ Prgce~ty~ xigr~atiir: -- - 1~ Fie;uiPoul(s;: ~ ~-] ~i ~ n~ .~n~ U`zi; ~L ! 7 .4.0~ ..,r.~" /F $ 30 /~' 3 f svlc~rt~~r,r ~rv~rrt>em;ock r ~cf ~ . i ~ nresc + ~lv211 ccad;tton :~,.ir~m;~r~: _ ! F~tat ~~tt': ;tnasttred 1420(7 '`e;~t ". _.... 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Winer r" i ~ _~~~_~_.~_e....-~-~...l-.Y---"..,.y.~ ~ ~ ~ ~.~. r ~.~m~ ~ ivz: ~ SAS ~t .._~__w~_____4.....~e-..a,~wsar~o.~,-~.i ~~~e _~_ _~_~.....,.~~_~...._-._...___s~_ ~.»M-4......~~.a-~.. ` ~ 4 , ~ ~ Page 1 of 1 Regg, James B (DOA) From: KRAMER, TED E [TED.KRAMER@chevron.com} c~ Sent: Wednesday, February 06, 2008 1:19 PM ~~1~ Z~~ 0a C~te,~ 1'P~cM-sR- To: Regg, James B (DOA) ~o C(~~Z~,~b ~,,~~ Cc: Greenstein, Larry P Attachments: K-24RD2 Temp Survey 12-21-07 vs 12-18-05.zip; 404 Corrected.pdf; 2002 Perf Dailys.zip; Well Bore Diagram.pdf ,/ ~'' -~ «K-24RD2 Temp Survey 12-21-07 vs 12-18-05.zip» «404 Corrected.pdf» «2002 Perf Dailys.zip» «Wel- Bore Diagram.pdf» Jim, Attached please find the overlay of the last two surveys (with the g zone perfs added), A corrected 404, the daily reports of the G zone perfjob ftom 2002, and a well bore diagram . hope this clears up the inconsistencies. And Chevron apologizes for the confusion. Ted E. Kramer Petroleum Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tel 907 263 7960 Cell 907-382-0059 Fax 907 263 7847 ted. kramer@chevron.com 2/7/2008 King Salmon Platform Well ~-24RD2 Injector AIO Administrative Ap royal AIO 5.010 - C... Regg, James B (DOA) Page 1 of 2 ~l- From: Regg, James B (DOA) ~~~~ ll~t~d~, Sent: Wednesday, January 09, 2008 11:14 AM ~ ' To: 'KRAMER, TED E'; Maunder, Thomas E (DOA) Cc: Greenstein, Larry P; Johnson, Wayne E Subject: RE: King Salmon Platform Well No. K-24RD2 Injector AIO Administrative Approval AIO 5.010 - Compliance Temp Survey Attachments: 10-404_TBU_K-24RD2.pdf; well schematic TBU K-24RD2.pdf; temp survey 12-18-05 TBU K- 24RD2.pdf Attached are PDF's of 10-404, well schematic, and results of temp survey run on 12-18-05. Note the discrepancy in perforated interval. It appears that the actual perforated interval is higher than indicated on the 12-21-07 temp survey graph provided. Please revise the 10-404 and current temp survey results to reflect actual perforated interval. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~~~~~~~~ JAN ~ ~ 2008 From: KRAMER, TED E [mailto:TED.KRAMER@chevron.com] Sent: Monday, January 07, 2008 3:21 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Greenstein, Larry P; Johnson, Wayne E Subject: King Salmon Platform Well No. K-24RD2 Injector AIO Administrative Approval AIO 5.010 -Compliance Temp Survey Jim & Tom, A compliance temp survey was conducted for King Salmon well number K-24RD2, AIO 5 (PTD 201-141) on 12121107. The previous compliance temp survey was conducted on 12118105. The attached temp plots (MD and TVD) contains overlays of the fast two temperature surveys for K-24RD2 (12121107 and 12!18/05). These two surveys closely resemble each other with the 12/18/05 survey being slightly cooler than the 12/21/07 survey. This is most likely due to a slightly shorter amount of SI time prior to running the 12/21/07 survey. The shape and signature of the latest survey confirms that the injected water is going below the packer at 12,518' and into the perforations (top perf at 12,680'). Please call me to discuss if you have any questions. Ted E. Kramer Petroleum Engineer MidContinent/Alaska Business Unit 1 /9/2008 King Salmon Platform Well ~-24RD2 Injector AIO Administrative A royal AIO 5.010 - C... Page 2 of 2 Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tel 907 263 7960 Cell 907-382-0059 Fax 907 263 7847 ted.kramer@chevron.com «Temp 12-21-07 vs 12-18-05.zip» 1 /9/2008 • P~~ z~ I - r 4 I Chevron Well: K-Z4RD2 Field: King Salmon Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 1 e d 1 v C~ L 1 it a a~ ~ 0 1i 1 1 1 ~ --- 40 50 60 70 80 90 100 110 120 130 140 Temperature (Deg. F) 12-21-07 Pressure - Perfs ~ GLM 4-1/2 13-318 9-5/8 7 12-21-07 Temp 12-18-05 Temp Pressure (psia) 0 500 1000 1500 2000 2500 .-. d d ... H s _~~~ ~-2A2~-z 3000 3500 4000 .vvvv 40 50 60 70 80 90 100 110 120 130 140 Temperature (Deg. F) 12-21-07 Pressure - Perfs ~ GLM 13 3/8 9 5/8 7 TBG 12-21-07 Temp 12-18-05 Temp Well with Questions on Determin~the Anniversary Dates for Compliance Temp Surveys Page 1 of 2 • Regg, James B (DOA) ~ ~ J - /'-~ l From: Regg, James B (DOA} !~ . 1~E'~rGj ~ Z,~~( (G 1 Sent: Wednesday, December 26, 2007 5:23 PM l To: 'Greenstein, Larry P' Cc: Maunder, Thomas E (DOA} Subject: RE: Well with Questions on Determining the Anniversary Dates for Compliance Temp Surveys Larry -Each of the listed admin approvals did not establish a formal anniversary date for determining when to perform compliance temperature surveys. There has been some confusion that has resulted. Based on what I have read below and our conversation earlier today, I believe using the effective date (signature date) of the administrative approvals is consistent with your request far nearly all wells accomplishes what you are after (efficiency}. The wells you reference below are (with a due date for the next temp survey}: Granite Pt State (Anna) 19 - AIO 6.008 (3!29(2005); next temp survey due 3/29/2009 Granite Pt State (Anna) 21 - AIO 6.009 (312912005); next temp survey due 3/29/2009 TBU G-11 - AIO 5.009 (12/15/05); next temp survey due 12115/2009 {you suggested 912009} TBU G-22 - AIO 5.006 (9114/2005}; next temp survey due 9/14/2009 TBU G-23RD - AIO 5.004 (6/3012005); next temp survey due 6130/2009 {you suggested 312009) TBU G-27 - AIO 5.003 {312912005}; next temp survey due 3/2912009 TBU G-29RD - AIO 5.007 (9123/2005); next temp survey due 9123/2009 TBU G-40 - AIO 5.002 {3129/2005); next temp survey due 3/29/2009 TBU K-11 - ABO 5.011 (2/6106}; next temp survey due 2/6/2010 TBU K-24RD2 - AIO 5.010 (216/06); next temp survey due 2/6/2010 There is nothing preventing Chevron from testing earlier (as you have proposed for 2 of these wells}. This does not affect any admin approvals that have anniversary dates specifically listed in the conditions. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~~;~ II~C ~ ~ Za07 From: Greenstein, Larry P [mailto:Greensteinlp@chevron.com] Sent: Wednesday,. December 26, 2007 10:45 AM To: Regg, James B (DOA) Subject: Well with Questions on Determining the Anniversary Dates for Compliance Temp Surveys Thanks for the conversation on this anniversary date topic Jim. It gets real confusing for me to keep the different basis for the anniversary dates separate for each well. The wells in question are: An-19 - AA signed 3129105 -last compliance temp survey 1013106. Would like to slide 101038 temp survey to 3109 to get on AA anniversary date cycle. An-21 - AA signed 3129105 -last compliance temp survey 10.14106. Would like to slide 10{08 temp survey to 3!09 for the AA date reason. K-11 - AA signed 216106 -last compliance temp survey 12111107 (just sent to you}. Would like to slide 12109 temp survey to 2110 for the AA date reason. 12/26/2007 Well with Questions on Determin the Anniversary Dates for Compliance Temp Surveys Page 2 of 2 K-24RD2 - AA signed 216106 -last ciance temp survey 12121!07 twill send t soon). Would like to slide 12109 temp survey to 2110 for the AA date reason. The Grayling wells have some other things going on. We have welts with AA anniversary dates in every quarter. I sure would like to get the number of logging visits down to just twice a year instead of four times a year. Maybe slide G-23RD forward from June to March and G-11 forward from December to September. This way only two wells get off the AA anniversary date cycle and we'll have three wells due for temp surveys each visit. G-11 - AA signed 12115105 -last compliance temp survey 6125107. Would like to slide to 6/09 temp survey to 09109 for efficiency. G-22 - AA signed 9114!05 -last compliance temp survey 4126107. Would like to slide 4109 temp survey to 9109 for the AA date reason. G-23RD - AA signed 6/30105 -last compliance temp survey 4119/07. Would like to slide 4109 temp survey to 3109 for efficiency. G-27 - AA signed 3129105 -last compliance temp survey 9121106. Would like to slide 9108 temp survey to 3109 for the AA date reason. G-29RD - AA signed 9123105 - las# compliance temp survey 6124107. Would like to slide 6109 temp survey to 9109 for AA date reason. G-40 - AA signed 3129105 -last compliance temp survey 9121106. Would like to slide 9108 temp survey to 3109 for AA date reason. I hope there aren't any more hiding out there. Surely next year I'll find one or two, but for now this list looks like all of them. Thanks again for your consideration Jim. Call me if you want to discuss some more. Larry 263-7661 12/26/2007 `~f~~~ 1 z (~~~r.~"1' 2-Year Temperature Survey Timing Requirements Granite Point Field and Trading Bay Unit Administrative Approvals for these welts did not include specific anniversary dates for determining when to perform compliance temperature surveys (alternate mechanical Background Info: integrity determinations in lieu of MITs). Clarification was requested by Chevron (L. Greenstein; 907-263-7661) on 12/26/2007. The following table summarizes admin approval info, anniversary date options, and the Commission's decision. Well PTD AA Anniversary Date AA Date Last Surve GP State An-19 168-006 6.008 3/29/2005 10/3/2006 GP State An-21 176-049 6.009 3!29/2005 10!4!2006 TBU G-11 168-043 5.009 12/15/2005 6/25/2007 TBU G-22 175-016 5.006 9/1412005 4/26/2007 TBU G-23RD 179-014 5.004 6/30/2005 4/19/2007 TBU G-27 178-070 5.003 3/29/2005 9/21/2006 TBU G-29RD 192-052 5.007 9/23/2005 6/24/2007 TBU G-40 190-003 5.002 3/29/2005 9/20/2006 TBU K-11 168-083 5.011 2/6/2006 12/11/2007 TBU K-24RD2 201-141 5.010 2/6/2006 12/21/2007 GP State An Granite Point Field, Anna Platform TBU G Trading Bay Unit, Grayling Platform TBU K Trading Bay Unit, King Salmon Platform AA Administrative Approval (AIO 5 and AIO 6, Rule 9) Options Next Temp Surve Due, Based on AA Date1 AA Date2 Last Surve 3/29/2007 3/29/2009 10/3/2008 3/29/2007 3/29/2009 1014/2008 12/15/2007 12/15/2009 6/25/2009 9114/2007 9/14/2009 4126!2009 6/30/2007 6/30/2009 4/19/2009 3/29/2007 3/29/2009 9/21/2008 9/23/2007 9/23/2009 6/24/2009 3/29/2007 3/29/2009 9/20/2008 2/6/2008 2/6/2010 12/11 /2009 2/6/2008 2/6/2010 12/21 /2009 last update: 12/26/2007 Next Survey Due (Chevron Proposed) Next Survey Due (AOGCC) Which Option? 3/29/2009 3/29/2009 AA Date 3/29/2009 3/29/2009 AA Da#e 9/30/2009 12115!2009 AA Date 9/30/2009 9114/2009 AA Date 3/30/2009 6/30/2009 AA Date 3/30/2009 3129/2009 AA Date 9/30/2009 9/23/2009 AA Date 3/30/2009 3/29/2009 AA Date 2/28/2010 2/6!2010 AA Date 2/28/2010 2/6/2010 AA Date • • ) ) Chevron .. J. Hal Martin Optimization Engineer Union Oil Company of California P,O, Box 196247 Anchorage, AK 99519-6247 Tel 907 263 7675 Fax 907 263 7847 Email martinh@chevron.com January 11, 2006 e~·, ".~ ·r1) . :.,..~. ·····r'~· .¡",.....'" . ".Þ c' :.....~'"J ~\,_A ¡\¡ Æ Commission Chair John Norman Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 ¡~ Attn: Tom Maunder -aD \~ I i.f \ REQUEST FOR ADMINISTRATIV;?AP ROVAL UNDER AREA INJECTION ORDER· \ ' "'\ l WELL NO. K-24RD2INJECTOR r~ "C~\CJ t)<ê KING SALMON PLATFORM U'.J--øvt-r' TRADING BAY UNIT McARTHUR RIVER FIELD --- ~\a S SCANNED JAN 3 1 2006 Dear Tom: Union Oil Cûmpany of California requests administrative approval under Area Injection Order 6, Rule 9 for the continuation of injection of non-hazardous Class II fluids for King Salmon Platform Well No. K-24RD2 Injector (Permit # 2011410) in Trading Bay Unit, McArthur River Field. To support this request, Unocal submits the following information and documentation: 1. Form 10-404 (attached). 2. Schematic (attached). 3. MD and TVD plot of temperature surveys (attached). 4. Maximum allowable injection pressure calculation in graphical form (attached). 5. Brief/relevant well history (below). The King Salmon Platform Well No. K-24RD2 was redrilled and completed as a producer in 10/01 in Hemlock Benches 1-5. In early 2002, the process was initiated to convert the well to a waterflood injector. Waterflood injection was initiated in 4/02, halted after a few days of injection due to the rig fire on the King Salmon Platform in 4/02, and then restarted in 5/02 until being shut-in in 6/02 to replace gas lift valves with dummies in all the mandrels. After a leak (missing dummy) was eventually located and repaired, Well K-24RD2 passed a standard MIT in 10/02. In 12/02, perforations were added to G-Zone Benches 1-5. In 1/05, the well again passed a standard MIT, On 7/31/05, Well K-24RD2 was shut-in due to tubing-to-casing communication. In 10/05 (after running a baseline temperature survey on 8/4/05), Union Oil Company of Union Oil Company of California I A Chevron Company http://www.chevron.com ') ') Tom Maunder AOGCC January 11, 2006 Page 2 California submitted a plan to restore waterflood injection to the AOGCC. Injection was restored from 10/15/05 until 12/17/05 when the well was shut-in for a follow-up temperature survey on 12/18/05. On 12/20/05, after reviewing the results of the follow-up temperature survey with the AOGCC and in consideration of process limitations on the King Salmon Platform, the AOGCC granted Union Oil Company of California permission to return K-24RD2 to injection provided monitoring standards were maintained. As discussed with the AOGCC, the 12/18/05 follow-up temperature survey has a slight temperature cooling anomaly between approximately 6600' - 8400' MD (4800' - 6000' TVD). Union Oil Company of California does not believe this is indicative of an injection fluid leak but more likely related to some characteristic of the formation at that depth. As depicted on the attached maximum allowable operating pressure (MAOP) graph, the MAOP for K-24RD2 is 3146 psi for the casing immediately outside of the tubing. Union Oil Company of California will operate this well within the MAOP. Union Oil Company of California will monitor and record daily injection rates and tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. A temperature survey will be run every two years to insure the injected water is contained within the completion interval. Please note also that McArthur River Field has an aquifer exemption per EPA 40CFR147.102b2ii. Please call me at (907)263-7675 if you have any questions. Sincerely, ffrIL//¡cdv Hal Martin Optimization Engineer Union .Oil Company of California JHM:jll Attachments Union Oil Company of California I A Chevron Company http://www.chevron.com ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JAN 1132006 StimulateU_~~CiMt~R41f0~ Waiver 0 Tim&6xtq.ion 0 Anchorage Re-enter Suspended Well 0 5, Permit to Drill Number: Exploratory 0 201-141 Service 0 6. API Number: 50-733-20330-02 9. Well Name and Number: K-24RD2 10. Field/Pool(s): McArthur RiverlHemlock Pool 1. Operations Abandon U Repair Well U Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2, Operator Union Oil Company of California (UNOCAL) Name: 3, Address: 909 W. 9th Anchorage, Alaska 99501 7. KB Elevation (ft): 100' RT above MSL 8. Property Designation: Trading Bay Unit 11. Present Well Condition Summary: Total Depth measured 14200 true vertical 9998 Effective Depth measured 14157 true vertical 9965 Casing Length Structural 330' Conductor 409' Surface 5712' Intermediate 10793' Production 6237' Liner Size 24" 18 5/8" 13 3/8" 95/8" 7" Perforation depth: RECEIVED Plug Perforations U Perforate New Pool 0 Perforate 0 4. Current Well Class: Development 0 Stratigraphic 0 feet feet Plugs (measured) 14157' ( cmt shoe) Junk (measured) none feet feet MD TVD Burst Collapse 330' 409' 5712' 10793' 14199' 330' 409' 4165' 7487' 9997' RECEIVED JAN 1 3 2006 A'~$kø Oi' & Gas Cons. Commission Anchorage Measured depth: various 13370' - 13882' True Vertical depth: various 9384' - 9760' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 41/2" & 3 1/2" 12.6# L-80 & 9.3# L-80 to 7879' & to 12599' 3 1/2"x7" Baker SAB Injection PKR @ 12518' & 4 1/2" TRSSSV @ 297' Treatment descriptions including volumes used and final pressure: RBDMS BFL JAN 3 1 2006 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 5700 40 o 5700 2260 15. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: oilD Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Prior to well operation: Subsequent to operation: 114. Attachments: Copies of Logs and Surveys Run Temp Logs Daily Report of Well Operations Oil-Bbl o o Contac1 Hal Martin Printed Name IIAt- IIMRnH . i:kt /J;~ Signature Form 10-404 Revised 04/2004 Tubing Pressure 2300 2300 Service 0 GINJ 0 WINJ 0 WDSPL 0 Sundry Number or N/A if C.O. Exempt: 305-313 Title Optimization Engineer Phone (907)263-7675 Date 1/11/2006 Submit Original Only UNOCAL. RKB to TBG Hanger = 34.85 L -- L J J J J / 2 J J J J J J J X 3 4 5 " L. x L 8/4/05: ~ Tagged at 13991'. TD = 14,200' MD/9999' TVD PBTD = 14157' ) Trading Jay Unit King Salmon Platform Well # K-24RD2 Injector Actual 1202 (G-Zone Perf Add) CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 24" Driven 330' 18-5/8" 101 H-40 0' 409' 13-3/8" 72/68 N80/K55 0' 5712' ~ 9-5/8" 47 N-80/S-95 0' 10793' (window) ~ 7" 29 L-80 KC Buttress 7962' 14199' Tubing: 4-1/2 " 12.6 L-80 Buttress 0' 7879' 3-1/2" 9.3 L-80 Buttress 7879' 12599' 7" liner top@ 7962' Gas Lift Mandrels: 1 2590' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 2 5169' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 3 6618' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 4 7744' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 5 8486' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 6 9324' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 7 10137' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 8 10788' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 9 11375' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 10 11936' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 11 12438' 3-1/2" SFO-2 GLM with Orifice valve and RK latch JEWELRY DETAIL ~ 9-5/8" window @ 10793' NO. 1 2 3 4 5 Item TRSSSV, 4-1/2" Xover, 4-1/2" x 3-1/2" buttress Baker SAB 3-1/2' x 7" injection packer 3-1/2" "X" nipple w/2.813" ID Tubing tail Depth 297' 7879' 12518 ' 12565' 12599' TOP 12680 12750 12860 12910 13070 BTM 12710 12790 12890 12980 13160 PERFORATION DATA ZONE SPF DATE COMMENTS G-l 6 12/5/02 G-2 6 12/5/02 G-3 6 12/5/02 G-4 6 12/5/02 G-5 6 12/4/02 13370 13400 HB-l 13445 13460 HB-2 13510 13520 HB-2 13570 13580 HB-2 13618 13633 HB-3 13640 13670 HB-3 13688 13733 HB-4 13767 13787 HB-4 13857 13882 HB-5 6 6 6 6 6 6 6 6 6 10/17/01 10/29/01 10/29/01 10/29/01 10/28/01 10/27/01 10/25/01 10/27/01 10/21/01 Max angle = 57° @ 4800' Hole Angle = 40° @ TD' 0: \OOE\OOEFields\ TBU\King\ W ells\K -24 \K -24 RD2\Schematics\K24 RD2ActSchem 1202.doc DRAWN BY: JHM well: Fìeld: Ki!1g Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 o ' Pressure-Temperature Profile 1000 2000 3000 4000 - 5000 - ..... Q) 6000 ~ - C 7000 - ::æ I .c ..... Q, 8000 Q) C 9000 10000 11000 12000 13000 14000 r 50 60 70 80 90 100 110 120 130 140 150 160 170 180 Temperature (Deg. F) 12-18-05 Pressure Perfs GLM 4-1/2 13-3/8 - 9-5/8 7 12-18-05 Temp -8-4-05 Temp ........... 4000 .... (I) (I) ...... - ~ 0 > 5000 , ..... I .c .... Q. (I) 0 6000 10000 50 well: o o Pressure (psi a) 2000 2500 3000 4500 500 1000 1500 3500 4000 2000 Profile 1000 -- ... 3000 7000 ~ 8000 9000 60 70 100 110 120 130 140 150 160 170 180 80 90 Temperature (Deg. F) 12-18-05 Pressure 13 3/8 TBG Perfs 9 5/8 12-18-05 Temp GlM 7 -8-4-05 Temp • ~. ~a '~ ' i ~ 1 1 ' ' ~ : t , ~ ~ 3i r' ~ 1 ,''(~'~ C®1~TSERQ~TSiO C 1~IIII Sip ADMINISTRATIVE APPROVAL AIO x.010 tilr. Hal Martin Optimization Engineer Unocal Alaska P.O. Box 196247 Anchorage, AK 99519-6247 ~~~ ~A~ ~ ~ 2008 333 W. 7`"AVENUE, SUITE 700 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 RE: TBU K-24RD2 (PTD 201-141) Request for Administrative Approval Dear NIr. Martin: Per Rule 9 of Area Injection Order 5, the Alaska Oil and Gas Conservation Commission ("AOGCC") hereby grants Unocal Alaska ("Unocal")'s January 11, 2006 request for administrative approval to inject water in Trading Bay Unit ("TBU") K-24RD2. Unocal notified the Commission on August 1, 2005 that TBU K-24RD2 exhibits tubing- casing pressure communication; the well was shut in at that time. Approval to continue injection for the purpose of performing well integrity diagnostics was granted by sundry number 305-313 on October 13, 2005. Unocal has elected to perform no corrective action at this time on TBU K-24RD2. Temperature surveys performed as part of the diagnostic testing confirm the injected fluids are exiting the well at the perforations and monitoring has shown that pressures are contained within the wellbore. Accordingly, the Commission believes that the w-ell's condition does not compromise overall well integrity so as to threaten the environment or human safety. The Commission's administrative approval to inject in TBU K-24RD2 is conditioned upon the following: 1. Injection is limited to WATER ONLY; 2. Unocal shall monitor and record tubing, inner annulus, and outer annulus pressures and injection rate daily; • FRANK H. MURKOWSK/, GOVERNOR 3. Unocal shall submit to the Commission a monthly report of well pressures and injection rates; • i~ir. Steve Rossberg February 6, 2006 Pa e 2 of 2 ~ g 4. Unocal shall perform a temperature survey- every 2 years in lieu of the mechanical integrity test as outlined in Rule ~ of AIO ~ to demonstrate continued production casing integrity; 5. Unocal shall immediately shut in the well and notify the Commission if there is any change in the well's mechanical condition; and 6. after well shut in due to a change in the well's mechanical condition, Commission approval shall be required to restart injection. As provided in AS 31.0.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ca and dated February 6, 2006. Cathy P. Foerster Commissioner f y r v'' ~ i ~ i '~~ ,~.. ~ `'` ~ ~ ~ ~ ~ ~ i i~ i y ` i ~y`~ L`~ i. _~ .. ~ ~. ~E ~ ~ ~' S rte` .~ i ~_ 'I ~ ~~Y Y, _ "~Y # rr Chairman 1.000 2,000 3,000 4,000 5,000 6,000 - 7,000 0 ~ - .c .... c.. CI.) 0 8,000 9,000 10,000 11 ,000 12,000 13,000 14,000 15,000 K...24RD2 aximum Allowa e Operating Pressure Graph o Pressure (PSI) 4,000 5,000 6,000 10,000 1,000 2,000 3,000 7,000 8,000 9,000 o 1/17/20059:16:38 AM Weight Grade Yield Top Bottom 29 L-80 8160.0 7962.0 14199.0 .0 .7 6S-~-1·762.6 8150.0 1762.6 2730.2 8150.0 2730.2 2737.5 8150.0 2737.5 10793.0 10793.0 10796.0 38.2 590.7 4;<1/2 5629.2 5631.0 5710.0 5712.0 409.0 330.0 N 80 8-95 8-95 S-95 5380.0 4217.2 5380.0 5629.2 5380.0 5631.0 5380.0 5710.0 2250.0 409.0 330.0 ing Pressure Analysis 20051117.xls - Internal Fluid Hydraulic Pressure Formation facture pressure @ 0.7 #/ft -Production CYP @ 70% -Outside Containment for Production casing -MASP (production casing) Intermediate CYP @ 45% -Outside Containment for Intermediate casing --MASP (Intermediate casing) Current Pressure Readings Disclaimers (fine orint) Casing Yield values taken !'rom pUblished sources where specifications are known. If specifications are unknown then values are the lowest value of probable materials. TVO interpolated from Openworks directional surveys. Values should be +/- 25 ft @ 10,000 ft. MO -- e e ':': 4~ , ¡fr ~ MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc RE: K-24RD2 (201-141) Follow-Up Temp Survey Results ') ) ~.~.~ ject:..RE:I~-~~RID2(~()1-141) Follow-Up. T~l11p.·..·SllrveY·Re~µlts FI"~ID:'.'¥. aïtí:J;ì,].f(ª,r''>mattinl1.@...·...unocal.c.û.m.:>.. ;....: :." : . ". . ".. .":'." ..", ".':' .... '. . nªte:TlJ~~ 2QÈ>¢ö2QÖ$.17:dS:$7.~090Q Tom, Thanks for the quick response. We certainly appreciate your willingness to work with us on this waterflood injection issue. We will monitor and record performance information from the well as in the past and will shut it in should conditions change and indicate an integrity or zonal isolation problem. We'll get you the Admin Approval application the first week in January. Thanx, Hal From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, December 20, 2005 4:39 PM 5CI\NNED ~Jt(%N 1 ~ 200B To: Martin, J. Hal Cc: Greenstein, Larry P; Cole, David A; Johnson, Wayne E Subject: Re: K-24RD2 (201-141) Follow-Up Temp Survey Results Hal, I have examined the plots you have provided for K-24RD2. I concur with your assessment that it does not appear that the injected water is going anywhere but the intended injection interval. The character of the individual surveys is similar reflecting both warming and cooling along the trajectory of the well. This is similar to the temperature profiles for other wells in the Inlet. In consideration of the process limitations on King Salmon, it is acceptable to place K-24RD2 back into service. The daily rate and pressure information should be obtained so that Larry can submit the monthly data plot for the well. Regardless of the effect on King operations, if the pressure/rate monitoring indicates some further problem with the well, it must be SI and the Commission notified. Please refer to the Administrative Approvals that have been issued for other King wells. I look forward to receiving the application for administrative approval on this well. Call or message with any questions. Tom Maunder, PE AOGCC Martin, J. Hal wrote, On 12/20/2005 1 :27 PM: Tom, " \0 Ç\ \)\\ ,,\:.d .'kJ \" (CècQÇ 1/18/2006 1: 16 PM 1 of3 RE: K-24RD2 (201-141) Follow-Up Temp Survey Results ') ) Purpose: As a follow-up to our phone conversation yesterday, I am sending this e-mail to you for the purpose of: 1) Communicating to you the results of the follow-up temp survey on K-24RD2 in advance of a formal submission for Admin Approval Request from the AOGCC. 2) Asking for verbal (e-mail) permission from the AOGCC to return K-24RD2 to injection immediately if you concur with our conclusions on the K-24RD2 temp survey. The formal submission for Admin Approval would follow shortly. 3) Asking for the same process to be applied to K-ll, which is due to have it's fOllow-up temp survey performed at this time, based on my earlier plan for working toward the Admin Approval for this well. J<ev Information: A. King Salmon Platform waterflood system lower operating limit of injection volume is +/- 21000 BWPD. B. Injection volume prior to shutting-in K-24RD2, K-l1, and possibly K-2RD was +/- 36000 BWPD. C. Well injection volumes: K-24RD2 -- +/- 6300 BWPD, K-11 -- +/- 8000 BWPD, and K-2RD -- +/- 600 BWPD. i Piscu~sion: 1) Attached are MD and TVD graphs of the base and follow up temp surveys on K-24RD2. K-24RD2, a G/HK injector, had been on injection for over 9 months before being shut-in due to tbg-to-csg communication on 7/31/05 and the base ¡ line temp survey was run 4.5 days later on 8/4/05. After an injection period of 9 weeks (10/15-12/17) the follow up temp survey was run on 12/18 after an 18 hrs of shut-in. The 12/18/05 survey has a couple of areas in question -- on the attached TVD plot it is about 4800' - 6000' (area of cooling) and 6100' - 7600' (area of warming). The area of cooling is the one of real interest. Both areas also have suppressed, but similar character in the 8/4/05 survey. I do not have an explanation for the area of cooling, but believe it is related to the character of the formation in that interval, not a casing leak. With more shut-in time, I believe the 12/18/05 temp survey would fall in line with the 8/4/05 temp survey. «K-24RD2 MD and TVD Temp Surveys DecOS.ppt» 2) Originally, we planned a stagger of the follow-up temp surveys on K-24RD2 and K-11 so that we could have the best chance of keeping the waterflood system on-line on the King. However, weather played a large role in delaying the planned survey on K-24RD2. Based on the results of the follow-up temp survey on K-24RD2, I am certainly interested in restoring production to the injector as soon as possible, both from keeping King Platform system injection on-line and for overall TBU waterflood injection pressure support. Based on our discussion yesterday, I would like to ask the AOGCC to consider giving us verbal (e-mail) permission to restore injection immediately on K-24RD2 if the AOGCC agrees with Union Oil's interpretation of the follow-up temp survey. The formal written Admin Approval request to the AOGCC would be submitted as soon as practical, but at least by 1/6/06. 3) We currently have K-11 on injection. If we can obtain verbal approval today 20f3 1/18/2006 1: 16 PM RE: K-24RD2 (201-141) Follow-Up Temp Survey Results ) ') from the AOGCC to restore K-24RD2 to injection, we plan to shut-in K-l1 this evening and run the follow-up temp survey tomorrow. Our plan would then be to follow the same process we are requesting on K-24RD2 above, that is, to get the follow-up temp survey to the AOGCC by Thursday morning and assuming no temp anomaly surprises, obtain verbal approval to immediately restore injection on K-l1 while preparing to formally submit the Admin Approval request. let me know if you have any questions or need more information. Thanx, Hal Martin Engr Resv Advisor Chevron Union Oil Company of California 909 W. 9th Avenue Anchorage, AK 99501 Tel 907 263 7675 Fax 907 263 7847 martinh@chevron.com 30f3 1/18/2006 1: 16 PM FW: K-24RD2 follow-up temp survey ) ) S~~Jf~~~f~:~-24RI)2foll~jY~¥Pt~~~!~~eY.... ....... ......... . ....... ...... F'~.f?¡~:··.."·~e~ns~~.i~,....I:.;!().lJ)'..~."....~pre7~.s~~inIp@µnOC(1I·.PPJPc·.·· 1)q]~e:·]hl1,OlDøG·.2005 ···09:40:3J-09()() Hi Tom, Hal thought you should know we are having a little trouble getting the follow-up temp survey on K-24RD2. It's just a weather thing, but it might delay the survey for a week or so. We are going to keep injecting until we get a break in the weather to get the wireline guys out there. Thís should be well within the limitations of the proposed plan for Admin Approval data gathering. Nothing has appeared to be out of the ordinary with the test injection rates or pressures. Ca II me if you want any further info. Larry 263-7661 From: Martin, J. Hal Sent: Thursday, December 01, 2005 9:26 AM To: Myers, Dave L; Greenstein, Larry P Cc: Brown, Glynn B Subject: RE: K-24 Dave, Turn K-24RD2 back on and let's try again around Tuesday of next week, if that works for Glynn. Larry, Can you can or e-mail Tom Maunder and let him know we have been trying to get the follow up temp survey on K-24RD2, but are having logistics problems and tell him we will try again next week. Thanx, Hal From: Myers, Dave L Sent: Thursday, December 01, 2005 8:40 AM To: Martin, J. Hal Subject: K-24 Hal, Shut in K-24RD2 last PM around 11 :00. Wireline was suppose to be here at 07:00 this AM. But it is still fogged in here no flights at all yesterday. Sent wireline back to shop as I didn't want to pay them for setting at heliport. Question is what do you want us to do with K-24RD2. Have no ideal when they will fly and there are quite a few flights to run before I could get wireline out. Still about -7 here in Kenai so it is cold. Hopefully they wont freeze up in lubricator but we do have methanol on board. ~~~~ \?G\t'~ \t<:P~ 1/18/2006 1:14 PM 1 of2 ,~ ijr" j6 11 s....=¡ FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. ORAND GAS CONSERVATION COMMISSION 333 W. 7'H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Hal Martin Optimization Engineer Union Oil Company of California (UNOCAL) P.O. Box 196247 Anchorage, Alaska 99519-6247 ~""::¡' " ;,~, 'Jv.~ . Re: Trading Bay Unit K-24RD2 Sundry Number: 305-313 ~ANNEL t~Ov Co [2005 Dear Mr. Martin: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. 11 K. Norman Chairman DATED thi~ay of October, 2005 Encl. 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate TI Waiv~r ~ Other ~ Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Tim~~'§~r\gn ja~W~oCfJIflmfSS Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well Q nchorage 2. Operator Name: 4. Current Well Class: 5. Permit to Drilll\4.umber: Union Oil Company of California (UNOCAL) Development 0 Exploratory 0 1201-141 V". 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 196247 Anchorage. Alaska 99519-6247 50-733-20330-02 / 7. KB Elevation (ft): 9. Well Name and Number: 100' RT above MSL K-24RD2 8. Property Designation: 10. Field/Pools(s): Trading Bay Unit / King Salmon Platform McArthur River/Hemlock & G-Zone Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): )¡rotal Depth TVD (ft): ¡IEffective Depth MD (ft): Effective Depth TVD (ft): ~rlUgS (measured): I:unk (measured): 14200 9998 14157 9965 14157 none Casing Length Size MD TVD Burst Collapse Structural 330 24 330 330 Conductor 409 185/8 409 409 Surface 5712 133/8 5712 4166 Intermediate 10793 95/8 10793 7487 Production 6237 7 14199 9997 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: I~Ubing Grade: rUbing MD (ft): various 12680-13882 various 8871-9755 4.5 to 7879/3.5 to 12599 12.6# L-80 /9.3# L-80 12599 Packers and SSSV Type: 3-1/2"x7" Baker SAB Injection packer 4- Packers and SSSV MD (ft): 12518/297 1/2" TRSSSV 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: upon approval of this sundry Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hal Martin 263-7675 Printed Named~ Hal Martin A Title Reservoir Engineer Signature /..., 1.7 - ~a _ 7 Phone 263-7675 Date 10/10/2005 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness ISUndry Number: ~"S-- ~C3 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Othe, \J-,J« \\ O?<-"""~~ 1:>.> p'\<:>~ <>-We o.~'o \ICe. Þ.(}~ ~\ \.. \a ~~~~~ \\"s\. RBDMS 8Fl OCT 14 100\ ~zïj'd~~ ~ d:ljt~~ APPROVED BY loll ~/~ COMMISSIONER THE COMMISSION Date: L/' V " --- / ) - STATE OF ALASKA CfY} lo--Il-ÛS ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 RECEIVEQ:Í OCT I 1 Z005 \Ol\':> on ~ l) .......... ~ ~ '^ Form 10-403 Revised 07/2005 .../ ORIGINAL Submit in Duplicate Chevron === J. Hal Martin Optimization Engineer Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519-6247 Tel 907 263 7675 Fax 907 263 7847 Email martinh@chevron.com October 10, 2005 RECEIVED OCT 11 ZgOS Tom Maunder State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 AI.~ka gi¡ & Gas Ctm~, Commission l\f!~hQf~Ôß Re: King Salmon Platform Well No. K-24RD2lnjector Return to Injection Test Dear Tom: Union Oil Company of California would like to propose the process below to qualify and obtain administrative approval from the AOGCC for the King Salmon Platform Well No. K-24RD2 (Permit # 2011410) as an injector under Area Injection Order 6, Rule 9 for the continuation of injection of non-hazardous Class II fluids. The King Salmon Platform Well No. K-24RD2, a waterflood injector, developed tubing to casing communication on 7/31/05 and has been shut-in since that time. A base line temperature survey was run on the well on 8/4/05 and no indication of injection outside the zones of interest is evident. The proposed plan is as follows: 1) Baseline temperature survey (performed 8/4/05). 2) Obtain permission to inject from AOGCC. 3) Inject for 5-6 weeks, keeping maximum injection pressure under 2900 psi. 4) FofiOw-up temperature survey. 5) Obtain administrative approval to inject. 6) Monitor well daily and repeat temperature surveys every two years. L..., t'<:L\"" t+ """"'f\..\. ~ \.., ld- <f- -1'IfJ\ \0 ( (~ ¡ ~···I!~ L Union Oil Company of California I A Chevron Company http://www.chevron.com Tom Maunder AOGCC October 10, 2005 Page 2 Please review the enclosed Form 10-403, 8/4/05 baseline temperature survey, maximum allowable operating pressure graph, and schematic and call me at (907)263-7675 if you have any questions. Sincerely, ()£A~ Hal Martin Reservoir Engineer Union Oil Company of California JHM:jll Attachments Union Oil Company of California / A Chevron Company http://www.chevron.com 3000 4000 5000 6000 - ...... ( ,) ( ,) ... - 7000 ~ C :e I J:: 8000 ...... c.. ( ,) C 9000 10000 11000 12000 13000 14000 15000 70 500 Pressure (psia) 1000 1500 2000 2500 3000 3500 4000 4500 85 100 115 130 145 160 175 190 Temperature (Deg. F) Perfs -4~1/2 - 4000 - (U ~ - ë > 5000 l- I J: - Q. (U Q 6000 10000 70 Field: o o 1000 Pressure (psia) 1500 2000 2500 3000 3500 4000 4500 500 1000 2000 3000 7000 8000 9000 80 130 160 180 140 150 170 90 100 110 120 Temperature (Deg. F) RKB to TBG Hanger = 34.85 4 5 6/9/02: Tagged at 14002' TD = 14,200' MD/9999' TVD PBTD== 14157' 7" liner top@ 7962' 9-5/8" window @ 10793' 3 24" 18-5/8" 101 H-40 0' 409' 13-3/8" 72/68 N80/K55 0' 5712' 9-5/8" 47 N-80/S-95 0' 10793' (window) 7" 29 L-80 KC Buttress 7962' 14199' Tubing: 4-1/2" 12.6 L-80 Buttress 0' 7879' 3-l/2" 9.3 L-80 Buttress 7879' 12599' Gas Lift Mandrels: ] 2590' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 2 5169' 4-l/2" SFO-2 GLM with R-2 valve and RK latch 3 6618' 4-1/2" SFO-2 GLMwithR-2 valve and RK latch 4 7744' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 5 8486' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 6 9324' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 7 10137' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 8 10788' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 9 11375' 3-1/2" SFO-2 GLM withR-2 valve and RK latch 10 11936' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 11 12438' 3-1/2" SFO-2 GLM with Orifice valve and RK latch 1 2 3 4 5 297' 7879' 12518' 12565' 12599' TRSSSV, 4-1/2" Xover, 4-1/2" x 3-1/2" buttress Baker SAB 3-1/2' x 7" injection packer 3-1/2" "X" nipple w/2.813" ID Tubing tail G-l 6 G-2 6 12/5/02 G-3 6 12/5/02 G-4 6 12/5/02 G-5 6 12/4/02 13370 13400 HB-1 6 10/17/01 13445 13460 HB-2 6 10/29/01 13510 13520 HB-2 6 10/29/01 13570 13580 HB-2 6 10/29/01 13618 13633 HB-3 6 10/28/01 13640 13670 HB-3 6 10/27/01 13688 13733 HB-4 6 10/25/01 13767 13787 HB-4 6 10/27/01 13857 13882 HB-5 6 10/21/01 Max angle = 57° @ 4800' Hole Angle = 40° @ TD' 0: \OOE\OOEFie1ds\TBU\King\ W ells\K-24\K-24RD2\Schematics\K24RD2ActSchem1202.doc DRAWNBY:JHM 1.OOO 2,000 3,000 4,000 5,000 6,000 - 7,000 c ¡:: - c. CI> c 8,000 9,000 10,000 11,000 12,000 13,000 14,000 15,000 K..24RD2 ng Pressure G h ximum lowable pe o Pressure (PSI) 4,000 5,000 6,000 7,000 8,000 9,000 10,000 1,000 2,000 3,000 o --._~~"-"~_. N-80 8-95 S-95 8-95 Yield Top Bottom 8160.0 7962.0 14199.0 .0 .7 6870.0 .7 1762.6 8150.0 1762.6 2730.2 8150.0 2730.2 2737.5 8150.0 2737.5 10793.0 10793.0 10796.0 5380.0 38.2 590.7 3450.0 590.7 4217.2 5380,0 4217.2 5629.2 53~29~~4---~ 5380,0 5631.0 5710.0 5380.0 5710.0 5712.0 2250.0 409.0 409.0 330.0 330.0 ------".__.._~._--,~,--,-, ,-,-~--~~~-~--~--- -Internal Fluid Hydraulic Pressure Formation facture pressure @ 0.7 #/ft -Production CYP @ 70% - Outside Containment for Production casing -MASP (production casing) Intermediate CYP @ 45% -Outside Containment for intermediate casing MASP (Intermediate casing) . Current Pressure Disclaimers (fine print) Casing yield values taken trom published sources where specifications are known. If specifications are unknown then values are the lowest value of probable materials. TVD interpolated from Openworks directional surveys. Values should be +/- 25 ft@ 10,000 ft. MD RE: K-24RD2 (201-141) Communication between Tubbing and 95/8 Subject: RE: K-24RD2 (201-141) Communication between Tubbing and 9 5/8 From: "Grcenstein, Larry pOI <greensteinlp@unocal.com> Date: Mon, 01 Aug 2005 13:35:42 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: Hal M.artin <martinh@unocal.com>, Jim Regg <jimJcgg@admin.statc.ak.us> Here you go Tom. d-Ð \_\L\\ Except for some up and down readings 3 months ago, the casing pressures has been very consistent and low until this most recent event that prompted the injection shutdown on K-24RD2. Our first step is to have the tree checked out for any seal leaks. If all looks well with the tree, then a temp survey will be scheduled to look for any temperature anomalies. After talking with Glynn Brown, it appears we will be able to run the temp log before the end of the week. As soon as we can get the survey analyzed, we willi send it on to you for your review. Let me or Hal know if you have any questions. Larry From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, August 01, 20057:49 AM To: McGahan, Greg Cc: Larry Greenstein; Hal Martin; Jim Regg Subject: Re: K-24RD2 (201-141) Communication between Tubbing and 9 5/8 Greg, Thanks for the notice. I look forward to hearing the results of the wellhead work. Please note that the correct well name reference is K-24RD2. K-24 and K-24RD were plugged some time ago. Larry, can you provide the 90 day history ofK-24RD2's pressure performance?? Please call or message with any questions. .., Tom Maunder, PE AOGCC McGahan, Greg wrote: Gentlemen Contacted Jeff Dolan 7/31/05 and we discused the communication problem between the tubing and 9 5/8 casing on K-24. I have Vetco Gray set up to come out on the morning of August 2 to check for a hanger leak.Well is shut in and will stay shut in. Also here is some info on the K-24 for the last week. Also sent Tom Maunder copy of email as per Jeff to inform him of what is going on. Greg McGahan King Salmon Platform Date Tubing 9 5/8 13 3/8 24 10f2 10/12/2005 7:49 AM RE: K-24RD2 (201-141) Communication between Tubbing and 9 5/8 7/31/05 7/30/05 7/29/05 7/28/05 7/27/05 7/26/05 7/25/05 7/24/05 o 2400 2400 2400 2400 2400 2400 2400 o 2380 30 30 30 40 40 40 118 120 110 110 110 110 115 115 5 Well Shut In 10 10 10 10 10 5 5 From: Marlowe, Robert L Sent: Sunday, July 31,20052:18 AM To: Martin, J. Hal Cc: Johnson, Wayne E; Waski, John Subject: Hal, Had 2380 psi show up on K-24's casing tonight. As the max is 500 psi attempted to bleed off, would not bleed off while well was injecting. Shut in and bleed off. Reopened and the casing pressure mirrors the tubing pressure. As of 01 :3007/31/05 K-24 is shut-in. Robert Marlowe Pressure Observations 2005 07 20f2 K-24RD2 Pressure Content-Description: Observations 200507 31.xls application/vnd.ms-excel base64 Content-Type: Content-Encoding: 10/12/2005 7:49 AM K-24RD2 Pressure Observations 3500 7000 o 03/29/05 6000 3000 2500 5000 HRS_ON 2000 -TBGPRESS 4000 f -CSGPRESS2 9 5/8 :::I CSGPRESS3 13 3/8 III III f CSGPRESS6 26 Q. 1500 -Daily Volume 3000 1000 2000 500 1000 04/18/05 05/08/05 OS/28/05 06/17/05 07/07/05 07/27/05 o 08/16/05 Date ) ) State of Alaska MEMORANDUM Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor DATE: Friday, May 13,2005 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA K-24RD2 TRADING BAY UNIT K-24RD2 FROM: Chuck Scheve Petroleum Inspector Src: Inspector ~D (- L) \~ON-CONFIDENTIAL , Well Name: TRADING BAY UNIT K-24RD2 Insp Num mitCS050114143722 Rei Insp Num: API W~~I Number 50-733-20330-02-00 Permit Number 201-141-0 Inspector Name: Chuck Scheve Inspection Date 1/1012005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well K-24RD2 Type Inj. w TVD 8317 IA 2160 420 420 420 P.T. 2011410 TypeTest SPT Test psi 2079.25 OA 110 100 100 100 Interval Four Year Cycle P/F Pass Tubing 2320 2320 2320 2320 Notes: IA had been pressured up and a chart recorder installed prior to my arrival. The chart recorder showed no pressure change in 8 hours. The IA pressure was then bled off to 420 psi and observed for 1 hour with no change noted. v("""'\......~<:;) \" ~""~"SQ. .\1::> ~\,)It"'> \- ~I ~~I ~~~-\q~ ~ /1}tw ì/S-DS SCA1'J~\!EL JU\ 0 r'(' 200~, Friday, May 13,2005 Page 1 of 1 ) ) State of Alaska MEMORANDUM Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor DATE: Friday, May 13,2005 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA K-24RD2 TRADING BAY UNIT K-24RD2 FROM: Chuck Scheve Petroleum Inspector Src: Inspector dvÐ\ - \L\ 1 NON-CONFIDENTIAL Well Name: TRADING BAY UNIT K-24RD2 Insp Num mitCS050114143722 Rei Insp Num: API Well Number 50-733-20330-02-00 Permit· Number 201-141-0 Inspector Name: Chuck Scheve Inspection Date 1/10/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well K-24RD2 Type Inj. w TVD 8317 IA 2160 420 420 420 _._.___~_______.w_____ P.T. 2011410 TypeTest SPT Test psi 2079.25 OA 110 100 100 100 Interval Four Year Cycle P/F Pass Tubing 2320 2320 2320 2320 Notes: IA had been pressured up and a chart recorder installed prior to my arrival. The chart recorder showed no pressure change in 8 hours. The IA pressure was then bled off to 420 psi and observed for 1 hour with no change noted. SCANNED ~JlJN 1 4 2005 Friday, May 13, 2005 Page 1 of 1 ') UNOCAL8 April 11, 2005 Mr. Bob Fleckenstein Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Form 10-404 Submittal King Salmon Platform Well No. K-24RD2 Permit No. 201-141 Trading Bay Unit McArthur River Field Dear Bob: ') ......."1"5 r\ft J!5 Hal Martin Optimization Engineer Dir 907263-7675 Fax 907 263-7847 RECEIVED APR 1 2 2005 Alaska Oil & Gas Cons. Commission Anchorage Per your request, enclosed is Form 10-404 for the King Salmon Platform Well No. K-24RD2, Trading Bay Unit, McArthur River Field. This sundry report is a follow up of the well operation to convert the well from a producer to waterflood injector, which was accomplished with first injection in April, 2002. Additionally enclosed, as requested by the AOGCC on Form 10-403 approved 1/11/02, is a copy of the standard MIT performed on the well in October 2002. Unocal apologizes for the inadvertent omission of this sundry report. Please call me at (907)263-7675 if you have any questions. Sincerely, Jt¿ Aeú-L ' Hal Martin CI Oil Optimization Engineer '8Cli\NNEC j~.PR 1. 820œ) Unocal Alaska I Union Oil Company of California 909 W. 9th Ave. P.O. Box 196247 Anchorage. AK 99519-6247 ) STATE OF ALASKA } ALASt\.A OIL AND GAS CONSERVATION COMMI~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator Union Oil Company of California (UNOCAL) Name: 3. Address: 909 W. 9th Anchorage, Alaska 99501 7. KB Elevation (ft): 100' RT above MSL 8. Property Designation: Trading Bay Un it 11. Present Well Condition Summary: Total Depth measured 14200 true vertical 9998 Effective Depth measured 14157 true vertical 9965 Casing Length Structural 330' Conductor 409' Surface 5712' Intermediate 10793' Production 6237' Liner Size 24" 18 5/8" 13 3/8" 95/8" 7" Perforation depth: RECr:;~\lF:D APR 1 2 ZOOS Plug Perforations U Perforate New Pool D Perforate D 4. Current Well Class: Development 0 Stratigraphic D Stimulate U Alaskftiilr&1li8~9ri~~~'T1~r5~ion Waiver D Time Extension [jnchorage Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 201-141 Service D 6. API Number: 50-733-20330-02 9. Well Name and Number: K-24RD2 10. Field/Pool(s): McArthur RiverlHemlock Pool feet feet Plugs (measured) 14151' ( cmt shoe) Junk (measured) none feet feet MD TVD Collapse Burst 330' 409' 5712' 10793' 14199' 330' 409' 4165' 7487' 9997' Measured depth: various 13370' - 13882' True Vertical depth: various 9384' - 9760· Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 4 1/2" & 3 1/2" 12.6# L-80 & 9.3# L-80 to 7879' & to 12599' 3 1/2"x7" Baker SAB Injection PKR @ 12518' & 41/2" TRSSSV @ 297' Treatment descriptions including volumes used and final pressure: RBDMS BFL.. APR 1 3 2005 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 288 1948 1170 o 1550 170 15. Well Class after proposed work: Exploratory D Development D 16. Well Status after proposed work: oilD Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 69 o MIT report Contact HilL /J1A 1Cf'; '" tk"'L /J1Iif¿TII'/ 4R-~ ' Printed Name Signature Form 1 0-404 Revised 04/2004 Tubing Pressure 100 2500 Service 0 GINJ D WINJ 0 WDSPL D Sundry Number or NIA if C.O. Exempt: Title 0 t:Jrl /A 1 ~fl7í (J"'6\/ (jN'&1N'6è~ Date iff);0' Phone Pl, 1fL? to 7J- ( \ G. } \ C,.. \ \1\\ ¡:"., \) r\ C} ~ ~ ·u' \ Submit Original Only .,::.~! ~. .-.~~ \:-;:. #VALUEl °110.' ·iI~~kd' ,+~t:1;i:J . .:::~: , STATE I ALA$KA ALASKA OIL AND GAS CONSERVATION COMMISSION . Mechanical Integrity Test ,. . ,. : 7-. .-" -..... - . E-Mail to;ToÎ11_Maunder@admin.state.ak.usandBob_Flèckenstein@admin.state.ak.us . OPERATOR: Unocal Alaska FIELD I UNIT I PAD: McArthur River Field I TBU I King Salmon DATE: . ~,i~~I¡'I=I~~;"~l!: ;!~~:;;ªlfll~,·. PTD: 2011410 S P S ·8,784 9518" 47# 8-95 10,793 4.5" 0 0 0 Well #: K-24RD 12,518 7" 29# L-80 14,199' 3.5" 2196, 0 ';). 300 pl,OO COMMENTS: p~pa~Et) Co...hJrt.S'aw FæoM 01(,.. P~C\A.C..~ TO (tJTe'C.{t:S~·~ ð/~ L(Ø'O (~\_ ldo . 11 ~ \ 1 '3.ç' #VALUEJ o,~ ',,' ;1'1'~ ~ '!,. oö'"' Il ~ ~H . )!r'-;~:":' . ¡ ....~.. ~1t.1tt~jM 't·r: ,~~~'f. ;'" . ,I';' I'~ i..1 Ÿ ~i,~ ~.: Ii ., ~';Aì ..i:m . . .' . 'F~t ".,~.:'( .\ ,;~ - PTD: S Well #: COMMENTS: P S PTD: Well #: COMMENTS: S P S -¡ . ~. . ~~ ~ -~..~.. ~. "T ". :"~.·t;i:". h!..'; / ,. " ".1- ;;:.. t:.·~ -j :~,¡-~ ' }h;:~~~'; " '. " 4, '::"'.¡'}~ ; .' PTD: S Well #: . COMMENTS: P S # VALUE! #VALUEl PTD: S . Well #: . , C.OMMEN1S: . .P S 8.413 . 0.44. 1- . :: ! : c,~. ~ I;: _ ~F,{~~;r;¡ WELL·TESTt ' . .~:, .~::: '. Initial ' - \. . ~ . 4 - Year .:; . Workov~r ,:.,: .,,;.j .. , Oth~r : - ¡.1f,,~- 18G. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS INJ. S = SA~TWATER I.NJ. . N = NOT INJECTING TEST TYPE: M = ANNULUS MONITORING p= SID ANNULUS PRESSURE TEST R= INTERNAL RAD. T~ACER SURVEY A = TEMpERATURE ANOMALY·TEST D = DIFFERENTIAL TEMPERATURE JEST . OPER(\~OR REP SIGNATUR~j (~[~ . , AOGCC REP SIGNATURE: ~ K-24RD-2 MIT form 20021024.xls ANNULAR. FLUID: DIESEL Gl yeOl SALTWATER. DRILUNG MUD OTHER P.P.G. Grad. ~ { Distribution: orIg - Well File . c .. Operator . . c .. Database . . . .. c"TrlP~Mr~vised by L.G. 8/~/OO . è - Inspector . 44t4~ ~ 1 p'25'200~ ;~_ f. -.~.;" :'~' ~!iN r- ----- ~"1~~E mF fÆ~fÆ~~~fÆ / TONY KNOWLES, GOVERNOR / ALAS IiA 0 IL AND GAS / CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501.3539 PHONE (9071279.1433 FAX 19071276-7542 November 20, 2001 UNOCAL Field Superintendents 260 Cavair Street Kenai, Alaska 99611 Re: No-Flow Verification TBU Well K-17 PTD 173-001 TBU Well K-19 PTD 174 008 TBU Well K-24RD2 .......... J-o I - I I..{ I Gentlemen: On November 14, 2001 AOGCC Petroleum Inspector Lou Grimaldi witnessed "no-flow" tests on Wells K-17, K-19, and K-24RD2 at UNOCAL's King Salmon Platform. Trading Bay Unit, McArthur River Field. Mr. Grimaldi arrived on King Salmon Platform and proceeded to observe the wells. Over the course of the three (3) hour witnessed period, the test performance of TBU wells TBU Well K-17 (173-001), K-19 (174-008) and K-24RD2 (201-141) demonstrated that the wells are incapable of unassisted flow of hydrocarbons to the surface. Therefore, these wells need not be equipped with a commission approved fail-safe automatic surface-controlled subsurface safety valve C'SSSV") system. However, these wells must be equipped with fail-safe automatic surface safety valve ("SSV") systems capable of preventing uncontrolled flow and maintained in proper working condition. If for any reason any of the wells become 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. Sincerely, 4-5: 1y\?~.~tL'b, Thomas E. Maunder, -IE. Sr. Petroleum Engineer ':)(.t-.NI\!E[ MÞ~' : 1. ¿O[;: /7 !V\jv ~Ù~J DATA SUBMITTAL COMPLIANCE REPORT 1 0/22/2003 Permit to Drill 2011410 Well Name/No. TRADING BAY UNIT K-24RD2 Operator UNION OIL CO OF CALIFORNIA <; r CA.-~ I ~ ^« 1 API No. 50-733-20330-02-00 MD 14200 .--- TVD 9998 - Completion Date 10/17/2001---- Completion Status 1-01L Current Status 1-01L UIC N - -- -- --- REQUIRED INFORMATION Mud Log No Samples No Directional Survey ~--y-~~-- - --------------- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) ~~ Log/ Data Digital Type Med/Frmt ~-ec. I~~ Electr Dataset Number 11586 Name Log Log Run Scale Media No 1 ------ -- _u, I 5 8M Interval Start Stop 0 0 0 0 OH/ CH Received ~ 3/3/2003 ~ Case 3/3/2003 Comments 1 -; Well Cores/Samples Information: Name i Cuttings I Interval Start Stop 10830 14200 Sent Received Sample Set Number Comments ----------- ---- 1106 I --- _n -- _1 ADDITIONAL INFORMATION Well Cored? Y /fib Daily History Received? <x / N ~/N Chips Received? 'f-f-N- Formation Tops Analysis Received? -'>.1 ~ ...-rn-- ~-"- ----- --- ----------- ~ l\ > ~. t s # t+V\It<J~{( I ~Cø ~/1}.tJ /NlJ.r-IJV1/~q,Vlll'Ýï Comments: '0\} " ~~ Compliance Reviewed By: ~ Date: /.:t tJ t J -~:iC~ - - cc _C - â "i. Unocal Alaska 909 W. 9th Avenue Anchorage, AK 9950 I Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb@unocal.com UNOCALØj Beverly Harrison Business Ventures Assistant March 3, 2003 To: AOGCC Lisa Weepie 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL - ~ - ~ ~II ~,J)~ ~ "'-l ~ , , mwe~ ~rw:I1.Ê- ~~C~~ ~(4!"7OÄ~ 'WJ tif:Ëfig,Ä~~l!:Ö(rJIÈQ' ~~6~~~ f"'"ÊDïUM~ . ,', "'" " . ,. ",..,'" ,~ , ' ",.,,'.., -' >, ,.' ..,". ',,' . ," ..." ," I G-21 RD COMPLETION RECORD 2.511 5 INCH 1/10/2003 9350-9450 1 B-Line HSD POWERJET G-21 RD COMPLETION RECORD 2.511 5 INCH 1/10/2003 9350-9450 1 CD HSD POWERJET G-21 RD COMPLETION RECORD 2.5" 5 INCH 1/1 0/2003 9350-9450 1 Film HSD POWERJET ~ COMPLETION RECORD 2 7/811 5 INCH 1/1/2003 1 B-Line HSD POWERJET - COMPLETION RECORD 2 7/811 5 INCH 1/1/2003 1 CD 1\:.1"=22J.RU HSD POWERJET CM4-Rfj COMPLETION RECORD 2 7/811 5 INCH 1/1/2003 1 Film HSD POWERJET G-26RD COMPLETION RECORD 2 7/811 5 INCH 12/30/2002 10660-11428 1 B-Line HSD POWERJETS G-26RD COMPLETION RECORD 2 7/811 5 INCH 12/30/2002 10660-11428 1 CD HSD POWERJETS G-26RD COMPLETION RECORD 2 7/811 5 INCH 12/30/2002 1 0660-11428 1 Film HSD POWERJETS M-30 COMPLETION RECORD 2 7/811 5 INCH 12/20/2002 13409-13818 1 B-Line HSD POWERJET M-30 COMPLETION RECORD 2 7/811 5 INCH 12/20/2002 13409-13818 1 CD HSD POWERJET M-30 COMPLETION RECORD 2 7/811 5 INCH 12/20/2002 13409-13818 1 Film HSD POWERJET Please acknowledge receipt by signing and returning one copy of this transrnittal~ ~~MJ~}~?8, ~~ Anchorage I Received~ ~ I Date J AN, 1. 2003 4:00AM T~ SALMON PLATFORM ( NO, 967 P. 8 Select lbg Slrîng: !aU K-24RD2 8 Select rnne Period: ~ 90 ~ 8 - ~~~III" Report Name Tbg String Time Peñod Date Created aol-14/ Waterftood Injector Well Status TBU K-24RD2 last 90 Days 1/1/2003 Oate Length Volume Tbg P ress Csg Press outer Csg Press ( (hour:s) (bpd) (Psi) (psi) (pSi) 12/31/2002 24 407 2600 20 6 12/3012002 24 395 2620 20 10 12129/2!JO2 24 416 2620 20 10 12.(Jßf200 2 24 414 2620 20 10 12/27/2002 24 428 2600 20 10 12{26/2002 24 396 2600 20 10 12125/2002 24 "165 2600 20 10 12/24/2002 2.4 416 2500 20 10 12/.2312002 24 444 2600 20 10 12/2212002 24 423 2600 20 10 12/21/2002 24 419 260D 20 10 12/20/2002 24 422 2600 20 10 12j19/20Q2 24 432 2600 20 10 12/1812002 24 423 2600 20 10 12/17/2002 24 427 26QO 20 10 12/16/2002 24 440 2590 20 8 12/15/2002 24 4S4 2590 20 8 12/14/2002 24 ~ 2590 20 8 12/1'3/2002. 24 613 2600 10 S 12/12/2002 24 499 2450 10 6 12111/2002 24 133 2600 10 5 12/10/2002 24 809 2600 10 S 1~/2002 24 899 2590 10 5 12/8/200l 24 927 2590 10 5 . 12f1/200"l 15.5 663 2590 20 4 1216/2002 0 0 0 810 4 12/S/200"l 0 0 0 810 4 1214/2002 0 0 0 7SO 4 '¡ 1213/2002 0 () 0 750 S 12/2/2IJO'2. 0 0 0 720 140 12/1/2002 0 0 0 700 120 I I J J ~ http://kodialcanchortown.unoca1.coro/daltemplates/tabular.asp 1/1/2003 . 1¡J4A "/0- to Z- ~I' STATE OF ALASKA ( tÆ"h? \/te tù.) ALASKA OIL AND GAS CONSERVATION COMMISSIONdTvll1 if I olo~ APPLICATION FOR SUNDRY APPROVALS D7:f C)j/16/0 L 1. Type of Request: Abandon: Suspend: - Alter casing: Repair well: - - Change approved program: Pull tubing: 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Address P. O. Box 196247 Anchorage, AK 99519-6247 4. Location of well at surface 733' FSL & 133' FEL of Sec.17, T9N, R13W, SM At top of productive interval - 13370' MD 769' FNL & 74' FEL of Sec.28, T9N, R13W, SM At effective depth (13370' MD/9384" TVD) 769' FNL & 74' FEL of Sec.28, T9N, R13W, SM At total depth (14200' MD/9998' TVD) 742' FNL & 361' FWL of Sec.27, T9N, R13W, SM 12. Present well condition summary Total depth: measured true vertical 14,200' 9998' Effectivè depth: measured true vertical 14,157' MD feet 9965' TVD feet Casing Structural Conductor Surface Intermediate Production Length 330' 409' 5712' 10793 6237 Size 24" 18-5/8" 13-3/8" 9-5/8" 7" Perforation depth: measured various 13370'-13882' MD true vertical various 9384'-9760' MD 4-1/2" 12.6#, L-80 to 7879', and 3-1/2" 9.3#, L-80 t012599' ~JAN 0 4 ZQf)1 3-1/2"x7" Baker SAB Injection packer @ 12518' 4-1/2" TRSSSV @ 297' Description summary of proposal: x Detailed operations program: Current Well bore Schematic: X 14. Estimated date for commencing operation 2/1/2002 16. If proposal well verbally approved: Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Attachments feet feet Operation shutdown: Plugging: Variance: 5. Type of well: Development: ~ Exploratory: Stratigraphic: Service: Plugs (measured) Junk (measured) Cemented Driven 548 sx 2412 sx ~x L%, :ç ,.,.,..,......,..- - Re-enter suspended well: - Time extension: Stimulate: - - Perforate: Other: Convert to an Injector 6. Datum elevation (DF or KB) 100' RT above MSL 7. Unit or Property name Oil: X - feet - - Trading Bay Unit 8. Well number King Salmon K-24RD2 9. Permit number 1.-01-14/ 10. API number 50- 733-20330-02 11. Field/Pool McArthur River/Hemlock Pool 14,157' MD (cmt shoe) 9965' TVD None Measured depth 330' 409' 5712' 10793' 14199' True vertical depth 330' 409' 4166' 7487' 9997' RECEIVED Alaska 011 & Gas Cons. Commission Anchorage BOP sketch: - - 15. Status of well classification as: Approved by order of the Commissioner Original SiDned By Cammy Oechsli ORIGINAL Gas: Suspended: - - Name of approver Date approved Service: 17. I hereby C~~rti that}¡he foreg~g is tru,e and correct to, the best of my knowledge. Chr' t ~JJf!////- - 't&, -1.g.~o Signed: j~ r ~ Title: Senior Reservoir Engineer '-' , c.!..J FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity- BOP Test- Location clearance Mechanical Integrity TestÍ Subsequent form required 10- 'IOLf Date: 1/2/2002 APpr~IÖ~ . () 0 Y Commissioner Date I " 02 Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ( ¡~' King Salmon Platform, Trading Bay Unit K-24RD2 Convert to an Injector Proposal Summary Status: / Gaslift Oil Producer (12/8/01 Well Test) - 175 BOPD, 3022 BFPD, 828 MSCF/D, 2912 MSCF/D liftgas ./ Convert this low rate oil producing Hemlock well to G zone/Hemlock water injection service Objective: Procedure: 1 Baseline reservoir temperature survey obtained - run 10n/01 2 Underbalance G zone Intervals raenc h I - - . Foota51!J From (M D) .. To (MD) . G-1 12680 12710 30 G-2 12750 12790 40 G-3 12860 12890 30 G-4 12910 12980 70 G-5 13070 13160 90 I Total 260 3 Install dummy valves in all gaslift mandrels, place inhibited fluid on backside / Perform MIT to ensure tubing/casing pressure integrity 4 5 Install new surface injection piping, gauges and meters 6 Set up PLC (Alarms and Automatic Shutdowns), insure pressure relief system integrity 7 File 10-404 notifying AOGCC of conversion and Production Accouting of new Allocations 8 Begin water injection JLH 1/2/02 UNOCAL8 ( { Trading Bay Unit King Salmon Platform Well # K-24RD2 As completed 10-01-01 CASING AND TUBING DETAIL SIZE "VT GRADE CONN TOP BOTTO M 24" Driven 330' 18-5/8" 101 H-40 0' 409' 13-3/8" 72/68 N80/K55 0' 5712' 9-5/8" 47 L-80 0' 1798' 47 S-95 1798' 10793' (window) 7" 29 L-80 KC Buttress 7962' 14199' Tubing: 4-1/2" 12.6 L-80 Buttress 0' 7879' 3-1/2" 9.3 L-80 Buttress 7879' 12599' RKB to TBG Hanger = 34.85 4 5 TD = 14,200' MD/9999' TVD PBTD = 14157' Max angle = 57° @ 4800' Hole Angle = 40° @ TD' 1 2 9-5/8" window @ / 10793 ' 3~ I'~r; 18 I f(dp/~ ~ G J 7flrJe ~eNc.-à(7l1O( ./ 1¿(¡¡~o...I,1 01/03/02 Gas Lift Mandrels: 1 2590' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 2 5169' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 3 6618' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 4 7744' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 5 8486' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 6 9324' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 7 10137' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 8 10788' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 9 11375' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 10 11936' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 11 12438' 3-1/2" SFO-2 GLM with Orifice valve and RK latch JEWELRY DETAIL NO. 1 2 3 4 5 Depth 297' 7879' 12518 ' 12565' 12599' Item TRSSSV,4-1/2" Xover, 4-1/2" x 3-1/2" buttress Baker SAB 3-1/2' x 7" injection packer 3-1/2" "X" nipple w/2.813" ID Tubing tail PERFORA TION DATA TOP ßTM ZONE SPF DA TE COM,MENTS /13370 13400 HB-l 6 10/17/01 13445 13460 HB-2 6 10/29/01 13510 13520 HB-2 6 10/29/01 13570 13580 HB-2 6 10/29/01 13618 13633 HB-3 6 10/28/01 13640 13670 HB-3 6 10/27/01 13688 13733 HB-4 6 10/25/01 13767 13787 HB-4 6 10/27/01 13857 13882 HB-5 6 10/21/01 DRAWNBY:LWB ~"I,¡~,',~(Q,~,.,~,:,U:,~i,[~~I~, ¡~I,:.~¡~I.:,&II~i,~i,~,,~:~I',1:!:Ii'J,(Ð15:8, Field: MCARTHUR RIVER (\)1~Z"'!>:3' I'(\)' 15 ! ¡,,'-. 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':' :':5~ . ,ii' :I:~~' i-'--c~~¡~'g'c~'lï~-;L-;~;t~r (CCÜ-------- ; I :-19 C----) 1 I I , Parameters DLiS Name Description Value CCLD CCl reset delat 12 IN CCLT CCL Detection eve I 0.3 V CMPMI Computation Mode All CSIZ Current Cuing Size 7.000 IN DO Depth Offset for Playback 0,0 FT MATT Maximum Attenuation 30 DB/F MODE Firing Mode All NFPI Near Free Pipe Sonic Amplitude 95 MV PP Playback Processing NORMAL VDlM VDL Firing Mode LTR1 Format: CbteAttn_' Vertical Scale: S. per 100' Graphics File Created: 01-Jan-1990 07:48 OP System Version: 9C2-303 MCM CBT-EB 9C2-303 SGT-L 9C2-303 TCC-B 9C2-303 CAL.Y 9C2-303 1_-..1 nl I~ 1::'11_- -7 .-- " '--- , - .' -. , -- 14000 .~ .. - -- '. -~ ---- , .. .. .. --- I-- -- - -- -.I.. ~.......:. ~- - --"'. ", -. J_- f--- - .- - -- ,-- -- - - " -'-- - - - - _... ( , -, ,~. j~" ,,~-¡¡.~~-~~~._~ .." I: ", -'" ". . .. . '" ",' '.." - .- . l' . - '", , - . . .." I'" .... , - '~,' ~', ¡:- ,,- ~'~'::I' ";:,::.--~,,;: ::~-:-: ' :~ '::~~I-i-_~.~_~':_'~_)':::.,,:~~~'~~::{_:- -...-.. '" "'-'--' ..." "'" ..... .._, - ... .. ..., .. , \3i~ -,,-~~:~c~;:r~;t;O"~l(~_~ -.-,1- - , Gamma Ray (GR) ~ ,0 (GAP ) 1001 l___.__--- ---~~ry~!~!1_;~.~~).._..._.._.. j ]10000 (lBF) 01 '-----------------------,- Casln Collar locator CCl -19 (----) DLiS Name CClD CClT CMPM CSIZ DO MATI MODE NFPI ,PP VDlM Format: CbteAttn_1 { .:, : J : . : , : .: :: : ' ~.. """"'~'~"'"!!':' :::'1" ;, , "'", "'.. .:H~ :--- : --~ -:,~< H:f : ,_.,.,.-,-.....!,_._,.... 1i'~oC~~~i' -'u-: "-,,:".-:- .~:'-:- -'-..~~¡:--~_:~;-:" :~:"'~;i:" ~ -1--~..'~'--;:::_~ -j.::!"-,',::-. tl.i~~~ 'I . "-""-"""--"'~"-"""-I""~"!'.'IiI:.. --,!~-.- ,,-- ---"--"-- ;,:,~!~.;.?~: ' - -,--- --- :- - ,.. --I "-,, ... -'" . ~;'~'{~" I ,:.'~:::;-':;"".-~~:":: :-_"'~".- .~~._. .-~:'.:~:": .~~i£- ;, i. :~!~- " Amplitude Maxi ,-_D.!!c.rl!!!,IQa!eË- ~!!!.n~~o.!!JD~!...NL__; '_-L_rLIi:~:J¡Hilllillill[!ffilllll,'- , i2O (DB/F) OJ VDL VarlableDensity (VDl) i : :200 (US) 12001 , - I ------------------, L. __N!a!_P!,_e~.dl?-~te.!'~!ltJ~'!J~fl.IN2. --: ' :W (DB/F) O¡ I ' Parameters Description CCL reset delay CCl Detection level Computation Mode Current C~sing Size Depth Offset for Playback Maximum Attenuation Firing Mode Near Free Pipe Sonic Amplitude Playback Processing VDl Firln Mode Vertical Scale: 5" per 100' Value 12 IN 0.3 V All 7.000 IN 0.0 FT 30 DB/F All 95 MV NORMAL lTR1 Graphics File Crellted: 01-Jan-1990 07:48 CBT.EB TCC.B DEFAULT DEFAULT Schlumberger 9C2.303 9C2.303 SPLlCE- CBT _019 CBT_020PUP OP System Version: 9C2-303 MCM SGT.L 9C2.303 CAl-V 9C2.303 Input DLiS Flies FN:1 PRODUCER 01.Jan-1990 07:46 14177,5 FT 7912,1 FT Output DllS Files FN:15 PRODUCER 01-Jan-1990 07:47 BOTTOM LOG INTERVAL 14143 It sc: :L~;v1::;cnG¡:R CiEFiH i<ii5Uit DEPTH DRILLER 14152 It KELLY BUSHING 100 It DRILL FLOOR 99 It GROUND LEVEL CEMENT BOND LOG 30..SEPTEMBER-2001'/ .. ( , , Ì".i:.CRANl CAL INTEGRITY REPORT .... ';~UD ~',7-: - . 1.J .-. _.::.. . , ' ? i Ò { 10/5/0/ , - OPER & FIELD UAlC C-i~ L - (II(,!tv Jt..u. V" t2/V'er --C ....,-.,.-.,...- - , "" ~ ' ,- . ..-' r,...--_r.~......' ¡orE LL N llliB E R K- - z.£I¡lD l ~a \- \ '--\ \ '" . I 7~1:LL DATA TD : /Lll C¡C1.!:ill.. 90/1 L TVD; :?BTD: ¡LÎ157 MD ".h~ \. ~ l,<.) Cê.S i~g : q ~ )/8 II, .sfte-e: i D 7tl5 HD ~¡'¡;-oo TVD j DV.. 11D ?tJ;5 TVD . Tv 1) :'::":1e~: --'- ' 7 JI Shoe: I Lj i q ~ HI) 3150 TVD i :CF: '7C¿¿,21-m ') ~5 D :"'-¡D :'Joi::g: 4i/lu~Š~;acke~ I#}~' HD 9ðtO TVu¡ See ét 1¿5/~ ==_ole Size ~_1!1.1" ana Perfs 13)70' to 13&KZ' ,'. ~C?.ÞlrIC;'J... INTEGRITY - PART f 1 A - ~ ~nnu~us ~ress Test: l.P 'looo ; 15 min 3 0 min - Comments: Pre ~ t'w\'e/Lt/t~ f-Il[r Tß \J ." - ~ ,..,- HECHÞ..NICAL INTEGRTTY - PART /2 J"Ji bb(~ Cement Volumes:" ,Amt. Liner (PI) Si¿ ; Csg--.l°50 ~tL-; DV Cwt -.]01 to cove:!:' Derfs ~ ç' " , ~ <, ¡; ~ . i' t' Theoretical Toe ~ <e~5 ,'X' 1.Z- DB ~ 10<9 I ¡ ~{o ~ e ~ 0'20 e.:)lc.'"') ~ ì^,~ LJ~~ 13f. Cement Bond Log (Yes or No) ; In AOGCC File' Lj AJ¿~ ~~üt- CBL Evaluation, =one ~bove perfs ~ ,~cU.c~:Þ~ ~ '.é (~L Proà.uc.tion Log: i Evaluati.on 'Type I \ I , ¡ ¡ ! i :. , ,:; CONC~LUSIONS : ?arf n :--Pr<. -k\~""--' ? a.r~ : Z: It I ~~ll&.. t<d ,: ". /vU T y- e-cO uJ, y..Æ1 d. . &¡ ~/Vl~t ~L<:, $-~ \1(()~C)d- \¡;JGI\- i l LOr 0 L ,I . ' -' -- \ Unocal Alaska ~I 909 W. 9th Avenue II Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb@ unocal.com UNOCALe Beverly Harrison Business Ventures Assistant November 16, 2001 DATA TRANSMITTAL To: From: Lisa Weepie Beverlv Harrison 333 W 7th Ave, #100 909 W, 9th Avenue Anchorage, AK 99501-3539 Anchoraqe, AK 99501 Alaska Oil & Gas Unocal Alaska Transmitting the following: I\tú;j~ ',:'",:" LOG TYPE/, ,:,:.:-,' '.. I ',SCALE " lOG,IINTERV,AL ~ ::-:> ",' 'Well:;~':"<;, ',"' Mediurírl ~ !VISION DENSITY NEUTRON - 12/5 INCH 18/1/200 ¡ 10160-125511 11MRU K-18RD IB-Line I )\""'^""-""-^"^"W""M'^"""~'M_""M"_"'_~W'M'M'""W'-"^"^""'_W^"""""'^','"'W'^'M',""M"_M",'"W^'-~W'W^'M,^""W^,",W,W"WM"^,-.W~,-'^,W^"'^W"",,,wm',"M"W,'"~"^""--^W^,W^"W"M"""'W"M'M"W",,""WM_M__"^'^"~-^"'-'W_^""MW'M''W^-"-",-,,~^,~,--~,,:, ~ It,~L§lQN.J?M5J~J""§lIYJi~J)IB9J~J",w:_,JgL§Jr~~wgH,wM'"M,.IZLß/~!LQw"l§Z§Q:lg 44"Q_j '" " l' R Y_JS~J 8 ~~w"".~lê- Li n ~--,~,! ra ¡COMPLETION RECORD ¡5INCH 19/17/20 ¡ 12043-12070 i 1 ¡ MRU K-18RD j Film i ¡COMPLETION RECORD 15 INCH ¡ 8/28/20 ¡ 6300-12550' 11 MRU K-18RD ! Film! '.""""""""""""""""""""""""""""""""""""""""""""'"""""""""""""""""""""""""""""",;:"""""""""""""""""""""""""""",,",,"""""""""""""""""""'+"""""""""""""""""""""""""",..' """""""""""""""",i""""""""""""""""""""""i ¡COMPLETION RECORD ¡5INCH 19/22/20 :11807-11888 l,MRU K-18RD iFilm I !"cOM'ÞLËfïÒÑ""R'Ë'CORÖ"""""" 5 I NCH"'r9j2'2ï2'ò""i"1"1'8Ö7~'1"1"ä8ä" """"'1"nvfRÜ""R~'1"äRï5"""""""""""""'j"B'~Gñ'e""""""1 IV ïS'ìÒ N"'ÖË't~js'ï TV' '" N 'ËÜY R ÖN"':" ' "¿js"'fÑ'ct:i""'" "II '8/1/ ¿ÕÖ' 'r' 1 '01 '6Ó~1" 25'S '1' r""""'" "'1" r MR U' K :'1'8 RÖ",§f f"ll3~Ü' ñ e""""" ¡ ---"'MWH'W^"_"_-'^-_W_-~'-""""'--"~-'W^""-"'MW__-M" "-^""'-"-"""~""M"HHHH^""'H"""'_"M",^_W^_.-"M""_""..'-.",,^"M"'H_'__H'~'~'^""""'HM"""'-----~'------"""'_W^----",' IBRIDGE PLUG INCH 18/31/20 '10580-108541 1 !MRU K-24 ¡Film i l/q~05 Î ¡'"äRÎ5GEPLLfG~"'-'-"--'--'-----"'~ 5 I NëR^--,w""lä/31/2-Õ""'r1()Š'ãõ:'1õ854 'rw"w,",M1-~^MÃU "K:24~-""WH"'-'TB-Ciñe"'^,^"w,~ -"""""""""'" """, ,.. ,..""", "', """"" ",...""...", ..""..,.."""",.' ,COMPLETION REPORT .5 INCH ,,10/29/2 , 1 MRU K-24RD2 : B-Line ' ~ ¡VISION DENSITY NEUTRON - !2/5INCH18/29/20 : 10793-1420; 1 IMRU K-24RD2 iB-Line ¡ 1 iVI$í.QNQ~N$íIYN~Y.IBQN:I?L§TNçB::I?!?$!?Q!jQj$~:i4 ÆQQjIM,BQß~?1BR~L:n3jJri~! RECEI\Ia=O Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907 263- r8~ Date: NOV 1 9 2001 Received ~j~~~a Oil & Gas Cons. Commission ,fi n'+~o f STATE OF ALASKA ~;' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG TUBING RECORD SIZE DEPTH SET (MD) 4-1/2" 0'-7879' 3-1/2" 7879'-12599' 12518' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 1. Status of Well OIL: X GAS: 2. Name of Operator Unocal Oil Company of California (UNOCAL) 3. Address P. O. Box 196247, Anchorage, Ak 99519 4. Location of well at surface Leg B 1, Slot 10 Steelhead Platform 733' FSL, 133' FEL, Sec. 17, T9N, R13W, SM , At Top Producing Interval 13370' MD ~ ,..LD-! r7~-(.)1 769' FNL, 74' FEL, Sec 28, T9N, R13W, SM .. ... , -'- At Total Depth (14200' MD/9999' TVD) 1 """.:,.'}1'_-'-- 742' FNL, 361' FWL, Sec. 27, T9N, R13W, SM .i~"....".,._._~-,.. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 100' KB above MSL ADL-18730 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 9/1/01 9/24/01 :t,D.léf6'r /ù, /'1.D/ I-;t-, 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 14200' MD/9998' TVD 14157' MD/9965' TVD Yes: X No: 22. Type Electric or Other Logs Run Schlumberger CBT 9/30/01, Anadrill LWD GR/Res/Neutron/Density 9/25/01 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM ~ 0 ~' 18-5/8" 101# H-40 0 409' 13-3/8" 72#/66# N-80/K-55 0 5712' 9-5/8" 47# L-80/S-95 0 10793' 7" 29# L-80 7962' 14199' 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) All 6 spf 13370'-13400' HB-1 13445'-13460',13510'-13520', 13570'-13580' HB-2 13618'-13633',13640'-13670' HB-3 13688'-13733',13767'-13787' HB-4 13857' -13882' H B-5 SUSPENDED: ABANDONED: SERVICE: lOCA t1ONS ~- t ~.(;>'" . ~~~~- ~L'V ". ::;"'-"'ì1""!~-';"::_;'_':'~ HOLE SIZE 24" 17-1/2" 12-1/4" 8-1/2" 25. 13370'-13882' MD=9384' -9760' TVD Classification of Service Well 7. Permit Number 201-141 8. API Number 50- 733-20330-02 9. Unit or Lease Name Trading Bay Unit 10. Well Number K-24RD2 11. Field and Pool McArthur River Field Hemlock Pool 15. Water Depth, if offshore 100' RKB to MSL 20. Depth where SSSV set 297' feet MD 16. No. of Completions 1 21. Thickness of Permafrost NA CEMENTING RECORD Driven AMOUNT PULLED 0 0 0 0 0 548 sx 2412 sx 1050 sx 613 sx PACKER SET (MD) 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 10/17/01 Gas lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF 10/30/02 24 TEST PERIOD => 392 649 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF Press. 190 1200 24-HOUR RATE => 392 649 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ORIGINAL Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE e;Jf»AS WATER-BBL 2872 WATER-BBL 2872 CHOKE SIZE GAS-OIL RATIO open 1656 OIL GRAVITY-API (corr) 29.0 RECEIVED NOV 1 9 2001 AIIIka Oil & GaB Cons. CœImI8sioo Anchorage AFE #151574 Submit in duplicate NOV 2 I 2001 br ( (" 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME MEAS. DEPTH Include interval tested, pressure data, all fluids recovered and gravity, TRUE VERT. DEPTH GOR, and time of each phase. G zone 12680' 8871' Hemlock Bench 1 13370' 9384' Bench 2 13444' 9436' Bench 3 13592' 9542' Bench 4 13688' 9611' Bench 5 13849' 9730' Bench 6 13960' 9814' Bench 7 14094' 9916' West Forelands 14151' 9960' TD 14200' 9998' 31. LIST OF ATTACHMENTS Wellbore schematic, Daily Summary of Rig Operations, Final MWD survey report 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Title - Drilling Manaqer Date 11/ b/ð I INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 UNOCAL8 ( ,{ ,\ Trading Bay Unit King Salmon Platform Well # K-24RD2 As completed 10/1/01 CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 24" Driven 330' 18-5/8" 101 H-40 0' 409' 13-3/8" 72/68 N80/K55 0' 5712' 9-5/8" 47 L-80 0' 1798' 47 S-95 1798' 10793' (window) 7" 29 L-80 KC Buttress 7962' 14199' Tubing: 4-1/2" 12.6 L-80 Buttress 0' 7879' 3-1/2" 9.3 L-80 Buttress 7879' 12599' RKB to TBG Hanger = 34.85 1 2 4 5 TD = 14,200' MD/9998' TVD PBTD = 14157' Max angle = 57° @ 4800' Hole Angle = 40° @ TD' K-24RD2 10-1-01 schematic. doc 7" liner top @ 7962 ' 3 9-5/8" window @ 10793 ' 11/05/01 Gas Lift Mandrels: 1 2590' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 2 5169' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 3 6618' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 4 7744' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 5 8486' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 6 9324' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 7 10137' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 8 10788' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 9 11375' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 10 11936' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 11 12438' 3-1/2" SFO-2 GLM with orif valve and RK latch JEWELRY DETAIL NO. 1 2 3 4 5 Depth 297' 7879' 12518 ' 12565' 12599' Itelll TRSSSV, 4-1/2" Xover, 4-1/2" x 3-1/2" buttress Baker SAB 3-1/2' x 7" injection packer 3-1/2" "X" nipple w/2.813" ID Tubing tail PERFORA TION DATA TOP BTM ZONE SPF DA TE COMMENTS 13370 13400 HB-l 6 10/17/01 13445 13460 HB-2 6 10/29/01 Proposed 13510 13520 HB-2 6 10/29/01 Proposed 13570 13580 HB-2 6 10/29/01 Proposed 13618 13633 HB-3 6 10/28/01 13640 13670 HB-3 6 10/27/01 13688 13733 HB-4 6 10/25/01 13767 13787 HB-4 6 10/27/01 13857 13882 HB-5 6 10/21/01 DRAWN BY: TAB ( (' K-24RD Abandonment Daily Summary Unocal Alaska Drilling Daily Summary Report K-24RD Abandonment 8/27/01 to 8/31/01 8/27/01 Accept rig after leg move from K-18RD ST1, NO tree, NU and test BOPE, Pressure test 9-5/8" casing above retainer at 7994' to 2246 psi, leaked off to 2228 in 30 min, 8/28/01 Pull hanger and lay down 7966' of 2-7/8" tubing kill string, Change top rams to 5" and test BOPs, 8/29/01 Pull FMC Unihead failed 9-5/8" x 13-3/8" casing packoff through BOP stack, Wash out packoff area, Run new packoff though BOP stack, Run in lock down screws and test new packoff to 3000 psi, RIH with 8-1/2" mill, 8/30/01 Mill up retainer at 8004', RIH to 10887', circ BU. POOH, 8/31/01 Run 9-5/8" bridge plug on E-line, set at 1 0817', RD E-line, Pressure test 9-5/8" casing above 1 0817', 1054 psi leaked off to 937 psi in 30 min, RIH with whipstock and tri-mill assy, Orient and set whipstock at 56L at 10817', Shear bolt and change over well from brine to oil based mud while milling window, k-24rd2 daily summary. doc I" ( ( K-24RD2 Redrill Dailv Summary Unocal Alaska Drilling Daily Summary Report K-24RD2 Redrill 8/31/01 to 10/29/01 8/31/01 Run 9-5/8" bridge plug on E-line, set at 1 0817', RD E-line, Pressure test 9-5/8" casing above 10817', 1054 psi leaked off to 937 psi in 30 min, RIH with whipstock and tri-mill assy, Orient and set whipstock at 56L at 10817', Shear bolt and change over well from brine to oil based mud while milling window, 9/1/01 9/2/01 9/3/01 9/4/01 9/5/01 9/6/01 9/7/01 9/8/01 9/9/01 Mill from 10794' to 10812', starter mill stopped making progress, POOH, ...... Mills in gauge but starter mill 60% worn on bottom, RIH with new starter mill and only one 8-1/2" watermelon mill. Mill from 10812' to 10814,5', Slow drilling with no progrss at end, POOH, Mills in gauge, starter mill 80% worn due to abrasive sand, RIH with 7-7/8" mill tooth bit and 8-1/2" watermelon mill. Finished milling window to 1 0825', Run FIT to 11,0 ppg EMW, POOH, mill in gauge, RIH with drilling assy, Drill from 10825' to 11079', Drill from 11079' to 11342' Drill from 11342' to 11622', Test BOPE, RIH with PDC bit #2, Drill from 11622' to 11758', ROP very slow, POOH, PDC Bit #2 inner cutters completely wore down to nozzles, outer rows of cutters in good shape, Appeared to be junk damage. RIH with used mill tooth bit and 2 junk baskets to 11758', Drill from 11758' to 11760', work pipe to recover junk, POOH, no metal found in junk baskets, Worn PDC apparently due to abrasive sand instead of junk, 9/10/01 RI H with insert bit. Drill from 11760' to 11929' 9/11/01 Drill from 11929' to 12211', High torque, POOH, 9/12/01 RIH with PDC bit, drill from 12211' to 12559', 9/13/01 Drill from 12559' to 12757', Observed 2 bbl pit gain while drilling, Shut down mud pumps and observe well flowing at low rate, Shut-in well, SICP = 140 psi, SIDPP=360 psi (due to motor and/or float), MW=9.4 ppg, Circ well thru choke holding casing pressure constant at 160 psi, increased to 240 psi and held steady at 240 psi throughout circulation of 835 bbls, Open annular and well static. k-24rd2 daily summary.doc ( (" 9/14/01 Resume drilling from 12757' to 13082'. Trip for bit. POOH 5 stands and observed hole not taking correct amount of mud, well flowing slightly, Trip back to bottom. 9/15/01 SIDPP=70 psi, SICP=180 psi. Circ out influx, still slight flow, Increase MW to 9,7 ppg, Observe well and still slight flow, Increase MW to 9,9 ppg, well static, POOH 5 stands and observe slight flow, Increase MW to 10,1 ppg, 9/16/01 POOH and well not taking correct amount of fluid, Trip back to bottom and condition oil-based mud which had been cut by water influx, (mud was probably thick and swabbed when POOH), POOH with proper fill and hole static, 9/17/01 Finished POOH with proper fill. Test BOPE, RIH with 8-1/2" insert bit. 9/18/01 Drill from 13082' to 13282', 9/19/01 Drill from 13282' to 13520', 9/20/01 POOH for new bit, hole took proper amount of fill, one overpull of 50k Ibs at 13102'. RIH with new bit, no hole problems, Drill from 13520' to 13596', 9/21/01 Drill from 13596' to 13907', Trip for new bit. 9/22/01 POOH for new bit, no problems, RIH with LWD logging tools, 9/23/01 Drill from 13907' to 14153', 9/24/01 Drill from 14153' to 14200' TD, POOH while making MAD pass with LWD tools, Up to 12580' , 9/25/01 Finish POOH, RU and run 7" liner. 9/26/01 Tag bottom with liner at 14200', Drop ball and set liner hanger, hydraulic release from hanger and blow ball seat out at 4300 psi. Pump 20 bbls Chem Wash spacer, 50 bbls Mud Push spacer and 130 bbls of 15,8 ppg cement. Displace with oil-based mud and bump plug, PU and set ZXP liner top packer with 60K down weight. Pressure test liner top to 2160 psi. PU and reverse out, spacer in returns but no sign of cement. 9/27/01 POOH with drill pipe, Test BOPE, RIH 6" bit cleanout assembly while PU 3-1/2" drill pipe, 9/28/01 Drill up landing collar at 14113' and hard cement down to 14157', Perform MIT, 2200 psi to 2131 psi in 30 min, Changeover well from 10,1 ppg oil-based mud to 3% KCL. 9/29/01 POOH LD 5" and 3-1/2" drill pipe, RU Schlumberger. 9/30/01 RUN CBT from 14150' to 7900', TOC at 10230', RU to run completion, 10/1/01 Run 3-1/2" x 4-1/2" gas lift completion with SAB packer, up weight = 175k and down weight = 110k Ibs, Land hanger and spot 50 bbls corrosion inhibitor at and above packer, Drop 1-3/4" ball, unable to seat ball in shear out sub/tubing tail. RU slickline, k-24rd2 daily summary.doc 1 0/2/01 1 0/3/01 ~' ~' RIH with 2,72" blind box working across each of 11 GLMs, tag shear out sub at 12586', still no ball on seat. Reposition tbg hanger 2' above seat. RIH with 2,813" RHC plug body on slickline, Set plug body in X nipple at 12561', RIH with RHC bar/ball and set down at 12561', Pressure up to 3000 psi to set SAB packer. PU 50' with ball/bar. Pressure test down tubing to 500 psi for 5 min, no circ so OK, POOH with ball/bar, RIH and retrieve RHC plug body, RIH and knock out shear out sub at 12599' with blind box. Some overpulls at lowest GLMs but all tools were recovered, Land tbg hanger with 105k downweight. Pressure tbg to 1100 psi and bled off to 300 psi in 30 min with returns up annulus, Pull on tbg to 195K (up weight was 175k before packer was set) to verify packer slips set. RU slickline and attempt to set RHC plug in X nipple to inflate packer element to 4000 psi. Could not locate X nipple, POOH and hung up at GLM #9 at 11384', Shear off and POOH, RIH with GS retrieving tool, pull and recover RHC plug body from GLM #9, RIH with PX plug, set down at G LM #11 at 12446', Attempt to PU with no luck, Shear off and POOH, RIH with GS retrieving tool and latch PX plug, jar up with no success, POOH, Change jars from 1-1/2" to 1-3/4", engage PX plug and jar up with no success, POOH, Pressure up tubing to 2000 psi with no circ up annulus, Packer and GL Vs appear to be in place, RIH with GS retrieving tool and more weight bars, Engage fish, jar up on fish, no luck, Shear off and POOH, RIH with 2,73" centralizer and stem, beat down on fish at 12431', no movement. POOH, RIH with centralizer and more stem, beat down on fish at 12431' with no movement, POOH, RIH with GS retrieving tool and 30' of 1,75" stem, Unable to engage fish at 12431', POOH, no marks on tool. RIH with LIB, Tag fish at 12431', POOH, impression showed V2 of internal fishing neck, RIH with 2,65" tapered swedge, worked swedge on top of fish, POOH, RIH with 2,75" bulldog spear, engage fish at 12431', jar fish up hole 4' with spang jars until fish came free, 10/4/01 Retest tubing to 2000 psi with no communication to annulus, Land hanger, retest tbg to 2000 psi with no communication to annulus, RIH with 2,75" gauge ring to 14145' wlm, POOH, 10/5/01 NO BOPE, NU and test tree, release rig at 12:00 noon 10/5/01, 10/7/01 Run slickline baseline temperature log from surface to 14,000' with stops every 1000', 10/17/01 Unload well with gas lift down to 11125', Add 900 psi tbg pressure, RIH with Schlumberger 2-1/2" power jet, 6 spf @ 60 deg phasing, Perf HB-1 at 13370' to-"'" 13400', POOH with spent guns and gas lift well. 10/21/01 RIH with Schlumberger 2-1/2" power jet, 6 spf @ 60 deg phasing, Perf HB-5 at 13857' -13882', POOH with spent guns and gas lift well. 10/25/01 RIH with Schlumberger 2-1/2" power jet, 6 spf @ 60 deg phasing, Perf HB-4 at 13688' -13733', POOH with spent guns and gas lift well. 10/27/01 RIH with Schlumberger 2-1/2" power jet, 6 spf @ 60 deg phasing, Perf HB-4 at 13767'-13787'. POOH with spent guns, Perf HB-3 at 13640'-13670', POOH with spent guns, k-24rd2 daily summary.doc ~¡! f 10/28/01 RIH with Schlumberger 2-1/2" power jet, 6 spf @ 60 deg phasing, Pert HB-3 at 13618' -13633'. POOH with spent guns and gas lift well. 10/29/01 RIH with Schlumberger 2-1/2" power jet, 6 spf @ 60 deg phasing, Pert HB-2 at 13570' -13580', POOH with spent guns, Perf HB-2 at 13510'-13520', POOH with spent guns" Perf HB-2 at 13445'-13460', POOH with spent guns, k-24rd2 daily summary.doc Client..""",.,.",.,.,: Unocal - King Salmon Field""",.""""",,: Trading Bay Unit Well"""""""."",,: K-24RD2 API number."",."",.,,: 50-733-20330-02 Engineer"."""""",,: Carlos Pacheco Rig:......,.......,...,.,: Nabors 58 State:"""""",.,.,.,: Alaska ----- Survey calculation methods------------- Method for positions"...: Minimum curvature Method for DLS""""",: Mason & Taylor ----- Depth reference ----------------------- Permanent datum".,."",: Mean Sea Level Depth reference""..",,: Driller's Pipe Tally GL above permanent"",.,: 100.00 ft KB above permanent"",.,: 100.00 ft DF above permanent.".",: 100,00 ft ----- Vertical section origin---------------- Latitude (+N/S-),."".,.: 0,00 ft Departure (+E/W-)"."",: 0,00 ft ----- Platform reference point--------------- Latitude (+N/S-),.""",: -999,25 ft Departure (+E/W-)""",,: -999,25 ft ANADRILL SCHLUMBERGER Survey report Azimuth from rotary table to target: 106,78 degrees [(c)2001 Anadrill IDEAL ID6_1C_10] 24-Sep-200122:29:55 Spud date."" ,."",.",: Last survey date",."",: Total accepted surveys",: MD of first survey,.,.",: MD of last survey,."".,: Page 1 of 3 29-Aug-01 24-Sep-01 39 10700,00 ft 14200.00 ft ~, ----- Geomagnetic data ---------------------- Magnetic model""",..,.: BGGM version 2000 Magnetic date""""",,: 31-Aug-2001 Magnetic field strength,,: 1107,42 HCNT Magnetic dec (+E/W-)"",: 20,80 degrees Magnetic dip",..."",.,: 73.55 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G, , , , , , . . , , , , . , : H, , , , , , , . , , , , , , : Dip"""""" : of G""""",: of H".""",,: of Dip", , , , , , , : Criteria --------- 1002,03 mGal 1107,42 HCNT 73,55 degrees (+/-) 2,50 mGal (+/-) 6,00 HCNT (+/-) 0,45 degrees ~~. ----- Corrections --------------------------- Magnetic dec (+E/W-)..",: 20,80 degrees Grid convergence (+E/W-),: 0,00 degrees Total az corr (+E/W-)",,: 20,80 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N)""",,: No degree: 0,00 ANADRILL SCHLUMBERGER Survey Report --- -------- -------- Seq Measured # depth (ft) --- -------- -------- 1 2 3 4 5 10700,00 10852,46 10942,30 11040,10 11134,44 6 7 8 9 10 11224,09 11318,86 11411,47 11504,80 11600,63 11 12 13 14 15 11692,79 11784,00 11878,78 11971,09 12065,71 16 17 18 19 20 12154,80 12247.53 12340,64 12435,00 12529.24 21 22 23 24 25 12621,70 12717,87 12812,08 12901,85 12996,47 26 27 28 29 30 13093,04 13185.05 13280,44 13370,07 13463,03 ------ ------ Incl angle (deg) ------ ------ 47.60 48.00 47,21 46,60 46,70 45.88 44,72 43,69 42.00 42,32 42.67 42,31 40,76 39,82 40,56 39.06 40.11 40,56 40,72 40,85 40,62 39,69 39,91 40,74 41.35 41,37 44,36 44,64 44.59 45,05 ------- ------- Azimuth angle (deg) ------- ------- 149.00 145,00 142,50 139,76 138,27 132,61 129,50 126,94 125,88 124,75 120,84 117,32 114,11 107,64 102,52 99,13 96,25 95,98 96,29 96,33 95,08 93,97 92,23 93,38 94,30 93,83 94,47 95.05 96,09 95,68 ------ ------ Course length (ft) ------ ------ 0,00 152,46 89.84 97,80 94,34 89.65 94,77 92,61 93.33 95,83 92,16 91,21 94,78 92.31 94,62 89,09 92,73 93,11 94.36 94,24 92,46 96.17 94.21 89,77 94,62 96,57 92.01 95,39 89.63 92,96 -------- -------- TVD depth (ft) -------- -------- 7424,90 7527,33 7587,91 7654,74 7719,50 7781,47 7848,14 7914,53 7982.96 8054,00 8121,96 8189,23 8260.18 8330,63 8402,93 8471,37 8542,84 8613,81 8685,42 8756,77 8826,83 8900.34 8972,72 9041.16 9112,52 9185.00 9252,43 9320,47 9384.28 9450.21 24-Sep-200122:29:55 -------- -------- Vertical section (ft) -------- -------- 5288,41 5374.63 5427.62 5486,57 5544,59 5601.40 5662,78 5722,87 5782.64 5843,62 5903,44 5963,61 6025.67 6085.14 6146,13 6202,85 6261,18 6320.40 6380,80 6441.34 6500.54 6561,15 6619,73 6676,11 6736.66 6798,91 6859,98 6925,37 6987,12 7051.47 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- -6081,20 -6175,88 -6229.38 -6284.98 -6336,76 -6382,91 -6427,16 -6467,11 -6504,79 -6541,97 -6575,67 -6605,61 -6632.89 -6654,17 -6670,02 -6680,76 -6688,64 -6695,06 -6701,63 -6708,40 -6714,40 -6719,29 -6722,55 -6725,40 -6729,57 -6734,09 -6738,63 -6744,18 -6750,29 -6757.00 3689,90 3751.40 3790,62 3835,42 3880,41 3925.83 3976,60 4027,31 4078.38 4130,86 4183,18 4237.00 4293,60 4349,29 4408,21 4464,21 4522,76 4582.68 4643.79 4704,98 4765,01 4826,83 4887,04 4945,06 5007.05 5070,70 5133,12 5199,75 5262,40 5327,58 Page --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 7113.11 7225,96 7292,05 7362,84 7430,49 7493,58 7557,89 7618,58 7677,59 7737,01 7793,48 7847,69 7901.28 7949,48 7995,09 8035,03 8074,24 8113,25 8153,32 8193,86 8233,37 8273.28 8311,19 8347,73 8387.94 8429,71 8471,01 8515,95 8559,16 8604,66 148,75 148,72 148,68 148,61 148,52 148,41 148,25 148,09 147,91 147,73 147,54 147,32 147,08 146,83 146,54 146,25 145,93 145.61 145,28 144,96 144,64 144,31 143,98 143,67 143,35 143,02 142,70 142,37 142.06 141.75 2 of 3 ----- ----- DLS (degl 10Of) ----- ----- 0,00 1,96 2,24 2,14 1,15 4,65 2,63 2,23 1,97 0,86 2,89 2,64 2.78 4,64 3,58 2,96 2,28 0,52 0,27 0,14 0,92 1.22 1,21 1,24 0.91 0,32 3,28 0,52 0.82 0.58 ----- ----- Srvy tool type ----- ----- TIP MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD ------ ------ Tool qual type ------ ------ 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis -~ 6-axis 5-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ~~-- 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report Seq # -------- -------- Measured depth (ft) -------- -------- 31 32 33 34 35 13545,67 13640,18 13733,77 13824,69 13925,32 ------ ------ Incl angle (deg) ------ ------ 44,62 43,49 42,83 41,74 40,68 40,18 39,60 39,32 ------- ------- Azimuth angle (deg) ------- ------- 95,55 97,16 98,23 98,70 98.50 98,97 99,45 99,69 ------ ------ Course length (ft) ------ ------ 82,64 94.51 93.59 90,92 100,63 91,17 28.19 60,78 -------- -------- TVD depth (ft) -------- -------- 9508,82 9576,74 9645,01 9712,27 9787,98 9857,39 9951,48 9998,41 24-Sep-200122:29:55 -------- -------- Vertical section (ft) -------- -------- 7108,63 7173.25 7236,47 7297,00 7362.61 Page ---------------- --------------- --------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- -6762,71 -6769,97 -6778.54 -6787.54 -6797,45 7421,14 -6806,43 7499,25 -6818.99 7537,57 -6825.42 Last survey is a projection to a TD of 14200 ft, 36 37 38 14016,49 14139,22 14200,00 [(c)2001 Anadrill IDEAL ID6_1C_10] 5385,57 5450,88 5514,32 5574,83 5640.37 5698,80 5776,59 5814,68 Total displ (ft) At Azim (deg) --------------- --------------- 8645,15 8691,64 8738,21 8783,47 8832,84 8877,15 8936,87 8966,42 141,47 141,16 140,87 140,60 140,31 140,06 139,73 139,57 3 of 3 ----- ----- DLS (deg/ 10Of) ----- ----- 0,53 1,68 1,05 1,25 1,07 0,64 0,98 0,52 ----- ----- Srvy tool type ----- ----- MWD MWD MWD MWD MWD MWD MWD MWD ------ ------ Tool qual type ------ ------ 6-axis 6-axis 6-axis 6-axis ~~~ ~~ "' (:' i' ( MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille 0, Taylor, < Chair (p ~ Tom Maunder, f(t1tJ~ c......P\ p, I. Supervisor}ä\ ~o-.J" DATE: November 14, 2001 THRU: FROM: Lou Grimaldi, Petroleum Inspector SUBJECT: No-Flow Test \L -ð4 Q~ d... UnocalSteelhead K-24 ~~ \ .- \ \".\ \ McArthur River Field TBU PTD NON-CONFIDENTIAL Wednesda November 14 2001: I witnessed a No-Flow verification on UNOCAL's King Salmon platform well #K24 in the McArthur River field. Following is a timeline and well status during test. 1000 Well flowing at less than 180 scf, no fluid. Shut-in well 1015 SITP 0 psi, Open well. Flow initially at 250 scf and dropped to 0 scf. Shut- in well. 1145 SITP 0 psi, Open well to atmosphere. Flow initially less than 180 sef and dropped to bare whisper. Shut-in well 1250 SITP 2 psi, open well to atmosphere. Flow initially less than 180 scf and dropped to bare whisper. Note: The gauge used to check flow was incable of measuring below 180 scf or above 2000 scf. This well exhibited inability to flow to surface unassisted and I recommend it be granted No-Flow status. This well is due for a workover during which a ESP will be installed. I explained to Mark Atkins (Platform Foreman) that any cleanout, perforating or other stimulation will require another No-Flow test. SUMMARY: I witnessed No-Flow verification on UNOCAL's King Salmon platform well #K-24 in the McArthur River field. NON-CONFIDENTIAL CC: Dwight Johnson/Mark Atkins (Unocal) Attachment: None No-Flow UNOCAL TBU K-24 11-14-01 LG,doc i '1, Unocal Alaska" 909 W. 9th Avenue ~ Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb@ unocal.com UNOCAL(; Beverly Harrison Business Ventures Assistant November 16, 2001 DATA TRANSMITTAL To: From: Lisa Weepie Beverlv Harrison 333 W 7th Ave, #100 909 W, 9th Avenue Anchorage, AK 99501-3539 Anchoraqe, AK 99501 Alaska Oil & Gas Unocal Alaska Transmitting the following: ~;U':,,;iI!;JN3r:I~, j'iMia'ûml! t§u ry~YJ:t~p'gI:L""""'."',^."""'M"L"""",.,w""-'."."W"'M"'W"M"'M.,"_jMw_"",2L?1LQ1L".""""""""""'M~""""'.'M""""'!~"",..?J,~ B.v.J~:tê.B,Q"""""'M,~",w1P-~,P~,L"""J=;) 0 ~ I ¡ ì I n I u mÞ e I9.~1".Ete.RQJ:LJw."M""M"""'^,""""""'."""".""'.""'""""",L~M""",w,]19JlQJ,w,.""""",.""",.,w,.",."",~.",,^,.,".j"',^"M".1LMB'~H"!S,:1§J3J?"'.""""""'M.,,LE~~p,,~L.,J """"""""""""""""",1""""""""""""",,,'" """"""""""",', """""",~""""""""",,""""""""""l""""""""'1"""""""""""""""""""""""'"""""""""""""'1""""""""""""""""""'""'I , , " ' " , , " ' , , " " " 1"""""""""""""""""""""""""""""'""""""""""""""""""""""""]""""""'"""""""""""""""""""""""""""""",""""¡"""""""""""""""""""""""""",,,""T"""""""""""" """"""""""""""""",.""""",..",."""".,"""""""""""""j"""""""""""""""'"",.,",..':: !' , " """"'."'M"M"""""'M"'._-'."""-"""'.""l"""M~'.'" 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CommissUm c r (' ( ( ", ~Ol-I'-I / UNOCAL r-d UNOCAL ALASKA RESOURCES, INC. K-24RD2 McARTHUR RIVER FIELD Section 17- T9N-R13W Cook Inlet, Alaska September 26, 2001 John Morris - Logging Geologist Andrew Buchanan - Logging Geologist [J EPOCH ( UNOCAL8 Unocal Alaska Resources, Inc. K-24RD2 McArthur River Field Cook Inlet, Alaska TABLE OF CONTENTS ,",E:L.L. FtE:~LJIWIE:....................................................................................................................~ L.11rtiC:>L.C:>~~ ~LJIWIIWI~Ft~ ......................................................................................................~ ( DAIL. ~ CtiFtC:>NC:>L.C:>G~ ......o.. .......... ......... ..... ..... .................. ........ ...... ......... .................... ...12 IWILJD FtE:Cc:>FtD ................ ......o. ..... ........... ....... ......... ................... .......... ..... ........................ .15 ~LJFtVE~ FtECC:>FtD.... ................... .................. ....................... ........ ..................... ............. ...16 BIT FtE:CC:>FtD. ............ ....................o. .............. ............. ........... ................. ..... ................. ......17 IWIc:>FtN ING FtE:POFtT~....................................................................................... .~PPE:N DIX 1 ,",E:L.L. L.OG~ ........... ...... ............. ..... ......... .... .... ..... ........... ............ .... ..... ....... .... ..~PPE:NDIX 2 ( ~ EPOC=H 2 UNOCAL8 K-24RD2 f WELL RESUME UN OCAL ALAS KA KI NG SALMON PLATFORM K-24RD2 WELL NAME: K-24RD2 FIELD: McARTHUR RIVER FIELD REGION: COOK INLET LOCATION: SEC, 17 T9N R13W SM BOROUGH: KENAI BOROUGH STATE: ALASKA ELEVATION: RKB: 100,0' AMSL API NUMBER: SPUD DATE 50-733-20330-02 SEPTEMBER 4, 2001 (Kick off) ( CONTRACTOR: UNOCAL ALASKA RESOURCES, INC. SHANE HAUCK, TERRY CHADDOCK MATT FRANKFORTER NABORS ALASKA DRILLING OPERA TOR: Operator Representatives: Company Geologist: DRILLING RIG: MUDLOGGING COMPANY: Logging Geologists: KING SALMON PLATFORM EPOCH WELL SERVICES, INC, John Morris, Andrew Buchanan MUD COMPANY: Mud Engineers: MI MONTY KANTA, MIKE FORMAN ANADRI LUSCHLUMBERGER MARK BROWN, CARLOS PACHECO MWD COM P ANY: MWD Engineer: DIRECTIONAL COMPANY: Directional Driller: ANADRI LL/SCHLUMBERGER MIKE WARD, M.VERY.CORKER DOWELL/SCHLUMBERGER CEMENT COMPANY: WIRELINE COMPANY: SCHLUMBERGER ( ~ EPOC:H 3 UNOCAL8 K-24RD2 ( LITHOLOGY SUMMARY DRILLED TYONEK AND HEMLOCK (10,820'-14,200') TYONEK (COMMEMCE LOG TO ) 10830' Sand/ConQlomerate = light gray overall, common salt and pepper appearance; clasts range from fine lower to granules; angular to rounded, dominantly subangular to subround; poorly sorted; composed of 70% quartz, 300/0 volcanic and metamorphic lithics; totally disaggregated in samples; oil based mud masks any petroleum indicators, 10880' Tuffaceous Claystone = light gray to light greenish gray; soft to occasional firm; irregular fracture; blocky to massive cuttings habit; trace carbonaceous material in part; interbedded with and grading to Tuffaceous ash. 10915' Sandstone/Sand = light gray; very fine upper to medium with coarse and rare very coarse; subround to subangular; low to moderate sphericity; composed of <95% clear and translucent quartz grains with minor accessory minerals; clay and ash infilling porosity in part; estimate good to fair intergranular porosity; oil indicators obscured by oil based mud, 10965' Coal = dark brown to black; firm to hard; conchoidal fracture to planar fracture; irregular to blocky cuttings; very clayey in part; grading to carbonaceous shale, ( 10995' Tuffaceous Claystone = light to medium brownish gray; soft to occasional moderately hard; crumbly to occasional moderately tough; matte to rarely slightly shiny luster; smooth to occasional moderately gritty texture; non to locally slightly calcareous; common carbonaceous specks and streaks; locally common thin streaks of light to medium gray ash, 11040' Sand = light gray overall; clasts range from very fine upper to coarse upper; dominantly fine to medium range; subangular to subround; poorly sorted; composed of 70°/Ó quartz, 30°/Ó volcanic and metamorphic lithics; grains are loose in sample; non to very slight acid reaction, 11105' Tuffaceous Claystone = light to medium brownish gray; soft to moderately firm; mushy to occasional moderately tough; dominantly earthy to occasional slightly shiny luster; smooth to slightly gritty texture; dominantly non to occasional slightly calcareous; scattered to common pinpoint carbonaceous specks; occasional medium to dark gray ashy streaks, 11145' Tuffaceous Siltstone = light gray to light greenish gray; soft to slightly firm; irregular fracture; curved, contorted pdc bit deformed cuttings; occasional visible shards; interbedded with and grading to clay, 11180' Coal = dark brown to black; firm to hard; conchoidal fracture to planar fracture; irregular to blocky cuttings; very clayey in part; grading to carbonaceous shale, ( ~ EPOCH 4 UNOCAL8 K-24RD2 ( 11210' Tuffaceous Claystone = light gray to light greenish gray; soft to occasional firm; irregular fracture; blocky to massive cuttings habit; matte to occasional sparkly luster; smooth texture; interbedded with tuff ash and Siltstone. 11245' Tuffaceous Siltstone = light gray to greenish gray brown; soft to slightly firm; irregular fracture; curved, contorted pdc bit deformed cuttings; matte to earthy with occasional sparkly luster; gritty texture; occasional visible shards; interbedded with and grading to clay. 11290' Sand/Sandstone = light gray; very fine lower to medium lower; moderately sorted; predominantly subround; moderately to good sphericity; commonly consolidated with tuff ash matrix; composed of 70% quartz, 30% metamorphic and volcanic lithics, rare chert; non calcareous to occasional very slightly calcareous; estimated poor visual porosity and permeability; oil indicators are obscured by oil based mud, 11370' Tuffaceous Claystone = light gray to light greenish gray; soft to occasional firm; irregular fracture; blocky to massive cuttings habit; matte to occasional sparkly luster; smooth texture; interbedded with tuff ash and Siltstone, 11405' Sand/Sandstone = light gray; very fine upper to medium lower with occasional coarser grains; predominantly subround; moderate sorting; predominantly unconsolidated; trace siliceous cement in part; composed of 90% clear and translucent quartz grains; 10% assorted lithic grains and minerals; assume grain supported; estimated fair to good intergranular porosity; occasional tuff ash matrix; oil indicators obscured by oil based mud, ( 11465' Sand = light gray; very fine lower to medium lower with rare coarser grains; angular to occasional subround; moderately sphericity; moderate to good sorting; unconsolidated; composed of 80% quartz, 20% lithics fragments and assorted minerals; grades to silt in part; occasionally consolidated with tuff ash; estimate poor to fair intergranular porosity; oil indicators obscured by oil based mud. 11520' Tuffaceous Siltstone = light gray to greenish gray brown; soft to firm; irregular fracture; curved, bit deformed cuttings; earthy to occasional sparkly luster; occasional visible shards; interbedded with and grading to clay in part. 11555' Coal = dark brown to black; firm to hard; conchoidal fracture to planar fracture; irregular to blocky cuttings; rarely clayey in part; gradational contacts coal to carbonaceous shale to clay. 11622 Pull out of the hole for bit. 11625' Coal = black to occasionally dusky yellowish brown; firm to moderately hard; brittle; fine to 5 mm cuttings; dominantly splintery and blocky; occasional conchoidal fracture surfaces; slightly shiny luster; dominantly smooth to occasional rough surface texture; rare medium brownish gray claystone laminations. ( [:I EPOCH 5 (' ( ( UNOCAL8 K-24RD2 11695' Sand/Sandstone = light gray; very fine lower to medium lower with occasional coarser grains; predominantly subround; moderately sphericity; moderate sorting; composed of 80°/Ó quartz, 20°/Ó lithic grains and assorted minerals; common tuff ash in matrix; estimate fair to poor intergranular porosity; grain supported; oil indicators obscured by oil based mud, 11757' Pull out of hole to check bit. 11755' Tuffaceous Claystone = light gray to light greenish gray; soft to occasional firm; irregular fracture; blocky to massive cuttings habit; matte to occasional sparkly luster; smooth texture; interbedded with tuff ash in part. 11790' Coal = dark brown to black; firm to hard; conchoidal fracture to planar fracture; irregular to blocky cuttings; very clayey in part; grading to carbonaceous shale in part, 11820' Tuffaceous Claystone = medium brownish gray; soft to occasional moderately hard; crumbly to occasional tough; blocky and irregular cuttings; matte to rarely slightly shiny luster; moderately gritty texture; non to occasional moderately calcareous; common black specks; occasional thin ashy laminations, 11885' Coal = black to occasional dusky brown; firm to moderately hard; crunchy to occasional moderately tough; dominantly brittle; matte to slightly shiny luster; dominantly smooth to occasional slightly rough surface texture; occasional very argillaceous, grading in part to carbonaceous shale, 11925' Sand = dominantly very light gray overall; clasts range from fine lower to coarse upper; dominantly medium range; angular to rounded, dominantly subangular to subround; poorly sorted; composed of 70 to 80°/Ó quartz, 20 to 30°/Ó metamorphic and volcanic lithics; common thin ashy residue on most grains; estimated poor to fair porosity and permeability, 11975' Ash Fall Tuff = light gray with rare brownish and bluish hues; very soft to occasional firm; amorphous to occasional platy or blocky cuttings; matte, chalky to rarely slightly resinous luster; moderately gritty texture; non calcareous; common pinpoint black specks; scattered to common volcanic glass shards; interbedded with claystone, 12025' Coal = black; brittle; firm to moderately hard; small irregular, blocky and platy cuttings; slightly resinous luster; scattered to common pieces with conchoidal fracture surfaces, 12055' Tuffaceous Claystone = medium brownish gray; soft to occasional moderately hard; crumbly to occasional tough; blocky and irregular cuttings; matte to rarely slightly shiny luster; moderately gritty texture; non to occasional moderately calcareous; common black specks; occasional thin ashy laminations. 12095' Sand/ConQlomerate Sand = light gray overall; very fine upper to upper medium with common bit fractured coarse and pebble size grains; angular to subround; low to moderate sphericity; poorly sorted; composed of 70°/Ó quartz, 20°/Ó metamorphic- and igneous lithic fragments; 10% assorted minerals; common tuff ash matrix; coarse and pebble grains quartz and metalithics; predominantly unconsolidated; grades to siltstone in part; occasional laminations of clay; estimate very poor to occasional fair intergranular porosity. [:I EPOCH 6 UNOCAL8 K-24RD2 ( 12165' Tuffaceous Siltstone = light gray to greenish gray brown; soft to firm; earthy fracture; predominantly massive cuttings; dull earthy luster; grades to sand in part; common quartz and lithic sand size grains; occasional carbonaceous material; common ashy blebs and streaks. 12211' Pull out of hole for new bit. 12215' Tuffaceous Clavstone = medium brownish gray; soft to occasional moderately hard; crumbly to occasional tough; blocky and irregular cuttings; matte to rarely slightly shiny luster; moderately gritty texture; non to occasional moderately calcareous; common black specks; occasional thin ashy laminations, 12255' Sand/Sandstone = light gray overall; very fine to occasional medium upper; fair to moderately sorting; predominantly subround to subangular; moderately to low sphericity; composed of 70% quartz, 20% lithic fragments, 10% assorted minerals; abundant tuff ash matrix; grades to siltstone in part; estimated very poor intergranular porosity. 12295' Coal = black; brittle; firm to moderately hard; small irregular, blocky and platy cuttings; slightly resinous luster; scattered to common pieces with conchoidal fracture surfaces; common laminae of carbonaceous shale, ( 12325' Sand = light gray overall, common milky white, clear, occasional light to medium greenish gray, occasional dark reddish orange; clasts range from fine to very coarse, dominantly medium range; angular to rounded, dominantly subangular to subrounded; poorly sorted; composed of 70% quartz, 30% metamorphic and volcanic lithics; grains are loose in samples; occasional with thin ashy coating; fair porosity and permeability inferred; oil indicators masked by oil base mud. 12385' Coal = black; brittle; firm to moderately hard; small irregular, blocky and platy cuttings; slightly resinous luster; scattered to common pieces with conchoidal fracture surfaces; common laminae of carbonaceous shale, 12415' Sand = light gray overall with slight salt and pepper appearance; clasts range from fine lower to coarse upper, dominantly in the medium range; angular to rounded, dominantly in the subangular to subrounded range; poorly sorted; composed of 700/0 quartz, 30% lithics; rare jasper; common free blebs of ashy matrix material. 12460' Tuffaceous Clavstone = medium brownish gray; soft to moderately hard; crumbly to rarely moderately tough; irregular, blocky and tabular cuttings; matte to rarely slightly shiny luster; smooth to common gritty texture; non to locally moderately calcareous; common black pinpoint specks and streaks; scattered to common volcanic glass shards; rare light to medium gray banding, 12535' Sand = light gray overall; clasts range from fine upper to coarse upper, dominantly medium range; angular to well rounded, dominantly subangular to subround; poorly sorted; composed of 70% quartz, 30% lithics, scattered chert fragments; oil show indicators masked by oil based mud. ( [:I EPOC:H 7 UNOCAL8 K-24RD2 ( 12575' Ash Fall Tuff = very light gray with rare brownish and bluish hues; very soft to occasional firm; amorphous to occasional sub blocky cuttings; matte to chalky luster; occasional gritty texture; occasional volcanic and lithic floating fragments; trace glass shards; interbedded with clays. 12615' Siltstone = light to medium gray; firm to soft; irregular to occasional blocky fracture; irregular to bit deformed cuttings; predominantly quartzose with minor lithics; common ash matrix; grades to very fine lower sand in part. 12650' Coal = black; brittle; firm to moderately hard; small irregular, blocky and platy cuttings; slightly resinous luster; scattered to common pieces with conchoidal fracture surfaces; abundant woody component. 12680' Sand = light gray overall with scattered medium to dark gray and black; clasts range from fine to very coarse, dominantly medium range grains; angular to subrounded; poorly sorted; composed of 80% quartz, 20% lithics; grains are loose in samples; slight acid reaction from bulk sample; scattered to common clusters of ash; fair estimated porosity and permeability; oil indicators obscured. 12757' Shut in well and circulate bottoms up using driller's method, 12750' Tuffaceous Claystone = light to medium brownish gray; soft to firm; crumbly to rarely moderately tough; irregular blocky and occasionally tabular cuttings; matte to rarely slightly shiny luster; smooth to moderately gritty texture; locally common blebs of ash; scattered volcanic glass shards; scattered black pinpoint specks, ( 12825' Coal = black; brittle; firm to moderately hard; small irregular, blocky and platy cuttings; slightly resinous luster; scattered to common pieces with conchoidal fracture surfaces; grades to carbonaceous shale in part. 12860' Siltstone = light to medium gray; firm to soft; irregular to occasional blocky fracture; irregular to bit deformed cuttings; predominantly quartzose with minor lithics; common ash matrix; grades to very fine lower sand in part, 12895' Sand/Sandstone = light gray overall; very fine lower to medium lower with common bit fractured coarse sand and pebble size grains; moderate with occasional very poor sorting; subangular to subround; moderate sphericity; composed of 80% quartz, 200/0 lithics and minor assorted minerals; commonly grading to siltstone; occasional tuff ash matrix; estimated very poor to occasional fair intergranular porosity, 12955' Sand/Sandstone = light gray; very fine lower to medium lower with occasional coarser grains; moderate sorting; subround to angular; moderate sphericity; composed of 80% quartz, 20% lithics and assorted minerals; commonly grades to siltstone; tuff ash matrix in part; estimated fair to poor porosity, 12995' Tuffaceous Claystone = medium brownish gray; soft to occasional firm, rarely moderately hard; dominantly irregular cuttings, occasional blocky and tabular; matte luster; gritty texture; non to locally moderately calcareous; locally silty, grading in part to Tuffaceous Siltstone; common carbonaceous specks; scattered blebs of ashy material. ( ~ EPO(~H 8 UNOCAL8 K-24RD2 ( 13040' Coal = black to occasional dusky yellowish brown; firm to moderately hard; brittle; moderately tough; fine to 10mm cuttings; splintery to platy, common conchoidal fracture surfaces; rare thin laminations of Tuffaceous Claystone and ashy material. 13082' Pull out of hole for new bit. 13090' Sand = light gray overall; very fine lower to fine upper with rare coarser grains; moderately well sorted; subround overall; moderate sphericity; composed of quartz with rare lithics; grades to siltstone in part; trace tuff ash matrix in part; estimated very poor to poor intergranular porosity; common coal cavings; oil indicators obscured by oil based mud. 13140' Tuffaceous Claystone = medium brownish gray; soft to occasional moderately hard; crumbly to occasional tough; blocky and irregular cuttings; matte to rarely slightly shiny luster; moderately gritty texture; non to occasional moderately calcareous; occasional black specks; occasional thin ashy laminations, 13180' Ash Fall Tuff = very light gray with rare brownish and bluish hues; very soft to occasional firm; amorphous to occasional sub blocky cuttings; matte to chalky luster; occasional gritty texture; trace shards. 13210' Coal = black; firm to moderately hard; brittle, crunchy; fine to 10 mm cuttings; hackly to occasional conchoidal fracture; slightly resinous luster; dominantly smooth to occasional moderately rough surface texture; scattered laminations of dark brown organic matter; scattered laminations of light to medium gray ashy claystone, \, 13280' Tuffaceous Claystone = medium brownish gray; soft to firm; crumbly to moderately tough; matte, earthy luster; moderately gritty texture; occasional very silty, grading to siltstone; common ashy streaks, 13310' Siltstone = medium gray; firm to stiff; irregular to occasional blocky fracture; massive to elongate cuttings; predominantly quartzose with common carbonaceous material, lithics and ash matrix; grades to very fine sandstone in part; interbedded with clays; no visible oil indicators. 13350' Sandstone = light to medium gray; fine lower to medium upper; poor to occasional moderately sorting; angular to subangular; low to moderately sphericity; composed of 70% quartz, 20% lithic fragments and 10% assorted minerals; grain supported; tuff ash matrix infilling porosity and acting as cement; estimated very poor intergranular porosity; abundant coal cavings, 13395' Sand = light gray overall; very fine upper to medium upper with occasional coarser grains; poor to occasional moderately sorting; subangular to subround; low to moderately sphericity; made up of 90% quartz, 10% lithics and assorted minerals; predominantly unconsolidated; common ash; estimated poor porosity; abundant coal cavings, ( 13435' Carbonaceous shale = dark brown; firm to moderately hard; moderately tough; 1 to 3 mm cuttings; dull to slightly resinous luster; smooth texture; non calcareous; common carbonaceous specks and streaks; grades to very argillaceous coal. n EPOCH 9 UNOCAL8 K-24RD2 ( 13470' Sandstone/ConQlomerate = very light gray overall; clasts range from fine to coarse, dominantly fine to medium range; occasional grains appear to be chips of granule or larger size grains; common pitted and frosted grains; composed of 80%> quartz, 20% lithics, trace jasper; oil indicators masked by oil based mud. 13520' Trip for new bit. 13525' Sandstone/ConQlomerate = light gray to white overall; friable; clasts range from fine lower to granule fragments; angular to rounded, dominantly subangular; moderately sorted in the fine to medium range; composed of 90% quartz, 10%) lithics; rare jasper and olivine; non to very slightly calcareous; estimated fair to good porosity and permeability; oil indicators masked by oil based mud. 13605' Sandstone/ConQlomerate = light gray to white with slight salt and pepper appearance; friable when consolidated; clasts range from fine lower to granule size, dominantly medium range grains; angular to rounded, dominantly subangular to subround; poorly sorted overall; composed of 90% quartz, 100/0 lithics, scattered jasper; 13650' Sandstone/ConQlomerate = light gray to white overall; friable when consolidated; clasts range from very fine upper to granule fragments, dominantly medium range grains; angular to rounded; low to moderate sphericity; poor to occasional moderately sorting; composed of 70% quartz, 200k lithic fragments and 100k assorted minerals; common tuff ash; occasional as matrix; predominantly unconsolidated; consolidated chips have siliceous cement; estimated poor to fair with occasional good porosity, ( , 13710' Sand/ConQlomerate = light gray overall; predominantly fine upper to medium upper with very fine lower to pebble; commonly bit fractured; very poor to occasional moderate sorting; angular to subround; low to moderately sphericity; composed of 700/0 quartz, 20% lithics and 10% assorted minerals; very ashy in part; common interbeds of clay and ash; unconsolidated; estimated fair to poor with occasional good intergranular porosity. 13765' Ash Fall Tuff = off white to gray and pale green; cohesive; hydrofissile; soft to firm; irregular to earthy fracture; massive cutting habit; dull to occasional waxy luster; smooth to gritty texture; occasional devitrified. 13800' Sand/ConQlomeratic Sand = light to medium gray; fine lower to bit fracture coarse and pebble; angular to occasional subround; very poor to occasional moderately sorting; low sphericity; 60% quartz, 30% lithics and 10% assorted minerals; very ashy; common laminations of clay; predominantly unconsolidated; estimated very poor to occasional fair intergranular porosity; no shows, oil based mud, 13840' Sand/ConQlomerate = light gray overall; clasts range from fine lower to granules, dominantly medium size range; angular to rounded, dominantly subangular; poorly sorted; common pitted and frosted grains; common bit sheared grains; composed of 70% quartz, 300k volcanic and metamorphic lithics; dominantly loose in sample, rarely consolidated with ashy matrix; non to occasional very slightly calcareous; estimated fair porosity. 13907' Trip for new bit. ( U EPOCH 10 ( (, ( UNOCAL8 K-24RD2 13910' Sand/ConQlomerate = light to medium gray overall; very fine upper to medium upper with occasional bit fracture coarser grains; moderate to poor sorting; angular to subround; predominantly moderately sphericity; composed of 80% quartz, 20% lithic fragments and occasional assorted minerals; predominantly unconsolidated; common to abundant ash and clay laminations; assume common ash matrix in part; estimated predominantly poor to fair intergranular porosity. 13960' Sand/ConQlomerate = medium gray overall; fine lower to coarse lower with occasional bit fracture very coarse and pebble; poor sorting; low to moderate sphericity; angular to subround; composed of 70% quartz, 20% lithic fragments, and 100/0 assorted minerals; abundant ash and clay laminations; common ash matrix; estimated very poor to poor intergranular porosity; ash commonly cloritized from 13960'-13990'. 14010' Tuffaceous Claystone = medium brownish gray; soft to occasional moderately hard; crumbly to occasional tough; blocky and irregular cuttings; matte to earthy luster; smooth to gritty texture; non calcareous; occasional silty in part. 14045' Sand/ConQlomerate = medium gray overall; fine lower to coarse lower with occasional bit fracture very coarse and pebble; poor sorting; low to moderate sphericity; angular to subround; composed of 70% quartz, 20% lithic fragments, and 10% assorted minerals; loose in sample; very slight acid reaction; oil indicators masked by oil based mud, 14095' Coal = black; firm to moderately hard; crunchy; small blocky and hackly cuttings; occasional conchoidal fracture surfaces; slightly resinous luster; smooth texture; rare thin laminations of tuffaceous claystone, 14155' Tuffaceous Claystone = medium brownish gray, occasional light gray; soft to firm; mushy to moderately tough; fine to 5mm cuttings; blocky to tabular, common irregular habit; matte, earthy luster; moderately gritty texture; non to locally slightly calcareous; common black pinpoint specks and streaks; locally common ashy blebs and glass shards, 14200' Total Depth 14,200' (9998.51' TVD) 09/24/01 0305hrs U EPOCH 11 UNOCAL8 K-24RD2 ( DAILY CHRONOLOGY 08/31/2001 Pull out of hole, work BHA, PJSM, rig up wire line. Run into hole with bridge plug. Set at 10817'. POOH with wireline. Rig down wireline. Test casing to 1000 psi for 15 minutes. Work BHA, pick up whipstock, and check MWD, Run in hole with whipstock, break circulation, orient and set whipstock at 56 degrees left at 10817'. Clean pill pit, prepare for displacement. Sheen noticed on water. Shut down and check for leaks and drips- none. Shear whipstock pin. Displace hole with oil base mud, Mill and displace with oil base mud. 9/1/2001 Mill window from 10793' to 10812', pull out of hole. 9/2/2001 Pull out of hole, work BHA, cut drilling line, work BHA, pick up drill pipe, run in hole, service top drive, run in hole, mill window from 10808' to 10814', pull out of hole. 9/3/2001\ . Pull out of hole, work BHA, drop mill, and pick up bit. Run in hole, mill window from 10814' to 10825'. Sweep hole, FIT to 11 PPG, check for flow. Pull out of hole, lay down BHA, service rig, pick up new BHA, and run in hole. Drill ahead. ( 9/4/2001 Drill from 1 0828' to 11 079' , 9/5/2001 Drill from 11079' to 11342'. 9/6/2001 Drill from 11342' to 11622', circulate bottoms up, pull out of hole, 9/7/2001 Pull out of hole, work on rig, pull out of hole, work BHA, test BOPE, cut drilling line, service rig, clean pits, run into hole, ream from 11474', 9/8/2001 Drill from 11622' to 11757', pull out of hole to check bit and mudmotor. 9/9/2001 Pull out of hole, work BHA, service rig, wait on tools, pick up BHA, run into hole with mill tooth bit and junk baskets, ream 11627' to 11758', cycle pumps, reciprocate pipe, drill from 11758' to 11760', cycle pumps, reciprocate pipe, pull out of hole. 9/10/2001 Run into hole, drill from 11760' to 11934'. ( 0 EPO(~H 12 UNOCAL8 K-24RD2 (' 9/11/2001 Drill from 11934' to 12211', circulate, pull out of hole. 9/12/2001 Pull out of hole, change bit, run into hole, drill from 12211' to 12559'. 9/13/2001 Drill from 12559' to 12757', well flowed, shut in well, circulate. 9/14/2001 Drill from 12757' to 13082', circulate, pull out of hole. 9/15/2001 Pull off bottom, hole not taking fluid, circulate, run into hole, raise mud weight, pull off bottom, hole not taking fluid, run into hole, raise mud weight. 9/16/2001 Circulate, pull 4 stands wet, pump pill, pull 1 0 stands, hole not taking fluid, monitor hole, Run 5 stands in hole, monitor hole, pull out of hole wet, hole not taking correct fill. Run in hole to 13062', circulate. Pull 4 stands out of hole, well swabbing. Run in hole to 13062', circulate, rotate pipe at 140 RPM, Work on top drive generator, circulate, pump out of hole. 9/17/2001 Pull out of hole, test BOPE, run into hole with new bit. ( 9/18/2001 Run into hole, circulate bottoms up, ream to bottom, drill 13082' to 13275'. 9/19/2001 Drill from 13275' to 13520', circulate, 9/20/2001 Circulate, pull out of hole, run with new bit, drill from 13520' to 13599'. 9/21/2001 Drill from 13599' to 13907', circulate, 9/22/2001 Drill from 13599' to 13907', circulate. 9/23/2001 Circulate, pull out of hole, change BHA and bit, pick up logging tools, run into hole 9/24/2001 .Run into hole, ream two stands to bottom, drill from 13907' to 14158', ( \. [:I EPOCH 13 UNOCAL8 K-24RD2 ( 9/25/2001 Drill ahead from 14158' to 14200'. Total depth reached at 0305hrs. Circulate bottoms up; pump slug and pull out of the hole to begin mad pass; log out of hole from 13907' to 12500'; circulate hole clean; pull out of the hole. 9/26/2001 Continue to pull out of the hole; test rams and rig to and run casing. Run casing to bottom and circulate hole clean; pump cement. Epoch rigged down and released. ( (" ~ EPOCH 14 UNOCAL8 K-24RD2 MUD RECORD Date Depth TVD MW VIS PV YP Gel FL HTHP Cake Sol C.Sol Oil Wtr OIW Porn CI- Salt Lime E- stab 8/31/01 10817 9.3 129 25 25 19/27/31 6,2 2 11 11 76 13 85/15 .5 22.5k 21.31 .65 1600 9/1/01 10815 9.25 134 27 26 22/32/35 6.0 2 10 10 76 14 84/16 ,5 22,Ok 19.74 ,65 1650 9/2/01 10815 9.35 137 26 26 24/33/34 5.9 2 10 10 76 14 84/16 ,6 22,Ok 19.74 ,78 1700 9/3/01 10830 7445 9.4 131 28 24 24/32/33 5.8 2 9 9 76 15 84/16 .6 22.0k 18,67 ,78 1780 9/4/01 11073 7595 9.2 123 30 20 25/33/33 6.0 2 11 10,18 75 14 84/16 ,7 22.0k 19.74 ,91 1703 9/5/01 11343 7860 9.1 123 28 23 26/33/37 6.0 2 11 10 76 13 84/16 .7 22.0k 20.94 .91 1598 9/6/01 11620 8070 9,1 109 30 18 26/32/35 6.0 2 10 9 76 14 84/16 .6 21.5k 19.38 ,78 1577 9/7/01 11652 8075 9,1 132 24 17 25/31/34 6.2 2 10 9 76 14 84/16 .6 21.0k 19,01 ,78 1478 9/8/01 11757 8170 9,1 101 27 19 25/31/35 6.6 2 10 9 75 15 83/17 ,7 20,5k 17,62 ,91 1344 9/9/01 11758 8170 9,2 139 29 18 27/32/36 6,6 2 10 9 75 15 83/17 ,6 20,Ok 17.26 ,78 1551 9/10/01 11902 8262 9.2 106 28 19 27/34/39 6,4 2 9 8 76 15 84/16 ,6 21.0k 17.97 ,78 1627 9/11/01 12211 8505 9,2 99 27 19 26/34/39 6.2 2 10 9 76 14 84/16 ,5 22.0k 19,74 ,65 1559 9/12/01 12517 8720 9.2 115 26 18 24/31/37 6,6 2 10 9 76 14 84/16 .6 22.0k 19.74 .78 1574 9/13/01 12757 8921 9.1 88 25 15 25/31/36 6,8 2 10 9 76 14 84/16 .5 24,Ok 21,15 ,65 1584 9/14/01 13082 9157 9,4 110 26 20 28/31/35 6.8 2 10 9 75 15 83/17 ,2 24.5k 20.36 ,26 1408 9/15/01 13082 9157 10,0 140 30 29 31/36/40 7.2 2 14 13 69 17 80/20 ,2 25,Ok 18.71 ,26 1407 9/16/01 13082 9157 10.1 107 29 23 26/35/36 7.2 2 13 13 69 18 79/21 ,7 26,Ok 18.44 .91 1467 9/17/01 13082 9157 10.2 123 30 22 21/30/33 6.4 2 12 12 70 18 80/20 .7 22,5k 16,36 .91 1380 9/18/01 13276 9291 10,15 92 27 20 23/33/34 6.8 2 12 12 70 18 80/20 .85 26.0k 18.44 1.11 1200 9/19/01 13520 9482 9,15 83 25 19 19/31/33 6.4 2 13 13 70 17 80/20 1.1 25.0k 18.71 1.43 1275 9/20/01 13600 9545 10,2 90 26 19 21/31/33 6.3 2 16 16 67 17 81/19 1.2 26,Ok 19.31 1,56 1435 9/21/01 13908 9773 10.15 83 26 19 21/31/33 5.8 2 15 15 70 15 82/18 .1 26.0k 21,34 1,3 1500 9/22/01 13908 9773 10,25 113 29 18 21/33/34 5.9 2 15 15 70 15 82/18 1,2 25.0k 20,69 1,56 1723 9/23/01 14200 9998 10.1 89 25 18 18/31/32 5,8 2 15 15 71 14 84/16 1.3 24,Ok 21.15 1.69 1585 U EPor-q 15 ~-' ""-'" --" UNOCAL8 K-24RD2 SURVEY RECORD " l. ( MD Inti Azim TVD VSec NS EW Closure CIAzim DLS (ft) (O) (O) (ft) (ft) (ft) (ft) (ft) (O) (O /1 DDft) 10700.00 47.62 149.00 7424.94 5288.41 -6081,17 3689.91 7113.09 148.75 --- 1 0852.46 48.00 145.00 7527,35 5374,64 -6175,86 3751.42 7225,96 148.72 1.96 10942,30 47.21 142,50 7587,93 5427,64 -6229.37 3790.64 7292.05 148.68 2.24 11040,10 46,60 139.76 7654,75 5486,58 -6284,96 3835,44 7362,84 148,61 2,14 11134.44 46,70 138,27 7719,52 5544.61 -6336.75 3880,43 7430.48 148.52 1.15 11224,09 45,88 132,61 7781.49 5601.41 -6382,90 3925.85 7493.57 148.41 4,65 11318,86 44,72 129,50 7848, 16 5662,80 -6427,14 3976.62 7557.89 148,25 2.63 11411.47 43,69 126,94 7914,55 5722,88 -6467,09 4027,33 7618,58 148,09 2,23 11504,80 42,00 125,88 7982,98 5782,65 -6504,77 4078.40 7677,59 147.91 1.97 11600,63 42,32 124,75 8054,02 5843,64 -6541,95 4130,88 7737,01 147,73 0,86 11692,79 42.67 120.84 8121,98 5903.46 -6575,65 4183,20 7793.48 147,54 2,89 11784.00 42.31 117.32 8189,25 5963,63 -6605,59 4237,02 7847,69 147,32 2,64 11878,78 40,76 114.11 8260,20 6025,69 -6632,87 4293,61 7901,27 147,08 2,78 11971.09 39.82 107.64 8330.64 6085.16 -6654.15 4349,31 7949.48 148.75 4.64 12065.71 40,56 102,52 8402,95 6146.15 -6670,00 4408,23 7995.09 148,72 3,58 12154,80 39.06 99,13 8471,39 6202,86 -6680,74 4464,23 8035,03 148,68 2,96 12247,53 40,11 96,25 8542.86 6261,19 -6688,63 4522,78 8074,24 145,93 2.28 12340.64 40,56 95,98 8613.83 6320.42 -6695,05 4582,70 8113,25 145,61 0,52 12435,00 40,72 96.29 8685.44 6380,82 -6701.62 4643,81 8153.32 145.28 0,27 12529.24 40.85 96.33 8756,79 6441.35 -6708,38 4704,99 8193.86 144, 96 0,14 12621,70 40,62 95,08 8826,85 6500,56 -6714,38 4765,03 8233.37 144,64 0.92 12717,87 39.69 93.97 8900,36 6561,16 -6719.28 4826.85 8273,28 148,75 1.22 12812.08 39,91 92,23 8972,74 6619,75 -6722,54 4887,06 8311 ,19 148.72 1.21 12901,85 40.74 93,38 9041,18 6676,12 -6725,38 4945,08 8347,73 143,67 1,24 12996.47 41,35 94,30 9112,54 6736,68 -6729,55 5007,07 8387.94 143, 35 0.91 13093.04 41.37 93.83 9185,02 6798,92 -6734,07 5070,72 8429.71 143.02 0,32 13185,05 44.36 94.4 7 9252.45 6859.99 -6738.61 5133.14 8471.01 142.70 3.28 13280,44 44,64 95,05 9320.49 6925.39 -6744,16 5199,77 8515,94 142,37 0.52 13370.07 44.59 96.09 9384,29 6987.14 -6750.27 5262.42 8559.16 142.06 0.82 13463,03 45,05 95,68 9450,23 7051.48 -6756,99 5327,60 8604.66 141,75 0,58 13545,67 44,62 95,55 9508,84 7108,64 -6762,69 5385,59 8645,14 141.47 0,53 13640.18 43.49 97,16 9576,76 7173.27 -6769,95 5450,90 8691.64 141,16 1,68 13733.77 42,83 98,23 9645.03 7236.48 -6778,52 5514,34 8738,21 140,87 1,05 13824,69 41.74 98,70 9712,29 7297,01 -6787,52 5574,84 8783.47 140,60 1.25 13925,32 40,67 98,50 9788,00 7362.63 -6797.44 5640.39 8832,84 140.31 1,07 14016.49 40.17 98,97 9857.41 7421,16 -6806.41 5698,81 8877.15 140.06 0.64 14139.22 39.60 99.45 9951.58 7499,17 -6819.01 5776,50 8936.82 148.75 0.53 14200,00 39,32 99.69 9998.51 7537.49 -6825.43 5814,59 8966.38 148.72 0.52 ( ~ EPO(~H 16 UNOCAL8 K-24RD2 Bit # Size Vendor Type Serial Jets In Out Feet Hrs-On Hrs-Qff Rap WOB GRADE I 0 0 L B G 0 R N U U E A T E T L A G A L R U S I E 0 N N G 1 8% STC MGR35SPX JS5065 10,825 11 ,622 797 40,6 30.4 20,6 25 2 5 8T T X 1/8 LT PR 2 8% SEC FM2841 7970290 11,622 11,758 136 9.1 10,6 13.2 15 8 1 JO N X I RO PR 3 8% HTC JG4 T20FF 11,758 11 760 2 0,5 0 4.0 10 3 3 WT G E I CO BHA 4 8% HTC MXR2000 T510W 11 ,760 12,211 451 26,2 6.8 17,1 35 3 4 8T G E 1/8 CT TQ 5 8% STC MGR68YPX JS6163 12,211 13,083 872 38,7 17,7 22.7 15 7 4 RO N X 1/8 LT BHA 6 8% HTC MX-RS20COOT R7500 13,083 13,520 437 38.0 4.0 11.4 30 7 8% HTC R280S EP4903 13,520 13,907 387 27.3 2.4 13.0 28 8 8% SEC ER6027PS 13,907 14200 293 22.4 2.7 13.1 28 5 6 8T G E 1/8 WT TO BIT RECORD (j EPo'"'q 17 ~ ~ ~ Andrew's Timesheets ( EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-24 RD2 DATE: :rJÆ September 4 2001 DAIL V COST:.J1ill CUM COST: $8575 Report for period Sep 3,01 12:01 AM DEPTH: 10828' YESTERDAY: 10814' 24 HR FTG: 11 ROP (FT/HR): 19 PRESENT: 19 24 HR AVE: n/a CURRENT BIT INFORMATION: NO.: PDM 1 MAKE: SMITH TYPE: MGR35SPX 8,5" DEPTH IN: 10825' Footage Hours On Bottom Off Bottom GRAND TOTAL: 3 ,16 .16 {) VESTERDA V'S TOTAL: 0 0 0 0 PAST 24 HOURS: 0 0 0 0 NO.: 2 MAKE: TYPE~ DEPTH IN~' ( Footage Hours On Bottom Off Bottom GRAND TOTAL: VESTERDA V'S TOTAL: PAST 24 HOURS GAS SUMMARY BACKGROUND GAS: Max: 6 Average: 4 Current: 3 CONNECTION GAS: Max: N/A Average: Current: TRIP GAS: 6 WIPER TRIP GAS: I N/A GROSS LITHOLOGY: COAL: SAND: CONGLOMERATE: COAL INTERVALS: COAL ANTICIPATED: % 30% Sil TSTONE: CLA VSTONE: 30% 20% 20% Lithology De'&criptions~ Bit Type: INTERVAL: I TOTAL: NET ROP WOB MW! GAS Ç1 g Ç! :,:'i," :!/~', g ( BEFORE DURING MAXIMUM AFTER REMARKS: Pull out of hole, work BHA, drop mill, pick up bit. Run in hole, mill window from 10814' to 10825'. Sweep hole, FIT to 11 ppg, check for flow. Pullout of hole, lay down BHA, service rig, pick up new BHA, run in hole. Drill ahead. .~,:' ::t~ , .,. ";. '~ .'>.:'~. .~~ ,- ( EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-24 RD2 DATE: .rug September 5 2001 DAILY COST: .!1I1.2 Report for period Sap 4,01 12:01 AM DEPTH: 11079' YESTERDAY: 10828' 24 HR FTG: ROP (FT/HR): 36 PRESENT: 10 CUM COST: $10290 251' 24 HR AVE: 10.5 CURRENT BIT INFORMATION: NO.:PDM 1 MAKE: SMITH TYPE: MGR35SPX 8,5R DEPTH IN: 10825' Footage Hours On Bottom Off Bottom GRAND TOTAL: 254 24.2 14.5 9,7 YESTERDAY'S TOTAL: 3 ,2 .2 0 ".I PAST 24 HOURS: 251 24,0 14.3 9,7 NO.~ 2 MAKE~ TYPE~ DEPTH IN~ ' Footage Hours On Bottom Off Bottom GRAND TOTAL: YESTERDAY'S TOTAL: PAST 24 HOURS ( GAS SUMMARY BACKGROUND GAS: I I Max: 68 Average: I 15 Current: 55 I CONNECTION GAS: Max: 0 Average: 0 Current: 0 TRIP GAS: N/A WIPER TRIP GAS: I N/A GROSS LITHOLOGY: COAL: SAND: CONGLOMERATE: COAL INTERVALS: COAL ANTfCIPA TED: 10% 40% SIl TSTONE: CLAYSTONE: % % 50% L\thology DescriptioM: Tuffaceous claystone = light to medium browni$h gray; soft to occ moderately hard; matte to rarely slightly shiny luster; smooth to occasionally moderately gritty texture; non to focally slightly calcareous; common carbonaceous specks and streaks; locally common thin streaks of light to medium gray ashy matter. Bit Type: PDC INTERVAL: I TOTAL: NET ROP WOB MWt GAS 9 C2 C3 C4 ç§ ( BEFORE DURING MAXIMUM AFTER REMARKS: Dril1 from 10828. to 11 079~ . ( ", ( ( EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-24 RD2 DATE: IY.S September 6 2001 Report for period Sap 5,01 12:01 AM DEPTH: 11342' ROP (FT/HR): 22.5 CUM COST: $12005 DAILY COST: $1715 YESTERDAY: 11079' PRESENT: 8 24 HR FTG: 269' 24 HR AVE: 11.2 CURRENT BIT INFORMATION: ;~-. NO.: 1 MAKE: SMITH TYPE: MGR35SPX 8,5" DEPTH IN: 10825' Footage Total On Bottom Off Bottom Conn. Hours Hours Hours Minutes GRAND TOTAL: 517' 48,3 28.1 20,2 YESTERDAY'S TOTAL: 251' 24 14,3 9.7 PAST 24 HOURS: 269' 24 ~ 10.5 . 70 Ib(b NO.: 2 MAKE: TYPE: DEPTH IN: ' Footage Total On Bottom Off Bottom Conn. Hours Hours Hours Minutes GRAND TOTAL: YESTERDAY'S TOTAL: PAST 24 HOURS GAS SUMMARY BACKGROUND GAS: Max: 205 Average: 63 Current: 14 CONNECTION GAS: Max: 65 Average: 0 Current: 0 TRIP GAS: N/A WIPER TRIP GAS: I N/A GROSS LITHOLOGY: COAL: SAND: CONGLOMERATE: 20% 10% S'L TSTONE: CLAYSTONE: 0% 20% 50% COAL INTERVALS: COAL ANTIC1P A TED: 11180'-11185',11195'-11205',11220'-11240' 11355' Bit Type: PDC INTERVAL: I TOTAL: NET ROP WOB Mm GAS ~ ~ ~ ~ .ø. BEFORE DURING MAXIMUM AFTER REMARKS: Drill from 11079' to 11342'. ( ( ( EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-24 RD2 DATE: September 7 2001 Report for period Sap 6,01 12:01 AM DEPTH: 11622' ROP (FT/HR): 22.4 .i11.1§ CUM COST: $13720 DAILY COST: YESTERDAY: 11342' PRESENT: 0 24 HR FTG: 280' 24 HRAVE: 11.7 CURRENT BIT INFORMATION: NO.: 1 MAKE: SMITH TYPE: MGR35SPX 8,5" DEPTH IN: 10825' Footage Total On Bottom Off Botto m Conn. Hours Hours Hours Minutes GRAND TOTAL: 797 71 40,6 30.4 YESTERDAY'S TOTAL: 269 24 13,6 10,5 70 PAST 24 HOURS: 280 22,7 12,5 10,2 122 NO.: 2 MAKE: TYPE: DEPTH IN: Footage Total On Bottom Off Bottom Conn, Hours Hours Hours Minutes GRAND TOTAL: YESTERDAY'S TOTAL: PAST 24 HOURS GAS SUMMARY BACKGROUND GAS: Max: 157 Average: 40 Current: 0 CONNECTION GAS: Max: 0 Average: 0 Current: 0 TRIP GAS: N/A WIPER TRIP GAS: I N/A GROSS LITHOLOGY: COAL: SAND: CONGLOMERATE: 20% 30% S'L TSTONE: CLAYSTONE: 0% 20% 30% COAL INTERVALS: COAL ANTICIPATED: 11350'-11375', 11430'-11445', 11535'-11560' 11630' Bit Type: PDC INTERVAL: I TOTAL: NET ROP WOB M.m GAS C1 - C3 - ~ C5 - ~ BEFORE DURING MAXIMUM AFTER REMARKS: Drill from 11342' to 11622', circulate bottoms up, pull out of hole. ( EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-24 RD2 DATE: September 8 2001 Report for period Sep 7,01 12:01 AM DEPTH: 11622' ROP (FT/HR): 0 DAILY COST: .!1lli CUM COST: ~ YESTERDAY: 11622' PRESENT: 0 24 HR FTG: 0' 24 HRAVE: 0 CURRENT BIT INFORMATION: NO.: 1 MAKE: SMITH TYPE: MGR35SPX 8.5u DEPTH IN: 10825' Footage Total On Bottom Off Bottom Conn, Hours Hours Hours Minutes GRAND TOTAL: 797 71 40,6 30,4 YESTERDAY'S TOTAL: PAST 24 HOURS: NO.: 2 MAKE: TYPE: DEPTH IN: 11622' Footage Total On Bottom Off Bottom Conn. Hours Hours Hours Minutes GRAND TOTAL: YESTERDAY'S TOTAL: PAST 24 HOURS ( GAS SUMMARY BACKGROUND GAS: Max: 17 Averaae: 17 Current: 17 CONNECTION GAS: Max: 0 Averaae: 0 Current: 0 TRIP GAS: N/A WIPER TRIP GAS: I N/A GROSS LITHOLOGY: COAL: SAND: CONGLOMERATE: % % S'L TSTONE: CLAYSTONE: % % % COAL INTERVALS: COAL ANTICIPATED: 11630' Bit Type: PDC INTERVAL: I TOTAL: NET BQf WOB .Mm GAS Ç1 a a ~ £§ ( BEFORE DURING MAXIMUM AFTER REMARKS: Pull out of hole, work on rig, pull out of hole, work SHA, test SOPE, cut drilling line, service rig, clean pits RIH, ream from 11474'. ( ( ( EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-24 RD2 DATE: September 92001 Report for period Sep 8,01 12:01 AM DEPTH: 11757' ROP (FT/HR): 14.8 DAILY COST: -11lli CUM COST: Ij7150 YESTERDAY: 11622' PRESENT: 0 24 HR FTG: 135' 24 HRAVE: 5,6 CURRENT BIT INFORMATION: NO.: 1 MAKE: SMITH TYPE: MGR35SPX 8,5" DEPTH IN: 10825' Footage Total On Bottom Off Bottom Conn. Hours Hours Hours M;n\lte$ GRAND TOTAL: 797 71 40.6 30.4 YESTERDAY'S TOTAL: PAST 24 HOURS: NO.: 2 MAKE: SEC TYPE: FM2841 8.5" DEPTH IN: 11622' . Footage Total On Bottom Off Bottom Conn, Hours Hours Hours Minutes GRAND TOTAL: 135 19.7 9,1 10,6 26 YESTERDAY'S TOTAL: 0 0 0 0 0 PAST 24 HOURS 135 19,7 9.1 10,6 26 GAS SUMMARY BACKGROUND GAS: Max: 111 Average: 43 Current: 0 CONNECTION GAS: Max: 0 Average Current: 0 TRIP GAS: 90 WIPER TRIP GAS: I N/A GROSS LITHOLOGY: COAL: SAND: CONGLOMERATE: 10% 40% SIL TSTONE: CLAYSTONE: 10% 10% 30% COAL INTERVALS: COAL ANTICIPATED: 11630' -11640', 11660'-11665' 11760' Bit Type: PDC INTERVAL: I TOTAL: NET ROP WOB MWt GAS Q1 g ~ Q4 ~ BEFORE DURING MAXIMUM AFTER REMARKS: Drill from 11622' to 11757', pull out of hole to check bit and mudmotor. (' EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-24 RD2 DATE: September 10 2001 Report for period Sep 9,01 12:01 AM DEPTH: 11760' ROP (FT/HR): 4 DAILY COST: $1715 CUM COST: $18865 YESTERDAY: 11758' PRESENT: 0 24 HR FTG: 2' 24 HRAVE:.1 CURRENT BIT INFORMATION: NO.: 2 MAKE: SMITH TYPE: MGR35SPX 8.5" DEPTH IN: 10825' Footage Total On Bottom Off Bottom Conn, Hours Hours Hours M;num GRAND TOTAL: 135 19.7 9.1 10,6 26 YESTERDAY'S TOTAL: PAST 24 HOURS: NO.: 3 MAKE: HTC TYPE: JG4 8.5" DEPTH IN: 11758' Footage Total On Bottom Off Bottom Conn. Hours Hours Hours Minutes GRAND TOTAL: 2 ,5 ,5 0 0 YESTERDAY'S TOTAL: 0 0 0 0 0 PAST 24 HOURS 2 ,5 ,5 0 0 GAS SUMMARY ( BACKGROUND GAS: Max: 14 Averaae: 9 Current: 0 CONNECTION GAS: Max: 0 Average Current: 0 TRIP GAS: 63 WIPER TRIP GAS: I N/A GROSS LITHOLOGY: COAL: SAND: CONGLOMERATE: COAL INTERVALS: COAL ANTICIPATED: 10% 40% SIL TSTONE: CLAYSTONE: 10% 10% 30% 11760' Bit Type: INTERVAL: I TOTAL: NET ROP WOB ~ GAS 9 C2 - g ~ g BEFORE DURING MAXIMUM AFTER " REMARKS: POOH, work BHA, SYC rig, wait on tools, pick up BHA, RIH with mill tooth bit and junk baskets, ream 11627' to 11758', cycle pumps, reciprocate pipe, drill 11758' to 11760', cycle pumps, reciprocate pipe, pull out of hole. ( ( ( ( EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-24 RD2 DATE: September 11 2001 Report for period Sep 10,01 12:01 AM DEPTH: 11934~ ROP (FT/HR): 13.8 $20580 DAILY COST: $1715 CUM COST: YESTERDAY: 11760' PRESENT:40 24 HR FTG: 174' 24 HRAVE: 7,3 CURRENT BIT INFORMATION: NO.: 3 MAKE: HTC DEPTH IN: 11758' TYPE: JG4 8,5" Footage Total On Bottom Off Bottom Conn. Hours Houl'$ Hours Minutes GRAND TOTAL: 2 ,5 ,5 0 0 YESTERDAY'S TOTAL: PAST 24 HOURS: NO.: 4 MAKE: HTC TYPE: MXRS20DD 8.5" DEPTH IN: 11760' Footage Total On Bottom Off Bottom Conn. Hours Hours Hours Minutes GRAND TOTAL: 174 14,6 12,6 2.0 16 YESTERDAY'S TOTAL: 0 0 0 0 0 PAST 24 HOURS 174 14,6 12.6 2.0 16 GAS SUMMARY BACKGROUND GAS: Max: 80 Average: 24 Current: 35 CONNECTION GAS: Max: 0 Average Current: 0 TRIP GAS: 84 WIPER TRIP GAS: I N/A GROSS LITHOLOGY: COAL: SAND: CONGLOMERATE: SIt TSTONE: CLAYSTONE: 10% 10% 30% 10% 40% COAL INTERVALS: COAL ANTICIPATED: 11770'-11790', 11815'-11530', 11885'-11890' 11985' Bit Type: INTERVAL: I TOTAL: NET ROP WOB Mm C1 ~ '9 ~ 9 GAS BEFORE DURING MAXIMUM AFTER REMARKS: Run into hole, drill from 11760' to 11934' I UNOCAL -...---. Ll_?ACn ( EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-24 RD2 DATE: September 12 2001 Report for period Sep 11,01 12:01 AM DEPTH: 12211~ ROP (FT/HR): 10.6 DAILY COST: $1715 CUM COST: $22.295 YESTERDAY: 11934' PRESENT: 0 24 HR FTG: 277' 24 HR AVE: 11.5 CURRENT BIT INFORMATION: NO.: 3 MAKE: HTC TYPE: JG4 8.5" DEPTH IN: 11758' Footage Total On Bottom Off Bottom Conn. Hours Hours Hours M;nutes GRAND TOTAL: 2 .5 .5 0 0 YESTERDAY'S TOTAL: PAST 24 HOURS: NO.: 4 MAKE: HTC TYPE: MXRS20DD 8.5" DEPTH IN: 11760' ( Footage Total On Bottom Off Bottom Conn. Hours Hours Hours Minutes GRAND TOTAL: 451 33,0 26,2 6,8 49 YESTERDAY'S TOTAL: 174 14,6 12,6 2,0 16 PAST 24 HOURS 277 18.4 13.6 4,8 33 GAS SUMMARY BACKGROUND GAS: Max: 62 Averaae: 25 Current: 0 CONNECTION GAS: Max: 0 Averaae 0 Current: 0 TRIP GAS: N/A WIPER TRIP GAS: T N/A GROSS LITHOLOGY: COAL: SAND: CONGLOMERATE: 10% 40% SIL TSTONE: CLAYSTONE: 10% 10% 30% COAL INTERVALS: COAL ANTICIPATED: 11960'-11965', 11235'-11255', 12267' Bit Type: INTERVAL: I TOTAL: NET BQf WOB ~ GAS £1 ,g 9 C4 ç§ BEFORE DURING MAXIMUM AFTER ( REMARKS: Run into hole, drill from 11934' TO 12211', circulate, POOH. ( ( ( EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-24 RD2 DATE: September 13 2001 Report for period Sep 12,01 12:01 AM DEPTH: 12559~ ROP (FT/HR): 44.6 .!1ill CAlLY COST: CUM COST: $24.010 YESTERDAY: 12211' PRESENT: 2.0 24 HR FTG: 348' 24 HR AVE: '4.5 CURRENT BIT INFORMATION: NO.: PDM 3 MAKE: HTC TYPE: MXRS20DD 8,5" DEPTH IN: 11760' Footage Total On Bottom Off Bottom Conn. Hours Hours Hours Minutu .GRAND TOTAL: 451 33.0 26,2 6.8 49 YESTERDAY'S TOTAL: PAST 24 HOURS: NO.: PDM 4 MAKE: SMITH TYPE: MGR68YPX 8.5" Footage Total Hours 12,1 0 2.1 DEPTH IN: On Bottom Off Bottom Hours Hours 7.8 4.3 0 0 4, Conn. Minutes 49 0 4 GRAND TOTAL: YESTERDAY'S TOTAL: PAST 24 HOURS 348 0 4 GAS SUMMARY BACKGROUND GAS: Max: 72 Average: 31 Current: 10 CONNECTION GAS: Max: 0 Average 0 Current: 0 TRIP GAS: 99 WIPER TRIP GAS: I N/A GROSS LITHOLOGY: COAL: SAND: CONGLOMERATE: 10% 50% S'L TSTONE: CLAYSTONE: 0% 10% 30% COAL INTERVALS: 12260'-12290', 12355'-12360', 12370'-12380', 12430'-12435', 12445'-12450', 12465'- 12470' 12630' COAL ANTICIPATED: Bit Type: INTERVAL: I TOTAL: NET ROP WOB MWt C3 C5 GAS C1 ~ C4 BEFORE DURING MAXIMUM AFTER REMARKS: Pull out of hole, change bit, run Into hole, drill from 12211' to 12559'. ( ( ( EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-24 RD2 DATE: September 14 2001 Report for period Sep 13, 01 12:01 AM DEPTH: 12151' ROP (FT/HR): 7,5 .!1ill CUM COST: J2572~ DAILY COST: YESTERDAY: 12559' PRESENT: 0 24 HR FTG: 198' 24 HR AVE: 8.3 CURRENT BIT INFORMATION: NO.: PDM 3 MAKE: HTC TYPE: MXRS20DD 8.5" DEPTH IN: 11760' Footage Total On Bottom Off Bottom Conn. Hours HOUT$ HoUT$ Minutes GRAND TOTAL: 451 33.0 26.2 6.8 49 YESTERDAY'S TOTAL: PAST 24 HOURS: NO.: PDM 4 MAKE: SMITH TYPE: MGR68YPX 8.5" DEPTH IN: 12211' Footage Total On Bottom Off Bottom Conn. Hours Hours Hours Minutes GRAND TOTAL: 546 36.1 26.2 9.9 73 YESTERDAY'S TOTAL~ 348 12.1 7.8 4.3 49 PAST 24 HOURS 198 24.0 18,4 5.6 24 GAS SU M MARY BACKGROUND GAS: Max: 76 Average: 30 Current: 45 CONNECTION GAS: Max: 0 Average 0 Current: 0 TRIP GAS: N/A WIPER TRIP GAS: I N/A GROSS LITHOLOGY: COAL: SAND: CONGLOMERATE: 10% 50% SIL TSTONE: CLAYSTONE: 0% 10% 30% COAL INTERVALS: 12660' .12685' COAL ANTICIPATED: .12765' Bit Type: INTERVAL: I TOTAL: NET ROP WOB MWt - - GAS C1 C2 ~ ~ g BEFORE DURING MAXIMUM AFTER REMARKS: Drill from 12559' to 12757', well flowed, shut in well, circulate. (" EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-24 RD2 DATE: September 15 2001 Report for period Sep 14, 01 12:01 AM DEPTH: 13082' ROP (FT/HR): 26.0 DAILY COST: .!!ill CUM COST: ~ YESTERDAY: 12757' PRESENT: 0 24 HR FTG: 325' 24 HR AVE: 13.5 CURRENT BIT INFORMATION: NO.: PDM 3 MAKE: HTC TYPE: MXRS20DD 8.5" DEPTH IN: 11760' Footage Total On Bottom Off Bottom Conn. Hours Hours Hours Minutes GRAND TOTAL: 451 33.0 26.2 6.8 49 YESTERDAY'S TOTAL: PAST 24 HOURS: NO.: PDM 4 MAKE: SMITH TYPE: MGR68YPX 8.5" DEPTH IN: 12211' Footage Total On Bottom Off Bottom Conn. Hours Hours Hours Minutes GRAND TOTAL: 871 56.4 38.7 17.7 140 YESTERDAY'S TOTAL: 198 24.0 18.4 5.6 24 PAST 24 HOURS 325 20.3 12,5 7.8 67 GAS SUMMARY ( BACKGROUND GAS: Max: 84 Average: 40 Current: 0 CONNECTION GAS: Max: 109 Averaae 75 Current: 70 TRIP GAS: N/A WIPER TRIP GAS: T N/A GROSS LITHOLOGY: COAL: SAND: CONGLOMERATE: 10% 50% SIL TSTONE: CLAYSTONE: 0% 10% 30% COAL INTERVALS: COAL ANTICIPATED: 12795' -12800', 12815'-12830', 13005' -13060J ,13160' Bit Type: INTERVAL: I TOTAL: NET ROP WOB MWt GAS Ç1 C2 C3 C4 ç§ BEFORE DURING MAXIMUM AFTER REMARKS: Drill from 12757' to 13082', circulate, pull out of hole. ( ( fh DATE: - Report for period Sep K: 01 12:01 AM DEPTH: 13082' I' ROP (FT/HR): 0 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-24 RD2 DAILY COST: .!1ill CUM COST: ~ YESTERDAY: 13082' PRESENT: 0 24 HR FTG: 0' 24 HRAVE: 0 CURRENT BIT INFORMATION: NO.: PDM 3 MAKE: HTC TYPE: MXRS20DD 8.5" DEPTH IN: 11760' Footage Total On Bottom Off Bottom Conn. Hours Hours Hours M'nutes GRAND TOTAL: 451 33.0 26.2 6.8 49 YESTERDAY'S TOTAL: PAST 24 HOURS: NO.: PDM 4 MAKE: SMITH TYPE: MGR68VPX 8.5" DEPTH IN: 12211' ( Footage Total On Bottom Off Bottom Conn. Hours Hours Hours Minutes GRAND TOTAL: 871 56.4 38.7 17.7 140 YESTERDAY'S TOTAL: 325 20.3 12.5 7.8 87 PAST 24 HOURS 0 0 0 0 0 GAS SUMMARY BACKGROUND GAS: Max: 88 Average: 25 Current: 45 CONNECTION GAS: Max: Nla Average Nla Current: N/a TRIP GAS: NJA WIPER TRIP GAS: I NJA GROSS LITHOLOGY: COAL: SAND: CONGLOMERATE: COAL INTERVALS: 0% 0% SILTSTONE: CLAYSTONE: 0% 00/. 0% COAL ANTICIPATED: .13160' Bit Type: INTERVAL: I TOTAL: NET BQf WOB .Mm GAS £1 g ~ ~ g BEFORE DURING MAXIMUM AFTER ( REMARKS: Pull off bottom, hole not taking fluid, circulate, run into hole, raise mud weight, pull off bottom, hole not taking fluid, run into hole, raise mud weight. ( EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-24 RD2 DATE:~ Report for period Sap 16, 01 12:01 AM DEPTH: 13082' ROP (FT/HR): 0 CAlL V COST: .11ill CUM COST: ~ YESTERDAY: 13082' PRESENT: 0 24 HR FTG: 0' 24 HRAVE: 0 CURRENT BIT INFORMATION: NO.: PDM 3 MAKE: HTC TYPE: MXRS20DD 8.5" DEPTH IN: 11160' Footage Total On Bottom Off Bottom COnn. Hours Hours Hours Minutes GRAND TOTAL: 451 33.0 26.2 6.8 49 YESTERDAY'S TOTAL: PAST 24 HOURS: NO.: PDM 4 MAKE: SMITH TYPE: MGR68YPX 8.5" DEPTH IN: 12211' Footage Total On Bottom Off Bottom Conn. Hours Hours Hours Minutes GRAND TOTAL: 871 56.4 38.7 17.1 140 YESTERDAY~S TOTAL: 0 0 0 0 1) PAST 24 HOURS 0 0 0 0 0 ( GAS SUMMARY BACKGROUND GAS: CONNECTION GAS: TRIP GAS: Max: Max: 550 Current: 15 Current: N/a 550 units 8 12:30 pm 50 units 8:30 GROSS UTHOLOGY: COAL: SAND: CONGLOMERATE: COAL INTERVALS: 0% 0% ail TSTONE: CLA VSTONE: 0% O.k 00/. COAL ANTICIPATED: .13160' Bit Type: INTERVAL: I TOTAL: NET BQf WOB ~ GAS Q1 ~ ~ ~ g BEFORE DURING MAXIMUM AFTER ( REMARKS: Circulate, pull 4 stands wet, pump pill, pull 10 stands, hole not taking fluid, monitor hole. Run 5 stands in hole, monitor hole, pull out of hole wet, hole not taking correct fill. Run in hole to 13062', circulate. Pull 4 stands out of hole, welf swabbing, Run in hole to 13062', circulate, rotate pipe at 140 RPM. Work on top drive generator, circulate, pump out of hole. ( ( ( EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-24 RD2 DATE: ~ Report for period Sep 17, 01 12:01 AM DEPTH: 13082' ROP (FTIHR): 0 ..Ifill CUM COST: ~ DAIL V COST: YESTERDAY: 13082' PRESENT: 0 24 HR FTG: 0' 24 HRAVE: 0 CURRENT BIT INFORMATION: NO.: PDM 3 MAKE: HTC TYPE: MXRS20DD 8.5" DEPTH IN: 11760' Footage Total On Bottom Off Bottom Conn. Hours Hours Ho\n Minutea GRAND TOTAL: 451 33.0 26.2 6.8 49 YESTERDAY'S TOTAL: PAST 24 HOURS: NO.: PDM 4 MAKE: SMITH TYPE: MGR68YPX 8.5" DEPTH IN: 12211' Footage Total On Bottom Off Bottom Conn. Hours Hours Hours Minutes GRAND TOTAL: 871 56.4 38.7 17,7 140 YESTERDAytS TOTAL~ 0 0 0 0 1) PAST 24 HOURS 0 0 0 0 0 GAS SUMMARY BACKGROUND GAS: Max: 50 Average: 25 Current: 0 CONNECT10N GAS: Max: NIA Average N/A Current: N/A TRIP GAS: N/A WIPER TRIP GAS: I N/A GROSS LITHOLOGY: COAL: SAND: CONGLOMERATE: 0% 0.% S\L TSTONE: CLA VSTONE: Q% tWo 0% COAL INTERVALS: COAL ANTICIPATED: .13160' Bit Type: INTERVAL: I TOTAL: NET ROP WOB Mm GAS 9 ~ g ~ g BEFORE DURING MAXIMUM AFTER REMARKS: Pull out of hole, test BOPE, run into hole with new bit. ( EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-24 RD2 DATE: September 19.2001 Report for period Sep 18, 01 12:01 AM DEPTH: 13275' Rap (FT/HR): 12.1 DAll V COST: .l1ill CUM COST: ~ YESTERDAY: 13082' PRESENT: 33.0 24 HR FTG: 193' 24 HR AVE: 8.0 CURRENT BIT INFORMATION: NO: PDM 4 MAKE: SMITH TYPE: MGR88YPX 8.5" DEPTH IN: 12211' FootaGe Total On Bottom Off Bottom COlin. Hours Hours Hours MinutM GRAND TOTAL: 871 56.4 38.7 17.7 140 YESTERDAY'S TOTAL: PAST 24 HOURS: " NO: PDM 5 MAKE: HUGHES TYPE: MX-RS20CDDT 8.5" DEPTH IN: 13082' Footage Total On Bottom Off Bottom Conn. Hours Hours Hours Minutes GRAND TOTAL: 193 18.1 15.9 2.2 32 YESTERDA Y'S TOTAL: 0 0 0 0 0 PAST 24 HOURS 1i3 18.1 15.9 2.2 32 ( GAS SUMMARY BACKGROUND GAS: Max: 73 AveraGe: 34 Current: 24 CONNECT10N GAS: Max: 20 Average 10 Current: 20 TRIP GAS: S80 WIPER TRIP GAS: I N/A GROSS LITHOLOGY: COAL: SAND: CONGLOMERATE: 10% 50% S'L TSTONE: CLA VSTONE: 0% 10% ~% COAL INTERVALS: 13082'-13090', 13165'-13170', 13205'-13210', 13230'-13235' COAL ANTICIPATED: 13310' Bit T.:œe: INTERVAL: I TOTAL: NET ROP WOB MWt - - GAS Q1 g C3 - ~ g BEFORE DURING MAXIMUM AFTER REMARKS: Run in hole, circulate bottoms up, ream to bottom, drill 13082' to ( (' EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-24 RD2 DATE:~ Report for period Sep 19, 01 12:01 AM DEPTH: 13520' ROP (FT/HR): 11.0 CAlL Y COST: .J1Z.1§ CUM COST: ~ YESTERDAY: 13275' PRESENT: 0 24 HR FTG: 245' 24 HR AVE: 10.2 CURRENT BIT INFORMATION: NO: PDM 4 MAKE: SMITH TYPE: MGR68YPX 8.5" DEPTH IN: 12211' Footage Total On Bottom Off Bottom Conn. Hours Hours Hours Minutea GRAND TOTAL: 871 56.4 38.7 17.7 140 YESTERDAY'S TOTAL: PAST 24 HOURS: NO: PDM 5 MAKE: HUGHES TYPE: MX-RS2OCDDT 8.5" DEPTH IN: 13082' Footage Total On Bottom Off Bottom Conn. Hours Hours Hours Minutes GRAND TOTAL: 438 42.1 38.0 4.1 60 YESTERDAY'S TOTAL: 193 18.1 15.9 2.2 32 PAST 24 HOURS 245 24 22.1 1.9 28 ( \ GAS SUMMARY BACKGROUND GAS: Max: 94 Average: 34 Current: 27 CONNECTION GAS: Max: 28 Average 20 Current: 15 TRIP GAS: NIA WIPER TRIP GAS: I N/A GROSS LITHOLOGY: COAL: SAND: CONGLOMERATE: 1J!'10 40% SIL TSTONE: CLAYSTONE: 10% 10% 30% COAL INTERVALS: 13305'-13315', 13355'-13360' COAL ANTICIPATED: 13835' Bit T e: INTERVAL: I TOTAL: NET BQf WOB Mm GAS C1 - ~ C3 - ~ ~ BEFORE DURING MAXIMUM AFTER REMARKS: Drill from 13275' to 13520', circulate. ( ( ( \. ( EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-24 RD2 DATE:~ Report for period Sep 20, 01 12:01 AM Cep:rH:..1359fV ROP (FTIHR): 13.0 .!!ill CUM COST: §37.73..Q DAILY COST: YESTERDA.~:, 135æ~ PRESENT: 17 24 HR FTG: 7.9! 24HRAVE: ~.3 CURRENT BIT INFORMATION: NO: PDM 5 MAKE: HUGHES DEPTH IN: 13082' TYPE: MX-RS20CDDT 8,5'" Footage Total On Bottom Off Bottom Conn. Hours Ho\n HouI$ M\nutu GRAND TOTAL: 438 42.1 38.0 4.1 60 YESTERDAY'S TOTAL: PAST 24 HOURS: NO: PDM 8 MAKE: HUGHES TYPE: R28DS 8.5" DEPTH IN: 13520' Footage Total On Bottom Off Bottom Conn. Hours Hours Hours MlnuUt$ GRAND TOTAL: 79 6.4 6.1 .3 0 YESTERDA Y~S TOTAL: 0 0 0 0 0 PAST 24 HOURS 79 6.4 6.1 .3 0 GAS SUMMARY BACKGROUND GAS: Max: Average: Current: CONNECTION GAS: Max: . Average' Current: . TRIP GAS: 150 WIPER TRIP GAS: I N/A GROSS LITHOLOGY: COAL: SAND: ÇONGLOMt:RA Tt:; COAL INTERVALS: 13530'-13535 10Ø/. 4,2% S'L TSTONE~ CLAYSTONE: 1.2% 1001. 30% COAL ANTICIPATED: 13835' Bit Type: INTERVAL: I TOTAL: NET ROP woe .M.m GAS ~ ~ g a ø. BEFORE DURING . MAXIMUM AFTER REMARKS: Circulate, pull out of hole, run in with new bit, drill from 13520' to 13599'. I t EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K -24 RD2 DATE:~ Report for period Sep 21,01 12:01 AM DEPTH: 13907' ROP (FTIHR):11.3 DAfL Y COST: .I1ill CUM COST: ~ YESTERDAY: 13699' PRESENT: 0 24 HR FTG: 308' 24 HR AVE: 12.8 CURRENT BIT INFORMATION: NO: PDM 5 MAKE: HUGHES TYPE: MX-RS20CDDT 8,5" DEPTH IN: 13082' Footage Total On Bottom Off Bottom Conn. Hours Hours Hours Minutes GRAND TOTAL: 438 42.1 38.0 4.1 60 YESTERDAY'S TOTAL: PAST 24 HOURS: NO: PDM 6 MAKE: HUGHES TYPE: R28DS 8.5" DEPTH IN: 13520' ( Footage Total On Bottom Off Bottom Conn. Hours Hours Hours Minutes GRAND TOTAL: 387 29.7 27.3 2.4 70 YESTERDAY'S TOTAL: 79 6.4 6.1 .3 0 PAST 24 HOURS 308 23.3 21.2 2.1 70 GAS SUMMARY BACKGROUND GAS: Max: 67 Average: 29 Current: 18 CONNECTION GAS: Max: 16 Average 15 Current: 14 TRIP GAS: N/A WIPER TRIP GAS: I N/A GROSS LITHOLOGY: COAL: SAND: CONGLOMERATE: 10010 60% StL TSTONE: CLAYSTONE: 20% 0% 10% COAL INTERVALS: 13825'-13830' COAL ANTICIPATED: Bit Type: INTERVAL: I TOTAL: NET ROP WOB MWt - - GAS ø. ~ 9 £4 Q§ BEFORE DURING MAXIMUM AFTER ( REMARKS:Drili from 13599' to 13907', circulate. ( ~.".~.- - .- /" - EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K -24 RD2 DATE:§ep~m~r~.2~ Report for period $ep 22, 01 12:01 AM DEPTH: 13907' ROP (FT/HR): 0 DAILY COST: ~ CUM COST: WJ§g YESTERDAY: 13907' PRESENT: 0 24 HR FTG: 0' 24 HRAVE: 0 CURRENT 81T INFORMATION: NO: PDM 6 MAKE: HUGHES TYPE: R28DS 8.5" DEPTH IN: 13520' fObtåg4J Total °" BbttoM Off BottoM Conn. Hours Hours Hours M~ GRAND TOTAL: 387 29.7 27.3 2.4 70 YESTERDAY'S TOTAL: PAST 24 HOURS: ' NO: PDM 7 MAKE: SMITH TYPE:ER6027PS 8.5" DEPTH IN: 13907' Footage Total On Bottom Off Bottom Conn. Hours Hours Hours Minutes GRAND tot Äl: YESTERDAY'S TOTAL: PAST 24 HOURS ( GAS SUMMARY BAC)(GROUND t3AS: ' Max: ' Averaae: Current: ' CONNECTION GAS: Max: Averaae Current: TRIP GAS: N/A WIPER TRIP GAS: I NIA GROSS LITHOLOGY: COAL: SAND: CONGLOMERATE: 10% 60% S'L TSTONE: CLAYSTONE: 20% 0010 10% COAL INTERVALS: COAL ANTICIPATED: Bit Type: INTERVAL: I TOTAL: NET ROP WOB MWt - - GAS Ç1 ~ ~ g ~ BEFORE DURING MAXIMUM , AfTER ( REMARKS: Circulate, pull out of hole, change 8HA and bit, pick up logging tools, run into hole. ( EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-24 RD2 DATE: September 24. 2001 Report for period Sep 23, 01 12:01 AM DEPTH: 14158' ROP (FT/HR): 13.1 DAILY COST: ~ CUM COST: ~2.875 YESTERDAY: 13907' PRESENT: 7.0 24 HR FTG: 251' 24 HR AVE: 10.5 CURRENT BIT INFORMATION: NO: PDM 7 MAKE: HUGHES TYPE: R28DS 8.5" DEPTH IN: 135201 Footage Total On Bottom Off Bottom Conn, Hours Hours Hours Minutes GRAND TOTAL: 387 29.7 27,3 2.4 70 YESTERDAY'S TOTAL: PAST 24 HOURS: NO: PDM 8 MAKE: SMITH TYPE: ER6027PS 8.5" DEPTH IN: 13907' Footage Total On Bottom Off Bottom Conn. Hours Hours Hours Minutes GRAND TOTAL: 251 21.2 19.2 2.0 36 YESTERDAY'S TOTAL: 0 1.4(Ream) 0 1.4(Ream) 0 PAST 24 HOURS 251 19.8 19.2 .6 36 ( GAS SUMMARY BACKGROUND GAS: Max: 64 Average: 22 Current: 17 CONNECTION GAS: Max: 10 Average 10 Current: 10 TRIP GAS: 196 WIPER TRIP GAS: I N/A GROSS LITHOLOGY: COAL: SAND: CONGLOMERATE: 10% 60% SIL TSTONE: CLAYSTONE: 20% 0% 10% COAL INTERVALS: 14090'-14095' COAL ANTICIPATED: Bit Type: INTERVAL: I TOTAL: NET ROP WOB Mm GAS ~ g g £4 ~ BEFORE DURING MAXIMUM AFTER ( REMARKS: Run Into hole, ream two stands to bottom, drill from 13907' to 14158'. (" EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. K-24 RD2 DATE: September 25. 2001 Report for period Sep 24, 01 12:01 AM DEPTH: 14200' ROP (FT/HR): 10.8 DAilY COST: ..lli.1§ CUM COST: ~ YESTERDAY: 14158' PRESENT: 0 24 HR FTG: 42' 24 HR AVE: 1.8 CURRENT BIT INFORMATION: NO: PDM 7 MAKE: HUGHES TYPE: R28DS 8,5" DEPTH IN: 13520' Footage Total On Bottom Off Bottom Conn. Hours Hours Hours M\nutes GRAND TOTAL: 387 29.7 27.3 2.4 70 YESTERDAY'S TOTAL: PAST 24 HOURS: NO: PDM 8 MAKE: SMITH TYPE: ER6027PS 8.5" DEPTH IN: 13907' Footage Total On Bottom Off Bottom Conn. Hours Hours Hours Minutes GRAND TOTAL: 293 25.1 22.4 2.7 53 YESTERDAY'S TOTAL: 251 19.8 19.2 .& 3& PAST 24 HOURS 42 3.9 3.2 .7 17 ( GAS SUMMARY BACKGROUND GAS: Max: 24 Average: 2219 Current: CONNECTION GAS: Max: N/a Averaae N/a Current: N/a TRIP GAS: WIPER TRIP GAS: T GROSS LITHOLOGY: COAL: SAND: CONGLOMERATE: 100/0 60% ail TSTONE: CLAYSTONE: 20% 0% 10% COAL INTERVALS: COAL ANTICIPATED: Bit Type: INTERVAL: I TOTAL: NET .BQf WOB .Mm GAS £1 ~ g £4 £§ BEFORE DURING MAXIMUM AFTER ( REMARKS: Drill from 14158' to 14200'. Circulate, pump out of hole for MAD run; pump sweep and circulate; POOH. ( ~~~1fæ (ffi~ &\~~~[\~ ~. ALAS IiA. 0 IL AlWD GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7TH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan R, Williamson Drilling Manager Unocal PO Box 196247 Anchorage AK 99519-6247 Re: Trading Bay Unit K-24RD2 U nocal Permit No: 201-141 Sur Loc: 733' FSL and 133' FEL, SEC, 17, T9N, R13W, SM Btmhole Loc, 817' FNL and 392' FWL, SEC, 27, T9N, R13W, SM Dear Mr, Williamson: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made, Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole, Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607, Sincerely, ch<.Lie., M I ~¿(~/r Julie M, Heusser Commissioner . BY ORDER OF PIE COMMISSION DA TED this '),,7 day of July, 2001 jj c/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ( ( J." /' W t~r/ '.' STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 1 b. Type of well Exploratory Stratigraphic Test Development Oil X Service Development Gas Single Zone Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool 100' RKB above MSL McArthur River Field 6. Property Designation Hemlock and G zone ADL 18730 1 a. Type of work Drill Redrill X Re-entry Deepen 2. Name of Operator Unocal 3. Address P, 0, Box 196247 Anchorage, Ak 99519-6247 4. Location of well at surface 733' FSL and 133' FEL See, 17, T9N, R13W, SM At top of productive interval Hemlock (9330' TVD) 718' FNL and 157' FEL See, 28, T9N, R13W, SM At total depth 817' FNL and 392' FWL, See, 27, T9N, R13W, SM 12. Distance to nearest 13. Distance to nearest well property line 1208' @ 14141' TO 6618' @ TO (G-25) 16. To be completed for deviated wells Kickoff depth 11 000 feet Maximum hole angle 43° 18. Casing oroaram size Specifications Hole CasinQ WeiQht Grade CouplinQ exist 24" exist 18-5/8" 1 01 exist 13-3/8" 72&68 7, Unit or Property Name Trading Bay Unit 8. Well Number K-24RD2 9, Approximate spud date 8/3/01 14. Number of acres in property $200,000 15 Proposed depth (MD and TVD) 14141' MD Lease 3840 acres 9930' TVD 17. Anticipated pressure (see 20 AAC 25.035 (e)(2) Maximum Surface 2064 psig. At total depth (TVD) 3900 psig SettinQ Depth Top Bottom TVD MD TVD 0 330' 330' 0 409' 409' 0 5712' 4166' Butt Butt LenQth 333' 409' 5712' MD 0 0 0 H-40 N-80 K-55 L-80 S-95 8.5" 7" 12.6 L-80 Butt 6241' 7900' 19, To be completed for Redrill, Re-entry and Deepen Operations Present well condition summary Total depth: measured 13908 feet true vertical 9377 feet exist" 9-5/8" 47 Butt 11 000' 0 0 11 000' KOP 14141' 7633' 9930' 11. Type Bond (see 20AAC25.025) AK Statewide Oil & Gas Bond Number U 62-9269 Amount Quantity of cement Driven 548 sx 2412 sx 1050 sx from 11795' 155 sx Plugs (measured) 11000' MD cmt retainer 7994' MD retainer 7633' TVD 5605' TVD Casing Length Size Cemented Structural 330' 24" Driven Conductor 409' 18-5/8" 548 sx Surface 5712' 13-3/8" 2412 sx Intermediate 11795' 9-5/8" 1050 sx Drilling Liner 2026' 7" 600 sx Ported Liner 482' 3-1/2" none Perforation Depth: measured Ported Liner at 13519'13897' MD true vertical Ported Liner at 9333' -9373' TVD 20. Attachments: Filing Fee X Property Plat BOP Sketch X Diverter Sketch Drillina Fluid Proaram X Time vs Depth Plot Refraction analysis Seabed Reoort 21. I hereby ce- tS.Y1rtifY that the foregoing is tr~e and correct to t,pe best of my knowledge r\ A 4 - ]}:;:.. ~ l2.. ú.J~ / It t:L H1. .\""'- .. J I Sianed A..-JO \..M...JZ.. I<:>A- Title: DrillinQ ManaQer Date '7 / ~O / b / () Commission Use Only I Permit Number API Number , Approval date ,(} T í '/1 ) See cover letter .~ D I - I 4{ 50- 73 3-- ;2 Ó "33ð-b2. . / /íA' 1//1 for other requirements Conditions of approval Samples required Yes (1CíG; Mud log requir~es (!j§:f/ I Hydrogen Sulfide measuresY, ,es ,rN'o/ Di~,. ional S"urvey required ~' No Required working pressure for BOP~ 2M M 5M 10M 15M Other: ORIGINAL SIG' 0 BY by order of Approved bv J M ., Commissioner the commission Form 10-401 Rev, 12-1-85 AFE #149281 Effective Depth measured true vertical 13897 9373 feet feet Junk (measured) 5642' Measured Depth 330' 409' 5712' 11795' 13522' 13897' OR! ~1~\fl~I.~- c: 0 'ëjj Cf -- 'E c::;) E c:::> 0 C".J U c::::> cñ~ c: ro 8,g Cf (.) ro c: (9c( oð ð ro ~ Drilling Program X ~ 20AAC25.050 Reauirements X 0 True Vertical DepW 330' > 409' - 4166' W 8002' f , 9335' \oJ 9373' W œ: C'! --1 => J Date 1 k 1~1 -v r Subryt'it in triplicate (' (' Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL8 Dan Williamson Drilling Manager 7/20/01 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Corrected Application for Permit to Drill (Form 10-401) McArthur River Field King Salmon Platform, Well K-24RD2 Commissioner Heusser: Enclosed is a corrected Application for Permit to Drill (Form 10-401) for King Salmon Well #K-24RD2, On July 12, 2001, the original Form 10-401 and accompanying attachments were delivered to you, All of the attachments still apply but I made several mistakes on the form itself in Section #18: "Casing Program Size". Please insert this corrected 10-401 form into the total Application package, The expected spud date for K-24RD2 is August 3, 2001 so your timely consideration for approval is appreciated, If there are any questions, please contact me at 263-7659 and I apologize for the error, Sincerely, -~ ;;~ ¡Jj fl Tim BiII~~ Driling Engineer RECEIVED JUL 2 0 2001 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL AOGCC cover letter K-24RD2 APD corrected,doc Tim Billingsley (' ~V~VŒ (ffi~ !Æ~!Æ~[K\!Æ l ~ 'to) -ILl ( ALAS IiA. 0 IL AND GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 w. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. 80.82A Corrected Administrative Approval Re: The application of Union Oil Company of California, operator of the Trading Bay Unit (TBU), to drill and complete TBU K-24RD2, Shannon W, Martin Land/Legal Analyst UNOCAL Corporation POBox 190247 Anchorage,AJe 99519-0247 Dear Mr, Martin: Your application dated July 12,2001 for a "Pennit to Drill" TBU well K-24RD2 is proposed to recover additional oil from the Hemlock-Middle Kenai G oil pools, The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling and completion of the TBU K-24RD2 well pursuant to Rule 5 of Conservation Order 80, Nunc pro tunc at Anchorage, Alaska and dated July 16, 2001, ~~.Jr Cammy Oechsli Taylor Chair f) ¡;2 ~,M.~ Daniel T, Seamount, Jr, Commissioner Julie M, Heusser Commissioner BY ORDER OF THE COMMISSION . ~1r~1fŒ (ill~ !Æ~~~[(!Æ .- AIA.S IiA 0 IL AND GAS COlVSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. "fTM AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. 80.82 Re: The application of Union Oil Company of California, operator of the Trading Bay Unit (TBU), to drill and complete TBU K-24RD2 well as part of the pressure maintenance project approved by Conservation No, 80, Shannon W, Martin LandlLegal Analyst UNOCAL Corporation POBox 190247 Anchorage, AK 99519-0247 Dear Mr. Martin: Your application dated July 12,2001 for a "Permit to Drill" TBU well K-24RD2 is proposed to recover additional oil from the Hemlock-Middle Kenai G oil pools, The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling and completion of the TBU K-24RD2 well pursuant to Rule 5 of Conservation Order 80, "t~ , Done at Anchorage, Alaska and dated July ~, 2001, ~,~~ C~echSli Taylor Chair Daniel T, Seamount, Jr. Commissioner ~M,~Ý Julie M, Heusser Commissioner BY ORDER OF THE COMMISSION { Unocal Alaska Resou1.... Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage. Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL8 July 12, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Trading Bay Unit McArthur River Field Permit to Drill, K-24RD2, ADL 18730 Request for Administrative Approval to Conservation Order 80 Dear Commissioners: Union Oil Company of California, as Operator of the Trading Bay Unit requests Administrative Approval to drill the McArthur River Field well K-24RD2, Adl 18730, pursuant to Rule 5, Conservation Order 80, The proposed drilling and completion of this well will allow for additional recovery from the Hemlock Oil PooL Enclosed with our Permit to Drill (form 10-401) is Unocal check No. 2004693 in the amount of$100,OO as required by 20 AAC 25,005 (c)(I). The specific location, interval and depth are as follows: Surface Location: 733' FSL, 133' FEL, Sec 17, T9N, R13W SM Top of Productive Interval: 718' FNL, 157' FEL, Sec.28, T9N, R13W SM Total Depth: 817' FNL, 392' FWL, Sec,27, T9N, R13W SM If you should require additional information, please contact the undersigned at (907) 263-7882 or Mr. Tim Billingsley, Drilling Department at 263- 7659, We appreciate your review and trust the enclosed is satisfactory to complete this request. Best regards, ~~; Shannon W, Martin, Esq. Project Landman enclosures ~2€i~- '\ 18731 l A~ Unocal \ Forest Oil VI' A-2~RD ~ I ~ -21 A-a'BA¡DING BAY I _,0 A-27 17594-1,A Unocal Forest Oil K-6 + MC ARTHUR ST, 1 ¡. , " E <> ING B 1 K-13 , , , , , 18772..1 Unocal , ø f! K-7 18772..8 Forest 18730..2 Unocal I 0 1,000 2.000 3,000 Forest Oil 6.,....-...J I --------=--c:I SCALE IN FEET G-9 UIIOCALO ;f l ! Trading Bay Unit ~ King Salmon Platform i ~ Well K..24RD2 ! PROPERTY PLAT ~ ( ( King Salmon K-24RD2 Hazard Analysis for APD 20AAC 25.005 (c) 4 (A) The maximum downhole pressure that may be encountered while drilling K-24RD2 is normal pressure of 8,33 ppg EMW in the G zone, The Hemlock should be slightly depleted, The maximum potential surface pressure based on the unlikely event of full-evacuation with a methane gradient is 2064 psi. (See Maximum Anticipated Surface Pressure attachment) (B) The Hemlock production in the area has an H2S content of up to 400 ppm, Prior to drilling the K-24RD2, a full cascade system and individual SCBA's will be in place, An H2S Safety Technician will service the equipment, conduct drills and refresh crew members in the proper use of the equipment. (C) The proposed redrill will be drilled with an 9,0 to 9,3 ppg oil based mud, The Tyonek interval is expected to be normally to subnormally pressured at 8,4 ppg, The Hemlock is expected to be subnormal pressure at 7,5 ppg EMW. If sloughing coals prove troublesome, the mud weight can be increased to appx 10,0 ppg, A potential for lost circulation exists and adequate supplies of lost circulation material will be on board before drilling commences, APD procedure and Hazard k-24RD2.doc 7/11/2001 ( .(' Procedure Summary of Proposed K-24RD2 Redrill (See Separate Description Summary for K-24RD Proposed Abandonment) 20 MC 25,O05(c) 5, 13 and 14 1 RIH with one-trip whipstock milling assy, (BOPE previously tested to 3000 psi during start of proposed abandonment procedure, weekly test will also be to 3000 psi) 2 Orient and set whipstock on top of abandonment retainer at 11000' MO, 3 Change over from brine to oil based mud, 4 Mill window in 9-5/8" casing at 11000', Drill 20' of new formation, 5 Circ BU and perform Formation Integrity test to 11,0 ppg EMW, 6 POOH with mills, 7 Oirectionally drill 8-1/2" hole from 11000' to 14141' MD. 8 Log with wireline logging tools or LWO tools depending on hole conditions, 9 Run 7" liner from 7900' to 14141' TO, Cement liner with appx 155 sx of 12,0 ppg cement, (see attached Cementing Program), Set ZXP liner top packer, 10 Run 4-1/2" x 3-1/2" tubing with gas lift mandrels and SAB hydraulic packer, 11 Set Packer, 12 NO BOPE, NU tree, 13 Oemob rig, 14 Wireline perforate selected Hemlock and G zone intervals, 15 Place well on gas lift production, The cuttings will be processed through a grinding unit on the King Salmon platform and the oil based mud and processed cuttings will be disposed in K-19 or one of four other annuli at King Salmon, A separate Sundry Application has been submitted for each of the five proposed annuli: K-6RO, K-12RO, K-19, K-25, K-26RO, APD procedure and Hazard k-24RD2.doc 7/11/2001 (' ( King Salmon Well #K-24RD2 Maximum Anticipated Surface Pressure The following presents data used for calculation of anticipated surface pressures (ASP) during drilling of the sidetrack K-24RD2, The pore pressure gradient was estimated from the nearby offset wells in the McArthur River Field: Well BHP Depth Q§l TVD EMW. ppq Comment 3774 8713' 8,33 Original G zone pressure K-24RD 3900 9330' 8.0 Hemlock should be depleted some The fracture gradient at sidetrack window at 11000'MD/7632'TVD is estimated at ,74 psi/ft or 14,2 ppg based on K-8RD (now known as K-26RD) leak off test on 1/25/85, 9-5/8" KOP Casing Pore Setting Fracture Pressure Mud Pore ASP Depth Gradient Gradient Weight Pressure Drilling JTVD ft) {Ibs/qal) Jibs/gal) {Ib/qal) ÍQ§.Ü ÍQ§.Ü 7632 14,2 8,33 9.0 3306 2064 Casing Size .üoJ 7" liner 9930' 14,2 8,0 9,0 3900 Procedure for Calculating Anticipated Surface Pressure While Drillinq ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat (with gas bubble just below shoe and mud gradient above shoe) or 2) formation pore pressure at the next casing point less gas gradient to the surface as follows: For 8-1/2" Hole Section from 7632' TVD to 9930' TVD 1) ASP = (FGx,052xD) - (MWx,052xD) = (14,2 x ,052 x 7632) - (9,0 x ,052 x 7632) = 2064 psi OR 2) ASP = FPP - (0,1 gas gradient xD) = 3900 - (,1 x 9930) = 3900 - 993 = 2907 psi f. (' K-24RD2 Casing Design 20 AAC 25,005 (c) (6) 9-5/8" Production Casinq: 47#, L-80 from 0'-1798' MO, 47# S95 from 1798'-11000' KOP Worst case for burst is the unlikely event of a gas kick while drilling at TO, If the wellbore filled up with gas as described on the Maximum Anticipated Surface Pressure attachment, the maximum surface pressure would be 2064 psi. Burst= 2064 psi 9-5/8" 47# L-80 rated @ 6670 psi for burst Safety Factor = 3.2 OK Worst case for collapse is if lost returns occur while drilling below the 9-5/8" casing. The 9-5/8" casing 47# N-80 is from surface to 1798' MO/1732'TVO, The 9-5/8" casing 47# S-95 is from 1798' MO/1732' TVO to 11000' MO/7633' TVO, Collapse = (8,33 x,052x1798') -(1798' x ,1) = 599 psi for full evacuation Collapse = (8.33 x .052 x 7633')-(7633' x .1) = 2543 psi for full evacuation 47# L-80 rated @ 4750 psi for clpse Safety Factor = 7.9 OK 47# S-95 Rated @ 5080 psi fpr clpse Safety Factor = 2,0 OK Tension = NA (casing already in place and cemented) 7" 29#. L-80, liner from 7900' MO to 14141' MO/9930' TVO Burst: There is no significant burst requirements for a drilling liner. The 7" 29# L-80 liner is rated to 8160 psi which is much more than even the pore pressure of 3900 psi at TO, Worst case for collapse is if full evacuation in the production mode (unlikely), Collapse = (3900 psi reservoir pressure)-(9930' x .1) 29# L-80 Rated @ 7020 psi = 2907 psi for full evacuation Safety Factor = 2.4 OK Tension= (14141 '-7900') x 29#= 181 K Rated = 676K for body yield Safety Factor = 3.7 OK ( i~ King Salmon K-24RD2 Cementing Program 7" Liner 8-1/2" hole TO @ 14141' MO, top of liner at 7900' MO Top of highest hydrocarbon interval= Top of G zone at 12615' MO/8812' TVO Calc TOC for 1000' above highest hydoracarbon interval or 11615', (ZXP liner top packer will isolate liner lap) Cement volume for liner based on open hole volume plus 20%, Estimated volume is: 3600' (14141' - 11615') x 0,1268 cuft/ft (8-1/2" x 7") x 1,20 = 384 cuft Cement will be 12,0 ppg Lite Crete with 2.48 cuft/sk yeild 384 cuft = 155 sx UNOCAL8 Report Date: Client: Field: Structure J Slot: Well: Borehole: UWUAPI#: Survey Name J Date: Tort J AHD J DDI J ERD ratio: Grid Coordinate System: Location Lat/Long: Location Grid NJE YIX: Grid Convergence Angle: Grid Scale Factor: K-24RD2 Proposed Well Profile - Geodetic Report July 10, 2001 Unocal McArthur River Unit King Salmon I K-24 (slot 31) 8 b 8. ity ~:~:RD2 Fea51 I 50-733-20330-02 K-24RD2 (P2) / July 10, 2001 210.875° J 9506.19 ft /6.456/ 0.95i NAD27 Alaska State Planes, Zone 4, US Feel N 60 5156.005, W 15136 21.14f N 2511807.000 flUS, E 213762.000 flUE -1.40278628° 0.99999323 Survey J DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Sea Bed J Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North.) True North: Local Coordinates Referenced To: st..dY Schlumberuer Minimum Curvature / Lubinski 106.850° N 0.000 ft, E 0.000 ft KB 100.0 ft relative to Mean Sea Level 20.782° 55387.667 nT 73.540° August15,2001 BGGM 2001 True North +20.782° Well Head /'"""- - Grid Coordinates Station ID I MD Northing Eating ft ftUS ftUS Tie-In Survey 10900.00 149.00 2505511.39 217374.05 N 60 50 54.893 W 151 355.158 Top of Window 11000.00 149.00 2505449.34 217409.29 N 60 50 54.290 W 151 354.416 Base Whipstock 11016.00 147.13 2505439.45 217415.13 N 60 50 54.194 W 151 35 4.294 KOP 5/100 11029.00 147.13 2505431.39 217420.05 N 60 50 54.116 W 151 354.190 11100.00 142.53 2505388.99 217448.38 N 60 50 53.706 W 151 353.598 11200.00 43.79 135.73 7773.31 5570.32 -6378.91 3888.22 5.00 2505334.87 217492.86 N 60 50 53.183 W 151 352.674 11300.00 42.70 128.61 7846.20 5632.15 -6424.88 3938.90 5.00 2505287.68 217542.40 N 60 50 52.731 W 151 351.652 ~~ 11400.00 42.08 121.24 7920.10 5696.15 -6463.44 3994.08 5.00 2505247.78 217596.62 N 60 50 52.351 W 151 35 0.538 11500.00 41.94 113.77 7994.45 5761.82 -6494.31 4053.35 5.00 2505215.47 217655.12 N 60 50 52,047 W 151 34 59.342 11600.00 42.28 106.33 8068.69 5828.67 -6517.26 4116.25 5.00 2505190.98 217717.43 N 60 50 51.820 W 151 34 58.073 End Crv 11683.63 42.92 100.23 8130.27 5885.10 -6530.23 4171.29 5.00 2505176.67 217772.14 N 60 50 51.692 W 151 34 56.962 Top Hemlock 13322.05 42.92 100.23 9330.00 6993.48 -6728.33 5269.39 0.00 2504951.75 218865.05 N 60 5049.737 W 151 34 34.802 Target 14004.87 42.92 100.23 9830.00 7455.40 -6810.89 5727.03 0.00 2504858.01 219320.53 N 60 50 48.922 W 151 34 25.567 TD 14141.44 42.92 100.23 9930.00 7547.79 -6827.40 5818.56 0.00 2504839.26 219411.63 N 60 5048.759 W 151 34 23.720 Leaal Description: Northina (Y) rftUSl Eastina (XHftUSl Surface: 732 FSL 135 FEL S17 T9N R13W SM 2511807.00 213762.00 Tie-In: 5086 FSL 1661 FEL S28 T9N R13W SM 2505511.39 217374.05 Target: 4480 FSL 4980 FEL S27 T9N R13W SM 2504858.01 219320.53 BHL: 4463 FSL 4888 FEL S27 T9N R13W SM 2504839.26 219411.63 K-24RD2 (P2) report.xls Page 1 of 1 7/10/2001-9:10 AM VERTICAL SECTION VIEW - ã3 > (J) _....J (j) cc (J) (J) '+-lfJ 0 c:: 0 cc I.!) (J) II ~ .~ (J) .,,- > _0 .c::.C! ..... cc 0. ..... (J)'+- 08 -6 ~o .- .,,- t- (J) IJJ >::x:: (J)-+-: :::¡ (J) ~o:: > ..5!2 w Client: Well : Unocal K-24RD2 (P2) Field: Structure: McArthur River Unit King Salmon Section At: 106.85 deg Date: July 10, 2001 7000 To"". SU~'Y 10900 MD 7562 TVD 4583' 14900' az 5402 depart"'" 7500 7633 TVD 7653 TVD 5471 depa,'"," 8000 End C~ 11654 MO 4292' 10023'" 8500 Hold Angle 42.92° 9000 TOp Hemlock 13322 MD 42.92' 100.23' 6993 depart"'e 9500 10000 K-24 10500 5500 6000 6500 7000 7500 Vertical Section Departure at 106.85 deg from (0.0, 0.0). (1 in = 500 feet) s 10 Ta'ge' 14005MD 9B30TVO 4292' 10023' az 7455 depart"'e TD 14141 MO 9930 TVD 42.92' 100.23' az 7548 depa,'"" 2500 -5500 -6000 ^ ^ ^ I I- a:: 0 z -6500 -7000 I I- :::;¡ 0 (f) V v -7500 V -8000 PLAN VIEW Client: well: Unocal K-24RD2 (P2) McArthur River Unit Field: Structure: King Salmon in ~ 500 f1: 10-Jul--200 Scale: Date: 3000 4000 3500 KOP 5/100 11029 MD 7653TVD 46,59' 147,13'" 6284 S 3813 E 3500 4000 «< WEST 4500 5000 End C", 11684MD 8130TVD 42,92- 100.23-.z 6530 S 4171 E HOld Azimuth 100-23° 4500 5000 EAST »> 5500 Schlum nor 6000 -5500 True North Mag Dec ( E 20_78° ) Top Hem'oc' 13322 MD 9330 TVD 42,92" 100.23' az 6728 S 5269 E 5500 -6000 -6500 TO -7000 -7500 -8000 6000 l \ ,65' Top of drill deck A 41/16" 5M Foster HeR Valve B 41/16" 5M Manual gate valve c 31/16" 5M Manual gate Kill line D 31/16" 5M Manual gate Kill line Graylock Hub Top of FMC Type CBS Tubing Head Adapter ~' 14,75' 16.00' 13.00' -I BLOW DOWN TO 10" CROWN VENT ==oJ -- 10 GAS BUSTER 8 TO CHOKE PANEL MANUAL ~/ 1 2 6 7 BLOCK 1 . . SWACO CHOKE SWACO CHOKE 10" TO SHAKER TO BOPE ~ IIMooI ~ ~ C)I a .. IIMIIMt AlASIC4 ItBIIDH MI8I8 - - - CH 0 KE MANIFOLD Unocal PLATFORM RIGS 4-1/16~ 11 3-1/ff', 511 liSP NOTE: SWACO CHOKES EACH HYDRAULICAlLY ACTUATED VIA REMOTE. ~,' " I( Drilling Fluids Program UNOCAL King Salmon Platform Well K-24RD Prepared by: Lee Dewees Reviewed by: Presented to: Tim Billingsly July 12, 2001 M-I Drilling Fluids LLC, 721 West First Avenue Anchorage, Alaska 9950 I (907) 274-5564 (907) 279-6729 Fax ~ DRILLINCi , J,I"/,,,I FLU IDS ~. " ~ Project Summary Well K24RD Casing Size Hole Size Casing Program Depth TVD Existing Mud System Mud Weight Sum Days Cumulative Mud Cost Window @ 11000' 14141 ' Versadrill 8.8-10.0 15 $125,000 9 5/8" 8,5" 8130' 9930' Comple- tion .Key ISSlle oN o. .1 Sloughing Coal Key lsslle .No. 2 .Hole Cleaning ](ey .Issue No.3 Drill Solids Key I~~sue No.4 .Lost Circlilation 14141 ' 9930' Mapco Base Oil 7.4 5 $150,000 . Increase mud weight if required to stabilize coals and well- bore, Unstable well-bore conditions in KIRD2 improved when the mud weight was increase to 10,OPPG, . Maintain sufficient 3 RPM reading in 8 1/2" interval to in- sure adequate hole cleaning, Sweep hole as needed to avoid cuttings buildup, Pump weighted sweeps to aid in hole cleaning, . Run as fme a mesh shaker screen as possible, Run centri- fuge during trips and as required to reduce drill solids in mud, . Follow lost circulation program, Safe Carb and Lowate should be used for seepage losses, . Excessive LCM in cuttings could plug the injection well, M-I Drilling Fluids LLC, 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRILLIN[i FLUIDS ( ( Interval Summary (8,5" hole) Well K24RD '1'10_00'~:_,t4t41t -, ": ',!:' ",(, , ;' ',\'::'"".,'.".' Drilling Fluid System Versadrill Oil Mud Key Products Mapco 200 / Versawet / Versacoat / Versa HRP / VG-69 / Versa- mod / Lime / Calcium Chloride / MI Bar / Ventrol401/Borax Solids Control Shale Shakers / Desilter / Centrifuge Potential Problems Coal sloughing, hole cleaning, drill solids buildup '~:t:"L:~':i:j:':¡ :lntePial:;,Drill:ing',':,;F lij:it;l,':,'Pròper1:Îes'" :,f'r"::>~.;"" .::'J"',,::»:/(,:'?U..,; >;i';:!,X::"',:"",,:,,:,:" "+':'~:<J;',;;:i:;;;;>"~:;::":§/:,;;: ;":" "':',( Mud Plastic Yield HTHP Weight Viscosity Point Fluid Loss (ppg) (cp.) (lb/100ft2) (ml/30min) 8.8-9.2 20 - 25 18 - 22 4 - 5 cc's 9.2-10.0 23-28 18-22 4-5cc's Depth Interval (ft) 11000'-13000' 13000 - 14141 Olw Ratio 85/15 90/10 Gels (lb/100ft2) 15 - 30 20 - 30 . Displace hole to oil based mud. Insure no spacer or oil based mud is discharged. . Set whipstock and mill window. . Drill ahead, maintain low shear rate values with VG-69, Versamod, Versa HRP, and Alcomer 274. . Run centrifuge as needed to reduce solids buildup. . Pump weighted sweeps to aid in hole cleaning. . If sloughing coal or unstable well-bore conditions occur consider increasing mud weight. If no hole problems are encountered mud weights should be kept below 9.2 ppg. . Run 7" liner. Treat cement returns with Borax. M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRilliNG FLUIDS (' ( Interval Summary (8.5" Hole) , .. '" ,", ',' :: \; ::..-;'",....'::'d,-,' , ",LOST,CIRCULATION '-, ' Lost Circulation Recommended LCM Pill Fonnulas Problems Key Products Drilling Fluid / OM Seal / SafeCarb Fine, Medium, Coarse / Versa- HRP . . . Lost, Circulation. .Pill (Slight Losses) . . Volume of Mud (barrels) 30 MIX II Fine SafeCarb Fine (ppb) 10 SafeCarb , Medium (ppb) 10 Versa HRP (ppb) 10 (ppb) 1/4 ", ',., :;,.. ,'....,. ::il1~':~~~~;~ !r~;~!~~~grj~~~~'~~!:~~[~~~~~j~~s~u' ~.~,.~ \¡~; "'...',., :'y i '."" Volume OMB Seal/MIX II SafeCarb SafeCarb Versa HRP Fine of Mud (barrels) 40 Medium (ppb) 15 Coarse (ppb) 10 (ppb) 15 (ppb) 1/2 c(:t ,,: .' ',..'.Lost ê i rcUláti ~"i.f!~ ~~~~f~ ~~~~~~~"(,'. ..~<~ t:r".,;: " Versa I1RP Polymer (ppb) 1 Volume of Mud (barrels) 50 OM Seal SafeCarb Medium (ppb) 20 SafeCarb Coarse (ppb) 30 (ppb) 15 . Versa HRP should be added last, only after all lost circulation material has been mixed. . Ifpossible, spot pill across theft zone. Apply moderate pressure (50 - 100 psi) to squeeze pill into theft zone. (Do not exceed previous E.C.D. of circulation fluid). . Note: Excessive LCM in cuttings to plug injection well. M-I Drilling Fluids LLC. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRilliNG FLUIDS It ( Mixing Pit 10. Suction -Þ- 10. Overboard Mixing Pump 248 Bbls 31 bbls/ft 2.6 bbls/inch 140 Bbls 16 bbls/ft 1.4 bbls/inch 10" Equalizer 172 Bbls 19 bbls/ft 1.6 bbls/inch 248 Bbls 31 bbls/ft 2.6 bbls/inch 10" Equalizer M-I Drilling Fluids LLC. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRILLINI:i FLUIDS :( UNOCALe (I' Trading Bay Unit King Salmon Platform Well # K-24RD Final as run 3/2/01 CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 24" Driven 330' 18-5/8" 101 H-40 33' 409' 13-3/8" 72/68 N80/K55 33' 5712' 9-5/8" 47 L-80 33' 1798' 47 S-95 1798' 11795' 7" 29 L-80 11496' 13522' ( window) Tubing: 2- 7 18" 6.4 L-80 Buttress 296' 7966' 3-1/2" 9.3 L-80 CS Hydril Blank Lnr 13420' 13518' 3-1/2" 9.3 L-80 CS Hydril Ported Lnr 13518' 13897' RKB to TBG Hanger = 32.7' 1 ~ 2 Retainer At 7994' dpm Gas Lift Mandrels: 2-7/8" CamcoSPGLMs @ 11798',12573' Retainer at 11,000' wi apx 200' of cmt on top of retainer 11,536' 3 ~ 11,507' NO. dpm 1 liner 2 top 3 4 4 5 5 6 6 7 7 8 8 9 10 JEWELRY DETAIL Dcpth Item 33.75 4-1/2" FMC 8rd Tbg hgr wlxover to 3-1/2" butt and xover to 2-7/8" buttress 7966' 2- 7 18" mules hoe kill string tubing tail 11536' 13370' 13405' 13444' 2- 7 18" top of fish, folded and corroded Otis 2-7/8" "XA" sleeve Otis 2-7/8" "XN" nipple w/2.205" No-Go Baker 2.992" seals at bottom of tubing 13415' dpm Baker FB-1 perm packer, 2-7/8" x 7" with 3' seal bore extension 3-1/2" CS Hydril blank tubing 3-1/2" CS Hydril ported liner Bottom of 3-1/2" liner 13420' 13518' 13897' . \ . \ , \ " -, -""""'- '-'- '------------------------ PERF ORA TION DATA TOP BTM ZONE SPF DA TE COMMENTS , \ " 9 """"------------------------ TD = 13,908' Hole Angle = 40° @ 13,522' (7" window) Max Hole Angle = 98° @ 13,700' K-24RD schematic final 3-2-01.doc 07/1 010 1 10 Ported liner from 13518' to 13897' (Hemlock) DRAWN BY: TAB f , UNOCAL8 RKB to TBG Hanger = 32.7' ~ SIZE \VT 24" 18-5/8" 101 13-318" 72168 9-5/8" 47 47 29 7" Tubing: 2- 7 18" 6.4 3-1/2" 9.3 3-1/2" 9.3 ( Trading Bay Unit King Salmon Platform Well # K-24RD Proposed Abandon Before Redrill CASING AND TUBING DETAIL GRADE CONN TOP Dri ven H-40 N80/K55 L-80 S-95 L-80 33' 33' 33' 1798' 11496' L-80 Buttress 11536' L-80 L-80 CS Hydril Blank Lnr 13420' CS Hydril Ported Lnr 13518' Gas Lift Mandrels: 2-7/8" Camco SP GLMs @ 11798',12573' Retainer At 11,000' 11,536' NO. Depth Item 3 ~ 11,507' dpm liner top 3 4 5 6 11536' 13370' 13405' 13444 ' 4 5 7 JEWELRY DETAIL 2- 7 18" top of fish, folded and corroded Otis 2-7/8" "X A" sleeve Otis 2-7/8" "XN" nipple w/2.205" No-Go Baker 2.992" seals at bottom of tubing 8 9 10 13420' 13518' 13897' 13415' dpm Baker FB-l perm packer, 2-7/8" x 7" with 3' seal bore extension 3-1/2" CS Hydril blank tubing 3-1/2" CS Hydril ported liner Bottom of 3-1/2" liner 6 7 I \ , \ , \ , , " " ", --------------------------- , \ " 9 ", '----------------------- 10 BOTTOM 330' 409' 5712' 1798 ' 11795' 13522 ' (window) 13444 ' 13518 ' 13897' TOP PERFORATION DATA BTM ZONE SPF DATE COMMENTS TD = 13,908' Hole Angle = 40° @ 13,522' (7" window) Max Hole Angle = 98° @ 13,700' Ported liner from 13518' to 13897' (Hemlock) K-24RD proposed abdn for redrill schematic.doc 07/10101 DRAWN BY: TAB ( ,( Trading Bay Unit King Salmon Platform Well # K-24RD Proposed Redrill, 8/01 CASING AND TUBING DETAIL GRADE CONN TOP Driven UNOCALe RKB to TBG Hanger = 32.80' SIZE WT 24" 18-5/8" 101 13-3/8" 72/68 9-5/8" 47 47 BOTTOM 330' 409' 5712' 1798 ' 10960' (window) 14141 ' H-40 N80/K55 L-80 S-95 33' 33' 33' 1798 ' 1 7" 29 L-80 7900' Tubing: 4-1/2" 12.6 3-1/2" 9.3 L-80 L-80 Buttress Buttress 0' 7850' 7850' 12400 ' Gas Lift Mandrels: 4-1/2" various depths 3-1/2" various depths J J 2 JEWELRY DETAIL 7" liner NO. top @ 1 2 7900' 3 4 5 6 9-5/8" window @ 3 11,000' Depth 295' 7850' 12300' . 12370' 12400' 13444' Item TRSSSV,4-1/2" Xover, 4-1/2" x 3-1/2" buttress Baker SAB 3-1/2' x 7" injection packer 3-1/2" "X" nipple w/2.813" ID Tubing tail Baker 2,992" seals at bottom of tubing 3 4 5 PERFORATION DATA BTM ZONE SPF DATE COMMENTS TOP Appx 300' of G and Hemlock perforations proposed 12615 13630 Appx proposed gross interval TD = 14,141' MD/9930' TVD Max angle = 57° @ 4800' Hole Angle = 43° @ TD' K-24RD proposed redrill schematic.doc 07/12/01 DRAWN BY: TAB ~.. ( Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL8 Dan Williamson Drilling Manager 07/12/01 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Application fro Permit to Drill (Form 10-401) McArthur River Field King Salmon Platform, Well K-24RD2 Commissioner Heusser: Enclosed is an Application for Permit to Drill (Form 10-401) for King Salmon Well #K-24RD2. A separate Sundry Application (Form 10-403) has been sent to you for the proposed abandonment of K-24RD. K-24RD2 will consist of approximately 3100' of 8-1/2" hole drilled with oil based mud. The OBM liquid waste and ground cuttings will be disposed in the 9-5/8" x 13-3/8" annulus of King Salmon K-19. If a problem develops with K-19's annulus, then disposal will switch to K-6rd's annulus. It is expected that K-24RD2 will initially be completed as a gas-lifted producer pending log evaluation. In the near future, K-24RD2 will be converted to water injection to provide pressure support in the east flank of the Main Feature of the McArthur River Field. The expected spud date for K-24RD2 is August 3, 2001 so your timely consideration for approval is appreciated. If there are any questions, please contact Dan Williamson at 263- 7677 or Tim Billingsley at 263-7659. Dan Williamson Drilling Manager RECEIVED JUL 11 2001 Alaska Oil & Gas Cons. Commission Anchorage AOGCC cover letter K-24RD2 APD.doc 0 l"', l ¡-.. 1 f' [ß. ! ~f if-.,. II i.' ' ) t \ ' \~../ : ! ~'~'\ l- Tim Billingsley '. ",:\):\:F~;~~":>:',!,'/"""" FOR 'NO""",:" "",^, "'"[""~\j~'~~~~ (""~...,,..!, ~~- ,~':: ~. ' II I ¡ ~:=~~-4 '0 'I II :':'()';~ ,~ :'8 7 .- . . -"-----'.--.. FOHM 4 .:!U 1B 1 (HE V 11-95) PRINTED IN U.S.A. DETACH STUB BEFORE DEPOSITING CHECK ... . -_t~~~!o 4~~~L~~~~+~-:!~~;; !-- ----g~o::~oo - DISCOUNT__--f NE~:u ~ TOTAL~ 100.00 100.00 CITIBANK DELAWARE A Subsidiary of Citicorp ONE PENN'S WAY NEW CASTLE, DE 19720 62.20 311 ...' -,'.-.....,..,.......,........"........ ""'......-.'-"""'.....--.. ....".,-,.........--..............-.,.--........--.-------------...---"-'----"'-------- 2004693 Union Oil Company of California Accounts Payable Field Disbursing UNOCALi) Pay One Hundred Dollars And 00 Cents* fo the )rder )f STATE OF ALASKA ALASK~! OIL/&GAS' CONSERVATION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE, AK99501 III 200 L, b g :'111 I: 0 j ¡. ¡. 0 0 20 g I: Date Check Amount , *****100.00 12....JUL....Ol , -",. Void after six months from above. date. -', .e -- .'l( - - ~.r¡ ¡. ¡.a¡. ~ 7 III ;{ I~ TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER" WELL NAME ¡¿if J::-ZY ÆI~ CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL V EXPLORATION INJECTION WELL INJECTION WELL REDRILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DISPOSAL <->NO ANNULAR DISPOSAL <-> YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well . Permit No, API No. . Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . .......""""'--"-' ........... .. ". ..........--.-. Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS <-> YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY C/I'/.Äj C-q / WELL NAME?;t FIELD & POOL S'2-0/~(!/.5""2 0/.'5'<:> INIT CLASS (}e..J-" /-ðJ) ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . , 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . , . 7. Sufficient acreage available in drilling unit.. . , . . . . . . . . 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can be issued without administrative approval.. . . . . 13. Can permit be approved before 15-day wait.. . . . . . . . . . 14. Conductor string provided. . . . , . . . . . . . . . . . . . . 15. Surface casing protects all known USDWs. . . , . . . . , . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. , . . . . , . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit., . . . . . . . . , . , . . , . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate wellbore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations. , . . , . . . . . 24. Drilling fluid program schematic & equip list adequate, . . . . 25. BOPEs, do they meet regulation, , . . . . . . . . . . . . . . 26. BOPE press rating appropriate; test to 3 C-Ò û psig. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . , . , . . . . . . . . . . , 30. Permit can be issued w/o hydrogen sulfide measures. , , . . 31. Data presented on potential overpressure zones, . . . . . . 32. Seismic analysis of shallow gas zones, . . . . . . . . . . . . A~f~R gAT~ 33, Seabed condition survey (if off-shore), . . . . . , . . , , . , ~7.,L!4(41 34, Contact name/phone for weekly progress reports [exploratory onl ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . , . , , . (B) will not contaminate. freshwater; or cause drilling waste. " to surface; . ~\J "" iß5to \ (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: ~~~é ~~.WM~()' '89s~ TE~ '71> c;- JMH 9 APPR -P~ T~ ~~/ ENGINEERING APPR DATE \ \ c:\msoffice\wordian\diana\checklist (rev. 11/01/100) t¿J2.. PROGRAM: exp - dev ~ redrll GEOL AREA r- 2-c::J Y N ~ ~ 1 é. c:/, ??o F't"','¿;<,¿ qç C>~h~~~/'~ ~ ~ 7/r" ~-4/ tv ,-;t re..- air $7 if ~ ~ ~tí. ~ ~ y e-~~;/~~ ~ ~~þ AA it U~ 7Ú-:;)d) - RfJ~ YN V Y N Y N Y Y Y N Y N'1 ~ ~\ ~~è~Ld; h's"'\'~~ '>-.:IE. \\ Nj N N N N g-~ 4c~ ë'JN <VN @N él) N '\ (J) N ~~~? 1.t~\'Z'..r-J.j,~~:~"; ~ ~~sa ~~\ '\ \\~ '" ~;, \, \/:7 o~t~ ~N ' ~ ~ ~\ð ~'\ '> \.:..t-C'~'" ~ì" \~\~"'~, ()9 \c. t.{.oo PP~"'I , Y N . , .. Û\),~)~,' ~..~ Y Y serv well bore seg _ann. disposal para req - UNIT# CJ / 2-ö '> t"'\ ON/OFF SHORE ~..r, # c 0 ( Z 0 -4 :E ::0 - -4 m - z -f :I: - en ( » ::a m » Y N Y N ~ "...0 \c.x V ~ ";> 'P ö <:.a '- 't-... ~ \0. I, ",eJ . -I '" 1'" "" P P II-<:> V€.D ~ ¡J "'I.-' {'~,~ ð'- K-.~ f D, ~) 2..9 D ¥-I ") , L~ t'1fL ~,t-..~ . .~,. ~~N~ l-~ 7'tt1~ W~u-. .' - ~\:;:JO) ()ÑlJ..t ð~~ ~y? ~O'\jU") ~t TBi~ 1,Nit. - Comments/Instructions:
