Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
188-028
CEWE • • STATE •OF ALASKA W ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 2 4 2017 la.Well StatuWEL❑L COMPLETION OR Other RE❑COMPLE❑TION Suspended AN t Oil SPLUG Abandoned lb.Well Class: 20AAC 25.105 20AAC 25.110 Development 0 ' Exploratory 0 GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp., or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC band• 12/18/2016 14188-028 / I,.---1-1c(0 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 April 8, 1988 50-733-20088-01-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 736'FSL, 135'FEL,Sec 17,T9N, R13W,SM,AK June 10, 1988 TBU K-06RD Top of Productive Interval: 9. Ref Elevations: KB: 4485" 17. Field/Pool(s): GL:73 BF:52 iZ Z4 McArthur River Field Hemlock Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1147'FNL,2024'FWL,Sec 22,T9N, R13W,SM,AK 8,062'MD/6,324'TVD ADL018772 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 213762 y- 2511799 Zone- 4 13,276'MD/10,070'TVD , N/A TPI: x- y- Zone- 12.SSSV Depth MD/fVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 221157 y- 2509724 Zone- 4 N/A N/A 5. Directional or Inclination Survey: Yes cached) No ❑✓ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 73 (ft MSL) N/A 22. Logs Obtained: 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 1)11-1; t- ."1t, 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 24" Surface 376' Surface 376' Driven 13-3/8" 61# J-55 Surface 2,186' Surface 2,092' 18" 1760 sx 9-5/8" 53#/47# S-95/L-80 Surface 11,958' Surface 9,055' 12-1/4" 1050 sx 7" 29# L-80 11,674' 13,089' 8,805' 9,917' 8-1/2" 1350 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 SIZE DEPTH SET(MD) PACKER SET(MD/TVD) and Number): N/A A6p,1.10ol.MVI 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. '- . `"` " Was hydraulic fracturing used during completion? Yes❑ No ❑✓ 1,2 lia ltG, Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED U- 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 -.♦ Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate — Form 10-407 Revis 11/2015 CONTINUED ON PAG 2 Submit ORIGINIAL only ma sly//7_ c `l ,CONTINUED, /Wu RBDMS 1,V MAR 2 3? 2017 �� • 28.COREDATA Conventional Core(s): Yes ❑ No E Sidewall Cores: es ❑ No ❑� If Yes,list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions, core chips,photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No QQ Permafrost-Top If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports,per 20 AAC 25.071. Formation at total depth: 31. List of Attachments: Wellbore Schematic, 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. Contact: Cody Dinger Email: cdinqer@hilcorp.com Printed Name: Cod Din Title: Drilling Tech Signature: Phone: 777-8389 Date: 3A4 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 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey, and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only H . • McArthur River Field ,H Well:K-06RD Schematic Last Completed:7/25/1988 PTD: 188-028 Hilcurn Alaska,LLC API: 50-733-20088-01 CASING DETAIL RKBtoTBG Hngr=34.00' SIZE WT GRADE CONN TOP BTM. Description i 1- 13-3/8" 61 J-55 BTC Surf 2,186' Casing 9-5/8" 53 S-95 BTC Surf 1,968' Casing 9-5/8" 47 L-80 BTC 1,968' 11,958' Casing TOW8,062' 7" 29 L-80 BTC 11,674' 13,089' Liner TUBING DETAIL 3-1/2" 9.3 L-80 DSS-HTC 9,401' 11,724' IPC Tubing I. CIBP Est.TOC _ 8,085' 8 '858' ,0'111% • --: JEWELRY DETAIL Cement 2 No Depth Depth ID Item Retainer (MD) (TVD) 9,390' / 1 8,085' 6,340' CIBP(Set for Whipstock) 2 9,390' 7,264' Cement Retainer 1 , 3 9,536' 7,359' Camco 3-1/2"MMG2 R-20,RK Latch 4 10,297' 7,866' Camco 3-1/2"MMG2 R-20,RK Latch 7 5 10,843' 8,212' Camco 3-1/2"MMG2 R-20,RK Latch 6 11,173' 8,436' Camco 3-1/2"MMG2 R-20,RK Latch 7 11,444' 8,632' 2.9" Otis straight slot locator w/19.43'seals 8 11,446' 8,634' Otis WD Perm Packer w/seal bore extension 9,400- 7,268'- 9 1-3/4"coil w/2-1/8"PDM and 2-1/8"MHA 8 11,540 8,705' 10 11,690' 8,820' 2.750' Camco"D"nipple - 11 11,724' 8,846' 3-1/2"tubing tail a9 all G I. SOZ PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status BlkSqz 12,060' 12,064' 9,115' 9,118' 4' Blk Sqz 12,650' 12,651' 9,558' 9,558' 1' SOZ Plugged H1 12,754' 12,807' 9,641' 9,684' 53' H2 12,816' 12,874' 9,691' 9,739' 53' B-1 B-2 '4. Fish: -.0,--- i5 s '°,e 13,093'(MD)-Fish lost 6/15/88 during rig operations,consists of the following equipment: BIT,DRILEX, = °' ""`°"-► XO,STB,DC,XO,D-JARS,1 HWDP and UP JARS) TD=13,276'MD PBTD=13,042'MD Max Hole Angle=53° Updated By:CJD 03/24/17 • • Hilcorp Energy Company Composite Report Well Name: MRF K-06RD2 Field: County/State: ,Alaska (LAT/LONG): avation(RKB): API#: Spud Date: Job Name: 1613025P K-06RD2 PreDrill Contractor AFE#: 1613025P AFE$: $981,600 iiMONitlitiTORINNIMMIDERMiliONMINEEMESittitiSiiiiiiiffiliMINNAININESINSTMEMIMBEESSIONN 12/8/2016 No activity on this AFE.,Change out saver sub to CDS-40.Rig up bales and link tilt.Make up Kelly hose(will need to be adjusted).,Rig up hoses to circulate and kill well.Test lines at 250 U1500 H.,Hold PJSM with all to be involved in job. Attempt to circulate.Troubleshoot lines to well head blockage.,K-06RD2 wellhead pressures:24"=42 psi,13 3/8"=0 psi,9 5/8"=0 psi,Tbg=0 psi Daily Code 8:Today= 0 Total: 92.5 12/9/2016 Troubleshoot HP line blockage to well head.Found HP hose plugged w/cmt. chg/out hoses and re-test lines t/250-1500 psi(ok).,Check valve alignment and pump FIW dn tbg and fluid pack well,catch pressure on 9-5/8"w/35 bbls away and open same to pipe line. Staging rate t/5 bpm, circ total 940 bbls w/110 bbls oil cap shut dn and shut in monitor pressures for(1)hr both tbg and annulus on vacuum within 15 min.Re-fill and establish+-11 bph loss rate. Shut dn and shut in monitor to both sides on vacuum blow dn and r/dn circ lines and set,IS type BPV(Good set)also while circ we finished install of Kelly hose and adjustment and check clearance issues.,Nip/dn tree and remove from well room inspect hanger.Appears to be SS threads,good and dress same.(1)LDS has broken tip.Lock open SSSV dress all LDS.Install LH blanking sub.,Install riser.Install choke and kill lines uni-bolt hose.Nipple up BOPE.Set flow box and rotary table and seal same.,K-06RD2 wellhead pressures:24"=42 psi, 13 3/8"=0 psi,9 5/8"=0 psi,Tbg=0 psi Daily Code 8:Today= 0 Total: 92.5 12/10/2016 Open lower rams and inspect(good).Open blind rams and noted damage to seals. Replace blind ram rubbers and reinstall.Install flow box flow line and rotary table.Sealed flow box and table.Set mouse hole.Begin making up 3 1/2"test joint.,Finish making up 3 1/2"test joint.Fill stack and purge air from BOPE.,Test BOPE as per sundry/PTD on 3 1/2" at 250 U3500 H,annular at 250 U2500 H. Tested gas alarms and PVT's(good).,Lay down 3 1/2"test joint and make up 4 1/2"test joint.,Test BOPE with 4 1/2"at 250 U3500 H.Perform accumulator draw down test.All was witnessed by AOGCC(Brian Bixby).Had one F/P on initial test of annular preventer.Worked air out and retested okay.,Pull and lay down 4 1/2"test joint and LH blanking plug.Tubing was on a vacuum.Close blind rams.Assist Tesco with changing out service loop and adjusting top drive torque.Work on sealing rig floor around rotary table.,Blow down boilers,steam and water lines.Assist rig and production electricians with rewiring transfer switch and modification. Rig up return line from annulus to production.,K-06RD2 wellhead pressures:24"=40 psi, 13 3/8"=0 psi,9 5/8"=0 psi,Tbg=0 psi Daily Code 8:Today= 0 Total: 92.5 12/11/2016 Finish installing fiber board on rigs transfer switch and re-lug cables.,Power rig back up. Fire boilers and warm up rig while pulling IS type BPV. Test circulating line to production 250-1500 psi(ok).,Check valve alignment and pump FIW dn tbg and fluid pack well.Catch pressure on 9-5/8"w/50 bbls away and open same to pipe line.Staging rate t/5 BPM. Circ total 632 bbls w/very little oil cap. Shut down,blow dn and r/dn circ line to production.Circulate across top of blinds and warm up HP lines and TDS.Shut down and test rigs HP lines 250-4000psi.,Rig repair.Change out rubber on stand pipe right above stand pipe valve and re-test 250-4000 psi(ok).Blow down mud line.,Chk tbg on vacuum.Open blinds.M/U 4-1/2"landing joint and check annulus.On vacuum.Back out LDS.Pull hanger off seat @ 60k and t/92k w/6'travel.Fill hole w/40 bbls and establish 21 BPH loss rate.Circulate tubing volume at 6 BPM/330 psi.LID pup and valve.,Rig up Pollard.Run#1 with 2.75 GR/JB to 9409'. Run#2 with 2.5"jet cutter.Correlate and make cut at 9390'with 10K over on slips.Saw good indication of cut.POOH.18 BPH loss rate.,Rig down Pollard.R/U Weatherford.Pull and lay down landing joints,tubing hanger and 4 1/2" pup joints.11 BPH loss rate. Pick up weight 70K after cut.,Hold well control drill.Install safety mats around rotary table.Monitor well(1 BPH loss rate). Install wiping rubber.Modify cross-over for lift nubbin for 3 1/2"DSS-HTC.,POOH laying down 3 1/2"DSS-HTC completion string from 9390'to 6900'. Flow check at 8400'.Well is static.,K-06RD2 wellhead pressures:24"=40 psi,13 3/8"=0 psi,9 5/8"=0 psi,Tbg=0 psi Daily Code 8:Today= 0 Total: 73.5(corrected). 12/12/2016 POOH laying down 3-1/2"DSS-HTO gas lift completion strina from 6900'to surface w/1.2 bbls over cal fill. Checking against 1988 run tally.Recovered hanger,(6)pups,SSSV assy,(4)GLM w/handling pups,299 jts&14.77'cut off.OD of pipe good shape.ID of pipe good t/a little over 1/2 way w/no norm detected above background.Then got+-1/16" scale build up and high norm of 60 micro/rim/hr.,Tesco hand observed spooling of drum(ok)and calipered Lebus grooving peaks and valleys and spot calipered drlg line and released Tesco hand to go discuss findings of rig repair w/Kuukpik management.,Clean and clear floor C/O elevators, Udn WATCO equipment.R/U drill pipe spinners.Power wash&scrub rig floor.,P/up two jts 4-1/2"CDS40 16.6#S-135 DP&install 9"ID wear ring.Install standpipe pressure gauge.,Pick up clean out BHA:8 1/2"Bit,casing scraper,bit sub,8 1/2"string mill,bumper sub,oil jars,XO,18 joints HWDP= 594.31. Well control drill 28 seconds.,RI H with clean out assembly picking up 4 1/2"CDS40 16.6# S-135 drill pipe to 2800'.,K-06RD2 wellhead pressures:24"=40 psi,13 3/8"=0 psi,9 5/8"=0 psi,Tbg=0 psi Daily Code 8:Today= 0 Total: 73.5. 12/13/2016 Run in hole with clean out assembly picking up,and drifting 4 1/2"CDS40 16.6# S-135 drill pipe from 2800'to 6038.,Run in hole with clean out assembly picking up,and drifting 4 1/2"CDS40 16.6# S-135 drill pipe from 6038'to 8272'.,Run in hole with clean out assembly picking up,and drifting 4 1/2"CDS40 16.6# S-135 drill pipe from 8272'to 9203',change over to rig power.,Wash down from 9203',tagged tubing stub at 9401'with 10K squat.80K DW,155K UW.,Circulate and reciprocate pipe at 560 GPM and 1550 PSI SPP to clean well bore and check parameters,(10 RPM,TQ 8K, RT/WT 110K),(20 RPM,TQ 8.2K,RT/WT106K),(30 RPM TQ 8.7K,RT/WT 106K),(40 RPM,TQ 9.2K, RT/WT 106K) NOTE:SPM on#1 mud pump fluctuated 5-14 SPM while moving blocks,SPP fluctuated 175 PSI. Circulated a total of 2 bottoms up had dirty water coming back with very little to no solids.,Lay down single,blow down top drive,trip out of hole with casing scraper assembly from 9371'to 8707,UW 150K.,Continue to trip out of hole with casing scraper assembly from 8707'to 7311',noticed vibration and shaking while tripping out,found drilling line was flattened with broken strands were line goes through drum at kick plate.,Cut and slip 90'of drilling line.,Rig service,inspect draw works bolts,drum,hydraulic motors,top drive,lube and check oils.,Continue to trip out of hole with casing scraper assembly from 7311'to 4678'inspecting drilling line every 15 stands.,K-06RD2 wellhead pressures:24"=40 psi,13 3/8"=0 psi,9 5/8"=0 psi,Tbg= 0 psi Daily Code 8:Today= 0 Total: 73.5. • • f 12/14/2016 Continue to trip out of hole with casing scraper assembly from 4678'to BHA,inspecting drilling line every 15 stands.,Rack back 9 stands of HWDP and lay down mill,scraper,and bit,inspecting all. Calculated hole fill 61.1 BBL,actual 64.0.,Open blinds after laying down BHA,noticed fluid fall+-3',then started ballooning back. First 20 minutes had a.5 BPH flow rate,tapering off to static,then back to slight loss rate.,Finish making up safety joint for wire line lubricator, rigged up E-line and run in hole with 8.125"Weatherford cement retainer. Tied in with E-line verifying collar locations,tag tubing stub,picked up 5 and set top of cement retainer at 9386'WLM.had good indication of set,pick up logging,and set back down to confirm set.,Pull out of hole,and log up from 8300'to 7900' for tie in and set of bridge plug,for whip stock anchor. Rig down Pollard E-line.,Change out elevators to 3.5",and rig up Weatherford power tongs.,Rig service, lube block,crown,top drive and drawworks.,Pre job safety meeting on,picking up stinger and making up BHA.,Pick up 30 joints of 3.5"tubing while strapping and drifting same.,Rig down Weatherford tongs,change out elevators to 4.5"drill pipe.,Trip in hole with cement stinger on 4 1/2"drill pipe from 931'to 5544'. Driller stopped block to quickly and backlashed drilling line.,Rig Repair: Hang blocks and straighten drilling line,then found a nut on the rig floor,after investigation found where it had backed out of make up tong ram,reinstalled with Lock-Tite. Attempt to move pipe and found hydraulic leak on valve bank kiv under draw works(leaking plug)tighten same and resume operations.,Trip in hole with cement stinger on 4 1/2"drill pipe from 5544'and tagged top of retainer `- at 9390 drill pipe measurement.,Rigged up and performed injectivity test,with FIW initial rate of 30 GPM,walking pressure up to 780 PSI where it broke over and we were able to inject at 30 GPM at 711 PSI,increased rate to 44 GPM and walked pressure up to 1500 PSI,shut down pumps and recorded pressure (1), drop. 15 SEC=1155 PSI,30 SEC=1099 PSI,45 SEC=885 PSI,1 MIN=800 PSI,2 MIN=538 PSI,3 MIN=534 PSI,4 MIN=524 PSI,5 MIN=512 PSI..Unacceptable injection rate.will proceed with balanced cement abandonmen plua..K-06RD2 wellhead pressures:24"=45 psi, 13 3/8"=0 psi,9 5/8"=0 psi,Tbg=0 psi Daily Code 8:Today= 1 Total: 74.5. 12/15/2016 Clean and clear rig floor,rig up Schlumberger cementers running high pressure treatment and water hoses,staged squeeze manifold on rig floor and plumbed up same with overboard line going to slop tank.,PJSM with all personnel involved in cement job. Blew air through lines going from rig to cement unit,found ice plugs in water lines and at cement mix hopper valves,rigged up jet heater to thaw lines. Flush cement lines with 10 BBL of fresh water taking returns to slop tank. Fluid pack all lines going up to pump in sub,pressure test lines 900 low and 3200 PSI high. Pumped 19.5 BBLS fresh water down hole at 5 BPM.,Batch up verify density with mud scales and found density meter on unit reading.4 PPG low,compensated by having cementers mix at 16.2 PPG reading on their density meter.Mix and pump 40 BBLS 15.8 PPG type"G"(193 sacks with a yield of 1.16)balanced cement plug,at 2.5 BPM with D046 antifoam.2%BWOC,D065 dispersant 03%BWOC,D255 fluid loss 05%BWOC,D177 retarder.03%BWOC,pumped 5 BBLS fresh water„changed over to rig pump and displaced with 109 BBLS FIW at 6.3 BPM caught pressure at 30 BBLS away. CIP @ 13:00 HRS estimate top of cement at 8858'. 70 BC= 05:26 HR:MN,100 BC=05:31 HR:MN.,Blow down and rig down circulating equipment,pull out of hole from 9390'to 8513'at 5 minutes per stand until out of cement,drop pipe wiper ball and circulate a surface to surface volume at 10 BPM 900 PSI. Note no cement seen at surface.,Pre job safety meeting on slip and cut drilling line. Slip and cut 350'of line and remove from rig floor.Quadco representative on board testing and certifying accumulator gauges.,Breakdown cementing assembly,trip out of hole from 8513'to 4243'standing back 4 1/2”CDS40 drill pipe in derrick.Calculated displacement 27.73 BBL,actual displacement 27.39 BBL.,Continue to trip out of hole from 4243'to 931'standing back 4 1/2"CDS40 drill pipe in derrick.Calculated displacement 49.41 BBL, actual displacement 49.05 BBL.,Change elevators from 4 1/2"drill pipe,to 3 1/2"YT,rig up Weatherford tongs, pull 931'of 3 1/2"tubing/cement stinger and lay down same,rig down Weatherford tongs,and change elevators back to 4 1/2"drill pipe.,Pull wear bushing.,Begin 9 5/8"casing test to 2500 PSI.,K-06RD2 wellhead pressures:24"=45 psi, 13 3/8"=0 psi,9 5/8"=0 psi,Tbg=0 psi Daily Code 8:Today= 0 Total: 74.5. 12/16/2016 Complete 30 minute,9 5/8"casing test to 2500 PSI all good blow down choke,and mud lines. Note:pressured to 2650 PSI pressure fell 50PSI in 30 minutes, with the last 20 straight line.,Rig up Pollard E-line,run in hole with 8.125"Weatherford CIBP,logged up from 8246'to 8015'looking for adequate formation behind casing to mill window(no coal). Set CIBP at 8085.5 WLM,(dirty sand formation behind casing),logged up and set back down to verify set,pull out of hole with Baker 20 setting tool,lost line weight at 1204'pulled out of hole and found line parted at weak point of rope socket.,Mobilize slick line unit from Steelhead,along with crew from the beach via the boat. While waiting on slick line clean and organize rig keep up with housekeeping,service top drive,blocks, ? draw works,fuel rig,run hoses to displace well over to OBM.,Pre job safety meeting with all parties,rig up Pollard slick line. Run#1: Run in hole with 1.25" \`J JDC pulling tool,with a 4.5:bell guide set down to 8100'WLM, picked up had additional weight indicating tool engagement,pulled out of hole to 8065'WLM clost weight. Run in hole tagging tools and picking up without tool engagement,several times. Trip out of hole with JDC pulling tool and found it sheared.,Redress JDC pulling tool with new shear pins. Run#2:Run in hole to 8100'engaged Baker 20 setting tool picked up had additional 450 LBS,pull out of hole,had full recovery,laid down tools and rigged down wire line.,Picked up 8.5"Baker window mill,lower string mill,flex joint,upper string mill,cross over, and 1 joint of HWDP. Picked up assembly and made up whip stock slide on bottom with 47K shear bolt,verified shipping bolt was removed and that 3 shear pins were installed with a shear value of 19890#,scribed back in hole and made up XO float sub and MWD.,Sperry plugged into MWD and uploaded,made up cross over and run in hole on 4 stands of HWDP to 335'and shallow tested MWD,all good,continue to run in hole with HWDP to 634'.,Trip in hole with whip stock and window mill assembly on CDS40 drill pipe from 634'3000',at 50-60'per minute.,K-06RD2 wellhead pressures:24"=45 psi,13 3/8"=0 psi,9 5/8"= 0 psi,Tbg=0 psi Daily Code 8:Today= 0 Total: 74.5. 12/17/2016 Continue trip in hole with whipstock and window mill assembly on CDS40 drill pipe from 3000'to 7968',at 50-60'per minute.,Kelly up fill pipe break circulation e ablish parameters and tool face, UW 132K,DW 79K,360 GPM,850 PSI. Wash down from 7968',position tool face at 46R,slack off and started taking eight at 8084'DPM set down 20K weight,had good indication of anchor set. Shut down pump,and pull 10K over string weight,to verify anchor set,set down 30K to shear bolt attaching window mill to whipstock.,Pick up and pull out of hole rack back 3 stands with 6K loss in string weight.NOTE:Top of 11 \5 whipstock at 8062.72',orientated at 46 right of high side and INC 42 degrees.,Blow down circulating Iines.,Make up test plug on CDS40 drill pipe,drain stack, and set test plug.,Make up test joint to include all floor valves,cross overs,and pump in sub.,Function test BOPE and work air out of system.,BOPE test:Test #1 Annular on 4 1/2"pipe,dart valve,Demco/kill,CMV 7,14,15,16,250-2500 PSI. Test#2 Upper VBR on 4 1/2"pipe,dart valve, Demco/kill,CMV 7,14,15,16,250-3500 PSI. Test#3 Upper VBR on 4 1/2"pipe,FOSV,outside kill,CMV 4,5,6,11,250-3500 PSI. Test#4 Upper VBR on 4 1/2"pipe,FOSV, hydraulic IBOP,inside kill,CMV 3,10,13,250-3500 PSI.,Test#5 Upper VBR on 4 1/2"pipe,FOSV,inside kill,CMV 2,9,12,250-3500 PSI. Had a fail/pass due to a leaking grease fitting on CMV 14 tighten and retest,on test 6. Test#6 Upper VBR on 4 1/2"pipe, FOSV,inside kill,CMV 2,9,12,250-3500 PSI. Test #7 Upper VBR on 4 1/2"pipe, FOSV,inside kill,CMV 1,8,manual IBOP,250-3500 PSI. Test#8 Upper VBR on 4 1/2"pipe,FOSV,inside kill,HCR/choke, 250-3500 PSI.,Test#9 Upper VBR on 4 1/2"pipe, FOSV,inside kill,manual/choke,250-3500 PSI. Test#10 Lower VBR on 4 1/2"pipe,FOSV,250-3500 PSI. Test#11 Blind rams,inside kill,CMV 1,12,8,250-3500 PSI. Test#12 Hydraulic choke function pressured up to 1500 PSI held 5 minutes,bled pressure to 900 PSI held for 5 minutes.,Test#13 manual choke function pressured up to 1500 PSI held 5 minutes,bled pressure to 1200 PSI held for 5 minutes.,Perform accumulator drawdown test: Starting pressures,Manifold=1550 PSI,Accumulator=3040 PSI,Drawdown pressures,Manifold=1500,Accumulator=1650 PSI. 200 PSI recovery=19 seconds,Full recovery 3040 PSI=96 seconds,4-N2 bottles=2500 PSI average.,Break down and lay down test joint,cross overs and floor valves.,Close blind rams,pull rotary table,disconnect hole fill/jet line,remove flow line and pull flow box,weld splash guards on flow box,reposition lifting d-rings, clean around drip pan,rotary beams and rotary table. Silicone and install new rubber seals on top of rotary beams,flow box and floor plates then installed rotary table. Connect fill lines,and flow lines coming off flow box,seal and install floor plate.,Set and install rotary table mats,and install drill pipe elevators.,Screw landing joint into test plug,and pull to rotary,break off landing joint and test plug laying test plug down,BOP test witness waived by Jim Regg.,K-06RD2 wellhead pressures:24"=45 psi,13 3/8"=0 psi,9 5/8"=0 psi,Tbg=0 psi Daily Code 8:Today= 0 Total: 74.5. • . 12/18/2016 After pulling test plug,flood BOP and test air boot on riser and flow line,run in hole to 8049'.,Rig repair,adjust HPU's troubleshooting mud pump#1 SPM variation.,Establish drilling parameters in water for comparison when changed over to OBM,UW 134K, DW 79K,with#1 mud pump on 285 GPM rate,300 PSI, UW 130K, DW 82K ROT 101K,TQ 7500 @ 66 RPM.,Pre job safety meeting with all personnel involved in displacement. Pump 19 BBL OBM spacer, begin displacement of FIW to 9 PPG OBM,taking returns to active system using pump#2. Pump FIW returns to TBPF via pipeline with pump#1 at 4 BPM rate,total pump 580 BBL. Minimal interface when displacement completed.,Clean pits,rig down hose from mud pump#1 to production pipe line,remove pancake bind from suction line of mud pumps,work on HPU changing out sequence valve and adjust same,transfer OBM from ISO tanks to active and upright tanks on deck,set drilling torque on top drive to 16K,service drawworks,top drive,and blocks,change out liner wash fluid from water to base oil.,Establish drilling parameters with OBM, UW 116K,DW 87K,with#1 mud pump on 285 GPM rate,2710 PSI,UW 117K, DW 90K ROT 98K,TQ 5500 @ 58RPM.,Wash dr un and fa0 tnp of whipstnrk at RC)R7 hpgin milling window at 450 GPM 2200 PSI,90 RPM,6-8K TQ to 8074'.,Mill window with Baker window mill,from 8074'to 8079'+20'to 8099'at 420 GPM,1830 PSI,6-8 TQ.,K-06RD2 wellhead pressures:24"=45 psi,13 3/8"=0 psi,9 5/8"=0 psi,Tbg =0psi y,I Daily Code 8:Today= 1 Total: 75.5. LL et)1 ALD • • • • P�or ?lit Alaska Oil and Gas ��--,., j,�e9 THE STATE F _i A o f e T a Conservation Commission ,.._.,„0,:____T.or1ZLr1s��\1 1 s#114i 333 West Seventh Avenue i.1.1 . •.- t GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 w� Main: 907.279.1433 O• 3 uo.rp Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis S QED FEB 1 ac17 Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil Pool, TBU K-06RD Permit to Drill Number: 188-028 Sundry Number: 316-490 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, U C& Cathy . Foerster Chair DATED this 2 day of September, 2016. RBDMS L L. cro ? 9 2016 • r STATE OF ALASKA SEP 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill 0' Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0 • 188-028 , 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20088-01 e 7.If perforating: 8.Weil Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 i Trading Bay Unit K-O6RD ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018772 ' McArthur River Field/Hemlock Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13,276 • 10,070 ` 13,042 , • 9,879 2,738 psi NA 9,400 Casing Length Size MD TVD Burst Collapse Structural Conductor 376' 24" 376' 376' Surface 2,186' 13-3/8" 2,186' 2,092' 3,090 psi 1,540 psi Intermediate Production 11,958' 9-5/8" 11,958' 9,055' 6,870 psi 4,760 psi Liner 1,415' 7" 13,089' 9,917' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12,754-12,874 • 9,641 -9,739 3-1/2" 9.3#/L-80 11,724 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Otis WD Packer&Camco TRD1-A SSSV 11,446'(MD)8,634'(ND)and 291'(MD)291'(TVD) 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 11/1/2016 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ J / 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarlowe©hilcorp.com Printed NameStan W.Golis\ Title Operations Manager Signature ��'t+v.w Phone (907)777-8356 Date ct 12. I 6 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Numb s,' n — C) Plug Integrity 0 BOP Test E Mechanical Integrity Test ❑ Location Clearance ❑ Other: '7;25 ."i�,_J-- `} Z o AA-c- Z:j I/7 /Z C�� Post Initial Injection MIT Req'd? Yes ❑ No ❑ / '.2-1 , II Spacing Exception Required? Yes EI No Ld Subsequent Form Required: h — /1 1. (�� �(� (✓ RBDMS L 'D 2 9 2016 APPROVED BY Approved by: ,9144.04•••—.. 4 COMMISSIONER /� THE COMMISSION Date: 9-?j�f //„ ep SlItv A ,/ Subs in Form ane Form 10-403 Revised 11/2015 ' Ail d for 12 months from the date of approval. Attachments in Duplicate i • Well Work Prognosis Well: K-06rd Hileorp Alaska,LELPTD: 188-028 Date: 09/23/2016 Well Name: K-06rd API Number: 50-733-20088-01 Current Status: Shut-in Gas Lift Producer Leg: Leg#4 (NW corner) Estimated Start Date: November 01, 2016 Rig: Kuukpik#5 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: _ Juanita Lovett (8332) Permit to Drill Number: 188-028 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: 3,600 psi @ 9,450'TVD 0.387 lbs/ft(7.35 ppg)estimated based on offset wells Maximum Expected BHP: 3,692 psi @ 9,534'TVD) 0.387 lbs/ft(7.35 ppg) Maximum Potential Surface Pressure:2,738 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Shut-in Tubing Pressure: 60 psi Shut-in Casing Pressure: 250 psi Brief Well Summary K-06rd is a shut-in Gas lifted Hemlock only producer. This workover will pull the current completion and plug the well for a sidetrack per 20AAC25.112(c)(1). Last Casing Test: N/A Procedure: 1. Skid Rig into position above K-06rd 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 open gas lift mandrel at 8,519'—Workover fluids will be_FIW. c7T ppb ._— 1 - -Q �- F4-A-10+5 Z-,' • 4. Pull and fish current completion to±9,400' (top of coil tubing fish). - 5. RIH with bit and scraper to ±9,400', circulate clean. POOH. 6. RIH with cement retainer and sgt at.+9,4.0.0'..__ • We request a. er'to 20AAC25.112(c)(1)to set the retainer>500'above top perforation. 7. RIH and sting into cement retainer. L' 8. RU cementing equipment and establish an injection rate with FIW. • If able to pump into well- Mix and pump±215 arrels cement to isolate existing completion. Un-sting from retainer and circulate hole clean. • If unable to pump into well unsting from retainer and spot±40 bbls on top of the retainer. 9. POOH 10. Pressure Test casing to 1,500 psig for 30 minutes and chart. ,, s ,v373 X3131/Fr 11. RU e-line and RIH w/CIBP to ±8,600', ±5' above casing connection. 12. RD a-line. sc• 13. PU whipstock and mills and RIH to CIBP. 14. Orient and set whipstock. �� c7� ***Remaining Procedure to be included on the Permit to Drill Sundry for the sidetrack*** 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. (onc)r, well f ,1e+.er q S7ro^d produce, old uiGcw 14 ft— Cn re, vlq.- /coAl/44 produce n' 100 &)/'°' Girl q 15i% wgry CUf aro( ce (3CQ Fir ie 7`,'AP), �+ r er 7-"A 4',7 7' C v/rs'° °6461' c Goi 712' 7 cfro� P���f�i` eke (.'-cil /,r lelli-/� 114071av�d q/�0w f Ur 1�W 7 • • Well Work Prognosis Well: K-06rd ni�ak�, Hileorp LEAPTD: 188-028 Date: 09/23/2016 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 0 McArthur RiverK-06RD Field . 11 W SCHEMATIC Last Completed:7/25/1988 PTD: 88 Hilcurp Alaska,LLC API: 50-733-20088-01 CASING DETAIL RKB to TBG Hngr=34.00' SIZE WT GRADE CONN TOP BTM. Description i 140. 1 13-3/8" 61 1-55 BTC Surf 2,186' Casing 9-5/8" 53 S-95 BTC Surf 1,968' Casing 9-5/8" 47 L-80 BTC 1,968' 11,958' Casing 7" 29 L-80 BTC 11,674' 13,089' Liner TUBING DETAIL ., ill 3-1/2" 9.3 L-80 DSS-HTC Surf 11,724' IPC Tubing II I. III III JEWELRY DETAIL ' Depth Depth f"f -2No ID Item (MD) (TVD) I 1 291' 291' 2.812" Camco TRPD1-A SSSV nipple I2,591' 2,466' Camco 3-1/2"MMG2 R-20,RK Latch 3,063' 2,846' Camco 3-1/2"MMG2 R-20,RK Latch 2 7,130' 5,654' Camco 3-1/2"MMG2 R-20,RK Latch 3 4 C..i8,519' 6,668' Camco 3-1/2"MMG2 R-20,RK Latch r. 9,536' 7,359' Camco 3-1/2"MMG2 R-20,RK Latch �5 10,297' 7,866' Camco 3-1/2"MMG2 R-20,RK Latch 10,843' 8,212' Camco 3-1/2"MMG2 R-20,RK Latch a ( 11,173' 8,436' Camco 3-1/2"MMG2 R-20,RK Latch 5 3 11,444' 8,632' 2.9" Otis straight slot locator w/19.43'seals za 4 11,446' 8,634' Otis WD Perm Packer w/seal bore extension `° a' `- t 9,400- 7,268'- C%5 ti k S 11,540 8,705' 1-3/4"coil w/2-1/8"PDM and 2-1/8"MHA -$ I 6 7 6 11,690' 8,820' 2.750' Camco"D"nipple L , 7 11,724' 8,846' 3-1/2"tubing tail PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status Block Sqz 12,060' 12,064' 9,115' 9,118' 4' Squeezed Block Sqz 12,650' 12,651' 9,558' 9,558' 1' Squeezed I SQZ HK-1 12,754' 12,807' 9,641' 9,684' 53' Open HK-2 12,816' 12,874' 9,691' 9,739' 53' Open HK-1 HK-2 AML 5413 Fish: • 13,093'(MD)-Fish lost 6/15/88 during rig operations,consists of the following equipment: BIT,DRILEX, L , XO,STB,DC,XO,D-JARS,1 HWDP and UP JARS) TD=13,276'MD PBTD 13,042'MD Max Hole Angle=53° Updated By:1LL 07/26/16 . McArthurll:K-06RD River Field . iii We PROPOSED Last Completed:7/25/1988 PTD:188-028 Hilcora Alaska,LLC API: 50-733-20088-01 CASING DETAIL RKBtoTBG Hngr=34.00' SIZE WT GRADE CONN TOP BTM. Description 13-3/8" 61 J-55 BTC Surf 2,186' Casing 9-5/8" 53 S-95 BTC Surf 1,968' Casing 9-5/8" 47 L-80 BTC 1,968' 11,958' Casing 7" 29 L-80 BTC 11,674' 13,089' Liner TUBING DETAIL 3-1/2" 9.3 L-80 DSS-HTC ±9,400' 11,724' IPC Tubing CIBP ±8,600 1 JEWELRY DETAIL Cement AO 2 No Depth Depth ID Item Retainer W*+� ' (MD) (ND) ±9,40fy .. i 1 ; 3, 1 ±8,600' ±6,729' CIBP(Set for Whipstock) di '4 ;._14111 � 2 ±9,400' ±7,268' Cement Retainer "' 5 �' 6 3 9,536' 7,359' Camco 3-1/2"MMG2 R-20,RK Latch tM 4 10,297' 7,866' Camco 3-1/2"MMG2 R-20,RK Latch .1 k 7 5 10,843' 8,212' Camco 3-1/2"MMG2 R-20,RK Latch 6 11,173' 8,436' Camco 3-1/2"MMG2 R-20,RK Latch 7 11,444' 8,632' 2.9" Otis straight slot locator w/19.43'seals 8 11,446' 8,634' Otis WD Perm Packer w/seal bore extension t,,' ', 9 9,400- 7,268'- 1-3/4"coil w/2-1/8"PDM and 2-1/8"MHA 11,540 8,705' I•` 10 11,690' 8,820' 2.750' Camco"D"nipple J'",'` 'Ut, 11 11,724' 8,846' 3-1/2"tubing tail J 0 l 's;°,k',�,<t�1,: , soz PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status • Blk Sqz 12,060' 12,064' 9,115' 9,118' 4' c w,f Blk Sqz 12,650' 12,651' 9,558' • 9,558' 1' a , ',i''.4'.".,.k,-:fir p H1 12,754' 12,807' 9,641' 9,684' 53' "`,,rte�+„,"1.t " +" r H2 12,816' 12,874' 9,691' 9,739' 53' .. 7":T it'k- 8-1 « ".' 1*,4 13-2 itlt y l Fish: qi:'.' , ; 13,093'(MD)-Fish lost 6/15/88 during rig operations,consists of the following equipment: BIT,DRILEX, »-s.lgii;n°`'• XO,STB,DC,XO,D-JARS,1 HWDP and UP JARS) TD=13,276'MD PBTD=13,042'MD Max Hole Angle=53° Updated By:iLL 09/23/16 King Salmon Platform K-O6RD Current 07/28/2016 flavor!'tlurku.1.1.t. King Salmon Tubing hanger,FMC-UH- K-6RD TC-1A-EN,13 5/8 5M X 4/] 24 X 13 3/8 X 9 5/8 X 3 1/2 IBT lift and susp,w/4"type IS BPV BHTA,B-11-A-0,4 1/16 5M FE LC Rrrty� J Valve,Swab,FMC-75, 7; 4 1/16 5M FE,HWO,EE __,.•,. 1 Valve,Wing,SSV, trim .,jy� FMC-20,3 1/8 5M FE, 1.. r 13"Axelson oper, EE trim \ j Valve,Master,FMC-75, ie ���',41/165M FE,HWO,EE ; �J1 Or trim Adapter,FMC ASP,13 5/8 5M API clamp X 4 1/16 5M,w/7" `:� extended neck pocket 14 1.1 ril Unihead,OCT type 3,13 5/8 5M API _1.le =f r.,-,-,1hub top X 13 3/8 BTC casing bottom, [— 3 w/1-2 1/16 5M SSO on lower _. III section,1-2 1/16 5M SSO on middle - section,3-2 1/16 5M SSO on upper section,IP internal lockpin assy ■► I .� ���_!.,.. . ® All annular valves are [=i�Iiiiiii, ■ ■� �'�� 21/165MFMC20 Starting head,FMC, 21'/<2M X 24"SOW, ; 11 -- w/1-3 1/8 2M EFO iUc- ;' i • "i` lill 24" 13 3/8" 9 5/8" 3/: • King Salmon Platform 2016 BOP Stack(Kuukpik) Harm]]:11aekn.11.1t06/22/2016 Rig Floor 16" Pipe 111'111!1 P I L1-1 tit lit lil lil III iii iii al 3'74' Shaffer 13 5/8 5M Iii III Ili II! ill m Shaffer SL 27/8-5.5Variables 2.83' __.1:1:41 13 5/8 5M .._._ —� —. Blind • O 2 1/16 5M manual and HCR valve 3 5M manual and HCR valve 111111111M1111 . 1.76 p it ill III III ® I' Shaffer SL 13 5 SM 2 7/8-5.5 Variables 1.44' C41-64 �� Drill deck 13.70' Riser 135/8 SM FE X 13 5/8 5M API hub 0 w Choke Manifold Valves 2 " To Shaker 3" Panic To Gasbuster 3 1/8" 2 1/16"O ----41...0 C) 2 1/16" •mi. .Q' i I + , ,8 /0 21/1 + 21/16"iv + / 3 1/8" ��© \`O + N L, .,L I _ J � 2 1/16" + 1/16" Manual Choke Automatic Choke 2 1/16" Inlet Pressure Sensor 3" 5,000 PSI Choke Manifold Kuukpik Drilling Rig 5 RED = 3 1/18" 5,000 PSI VALVES AND LINES BLUE = 2 1/16" 5,000 PSI VALVES Kuukpik Drilling Rig 5 Choke Manifold 4, . ,�, ., 40 Cs #10 0 #9 ,, ir #f3 ill #16 #5 r �� .~2 at #15 Os M Kuukpik Drilling Rig 5 Choke Manifold • 0 E cC t e oi'ai Qi'oi 'a wi of�i r1 a, a,,. a+• I--I ▪ 01 ,sl t4 ,8l:1 '^I kpxi a OiviOiUiA+ VIOi , O a, iii ql I al a I I I .. _ - it I,AI�i ad I I .* p In Qi •I ai ni qi.I I OQ D N —II IaI;:JI ""1:-•1 i 4•I L. 3 E , 2 Q. y 1!cdI i i a+ .91 0jai _rn di�li gia1121 aa) gixi�I oli a f Iyt.2IoI I .° ai �iC I I.I lA I 03 e. •l yl I�I �I VI I 'NI I'al SI 1 1 i>.< , .-.I 1 1O1 1 1 d' co N r I I I I ' II o' o e. I 1 i N N N ,,re,ee.es. 8 N,N,N, - I I I I I I I N 4-- N N N w o ^ a in N _ _ A w, � A I - J L 1 I I I 1 — co A o.c.o.v.0. o.v.iv.v.O wi NI NI NI NI NI NI NI Ni .. 9.1.2121212.121:2121;121 W a° Vi�i�'iviviVi�'iVic'i c J0 I q,qi•-• dl ql qi al �I I O o N L 10101 ji ji itoi .11 ai CCS 10. ii DI Ot Ol of of 0101 O1'ai ?i8i8oio � 8ioii i_c iiiu CL1 I' .1 v' .1 i.- I: .1'0.10' .1..c.,4. 10I 21', 0 0) 111�1�1�1�1 qi I Tri CO0 N J 1eo..,10+I.1IriI,„I01,11 1 E N 10..11 IA Ai IA Ai 4.1 i i i i i i i i i I- ♦ '00 'CI 0 r ♦ Q .+..r..r.. ..,....ti.. ..r, I III I III I I Z 4- • ►4 C .p' It a) L r♦ ♦, A w r'°. a) Y 3 O o U) �i • • E Cd s. a) czt i of yl aal al" oyl Q al 0f al al n V. 0I a Noo . oI^ o• a. IQ! 1 IAU! 1 p 4,1 11 al i i wi i_I al 1 I4-1 yl ;il'-I I al` .ili9'i i� • N -a, .F....1. �l1+10,1j ++ �T- = 2 _ IiI LL 73 011:41F1! 1 d 'cl•o 10.1 ' Q1-1-17414 lal q• , l °I ai ;nql I I -. `_ ql i blI jl -,1 .-.1 I N 'I I al.l —1 °1 I (n ® NNt n apl 'a ,Ni U11 I Nt CO i i 1 N N i ig 11 .rl ell rtl rel 7 r1l eel rel 1 1 1 I' II I N o w • U y c � a ', .1 LO 7 NN LI A n 1 JAL v, Iii U ���— n �: x:91 �: �1 �1 �1 �; �1 N g al al al al al al al al a1 O C r N. N. N. N. N. N. N. H. N• N 21 91?I?1.1.I 2I I2I V a U•U'U'U'U'U'U'U'U• ct O 1 1 1 1 1 1 1 C.. '7O N LL Ialalalalalalal ?+I I A. Al N.II. Q. UN L IUIC�1VI0IVI(5101 1 al 0 Y I al al'a,'al a1'�1 a l 01 (� 1011' � �'Iolol0l01010101 011 r I1:?Io1pIplolo101-1 LI I V, • I. 1. 1. i-I' I• I. 1 ql 0'I Cd •Co.Co.• zo.Co,• • p. C.) I.41 ►I - L I,�I4.t1enlMlfel,l'nljl 1 1-4 6.1111111111 U N. ♦ -N ' A _p ' co Iol. 1eelenl.�I V,I.olrlaol AN— O 1 1 1 1 1 1 1 1 1 1 ll.41 / i i t i I t i i I N C 'o OV N CC� VM 5 L r r . A O P4 ^^`` ^` q q ^` {Ja U) a L as 0 ►4 4 • a 1 I I I I I ill �1 �• co.♦ al al alaialalaiylNI ai ai ai ai ai ai O. e• 0' 1 1 1 1 1 1 1 1 1 ai == °=i °= i, 1. °'i. °=i,='i qqiqqi .4 % qqq V.U,c).cI c)1 U1 01 01 U1 N N N' N N M' N' N N• a a1 p•I al a•I al 0.1 al p•1 al 4oI OI OI OI OI o1 OI OI o % O1O1 Ol OIOlO.1 OIOIO 1 It ell ee1nIell eeleelelIeelell ,,,�// U y 1 1 1 1 1 1 1 1 1 F•�•I a ..1 eq!in!a I y,1,,0 I r`.I o01 ov 1 to a_ j 111111111 b CO•--y ;-t q H I• '' a ti 0 U • • E 1 1 1 1 1 1 1 S. l ai al a+1.0 al a+1 ai C ap 0,0,8iVIaa0 O0.Q v'a „I 1 1 1 1 1 1 AI i ..ti '•-i 1 O �I i ai:i 01 ,„,1 1 w L �,, al 1 „1 01 nl ql 1 9 « 1 •,'� O O ai• i 1 i%1 i co 1 n y alalp1;=1I y 11,1.111 4-1 i �IU1.41-1i '1 0101 N O a I�'1 =1 SIS �1 rlr'I q a n. a al 1 .11".1 .1 ,.1 1 --------- 1 ISI „1 Al 0l I „1 1:01 1 UI rI Im Q '^ I MI I I IO "1 I I 1 1 1 I `moi , - - r I I I 1 ... 1 1 1 m d a, d' co .o 0,101.. 1"1.* ,1.0.,,IN N v � ..I rt.rt.rt, 1 et•et•et i K 1 I 1 1K I I 1 7 o c ♦‘1".. y 'a 1.0 A N ! $ e �! y q N L h L, O. u ,— ij NI HI HI NI y1 NI HI NI °y1 a) 1. 0 21,121-2i8i 21 2i 2181 a� - 4 uiviuivi iviui(j i c V1 p I21 a,1 „1 „i ad a,l „1 al I 0 LL 4) O I ql ql�I•�I•ql ql�1�1 I 0 yo N I._ t,101.",O.0.t 031. w „, 1 HI'NI•NI.NI'NI'NI•..I"ISCI +' t a) a., a y, a. 0, cd U Y t10lo1oI =I 1C�I01 01x1 (6 N lol Ololol010101'21 ,.1 i•v,,v,,o.o„n,v,,o,U, „. O I; I; I_ I•_ 1; I; I I a Il al .-.I. l4?12?i,I...1??1 al0,l O) a0 N .et•et•"1. 1-.1-.1 1-1 i rt•rh rt•rt �. [Xi i 1 1 i i I I l I i 401111111111 a) N C7 iCO 0I „I7,I,.,I,"',tl„�„I,tI,,tl,�ISI L�� "a 1 i 1 1 i i i i I I O D4 1 0 9 d C o L O g N (6 M a .r N .. a N Y 1 = O o �g ZM -C Ast v 0 >a 4 4 - hi F-Z COQ r ♦ • In ° �°1 °1 o a• a a• a• a a a ,• CI4'1 ! 4'! l l IN1 I . 0.. o. 0., 4 aa o, o, — 4 01010101010101 C1 l 111114411 4112,14'1 w1 21 5:1 6 ,1 4'1 q. q. q. q. q. q• q. q. q. 0101(..111.,1010101c)101 741 41 .74I 17;I 1;I ;I 1;11 u71 ;1 a, a., Cu. a., a.. Cu a., a• a., .t: 5° 01010101010101101. , .0 . A 010101010101010101 r v,.V,,v,.V,,,n.V.,.V,.vn.,11, —to—kr) - __ _ 01. ___. 701- 1�1v1k,1�1014D1�1 etlrtlrtlrolrtirtlr ,et,et, •� U 1 1 4 1 1 1 1 1 1 a a, 1 1 1 1 1 1 1 1 1 rt er, v v, ?o t-- WIC”' RS ; I I I I I I 1 1 1 a % 1 1 1 1 1 1 1 1 1 ,--1 M v ... i-t A q g d 7. o a QJ • Kuukpik 5 BOP Test Procedure Hilcorp AIa,ka,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 HilcorpAlaska,LLC Attachment#1 If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree and test. May have to tap out if scaled up or paraffined up if well is not dead may have to be done w/ pressure lubricator (diesel or acid could help) 2) If unsuccessful, or BPV profile is eroded and well is dead. Best practice is to have two barriers a. Fluid column b. Set wire line plug or tag fluid level with slick line to establish static fluid level or shoot fluid level with an echo meter gun. 3) Shoot off tubing very shallow( 300-500' most likely just under SSSV if applicable) 4) Spear hanger w/upside down cup provided by fishing company 5) Proceed to get best test we can achieve against cup and confirm no visual leaks on all flanges of BOPE 6) Notify Hilcorp Anchorage Operations Engineer and AOGCC of situation 7) Pull hanger and cut off stub 8) P/U test plug and set same. 9) Perform complete BOPE test as per Kuukpik's standard procedure . • • � CD P> 0 f =W o Q _ ■ ■ § 77 � o12 E t 2 k0. § ) « � E E ) a = § 10m d » < O. £ �.- � / 2 - � ■ Y � 7 � i0E �\ a g / O . ® a a R @ 2 ■ 2 ■ ■ $ C t � Ec 2c / 0 @ NI Q £ B k tTo a) � _o J U a2 k co CO k/ a) // os .c 0 730 I) k \ q) ■ E © 2 o S ƒ a O 0. / a) k - » q ■ L. �f § C co kp c W t 2R r.§ ■ @ 2 § � a 0 1-4 p o. a. � cu a « CU0 0 ■ 4 as Cd 2 cal . E p 0 2 ■ a _a k � � g - 0 § o a ) a. $ g v 0 > Q ir- 0 .. ■ � %0 �>.. g C© 2 �Q o.E O o o_ 0 2 co k ? m ¢ 2 • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the"Abandon"or "Suspend" boxes are also checked, cross out that erroneous entry and ✓ initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work)the initial reviewer will cross out that erroneous entry and initial / then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time,they will also review the list of suspended wells for accuracy. Im&~,~ Project Well History File Cove, Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. -~ ~-(~O-- J~C::~ ~ Well History File Identifier Organizing (,Jo,.:) olor items: DIGITAL DATA OVERSIZED (Scannable) [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERY~INDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL(~~WINDY Scanning Preparation [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other + l BY: BEVERLY ROBIN VINCENT SHERYL~WINDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: _ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ..~ YES Stage 2 IF NO IN STAGE t, PAGE(S) DISCREPANCIES WERE FOUND: __ YES (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) ReScanned (indfvid~!al p;.~g~ l,~pe, cial ,~tte~}tiot~] ,~c~:mnil~g :pmph.~,led) i i i NO NO RESCANNEDB?'; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: I$1 General Notes or Comments about this file: Quality Checked 12110/02Rev3NOTScenned.wpd PO Box 196247, Anchorage, AK 99519 " STATE OF ALASKA ) ALf. .lA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AJaska Oil & GtjS Cons. Commission Stimulate U Othe~~l~i~eanout Waiver 0 Time Extension D' \.' Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory 0 1880280 Service 0 6. API Number: 50-133-20088-01 9. Well Name and Number: K-06RD 10. Field/Pool(s): McArthur River/Hemlock RECEIVE[) JUN 0 9 Z005 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 Name: 3. Address: Plug Perforations U Perforate New Pool 0 Perforate 0 4. Current Well Class: Development 0 Stratigraphic 0 7. KB Elevation (ft): 100' RKB 8. Property Designation: King Salmon Platform, Cook Inlet 11. Present Well Condition Summary: Total Depth measured 13,276' true vertical 10,060' Effective Depth measured 13,042' true vertical 9,877' Casing Length Size Structural Conductor 376' 24" Surface 2,186' 13-3/8" Intermediate 11,958' 9-5/8" Production Liner 1,415' 7" RfC£\V£D JU\'t 1 S 2005 feet Plugs (measured) feet DR\lL\NG Junk (measured) Coil tubing fish @ 9,400' ALASKA feet feet MD TVD Burst Collapse 376' 376' 2,186' 2,088' 3,090 psi 1,540 psi 11,958' 9,031' 6,870 psi 4,760 psi 13'~AN~\lED J~03: 7 20DS 8,160 psi 7,020 psi Perforation depth: Measured depth: 12,754 to 12,874' True Vertical depth: 9,639 to 9,738' Tubing: (size, grade, and measured depth) 3-1/2", 9.3 #, L-80, @ 11,724' Packers and SSSV (type and measured depth) Otis WD Packer @ 11,446'. Camco 3-1/2" TRD1-A SSSV @ 291'. 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf I Water-Bbl I Casing Pressure n/a Tubing Pressure 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 15. Well Class afteÖrOPOsed work: Exploratory Development 0 16. Well Status after proposed work: Oil0 Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 0 x GINJ 0 WINJ 0 WDSPL 0 Sundry Number or N/A if C.O. Exempt: Contact Larry W. Bus}er~07~6~-7853 ---:'7 "- Printed Name Larj)V4.';- '_ , --, s¡gnatk' 1 \ è~ \]v Title Acting Drilling Manager Phone 907-276-7600 Date 6/9/2005 ORIGINAL RBDMS BFL JUN 15 2005 Form 10-404 Revised 04/2004 Submit Original Only UNOCAL~ J J J J L J ~ J J J 2 - _ 3 ¿ II 4 6 ~ ?-:'I ::;: ªL., ~ ;:;.1.,= ~ SQZ ?" SQZ =- B-1 . B-2 - ) ) Technical Schematic King Salmon Platform, K-06RD last revised 5/30/03 (OED) Unocal Alaska API#: Well Type: Spud Date: Completion Date: Original RKB: RKB to Hanger: 50-133-20088-01 Producer 3/30/88 7/25/88 100' MSL 34' Casing and Tubing Size Weight Grade Thread Top Bottom Description 13-3/8" 61# J-55 BTC 34' 2,186' Casing 9-5/8" 53# S-95 BTC 34' 1,968' Casing 9-5/8" 47# L-80 BTC 1,968' 11,958' Casing 7" 29# L-80 BTC 11,674' 13,089 Liner 3-1/2" 9.3# L-80 DSS-HTC 34' 11,724' IPC Tubing Jewelry 1 291' Camco TRPD1-A SSSV Nipple: ID = 2.812" 2 11,444' Otis straight slot locator w/19.43' seals, ID = 2.9" 3 11,446' Otis WD perm. Packer w/seal bore extension 4 11,690' Camco D Nipple: ID = 2.750" 5 9,400-11,540' 1-3/4" coil w/2-1/8" PDM and 2-1/8"MHA 6 11,724' 3-1/2" tubing tail Gas Lift Information Depth Stn. TVD Mandrel Size Type Valve Latch Port Sz. 2,591' 1 2,469' Camco 3-1/2" MMG2 R-20 RK 3/16" 3,063' 2 4,295' Cameo 3-1/2" MMG2 R-20 RK 3/16" 7,130' 3 5,652' Cameo 3-1/2" MMG2 R-20 RK 1/4" 8,519' 4 6,668' Camco 3-1/2" MMG2 R-20 RK 1/4" 9,536' 5 7,358' Cameo 3-1/2" MMG2 R-20 RK 5/16" 10,297' 6 7,864' Cameo 3-1/2" MMG2 R-20 RK 5/16" 10,843' 7 8,209' Cameo 3-1/2" MMG2 R-20 RK 3/8" 11,173' 8 8,443' Cameo 3-1/2" MMG2 R-20 RK 3/8" TRO PSC 1,175 1,218 1,209 1,213 1,256 1,192 1,266 1,181 1,317 1,162 1,318 1,152 1,381 1,138 1,379 1,131 Zone Squeeze Squeeze 1 2 3 4 5 Perforation Data - DIL depths Top MD Top TVD Perf Interval FT SPF 12,060-12,064 4' SOZD 12,650 l' SOZD 12,754-12,807 53' 8/12 12,816-12,874 53' 8/12 not perforated not perforated not perforated 12,748 12,810 12,885 12,964 no data 9,534 9,576 9,647 9,713 PBTD: 13,042' MD TOF: 13,093' MD (Fish lost 6/15/88 during rig operations, consists of the following equipment: BIT, DRILEX, xo, STB, DC, XO, D-JARS, 1 HWDP and UP JARS) TD: 13,276' MD Datum: 12,514' MD (9,350' 55. 9,450' TVD) ) ) Unocal Alaska Daily Summary Form 10-404 Well K-6RD 12/9/02 Arrive on King Salmon Platform and prep well for coil tubing work. 12/10/02 RlU and test coil tubing unit. Test coil BOP to 250/4,000 psi. 12/11/02 Load coil with water and RIH washing out tubing bridges and out thru the EOT at 11,724'. Pull up into tubing and stick coil at 11,580'. Drop circulating sub ball and CBU. Attempt to free stuck coil. 12/12/02 Continue to work stuck coil and able to move approximately 17' up hole, but still stuck. RlU Nitrogen and pump down coil in attempt to free coil. 12/13/02 Continue to pump Nitrogen in attempt to free coil. No luck. 12/14/02 Continue to pump Nitrogen and surge coil in attempt to free. Set coil slips and close rams. Cut coil above BOP. 12/15/02 M/U chemical cutter for cutting 1-3/4" coil. Unable to work cutter down hole. R/U slick line and RIH tagging up on tight spot at 9510' . 12/16/02 Fill 9-5/8" casing with sea water taking returns thru 3-1/2" tubing. Shut down for the night. 12/17/02 RlU e-line. RIH and cut 1-3/4" coil tubing at 9400'. Circulate coil tubing x tubing annulus and confirm well is dead. RID e-line. 12/18/02 POOH with cut coil. RID coil tubing operation. R/U on well for well for injectivity test. Work finished. · ~ ..ÀIIrEII UNOCALe Transmittal Form Unocal Alaska Regulatory Filing ) Date: 109 JO.5 Submitted by: Dr) n hevvn Well Name:f- ()j tfJproject Manager :- 73 Uf-J.{ IV Type of Form: D AOGCC 10-401 ) D AOGCC 10-403 . J'f AOGCC 10-404( f2e-6u b yYl' if~ .. ti AOGCC 10-407 D BlM 3160-05 (Notice of Intent) D BlM 3160-05 (Subsequent Report) Sent to: . D Bureau of land Management 6881 Abbot loop Anchorage, AK 99507 'r¡L. AOGCC 333 W. 7th Avenue Anchorage, AK 99501 Sent via: D Mail o Courier )i9rilling Personnel Page 1 of 1 TBU K-06RD (188-028) (50-733-20088-01) ..¡: r Þe~m2 ) Subject: TBU K-06RD (188-028) (50-733-20088-01) From: Thomas Maunder <tom_maunder@admin.state.akus> Date: Tue, 07 Jun 2005 13 :00:05 -0800 To: Larry Buster <1 buster@unocal.com>, Larry Greenstein <greensteinl p@unocal.com> cc: Steve McMains <steve_mcmains@admin.state.ak.us>, Bob Fleckenstein <bob_fleckenstein@admin.state.akus>, Steve Davies <steve_davies@admin.state.akus> Larry and Larry, Not sure which of you is the right one for this message. It may be possible that someone else might be the appropriate one for the answer. If so, please forward on. According to the last information we have in our file over here for this well, an attempt was made to perform a coil cleanout in December 2002. On the TOH, the coil got stuck and eventually some 2000' of coil was left stuck in the bottom of the tubing. The last entry in the operations report says, "RU on well for injectivity test. Work finished. II Based on the operations accomplished, I presume that the purpose of the injectivity test was to determine if there was any communication to the formations past the junk. The 404 filed at that time (signed by Larry B.) lists the well as a service well. I do not see how this can be correct. There is no sundry application to convert the well from a producer to an injector and the cleanout and subsequent stuck coil can hardly be considered sufficient "work to convert ". Our production records show that no production was reported for the well beginning in 1998 up through the end of 2003. We have not received any production information for the well since then. We also do not find any injeciton information having been submitted. Based on my assessment of the available information, I believe the well is still an oil well which has not produced since 1998. I request that this matter be looked into and resolved. As I noted, please forward this on if neither of you can help resolve this. Call or message with any questions. Tom Maunder, PE AOGCC SCANNED JUN 1 4 2005 1 of 1 6/7/2005 1:14 PM UNOCAL(; J J J J L J ~ J J ..J 2 - - 3 L 4 6 ~ SQl SQl B-1 B-2 ) ) Technical Schematic King Salmon Platform, K-06RD ¡last re\1Iised 5/30/03 «iDlED)) ilJInocall Allasl<.a API#: Well Type: Spud Date: Completion Date: Original RKB: Hanger Type: RKB to Hanger: Top of Hemlock: Maximum Hole Angle: Angle of Perforations: Annulus Fluid: 50-733-20088-4]1, Producer 3/30/88 7/25/88 100' MSL 4-112 FMC 34' 12,748' 53 deg i 35 deg Sea Water r88-0)8 J EI(JYII+ Casing and Tubing i I Size Weight Grade Thread Top lBottom Description ¡ 13-3/8" 61# J-55 BTC 34~ 2,186" Casmnq I I 9-5/8" 53# 5-95 BTC 34~ r 1,968" ! CasœnQ I " 9-5/8" 47# L-80 BTC 1,968' 11 ,958" Casœnq 7" 29# L-80 BTC 11,674' 13,089 liner 3-1/2" 9.3# L-80 DSS-HTC: 34~ 11,724" IPC Tubijllllg I Jewelry 1 291' Cameo TRPD1-A S55V Nipple: 10 = 2.812'" 2 11,444' Otis straight slot locator w/19.43" seals, 10 = 2_9~1 3 11,446' Otis WD perm. Packer w/seal bore extensœon 4 11 ,690' Cameo 0 Nipple: 10 = 2.750'" 5 9,400-11,540' 1-3/4" coil w/2-1/8" PDM and 2-1/8"MHA 6 11,724' 3-1/2" tubing tail Gas Lift Information 1 Depth Stn. TVD Mandrel Size Type Valve. Latch Port Sz.1 TRO PSC 2,591' 1 2,469' Cameo 3-112" MMG.2 R-20· RK 3/16"' 1,175 1,218 3,063' 2 4,295' Cameo 3-1/2" MMG2 R-20 RK 3/16'" 1,2091,213 7,130' 3 5,652' Cameo 3-1/2" MMG2 R-20 RK 114"' 1,256 1,192 8,519' 4 6,668' Cameo 3-1/2" MMG2 R-20 RK 1#4"' 1,266 1,181 9,536' 5 7,358' Cameo 3-1/2" MMG2 R-20 RK 5'16'" 1,317 1,162 10,297' 6 7,864' Cameo 3-1/2"' MMG2 R-20 RK 5i16'" 1,318 1,152 10,843' 7 8,209' Cameo 3-1/2" MMG2 R-20 RK 3/8" 1,381 1,138, 11,173' 8 8,443' Cameo I 3-1/2" MMG2 R-20 RK 3/8" 1,319 1,1311 Zone Squeeze Squeeze 1 2 3 4 5 Perforation Data - DIL depths Top MD Top TVD Perf Interval FT SPF ,12,060-12,064 4' I SQZO 12,650 1~ sazo 12,754-12,807 53" 8/12 12,816-12,874 53'· 8/12 not perforated not perforated not perforated 12,748 12,810 12,885 12,964 no data 9,534 9,576 9,647 9,713 PBTD: 13,042' MD TOF: 13,093' MD (Fish lost 6/15/88 during rig operations, consists of the following equipment: BIT. DRllEX, XO, STB, DC, XO, D-JARS, 1 HWDP and UP JARS) TO: 13,276' MD Datum: 12,514' MD (9,350' SS. 9,450'1VD) (" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION % JMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: Other: Convert to water injector 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. Box 19-6247 Anchorage, AK 99519-6247 4. Location of well at surface 729' FSL & 130' FEL, Sec. 17, T9N, R13W, SM At top of productive interval 2168' FSL & 1633' FEL, Sec. 19, T9N, R13W, SM At effective depth 1948' FSL & 2080' FEL, Sec. 19, T9N, R13W, SM At total depth 1914' FSL & 2152' FEL, Sec. 19, T9N, R13W, SM 5. Type of Well: Development: X Exploratory: Stratigraphic: Service: 6. Datum elevation (DF or KB) 100' RKB 7. Unit or Property name Trading Bay Unit 8. Well number K-6RD 9. Permit number/approval number 88-28 10. APl number 50- 133-20088-01 11. Field/Pool McArthur River/Hemlock 12. Present well condition summary Total depth: measured true vertical 13,276' feet 10,060' feet Plugs (measured) 13,282' Effective depth: measured 13,042' feet true vertical 9,877' feet Junk (measured) 13,168' Casing Length Size Structural Conductor 376' 24" Surface 2,186' 13-3/8" Intermediate 11,958' 9-5/8" Production Liner 1,415' 7" Perforation depth: measured 12754'-12807', 12816'-12874' Cemented Measured depth To Surface 376' 1760 sxs to Surface 2,186' 1,050 sxs 11,958' 585 sx 11,674' - 13,089' True vertical depth 376' 2,088' 9,031' 8,794'-9,909" true vertical 9639'-9682", 9689'-9738' Tubing (size, grade, and measured depth) 3-1/2", 9.3 #, L-80, @ 11,724' Packers and SSSV (type and measured depth) Otis WD Packer @ 11,446'. Camco 3-1/2" TRD1-A SSSV @ 291'. 13. Stimulation or cement squeeze summary Intervals treated (measured) n/a Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments: Copies of Logs and Surveys run: Daily Report of Well Operations: 16. Status of well classification as: Oil: Gas: Suspended: Service: water injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: Larry Bust le~~ Form 10-404 Rev 06/15/88 Title: Drilling Engineer Date: 3/22/2003 ORIGINAL SUBMIT IN DUPLICATE Unocal Alaska Daily Summary Form 10-403 Well K-6RD 12/9/02 Arrive on King Salmon Platform and prep well for coil tubing work. 12/1 O/02 R/U and test coil tubing unit. Test coil BOP to 250/4,000 psi. 12/11/02 Load coil with water and RIH washing out tubing bridges and out thru the EOT at 11,724'. Pull up into tubing and stick coil at 11,580'. Drop circulating sub ball and CBU. Attempt to free stuck coil. 12/12/O2 Continue to work stuck coil and able to move approximately 17' up hole, but still stuck. R/U Nitrogen and pump down coil in attempt to free coil. 12/13/O2 Continue to pump Nitrogen in attempt to free coil. No luck. 12/14/02 Continue to pump Nitrogen and surge coil in attempt to free. Set coil slips and close rams. Cut coil above BOP. 12/15/02 M/U chemical cutter for cutting 1-3/4" coil. Unable to work cutter down hole. R/U slick line and RIH tagging up on tight spot at 9510'. 12/16/03 Fill 9-5/8" casing with sea water taking returns thru 3-1/2" tubing. Shut down for the night. 12/17/03 R/U e-line. RIH and cut 1-3/4" coil tubing at 9400'. Circulate coil tubing x tubing annulus and confirm well is dead. R/D e-line. 12/18/02 POOH with cut coil. R/D coil tubing operation. R/U on well for well for injectivity test. Work finished. Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL RECEIVED OCT 2 5 2001 Alaska 0il & Gas Cons. Commission Anchorage Dan Williamson Drilling Manager October 25, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Report on Annulus Disposal McArthur River Field, King Salmon Platform, Well K-6RD Commissioner Heusser: Enclosed is the final report on annulus disposal for K-6RD as required by the Sundry Application Approval #301-034 dated 3/21/01. Unocal has completed annulus disposal at King Salmon platform. Attached is the daily summary of disposal volumes in K-6RD's annulus while drilling at K-1 RD2, K-13RD2 and K-24RD2. The following is the total volumes disposed in K-6RD's annulus by drilling well source. Well OBM Waste Slurry, Seawater Flush, bbls Total Bbls bbls K-1RD2 6299 8418 ~14717 K-13RD2 4475 6170 10645 K-24RD2 2107 2630 4737 Total 12881 17218 · 30099 If there are any questions, please contact Dan Williamson at 263-7677 or Tim Billingsley at 263-7659. Sincerely, Drilling Manager AOGCC K-6 final report.doc ORI61NAL Tim Billingsley RECEIVED OCT 2, 5 2.001 Alaska Oil & Gas Cons. Commission Anchorage 0 (~'~ 0 ~¢3 1 · - °~ ,i 0 ~ ~ ~ e 000~~~0~~~~~0~~0~~ ~oooooOOO~~ ~ ~~~°°° ooooo~oooooooooo ~ ~ > i ~ 00000000000000 O00000000000 0000000 O0000000 O00000000000 0000000~ ~0 O0000000000 ~ 000 O0000000 · · ~0~ '- gggooooooogooo ooooooo oo ~ 0000 O00000 O0000 O0 O0 O0000 O00 0 ~ g 00 O0000 O00 O0000 O00000000 O00 0 I~%~.,~i~ I V i%L~' OCT 2 5 2 G Ala~ka Oil & Gas Cons. Commissio~ Anch0r~e ~ ~~ ~ oo~~o~~~o -- 0 ~ ~ --0 ~ 0 -- ~z~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 000 ~ 000000000000o ~ ~ 0000000000 Dan Williamson Drilling Manager Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOF..AL 08/01/01 RECEIVED AUG 0 1 2001 Alaska Oil & Gas Cons. CommJssiorl Anchorage Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Proposed Drilling Waste from Monopod Platform to King Salmon Platform Approved and Proposed Annulus Disposal Wells Well K-6RD (Approved) Well K-12RD Well K-19 (Approved) Well K-25 Well K-26RD Commissioner Heusser: Unocal requests permission from the AOGCC to dispose of drilling waste from proposed drilling on the Monopod platform in the above annuli on the King Salmon platform. Sundry Applications (Form 10-403) for King Salmon Well's #K-6RD, K-12RD, K-19, K-25 and K-26RD have been submitted to you. Two wells, K-6RD and K-19, were approved and the remaining three have been on hold pending whether more than two annuli will be required to dispose of all of the drilling waste. The two approved annuli, K-6RD and K-19, have been used as annulus disposal wells for drilling waste generated by drilling on the King Salmon platform at K-1RD, K-13RD2, K-18RD and will be used for the upcoming K-24RD. After K- 24RD is completed, no more drilling will be done on the King Salmon platform and the crews will move to Monopod to drill one to two wells as follow-up wells to the highly successful K- 13RD2 (8000 BOPD). There will also be one or more workovers on Monopod while the rig is active but workover waste will not be transported to King Salmon for annulus disposal. It is unknown at this time how many annuli will be needed at the King Salmon to handle all of the waste from the Monopod without exceeding the 35,000 bbl limit on any one annulus. Therefore, Unocal requests a waiver from the AOGCC for all 5 of the above King Salmon annuli as described in 20 AAC 25.080(d) (4) "Unless the operator demonstrates that compliance with a limitation established in 1-4 of this subsection is imprudent, the commission will not authorize disposal of drilling waste: ... (4) through annular space of a well not located on the same drill pad or platform as the drilling operation generating the drilling waste." Unocal believes it is more prudent to utilize existing equipment on the King Salmon platform to dispose of drilling waste from the Monopod platform than to haul and store waste at other locations. The grind and inject unit and disposal annuli on the King Salmon platform have AOGCC letter Monopod Waste to King. doc Tim Billingsley proven to be an efficient, safe and environmentally attractive means of disposing of oil based mud cuttings. Unfortunately, there is not as much room on the Monopod platform as the King Salmon platform and the grind and inject unit can not be moved to the Monopod. There will be one to two wells drilled with oil based mud on the Monopod platform and the ultimate disposal of the cuttings are in question. The cuttings could be hauled to Bruce platform and ultimately injected into a disposal well there. However, this would be a longer process due to lack of equipment currently on Bruce, summer-only operating situation currently at Bruce and lower throughput capacity at Bruce that would limit injection and necessitate long term storage of cuttings in drums. The big advantage of the King Salmon grind and inject unit is that it can process cuttings as soon as they are generated. Cuttings could be hauled from Monopod in 25-bbl rental totes. The rental totes could be quickly dumped into the 300 bbl receiving tank of the grind and inject unit and return to Monopod for more cuttings. This would be much better than hauling and storing the cuttings as would be the case on the Bruce platform or other disposal options. The Monopod-King Salmon relationship has many characteristics that are beneficial regarding this disposal proposal. The Monopod platform is only one platform to the north of the King Salmon. The proposed wells on the Monopod will be drilling to the south and will be targeting the same Northern Nose geologic feature that K-13RD2 is currently completed in. The Monopod and King Salmon Platform have the same ownership, Unocal and Forest Oil. Therefore, it would be environmentally and economically more prudent to transport oil based mud cuttings from the Monopod platform to the King Salmon platform where annulus disposal will be quick and storage problems will be minimal. Please respond with your decision regarding this request for waiver of 20 AAC 25.080(d)(4) in a timely manner. If the waiver is not granted, there will be significant planning required to provide a viable alternative to the cuttings disposal problem. The proposed drilling on the Monopod platform should commence in October 2001. If there are any questions, please contact Dan Williamson at 263-7677 or Tim Billingsley at 263-7659. K-6 injectivity test Subject: K-6 injectivity test Date: Wed, 21 Mar 2001 08:14:07-0800 From: "Billingsley, Tim -Contract" <billita@unocal.com> To: "Maunder Tom (E-mail)" <tom_maunder@admin.state.ak. us> CC: "Hauck, Shane R" <haucks@Orion. Unocal.com>, "Scales, Nicholas J -Contract" <scalesn@Orion.Unocal.com>, "Byme, Don S" <byrneds@Odon. Unocal.com>, "Williamson, Dan R" <williamsond@Orion. Unocal.com> Tom, An injectivity test was performed on K-6RD last nite, 3t20t01. 150 bbls of FIW was injected down the 9-5/8" x 13-3/8" annulus at 3 bpm and a constant 950 psi throughout the test. The inner tbg x 9-5/8" annulus remained at 500 psi before, during and after the test and the outer 13-3/8" x 24" remained at 125 psi before, during and after the test. Offset wells K13RD, K-15RD, K-25 and K-26RD were monitored and their 13-3/8"x24" and 9-5/8" x 13-3/8" annuli remained constant before, during and after the test. Due to this acceptable injection rate and pressure in K.6RD and the fact that K-6RD is a shut. in producer instead of an active gas-lift producer like K~19, Unocal would like to commence annular injection in K-6RD when drilling commences on K-1RD2 which will probably start on 3/22/01. K-19 will then be used as a back-up to K-6RD for annular injection. We do not have the approved Sundry from you for K-6RD so are in need of this approval before the end of business today if possible. Thanks, Tim Billingsley 263~7659 1 of 1 3/21t01 10:05 AM Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) RECEIVED FEB 1 5 ZOO] Alaska Oil & Gas Cons. Commission Anchorage Dan Willlamson Drilling Manager February 14, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Sundry Application (Form 10-403) McArthur River Field, King Salmon Platform, Well K-6RD Well K-12RD Well K-25 Well K-26RD Applications for Annulus Injection Commissioner Heusser: Enclosed are Sundry Applications (Form 10-403) for King Salmon Well #K-6RD, K-12RD, K- 25 and K-26RD. Unocal requests permission to dispose of oil-based mud and cuttings from the upcoming drilling program at King Salmon into the 9-5/8" x 13-3/8" annulus at these four wells in addition to the annulus of K-19 which had a Sundry Application Form 10-403 submitted 12/28/00. The planned drilling program at King Salmon will be K-1RD2, K-13RD2, K-5RD, K-20RD and potentially K-18RD. There are five proposed annuli because if one of the annuluses becomes plugged during disposal operations, the process can continue in the remaining four annuli. The attached pages to each Sundry Application provide information required under 20 AAC 25.080 regarding annulus disposal. Also included for all four applications is a summary of all the surface casing cement jobs at King Salmon and a summary of leak-off tests performed beneath the surface casing, There has been no prior annulus disposal at any of the wells at King Salmon platform according to ARCO and Unocal records and production personnel on the platform are not aware of any prior annulus disposal at King Salmon. The expected start date for annulus disposal is March 1, 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 AOGCC cover letter K-25.doc Tim Billingsley STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair Well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: Annular I.njection 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 100' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: Trading Bay Unit 4. Location of well at surface 8. Well number 736' FSL & 135' FEL of Sec.17, T9N, R13W, SM RECEIVED King Salmon K-6RD At top of productive interval 9. Permit number 913' FNL &1841' FWL of Sec 22, T9N, R13W, SM 88-28 At effective depth FEB 1 5 Z001 10. APInumber 50- 133-20088-01 At total depth 11. Field/Pool 1147' FNL & 2024' FWL of Sec 22, T9N, R13W, SM Alaska 0il & Gas Cons. Commission McArthur River/Hemlock Pool 12. Present well condition summary ........ ~'" Total depth: measured 13,276 feet Plugs (measured) true vertical 10,060 feet Effective depth: measured 13,042 feet Junk (measured) None true vertical 9,877 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 376' 24" Circ to Surf 376' 376' Surface 2186' 13-3/8" 1760 sx oirc to surf 2186' 2088' Intermediate 11958' 9-5/8" 1050 sx 11958' 9031' Production Liner 1415' 7" 585 sx 11674'-13089' 8794'-9907' Perfo ration depth: measu red 12754'- 12807', 12816'- 12874' true vertical 9639'-9682', 9689'-9738' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 @ 11724' Packers and SSSV (type and measured depth) Otis WD packer @ 11,446' , 3-1/2" Camco TRD1-A SSSV @ 291' 13. Attachments Description summary of proposal: x Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 3/1/00 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: ' 7' I hereb'"y-q'ertify that ff ~ ~e/gl~:i~ i~e and °°rre°t t° the best °f mY kn°wledge' Signe~ ~, [~I~N ~[~lfn'~ II ia m so n 'Title: Drilling Manager Date:&"' " FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity BOP Test Location clearance - I ~.) 1" ~_.~%L~ Mechanical Integ'----'ri~ Test .... ~u--bsequent form required 10-~3~3,~,,, (--) Approved by order of the Commissioner D Taylor Se.'-~m,(:., u~'"~ Commissioner Date Form 10-403 Rev 06/15/88 b SUBMIT IN TRi ARCO Alaska, Inc. Trading Bay Unit - King Salmon Platform W_ell K-6.RD API~. 50-733-2[]088-01 Spud Date: 3-30-88 Completion Date: 7-25-88 Original RKB: 100' MSL Hanger Type: 4-1/2" FMC Top of Hemlock: 12748' Maximum Hole Angle: 53° Annulus Fluid: Sea water Last Revised: 9-92 All Depths are RKB MD to Top of Equipment. 7 10 11 4 5 8 12 13 14 15 16 9 17 18 Jewelry 1 291' 2 11444' 3 11446' 4 11690' 5 11724' 12 13 14 15 Well Type: Producer New 121 Workover [] RKB to Hanger: 34,00' Angle at Perforations: 35° Reason: GR data update Camco TRPD1-A $Sb'V nipple: ID = 2.812' Offs straight slot Iocator w/19.43' seals, ID = 2.9" Otis WD perm. packer w/seat bore extension Ccrnco "D' nipple: ID -- 2.750" 3-1/2" Tubing Tall RECEIVED FEB 1 5 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage Co, in9 and Tubing 6 13-3/8' 61# J-55 BTC 34' 2186' Casing 7 9-5/8" ~ $-95 BTC 34' 1968" Casing 8 9-5/8' 47# L-80 BTC 1968" 11958" Casing 9 7' 29# L-80 BTC 11674' 13089' Uner 10 3-1/2" 9.3# L-80 DSS-HTC 34' 11724' IPC Tubing 11 Gas Lift Information ~ Stn. TVD ~ Slze 2591' 1"' 2469" Camco 3-1/2" MMG2 R-20 RK . $/16" t175 1218 ,5063' 2 4295' Camco 3-1/2" MMG2 R-20 RK 3/16' 1~D9 1213 7130' 3 5652' Camco 3-1/2' MMG2 R-20 RK 1/4' 1256 1192 8519' 4 6668' Camco 3-1/2" MMG2 R-20 RK 1/4' 1266 1181 9536' 5 7358' Camco 3-1/2' MMG2 R-20 RK 5/16" t317 1162 10297' 6 7864' Camco 3-1/2' MMG2 R-20 RK 5/16" t318 1152 10843' 7 8209" Camco 3-1/2' MMG2 R-20 RK 3/8" 1381 11,38 11173' $ 8453' Camco 3-1/2" MMG2 R*20 ~K 3/8" 1379 1131 Perforation Data - DIL depths Gauge Ring and Fill Level Data Squeeze Pe~ 1~12064 4' SQZD 8-21-88 2.70" 13044' Tagged Fill Squeeze Perfs 12650' 1' SQZD 1-21-89 1-11/16' 12990'~PLt~ 1 12748/9534 12754-12807 53' 8/12 left 40*cntdizr 2 12810/9576 12816-12874 53' 8/12 1-17-~X) 2.60' 12973' Tagged fill 3 12885/9647 not perforated 10-12-91 2.6" 12968' WLM tagged 4 12964t9713 not perforated 7-20-92 2.7" 129~' WLM tagged 5 no data not perforated 16 PBTD= 13042'MD 17 TOF= 13093' MD (Fish lost 6-15-88 during rig operations consists of the following equipment: BIT, DI~tLEX, XO, STB, DC, XO, D-JARS, I HWDP & UP-JARS) 18 'rD = 1,3276' MD Datum -- 12514' MD (9350' SS, 9450' TVD) JI.B 9/1/92 Information Required for Annulus Disposal of Drilling Waste 20 AAC 25.080 K-6RD RECEIVED FEB 1 5 2001 1 Annulus to be used for disposal: Alaska 0il & Gas Cons. Commission Anchorage K-6RD, 9-5/8" x 13-3/8" annulus, 13-3/8" shoe is at 2186' MD/2088' TVD. 2 Depth to the base of freshwater aquifers and permafrost There is no permafrost at the King Salmon platform. At the 13-3/8" casing shoe depth of 2186' MD/2088' TVD for K-6RD, the formation waters exceed 6000 ppm chlorides. Also, there is a fresh water exemption for wells at the King Salmon platform. Strati~lral~hic description of the interval exposed to the open annulus and other information sufficient to support a commission findinq that the waste will be confined and will not come to the surface or, except to the extent allowed under (e) I of this section, contaminate freshwater The 13-3/8" shoe is at 2186' MD/2088' TVD in K-6RD. This corresponds to the Middle Tyonek formation. The waste is expected to be confined within this strata as this is the primary gas trap in the McArthur River Field with no evidence of surface breaching. 4 List of all publicly recorded wells within 4,4 mile, and all publicly recorded water wells within one mile, of the well that will be receiving drilling waste The attached plat shows the adjacent wells to King Salmon K-6RD. 5 Types and maximum volume of waste to be disposed of and the estimated density of the waste slurry The waste will consist of 9.0 ppg oil base mud with small concentrations of drill cuttings mixed with high concentrations of water or ground cuttings slurrified in gelled water. Seawater will be injected ahead and behind the waste slurry injections. The average density of the waste will be appx. 8.8 ppg when the seawater dilution and the pre/post- flushes are taken into account. The estimated maximum volume from the five potential redrills to be disposed of is 8,000 bbls OBM/water and 26,000 bbls seawater. Description of any waste souqht to be determined as drillinq waste under (h)(3) of this section- 20 AAC 25.080(h)(3) Other substances that the commission determines upon application are wastes associated with the act of drillinq a well permitted under 20 AAC 25.005. None at this time. 7 Estimate of the maximum anticipated pressure at the outer casinq shoe durin.o disposal operations and calculations showinq how this value was determined. An injectivity test was performed on the 9-5/8" x 13-3/8" annulus of K-6RD on 10/26/00 and 800 BWPD was injected at 1150 psi. The maximum injection pressure while disposing of mud and cuttings down the K-6RD annulus will be 1500 psi. The proposed 1500 psi limit on injection pressure will not cause a problem with 13-3/8" casing burst or 9-5/8" casing collapse as shown in item #9. AOGCC ann disp K-dRD.doc Tim Billingsley RECEIVED FEB 1 ~ ZO0I Alaska Oil & Gas Cons. Commission Details that show that the shoe of the outer casinq is set below theA~c, of permafrost, if present, and any freshwater aquifer,other than freshwater excepted under (e)(1) of this section, and is adequately cemented to provide zone isolation; the information relied upon and submitted must include (A) cementing records; and (B) a cement quality log or formation inteqrit¥ records; The 13-3/8" shoe on K-6RD was set at 2186' MD/2088' TVD which is below any freshwater aquifer. (A) The casing was cemented on 2/26/68 with 1100 sx (2288 cuft or 408 bbls) of 12.8 ppg lead cement and 660 sx (135 bbls) of 15.8 ppg tail cement. Full returns were observed throughout the job with "good cement returns to surface". (B) No bond log was run on the 13-3/8" casing. There also was no leak off test below the 13-3/8" shoe when the well was first drilled in 1968 as K-6. However, in 1988, the 9-5/8" casing was cut and removed and the well was redrilled as K-6RD from an open hole kick- off plug. A leak-off test was performed 4/10/88 after kicking off from the open hole cement plug at a depth of 2295' MD/2190' TVD. The LOT was noted as 15.0 ppg EMW. Details that show that the inner and outer casinG strings have sufficient strenqth in collapse and burst to withstand the anticipated pressure of disposal operations: The 13-3/8" outer casing in K-6RD is 61#, J-55 which has a burst rating of 3090 psi for new pipe. Therefore, the anticipated maximum' injection pressure of 1500 psi will not be a problem and will only be 49% of new pipe burst rating. The 9-5/8" inner casing in K-6RD was run in 1988 and is as follows: 53.5#, S-95 from surface to 1968', collapse rating = 7330 psi 47#, L-80 from 1968' to 11,958', collapse rating = 4750 psi 7" 29# L-80 liner top at 11,674', collapse rating = 7020 psi The collapse force exerted by the anticipated maximum injection pressure to 1500 psi on the 9-5/8" x 13-3/8" annulus would be: (1500 psi + (8.8 ppg x .052 x TVD)) The estimated top of cement as outlined in item #11 below is at 9508' MD/7324' TVD. K-6RD is a shut-in well with a fluid level in the 9-5/8" x tbg annulus up to near surface with a 8.5 ppg gradient. The worst collapse case would be just above the top of cement at 9508' MD/7324' TVD in the 9-5/8" 47# L-80 which would be: ((1500 psi + (8.8 ppgx.052x7324')) - (8.5 ppg x .052 x 7324') - 1614 psi = 34% of new collapse rating of 4750 psi for 9-5/8 47#, L-80 casing 10 This collapse pressure is acceptable and there will be a requirement placed on the annulus disposal crews to verfiy that the K-6RD inner annulus is full of 8.5 ppg water before injecting in the outer 13-3/8" x 9-5/8" annulus. The injectivity test in K-6RD on 10/26/00 indicated the formation at 2186' MD/2088' TVD will readily take fluid at 1150 psi. Therefore, the actual disposal pressure will probably be less than 1500 psi but will not be allowed to exceed 1500 psi. The downhole pressure obtained durinc~ a formation integrity test conducted below the outer casing shoe; There was no leak-off test performed on the original K-6 well when the 12-1/4" hole was drilled on 2/26/68 below the 13-3/8" casing shoe at 2186' MD/2088' TVD. When the well was redrilled in 1988 as K-6RD, the 9-5/8" casing was cut and pulled all the way back to surface. An open hole cement plug was utilized to kick-off the redrill. On 4/10/88, a leak- off test was performed after drilling off the cement plug at 2295' MD/2190' TVD. The morning report notes the LOT was 15.0 ppg EMW. Since 8.8 ppg mud was being used at the time, the surface leak-off pressure was 675 psi. There was no indication of any circulation to surface so this would indicate a frac gradient of .78 psi/ft. On 10/26/00, an injectivity test with 8.5 ppg filtered inlet water was performed down the 9- 5/8" x 13-3/8" annulus of K-6RD. The test injection rate was 800 BPD at 1150 psi. The 13-3/8" x 24" annulus was monitored during this test. There was no communication up to the 24" conductor set at appx 376' during the injectivity test. As per 20 AAC 25.080(e)(2), Unocal requests the AOGCC to grant an exception for the downhole disposal pressure exceeding the downhole pressure obtained during the formation integrity test conducted below the outer casing shoe in 1988. The proposed maximum disposal pressure of 1500 psi at the surface with 8.8 ppg disposal slurry as opposed to the 675 psi with an 8.8 ppg mud during the leak off test in 1988 is justified due to the good 15.8 ppg tail slurry pumped at the 13-3/8" casing shoe with cement circulated to surface, the evidence of no communication up to the 24" conductor shoe at 376' during the injectivity test, and the geological interpretation that the Middle Tyonek formation is sufficiently confined with no evidence of surface breaching in the McArthur River Field. 11 Identification of the hydrocarbon zones~ if any~ above the depth to which the inner casing is cemented; The 13-3/8" shoe is at 2186' MD/2088' TVD and the 9-5/8" shoe is at 11,958' MD in K- 6RD. There is a 7" liner top at 11674'. There was no bond Icg on the 9-5/8" casing but there was a bond Icg run on the 7" liner on 7/2/88 which showed cement to the top of the liner at 11674'. The 9-5/8" casing in K-6RD was cemented on 5/13/88 with 1050 sx (215 bbls) of 15.8 ppg cement. The calculated top of cement was 9508' MD. This calculated TOC is based on the following: 215 bbl total cement pumped Float track = 80' x .0732 bbl/ft = 6 bbls Rathole - 11983'-11958' = 25' x .146 bbl/ft of 12-1/4" hole - 4 bbls Cement behind pipe = 215 - 6 - 4 = 205 bbls No caliper, annulus size - .0558 bbl/ft for 12-1/4" hole by 9-5/8" csg Cmt behind pipe = 205 bbls/(.0558 x 1.5 for est 50% washout) =2450' TOC= 11958' - 2450' = 9508' RECEIVED FEB i 5 Z001 Alaska Oil & Gas Cons. Commission The open annulus in K-6RD is therefore from 2186' MD/2088' TVD' to 9508A'n~a~324' TVD which is in the Middle Tyonek of the Main Feature of the McArthur River Field. This interval is Iow on structure in K-6RD and there are no hydrocarbons present. 12 The duration of the disposal operation, not to exceed 90 days; Unocal requests permission to use K-25's 9-5/8" x 13-3/8" annulus for oil based mud and cuttings disposal for more than 90 days. It is anticipated that the workover/drilling program at King Salmon will be 3 workovers and up to 5 major redrills. The first drilling well will be K-1 RD and disposal from this drilling well should commence about 3/1/01 and the entire drilling program could last until December 1, 2001. Disposal operations for the drilling mud from the five drilling wells should be completed by December 31, 2001. There will be applications for annulus disposal at four other wells at King Salmon in case one or more annuli become plugged. The five wells which will be applied for annulus disposal are: K-6RD, K-12RD, K-19, K-25 and K-26RD. 13 Whether drillinq waste has previously been disposed of in the annular space of the well andT if sot a summary of the dates of the disposal operations, the volumes of waste disposed oft and the wells where the drillinq waste was generated; No drilling waste has previously been disposed of in the annular space of K-6RD. There has also been no known annulus disposal at any of the other King Salmon wells. 14 The well where the drillinq waste to be disposed of was or will be generated; The 2001 proposed drilling program consists of K-1RD, K-13 RD, K-20RD, K-5RD and possibly K-18RD. There will also be 3 workovers at K-15RD, K-24RD and K-30. Fluids from these three workovers will not be disposed of in the K-6RD annulus. 15 If the operator proposes not to comply with a limitation established in (d) of this sectionT an explanation of why compliance would be imprudent; Compliance with section (d) limitations as outlined below will not be a problem. The commission will not authorize disposal of drilling waste (1) in a volume greater than 35,000 barrels through the annular space of a single well. (2) For a period longer than one year through the annular space of a single well (3) Into a hydrocarbon-bearing stratum; or (4) Through the annular space of a well not located on the same drill pad or platform as the drilling operation generating the drilling waste. 16 Any additional data required by the commission to confirm containment of drillino waste; The attached spider plot describes K-6RD's 13-3/8" casing shoe in relation to other King Salmon wells' 13-3/8" shoes. In order to verify that the proposed annulus injection in K- 6RD does not communicate to other wellbores, Unocal proposes to monitor the following four 9-5/8" x 13-3/8" annuli: K-26, K-13RD, K-15RD and K-25. These four wellbores are close to K-6RD and in different directions from K-6RD thereby surrounding the proposed injection point with monitoring locations. King Salmon Platform Surface Casing Cement Summary Well Surf Csg Size Shoe MD Shoe TVD Cmt Volume, sx Comments K-1 RD 13-3/8' 2384' 2147' 2608+80 Tag firm cmt at 82', pump 80 sx top job with cmt to surf K-2RD 13-3/8" 2372' 2298' 2608+450 Lost returns during primary job, pump 450 sx top job @ 350' with cmt to surf K-3RD 13-3/8" 2506' 2337' 1560 No top job required No cmt to surf on 3675 sx primary job. Top job found TOC @ 125', pump 125 sx with K-4RD 13-3/8" 2880' 2769' 3675+125 .qood cmt to surf K-5 13-3/8" 2476' 2252' 1625 Cmt returns to surf - K-6RD 13-3/8" 2186' 2088' 1760 Cmt returns to surf K-7RD 13-3/8" 3618' 3039' 1600 650 sx 1st stage and 950 sx thru DV tool @ 1480' K-9 13-3/8" 2492' 2360' 1625 No top job required K-10RD 13-3/8" 4998' 3883' 2255 1300 sx 1st stage, 955 sx thru DVT @ 1511 ', 335 sx cmt returns to surf K-11 13-3/8" 2470' 2400' 1550 Cmt cim to surface, 500 cuff K-12RD 13-3/8" 2510' 2429' 1500 Cmt circ to surface, 150 sx. K-13RD 13-3/8" 5011' 4166' 1050+200 650 sx 1st stage, 400 sx thru DVT @ 2509', 200 sx top job @ 180' with 25 sx to surf K-15RD 13-3/8" 2401' 2284' 1550 Cmt cim to surf, 500 cuff , K-17 13-3/8" 2183' 2032' 1371 Cmt circ to surf, 350 cuff K-18 13-3/8" 2477' 2283' 1800 Cmt cim to surf, 1030 cuff K-19 13-3/8" 2591' 2302' 1750 Cmt cim to surface, 800 cuft K-20 9-5/8" 4999' 2899' 2325 1400 sx 1st stage, 925 sx thru DVT @ 1396', cim 150 sx cmt to surf on 2nd stage K-21 RD 13-3/8" 2714' 2390' 1775 Cmt cim to surface, 798 cuft K-22RD 13-3/8" 5493' 4825' 2200+500 1500 sx 1 st stage, 700 sx thru DVT @ 2881 ', 500 sx (905 cuff) bradenhead ~-top job K-23 13-3/8" 5005' 3940' 2387 Cmt circ to surface K-24RD 13-3/8" 5712' 4229' 2412 Cmt circ to surface, 798 cuff K-25 13-3/8" 1997' 1997' 1260 Originally known as K-16, cmt cim to surface K-26RD 13-3/8" 2938' 2710' 2050 Cmt circ to surface, 80 bbls. K.30RD 13-3/8" 2187' 2012' 1490 Cmt circ to surface Bold indicates updated information from K-19 12/28/00 info and 1/23/01 info. Tim Billingsley KS surf csg cmt and LOTsummary.xls 1/26/01 )DLE ~]VER ST 2 ~ K-12RD K-3RD G 29RD '~ O 27 }0 25 K6 i (OH) K-6RD ~033'(K 17) 2.~98'(K-- 3RDi i STATE OFALASKA ,f' ' ALA~SKA OIL AND GAS CONSERVATION COM~,....,,ON REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate __ Plugging .. Perforate X Repair well Pull tubing Ot h er 2. Name of Operator UNOCAL Corporation (ARCO Alaska, Inc. is sub-operator) '3. Address P. O. Box 190247, Anchorage, AK 99519 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 736' FSL, 135' FEL, Sec 17-T9N-R13W-SM At top of productive interval 913' FNL, 1841' FWL, Sec 22-T9N-R13W-SM At effective depth 1147' FNL, 2024' FWL, Sec. 22-T9N-R13W-SM At total depth 1147' FNL, 2024' FWL, Sec. 22-T9N-R13W-SM 6. Datum elevation (DF or KB) 100' RKB 7. Unit or Property name Trading Bay Unit feet 8. Well number K-6RD 9. Permit number/approval number 88-28/9-220 10. APl number 5o-133-2008801. 11. Field/Pool McArthur River Field/Hemlock 12. Present well condition summary Total Depth: measured true vertical 1 3042' feet 9877' feet Plugs (measured) N/A Effective depth: measured 1 3 0 4 2' feet true vertical 9 8 77' feet Junk (measured) N/A Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 12754-12807; 9639-9682'; Length Size 336' 24" 2146' 13-3/8" 11958' 9-5/8" 1415' 7" measured 12816-12874' true vertical 9689-9738' Cemented Measured depth Yes 376' 1760 sx Class G 21 8 6' 1050 sx Class G 1 1 95 8' 60 sx class G 1 3 0 8 9' 525 sx class G (w/ latex) Tubing (size, grade, and measured depth) 3-1/2", L-80, 11724' MD Packers and SSSV (type and measured depth) SSSV: Camco TRDP1-A @ 291' MD; Otis WD pkr. @ 11446' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure True vertical depth 376' 2088' 9031 ' 9915' 14. Prior to well operation (1/15/89) Subsequent to operation (2/8/89) 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations . X Re0resentativ~ Daily Average Production or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 285 305 486 1080 16. Status of well classification as: Water Injector__ Oil , X, Gas Suspended __ 120 100 Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned Form 1 Title Environmental Analyst Date 1 / 3/90 SUBMIT IN DUPLICATE WELL TBU K-6RD RE-PERFORATION REPORT OF WELL OPERATION Procedure: 1. Conducted a safety meeting. 2. Rig-up E-line unit. 3. Re-perforated the following intervals under draw-down conditions: Run No Bench Interval (CET-MD) IntCrval(DlL-MD) Length 1 2 12841-12861' 12843-12863' 20' 2 2 12821-12841' 12823-12843' 20' 3 1 12777-12797' 12779-12799' 20' 4 1 12757-12777' 12759-12779' 20' SPF NOTE: Lubricator was pressure tested to 2500 psig prior to well operation. 4. Rig-down E-line unit and lubricator. 5. Returned well to injection. APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon m Alter casing __ Change approved program Suspend __ Operation shutdown __ Re-enter suspended well __ Repair well ~ Plugging ~ Time extension m Stimulate __ Pulltubing__ Variance ~ Perforate__ Other X Re-per f 2. Name of Operator UNOCAL Corp. (ARCO Alaska is sub-operator · A re ~. c~d. ~ox 190247 Anchorage, AK 99519 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 736' FSL, 135' FEL, Sec. 17, T9N, R13W, SM At top of productive interval 913' FNL, 1,841' FWL, Sec. 22, TgN, R13W, SM At effective depth At total depth 1,147' FNL, 2,024' FWL, Sec. 22, TgN, R13W, SM 6. Datum elevation (DF or KB) 100' KB 7. Unit or Property name Trading Bay Unit 8. Well number K-6RD 9. Permit number 88-28 10. APl number 50-- 1332008801 11. Field/Pool Field 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length ~~x Conductor 336' Surface 2, 146 ' Production 11,958 ' Liner 1,415 ' Perforation depth: measured Bench 1: 13,042 feet Plugs (measured) 9,877 feet N/A feet Junk (measured) feet i',,:..',.;.i,?:/~iJ!~.~. r;' O{~$ CONS, r',,~,t,,~I~;.:.,i ~' '. ,.,.;;.~, ~)i"~" Size Cemented Measured depth True vertical depth 24" yes 376' MD 376' TVD 13-3/8" 1,760 SX class G 2,186' MD 2,088' TVD 9-5/8" 1,050 SX class G 11,958' MD 9,031' TVD 7" 60 SX class G 13,089' MD 9,915' TVD 525 SX class G (w/ latex) 12,754 - 12,807' MD; Bench 2: 12,816 - 12,874' MD. truevertical Bench 1~ 9,639 - 9,682' TVD~ Bench 2~ ~bing(size, grade, and measureddepth) 3-1/2", 9.3#, L-80, 11,724' MD. PackersandSSSV(tvBeandmeasureddepth) Camco TRDD 1-A SSSV @ 291' MD. Otis WD packer @ 11,446' 13. Attachments 9,689 - 9,738' TVD. MD. Description summary of proposal ~ Detailed operations program X BOP sketch 14. Estimated date for commencing operation January, 1989 16. If proposal was verbally approved Name of approver Mike Minder 1/17/89Dateapproved 15. status of well classification as: Oil X Gas ~ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed c-:~'~/,~ .... '~:.~.~'/;:.,,,..; ,..Z~:..../ Title ........ :' FOR COMMISSION USE ONLY Conditions of approval: Notify CommiSsion so representative may witness Plug integrity ~ BOP Test ~ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- ORIGINAL SIGNED BY Returnec~ Approved by order of the Commissi~¢l~'']IF- C. SMITH '~ C-~-'~~ ~ommissioner feet J Approval No. ¢~.~..~ O Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Well TBU K-6RD Re-Perforate KS 3 Objective Re-establish well productivity. The tool string will consist of perforating guns, CCL, and adequate weight bars. Current Status K-6RD is producing approximately 600 BFPD at a 57% water cut. Procedure 1. Obtain a representative 12-hour test prior to perforating. 2. Conduct a safety meeting. 3. MIRU E-line unit and lubricator. MU tool string. 4. Perforate the following intervals in 4 separate gun runs. Tie-in and shoot from CET depths shown in italic print below: Run No. Bench Interval (CEW-MD} Interval (D1L-MD) L~nuth SPF -- 1 B2 12841-12861' 12843-12863' 20' 4 2 B2 12821-12841' 12823-12843' 20' 4 3 B1 12777-12797' 12779-12799' ~20' 4 4 B1 12757-12777' 12759-12779' 20' 4 5. RD E-line unit. 6. Return K-6RD to production, and obtain a stabilized 12-hour well test. ARCo Alaska, Inc. adlng Bay Unit - King Salm~~ .atform WGII K-6RD APl#: ,.~)-73~20D88-01 Spud Date: 3-30-88 Completion Date: 7-25-88 Original RKB: 100' MSL Hanger Type: 4-1/2" FMC Top of Hemlock: 12748" Maximum Hole Angle: ,53° Annulus Fluid: Sea water Last Revised: 8-22-88 All Depths are RKB MD to Top of Equipment. Well Type: Producer New I~ Workover r-1 RKB to Hanger: 34.00' Angle at Perforations: 35° Reason: New Gauge Ring 7 10 11 4 5 8 12 13 14 15 16 9 17 18 Jewelry 1 291' 2 11444' 3 11446' 4 1169~ 5 11724' Camco TRPD 1 -A SSSV nipple: ID · 2.812' Offs straight slot Iocator w/19.43' seals, ID = 2.9' Otis WD perm. packer w/seal bore extension Camco "D" nipple: ID - 2.750" 3-1/2" Tubing Tall Casing and Tubing 6 13-3/8" 61~ 7 9-5/8" 5,3, 8 9-5/8" 47~ 9 7" 29~ 10 3-1/2' 9.3~ Grade Thread Z.9.R Bottom J-,.55 BTC ,.~' 2186' S-95 BTC 34' -1968' L-80 BTC .-1968' 11958' L-80 BTC 11674' 13089' L-80 DSS-HTC ~' 11724' Casing Casing Casing Uner IPC Tubing Gas Uti Information ~ Stn. TVD 2591' 1 246~ ._ _c~65'2 4295' 713(/ 3 ._r~_$2' Camco 3-1 851<~ 4 6668' Camco 3-1 9536' 5 7358' Camco 3-1 10297' 6 7864' Camco 3-1 10B43' 7 8209' Camco 3-1 11173" 8 8433' Camco 3-1 Camco 3-1/2" MMG2 1.5" R-20 I~K Camco 3-1 ~2' MMG2 1.5' R-20 R K ~2' MMG2 1.5" 1~-20 I~ K 12' MMG2 1.5" R-20 r~ K 12" MMG2 1.5" R-20 r~ K 12" MMG2 1.5" !~-20 r~ K 12" MMG2 1.5" R-20 I~ K 12" MMG2 1.5" R-20 R K 3/16' 1175 3/16' 1209 1/4" 1256 1/4" 1266 5/16' 1317 5/16' 1318 3/8" 1381 3/8" 1379 Perforation Data - DIL depths 12 Squeeze Perfs 1 _2060-__12064 4' SQZD 8-21-88 13 Squeeze Perfs 12650' 1' SQZD 14 1 12748/9534 12754,12807 53'8 15 2 12810/9576 12816-12874 53'8 3 12885/9647 not perforated 4 12964/9713 not perforated 5 no data not perforated Gauge Ring and RII Level Data 2.70' 13044' Tagged Fill 16 PBTD= 13042'MD 17 TOF= 13093' MD (Fish lost 6-15-88 during rig operations consists of the following equipment: BIT, DRILEX, XO, STB, DC, XO, D-JARS, 1 HWDP & UP-JARS) 18 'rD= 13276'MD Datum =9~ ~= 9450'~ = 12514' MD E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Master Valves Wellhead DML 7/22/88 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL r~ GAS [~ SUSPENDED [] ABANDONED [] SERVICE J~ 2. Name of Operator 7. Permit Number UNOCAL (ARCO Alaska, Inc. is sub-operator) 88-28 3. Address 8. APl Number P.0. Box 190247, Anchorage, AK 99519 50- 133-20088-01 -,, 4. Location of well at surface 9. Unit or Lease Name 736' FSL, 135' FEL, 5ec.17, TgN, R13W, 5H Trading Bay Unit At Top Producing Interval 10. Well Number N/A K-6RD At Total Depth 11. Field and Pool 1147' FNL, 2024' FWL, Sec.22, T9N, R13W, SM McArthur River Field 5. Elevation in feet (indicate KB, DF, etc.) ~ 6. Lease D~ignation and Serial No. Hemlock 0i 1 Pool RKB 100' [ ADL 18772 12' Date Spudded04/08/88* 13. Date T.D. Reached06/1 0/88 14' Date C°mp" Susp' °r Aband' ! 15' Water Depth' if °'fsh°re [ 16' N°' °f C°mpleti°ns07/24/88* N/A feet MSL 1 17. TotalD~th(MD+TVD) 18. Plug Back Depth (M~D)19. DirectionalSurvey I 20. Depth where SSSV set ~ 21. Thickness of Permafrost 13276~HD~10068~TVE 130~2~HD~ 9875~T~ 9YES~ NO ~ 291 ~ feet MD N/A . 22. Type El~tric or Other Logs Run CR/CCL~ DIL/SDT/GR/PHS~ GR~ CNL/DEN/CAL/GR~ CET/GR/CCL~ Cal/CR~...Gyro~ CRT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 7" 29.0~ L-80 11R7~' I~R~ R-l/?. ~n ~ C]as~ 0 ~ 5?5 ~ C' ~ss O (Latex) 24. Perforations open to Production {MD+TVD of Top and Bottom and 25. - ....... ~b~N~ R'E~OR'6' ' -" interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None 3-1/2" ... 1172~ ~ 11 ~6~ 26. AcID~ FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL'~MD) AMOUNT& KINDOF MATERIAL USED Plug f/~751~-~900~ 250 sx C~ass G Plug f/12622~1286 ~ 1~0 sx Class C ..... ,, , Plug f/12568~-1270 ~ 180 sx C~ass G Plug f/123~1~-1286{)~ ~00 sx Class C 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO TEST PERIOD ~ '"Fl°~ Tubing Casing Pressure CALCULATED~ I OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl {corr) Press. 24-HOUR RATE ~ , , 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. .~",~ ~ .... '~, w NOTE: Redr~]] operations began 0~/08/88, "' Form 10407 Submit in duplicat~ Rev. 7-1-80 CONTINUED ON REVERSE SIDE WC5/055.1 29. 30. GEOLOGIC MARKERS NAME N/A MEAS. DEPTH 31. LISTOF ATTACHMENTS Gyro (2 copies), Attachment, Well History TRUE VERT, DEPTH FORMATION TESTS Include interval rested, pressure data, all fluids recovered and grav:ty, GOR, and time of each phase. N/A 32, I hereby certify that the foregoing is true and correct to the best of my knowledge Environmental Engr. Date February 14, 1989 INSTRUCTIONS General' This form is designed for' subrnitting 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 depti~ measurements §iven in other spaces on this form and in any attachments. Item 16 and 24: if this well is cornpleted for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the 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: I'f no cores taken, indicate "none". Form 10-407 WC5/055.2 , ARCO Oil and Gas Company Daily Well History--Interim Inatructiolto: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report otficial or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and fotlowing setting of oil string until completion. District ICounty°r Parish ARCO Alaska, Inc. I KENAI BOROUGH Field ~Lease or Unit TRADING BA~ UNiT I K-6/K-6RD Complete record for each day while drilling or workover in progress KING SALMON Date and depth as of 8:00 a.m. 04/12/88 ( TD: 3774' ( ~8) SUPV: ML 04/13/88 ( 14 TD: 4490' ( 7.6) SUPV: ML 04/14/88 ( 15 TD: 4850' ( 350) SUPV: ML 04/15/88 ( 16 TD: 5270' ( 4 SUPV: ML 04/16/88 ( 17 TD,: 5548' ( 2"8) SUPV: ML 04/17/88 ( 181 TD: 4835' ( 0) SUPV: ML 04/18/88 ( 19] TD: 5007' ( 172) SUPV:ML 04/19/88 (20) TD: 5596' ( 58~) SUPV:ML The above is correct PREP TO RIH W/ BHA MW: 9.0 VIS: 40 RIH. DRLD 12-1/4" HOLE TO 3775'. CBU. POOH. PU AND MU BHA. DAILY: $29,609 CUM: $355,762 ETD: $355,762 EFC:$3,860,000 CHANGE BIT AND BHA RIH. WASH AND REAM TO 3774'. CBU. SURV. PUMP PILL. POOH. DAILY:S16,455 CUM:$372,217 MW: 9.0 VIS: 42 DRLD 12-1/2" HOLE TO 4490' CHANGE BIT AND BHA. ETD:S372,217 EFC:$3,860,000 DRLG MW: 0.0 VIS: 43 POOH. CHANGE BHA. RIH. DRLD 12-1/4" HOLE TO 4850' DAILY:S36,452 CUM:$408,669 ETD:S408,669 EFC:$3,860,000 DRLG MW: 9.0 VIS: 43 DRLD 12-1/4" HOLE TO 4948'. CBU. PUMP PILL. POOH. CHANGE BHA. RIH. REAM F/ 4446' TO 4948'. DRLG 12-1/4" HOLE TO 5270'. DAILY:S35,548 CUM:$444,217 ETD:S444,217 EFC:$3,860,0~0 POOH MW: 9.1 VIS: 41 DRILL 12-1/4" HOLE TO 5548'. CBU. POOH. TAKE MWD CHECK SURVEYS. LD BHA. RIH WITH OEDP TO 5325'. SPOT 17.5 PPG MUD FROM 5325'-4900'. PULL UP TO 4900'. MIX AND PUMP 250 SX CLASS G CEMENT FROM 4900'-4500' CIP @ 0330 HRS 4/16/88. POOH TO 13-3/8" CASING SHOE. CBU. POOH. DAILY:S24,805 CUM:$469,022 ETD:S469,022 EFC:$3,860,000 DRILLING MW: 9.0 VIS: 44 CBU @ 2186'. FINISH POOH LD EXTRA DP. WOC. PU BHA ~9 TEST MWD AND MOTOR. RIH TO 4000'. CBU. RIH TO 4500'. TAG CEMENT PLUG AND POLISH TO 4751'. SIDETRACK HOLE @ 4751' DRILL 12-1/4" SIDETRACK HOLE TO 4835' DAILY:S51,974 CUM:$520,996 ETD:S520,996 EFC:$3,860,000 REPAIRING MWD TOOL MW: 9.0 VIS: 44 DRILLING 12-1/4" HOLE WITH MUD MOTOR FROM 483'5-4858'. PUMP PILL. POOH. CHANGE OUT BHA. TIH. REAM FROM 4697'-4858'. DRILL 12-1/4" HOLE FROM 4858'-5007'. BIT PLUGGED. POOH. REPAIR MUD. DAILY:S26,684 CUM:$547,680 ETD:S547,680 EFC:$3,860,000 POOH MW: 9.2 VIS: 44 PU LC. TEST MUD. TIH. REAM 60' TO BOTTOM. DRILL 12-1/4" HOLE TO 5226'. ELECT WORK ON MUD PUMP PROBLEM. DRILL 12-1/4" HOLE TO 5235'. ELECT WORK ON MUD PUMP PROBLEM. DRILL 12-1/4" HOLE TO 5596'. DROP SURVEY. PUMP PILL. POOH. DAILY:$21,~$~ QUM:S568~815 ETD:~5~R~RI~ For form preparation a,~l distribution see Procedures ManuaJ/Section 10, Drilling, Pages 86 and 87 IDate ITitle IWell no. ARCO Oil and Gas Company Daily Well History--lnterin InstnJctlonl: This form ~s used during drilling or workover operations, If testing, coring, or perforating, show formation name in describing work performed. Number all drdl stem tests sequentially. Attach descrlphon of all cores. Work performed by Producing Section will be reported on "lflt~rlm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set, Submit weekly for workovers and following setting el oil strinG until completion. District Field ARCO Alaska, Inc. ICounty or Parish KENAI BOROUGH Lease or Unit K-6/K-6RD I State~K TRADING BAY UNIT well no, Date and depth as of 8:0/) a.m. 04/06/88 ( TD: 0'( SUPV:HP 04/07/88 ( TD: 0'( SUPV:ML 04/08/88 ( TD: 0'( SUPV:ML 04/09/88 ( TD: 2295'( SUPV:ML 04/10/88 ( TD: 3044'( SUPV:ML 04/11/88 ( TD: 3496'( SUPV:ML The above is correct Complete record for each day while drilling or workover in progress KING SALMON 7) 0) 8) O) RU FOR CMT JOB MW: 0.0 VIS: RD SOS/Ai~RS. PU 9-5/8" CSG CUTTER. TIH. CUT 9-5/8" CSG @ 2250' MD. CBU. TOH. REDRESSED SPEAR. PU SAME AND SPEARED 9-5/8" CSG. PULLED CSG FREE WITH 325M. BREAK OFF CSG HANGER. CIRCULATE BOTTOMS UP. LD 52 JTS 9-5/8" CSG. CFJ%NGED RAMS TO 5" AND TESTED. TIH. SPEARED CSG STUB @ 2250' JARRED ON SAME - UNABLE TO PULL FREE. RELEASED SPEAR. TOH. LD SPEAR AND 3 DC'S. PU 3-1/2" STINGER PIPE. TIH WITH OEDP. DAILY:S21,220 CUM:$196,383 ETD:S196,383 EFC:$3,860,000 9) 0) ,0) :295) 1) 749) 2) 452) LOGGING MW: 8.5 VIS: SPOTTED 375 SX CLASS G ON TOP OF RETAINER @ 2550' PULLED 8 STDS. REV. CIRC. DP. POOH. LDDP. PU CLEAN OUT ASSEMBLY. TIH. WOC. TESTED 13-3/8" CASING TO 1500 PSI. TIH. TAGGED TOC @ 2079'MD. DRILLED CMT F/2079'-2192'. RU SOS. RAN CET F/2150'-SURFACE. DAILY:S19,630 CUM:$216,013 ETD:S237,399 EFC:$3,838,614 CBU MW: 8.5 VIS: FINISHED RUNNING SOS CASING EVALUATION LOG TO 2186'. RD. RIH WITH MOTOR. DRILLED F/2192'-2250'. HIT CASING STUB. CBU. POH. RIH OPEN-ENDED TO 2250'. SPOTTED 225 SX CLASS G ON TOP OF CSG STUB. Cf? ~ :-3, 4/7/88. CBU. POH. WOC. TAGGED TOC @ 2195'. i i 'BU. DAILY:S24,600 CUM:$~.;., . ~TD:$261,999 EFC:$3,838,614 RIH W/ NEW BHA MW: 8.5 VIS: POOH. PU MWD AND RIH. PLUGGED & ABANDONED K-6 @ 1130 HRS, 4/8/88. SPUDDED K-6RD @ 1130 HRS, 4/8/88. KICK-OFF & DRILLED 12-1/4" HOLE F/2193'-2295' PLUGGED BHA. REV CIRC. POOH. CHANGE BHA. RIH. WORK THRU WINDOW. BHA PLUGGED. ATTEMPT TO CLEAR. POOH. CHANGE BHA. LD MUD MOTOR AND BENT SUB. PU ANGLE BUILD ASSY. RIH. DAILY:S20,469 CUM:$261,082 ETD:S261,082 EFC:$3,860,000 RIH W/ COND ASSY MW: 8.8 VIS: 38 FIN RIH. WASH AND REAM F/ 2228' TO 2295'. CHANGE OVER TO MUD. LEAK OFF TEST. EMW = 15 PPG. DRLD 12-1/4" HOLE TO 3044' CIRC BTMS UP. PUMP PILL. POOH. PULL WB. TEST BOPE. RIG DOWN TEST TOOLS. DAILY:S42,826 CUM:$303,908 ETD:S303,908 EFC:$3,860,000 RIH W/ MUD MOTOR MW: 9.0 VIS: 40 RIH. WASH AND REAM TO 3044' ClRC BTMS UP. PUMP PILL. POOH. CHANGE BHA. RIH W/ PACKED ASSY. DRLD 12-1/4" HOLE TO 3496' CIRC BTMS UP. PUMP PILL. POOH. DAIL~:$22,245 ~u~:$326, i53 E-YD;$326,153 ---;$3,860,000 Signature . IDate For form preparation and di,~ribution see Procedures Manual Se(~t~n 10, Drilling, Pages 86 and 87 ARCO Oil and Gas Company Daily Well History--Interim lnltrUCtlOnl: This form is used during drilling or workover operations, If testing, coring, or perforating, show formation name in describing work performed. Number ail drill stem tests sequentially. Attacll descriphon of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final complebon. Report official or representative test on "Final" form. I) Submit "Interim" sheets when filled out but not less frequently ti'lan every :30 days, or on Wednesday of the week in which oil strtng is set. Submit weekly for workovers and following setting of oH string until completion. District ICounty or Parish KENAI BOROUGH Lease or Unit K-6/K-6RD I Sfat~ Field ARCO Alaska, Inc. TRADING BAY UNIT Well no. Date and depth as of 8:00 a.m. 04/20/88 ( 2 TD: 5816'( SUPV:ML 04/21/88 ( 2 TD: 6445'( SUPV:ML 04/22/88 ( 2 TD: 6445'( SUPV:ML. 04/23/88 ( 2, TD: 7216'( ' SUPV:ML 04/24/88 ( 2~ TD: 7652'( SUPV:ML 04/25/88 ( 2( TD: 8194'( SUPV:ML 04/26/88 ( TD: 8412'( SUPV:HP Complete record for each day while drilling or workover in progress KING SALMON L) ~-20) DRILLING MW: 9.2 VIS: 40 LD BHA. REPAIR ELECTICAL FOR ~2 MUD PUMP AND DRAWWORKS. BOPE TEST TO 3000 PSI. PU BHA (BATTERY POWER MWD TOOL NOT OPERABLE LD SAME AND PU TURBINE POWERED MWD). TIH. BREAK CIRCULATION. DRILL 12-1/4" HOLE TO 5816'. DAILY:S19,736 CUM:$588,551 ETD:S588,551 EFC:$3,860,000 ~) ;29) REPAIR ROTARY TABLE MOTOR MW: 9.2 VIS: 45 DRILL 12-1/4" HOLE TO 6445'. CHECK ELECT PROBLEM WITH ROTARY TABLE. DROP SURVEY. PUMP PILL. POOH. REPAIR ROTARY TABLE MOTOR. DAILY:S22,129 CUM:$610,680 ETD:S610,680 EFC:$3,860,000 RIH MW: 9.1 VIS: 37 REPAIR BRUSHES ON ROTARY TABLE MOTOR. MU BHA. RIH. CHECK ROTARY TABLE. UNABLE TO GET ELECTRIC MOTOR TO WORK. MOTOR FIELD SHORT. CBU AND PUMP PILL. POOH TO CASING SHOE. CHANGE OUT ROTARY TABLE ELECTRIC MOTOR. RIH. DAILY:S20,924 CUM:$631,604 ETD:S631,604 EFC:$3,860,000 ) 71) DRILLING MW: 9.2 VIS: 42 WASHED AND REAMED TO 6445'. DRILLED TO 6903'. SHORT TRIP. DRILLED TO 7216'. DAILY:S21,405 CUM:$653,009 ETD:S653,010 EFC:$3,859,999 ) 36) SHORT TRIPPING MW: 9.2 VIS: 41 DRILLED 12-1/4" HOLE TO 7247'. CIRCULATE BOTTOMS UP. PUMPED PILL. DROPPED SURVEY. POH. CHANGED BIT & TIH. DRILLED TO 7652' CIRCULATE & SHORT TRIP FOR HOLE CONDITIONING. DAILY:S31,635 CUM:$684,644 ETD:S684,644 EFC:$3,860,000 ;) ,42) DRILLING MW: 9.2 VIS: 48 SHORT TRIP FOR HOLE CONDITIONING. DRILLED TO 8058'. PUMPED PILL & POH. CHANGED BHA. RIH. DRILLED 12-1/4" HOLE TO 8194'. DAILY:S19,235 CUM:$703,879 ETD:S703,880 EFC:$3,859,999 ) 18) RIH MW: 9.2 VIS: 42 DRILLED 12-1/4" HOLE TO 8412'. CBU. DROPPED SURVEY. PUMPED PILL. POOH. LD BHA. TESTED BOPE TO 3000 PSI. MU BHA & NEW BIT. RIH. DAILY:S28,738 CUM:$732,617 ETD:S732,618 EFC:$3,859,999 The above is correct Signature ,]~{ ~.."~% ~ For form preparatiot~ a6~l-distribution see Procedures M(~ual Section 10, Drilling, Pages 86 ~nd 87 ASSOCIATE ENGINEER ARCO Oil and Gas Company,~,," Daily Well History--Interim Instructions: This form ~S used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach descriPhon of all cores. Work performed by Producing Section will be reported on "interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or on Wednesday of the week in which oil str,ng is set. Submit weekly for workovers and following setting of oil strin(:3 until completion. District ICounty or Parish I ARCO Alaska, Inc. I KENAI BOROUGH Field I Lease or Unit TRADING BAY UNIT I K-6 /K-6~ Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. KING SALMON 04/27/88 (2.3) DRILLING MW: 9.3 VIS: 50 TD: 8772' ( lState 360) DRILLED TO 8772' CIRCULATE BOTTOMS UP. POH. CHANGED BIT SUPV: HP 04/28/88 ( 2 TD: 9128' ( SUPV: MAL 04/29/88 ( 3 356) & BHA. RIH. CUT DRILLING LINE. DAILY:S32,769 CUM:$765,386 POH, CHANGE OUT BIT DRILLED 12-1/4" HOLE TO 9128'. TOH. DAILY:S22,215 CUM:$787,601 RIH. ETD:S765,387 EFC:$3,859,999 MW: 9.3 VIS: 44 DROPPED SURVEY, PUMPED PILL. ETD:S787,601 EFC:$3,860,000 TIH MW: 9.2 VIS: 49 TD: 9388'( SUPV:MAL 04/30/88 ( 3 TD: 9640'( SUPV:MAL 05/01/88 ( 3, TD:10007' ( ~ SUPV:MAL 05/02/88 ( 32 TD:10258' ( ~ SUPV:MAL 05/03/88 ( 34 TD:10318' ( SUPV:MAL 05/04/88 ( 3[ TD:10601' ( SUPV:MAL :60) .) :52) :) 167) ,) :51) ) 60) ) 83) 05/05/88 (3() TD:10895'( 294) SUPV:HP CHANGED OUT BIT. TIH. DRILLED TO 9388'. POOH FOR BIT. CHANGED OUT STB & BIT. TIH. DAILY:S21,434 CUM:$809,035 ETD:S809,035 EFC:$3,860,000 DRLG MW: 9.2 VIS: 45 TIH AND DRLD 12-1/4" HOLE F/ 9388' TO 9594'. SHORT TRIP. DRLD 12-1/4" HOLE TO 9640'. DAILY:S19,720 CUM:$828,755 ETD:S828,755 EFC:$3,860,000 DRLG MW: 9.2 VIS: 49 DRLD 12-1/4" HOLE F/ 9640' TO 9787'. SHORT TRIP. DRLD 12-1/4" HOLE TO 10007' DAILY:S30,563 CUM:$859,318 ETD:S859,318 EFC:$3,860,000 TOH MW: 9.3 VIS: 47 DRLD 12-1/4" HOLE F/ 10007' TO 10101'. SHORT TRIP. DRLD 12-1/4" F/ 10101' TO 10258'. JUMPED BUSHING AND BACKED OFF DP. FISH DP AT 964'. CATCH FISH. TOH. DAILY:S21,206 CUM:$880,524 ETD:S880,524 EFC:$3,860,000 DRLG MW: 9.3 VIS: 47 TOH. LD HWDP. CHANGE OUT MWD. TIH. WASH AND REAM F/ 10091' TO 10258'. DRLD F/ 10258' TO 10318' DAILY:S32,982 CUM:$913,506 ETD:S913,506 EFC:$3,860,000 TIH DRLD 12-1/4" HOLE TO 10601'. POOH F/ BIT. PULL WEAR RING. SET WEAR RING. TIH. DAILY:S21,024 CUM:$934,530 DRILLING DRILL 12-1/4" HOLE TO 10895'. DAILY:S37,665 CUM:$972,195 MW: 9.2 VIS: 45 CIRC. DROP SURV. PUMP PILL. RU AND TEST BOPE TO 3000 PSI. ETD:S934,530 EFC:$3,860,000 MW: 9.2 VIS: 42 ETD:S972,195 EFC:$3,860,000 Well no. The above is correct Signature For form prepa;'~ion and distribution see Procedure~,,Manual Section 10, Drilling, Pages'.86 and 87 ITitle ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History--Interim Inatructione: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work oerformed. Number aH drill stem tests sequentially. Attach descmphon ol all cores. Work Derformed by Producing Section will be reporled on "interim" sheets until Iina[ completion. Report olficial or representative test on "Final" form, 1) Submit *'interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string iS set. Submit weekly for workovers and following setting of oil strinG until completion. District Field ARCO Alaska, Inc. County or Parish KENAI BOROUGH Lease or Unit K-6 /K-6RD TRADING BAY UNIT StatL Well no. Date and depth aa of 8:00 a.m. 05/06/88 ( TD: 11416' ( SUPV: HP 05/07/88 ( TD:11632' ( SUPV:HP 05/08/88 ( TD:11735' ( SUPV:HP 05/09/88 ( TD:11807' ( SUPV:HP 05/10/88 ( TD:11895' ( SUPV:HP 05/11/88 ( TD:11983' ( SUPV:HP 05/12/88 ( TD:11983' ( SUPV:ML 05/13/88 ( TD:11983' ( SUPV:ML Complete record for each day while drilling or workover in progress KING SALMON 7) 521) POOH DRLD 12-1/4" HOLE TO 11229'. TO 11416'. CIRC. POOH. DAILY:S25,486 CUM:$997,681 MW: 9.2 VIS: 57 SHORT TRIP. DRLD 12-1/4" HOLE ETD:S997,681 EFC:$3,860,000 ~8) 216) DRLG MW: 9.2 VIS: 46 POOH. CHANGE BHA. RIH. REAM F/ 5521' TO 5722'. DRLD 12-1/4" HOLE TO 11632' DAILY:S41,642 CUM:$1,039,323 ETD:S1,039,323 EFC:$3,860,000 9) 103) DRILLING MW: 9.2 VIS: 50 DRILL 12-1/4" HOLE TO 11716'. CBU. POOH. PU DRILEX MOTOR. RIH. ATTEMPT TO DRILL. HAVING SIGNAL PROBLEMS WITH MWD. DRILL 12-1/4" HOLE TO 11735' DAILY:S27,637 CUM:$1,066,960 ETD:S1,066,960 EFC:$3,860,000 0) 72) DRILLING MW: 9.2 VIS: 48 DRILL 12-1/4" HOLE TO 11771'. UNABLE TO DEBUG SIGNAL PROBLEM WITH MWD. POOH. CHECK MWD. TEST MOTOR AND MWD. DRILL 12-1/4" HOLE TO 11807'. DEBUG MWD SIGNAL AND PROCEED. DAILY:S26,307 CUM:$1,093,267 ETD:S1,093,267 EFC:$3,860,000 1) 88) REAMING MOTOR RUN MW: 9.2 VIS: 44 DRILL 12-1/4" HOLE WITH MUD MOTOR TO 11895'. POOH LD MUD MOTOR. RIH TO SHOE. TEST MWD. REAM MOTOR RUN. DAILY:S25,121 CUM:$1,118,388 ETD:Si, iI8,388 EFC:$3,860,000 2) 88) POOH FOR CASING MW: 9.2 VIS: 45 FINISH REAMING FROM 11700'-11895'. DRILL 12-1/4" HOLE TO 11983'. PUMP PILL. SHORT TRIP TO SHOE. RIH. CIRC AND CONDITION FOR CASING. DROP SURVEY. PUMP PILL . POOH FOR CASING. DAILY:S24,232 CUM:$1,142,620 ETD:S1,142,620 EFC:$3,860,000 MU CASING HANGER MW: 9.2 VIS: 44 POOH LD BHA. CHANGE TO 9-5/8" PIPE RAMS. RU TO RUN 9-5/8" CASING. RIH WITH 9-5/8" CASING TO 11958'. MU CASING HANGER. DAILY:S21,522 CUM:$1,164,142 ETD:S1,164,142 EFC:$3,860,000 4) RIH INSPECTING DP MW: 9.4 VIS: 45 FINISH RUNNING 9-5/8" CASING. RAN 48 JTS OF 539, S-95, BTC 9-5/8" CASING AND 248 JTS OF 47#, L,80, BTC 9-5/8" CASING. FC @ 11872'. FS @ 11958'. CEMENT CASING WITH 1050 SX 15.8 PPG CLASS G CEMENT. CIP @ 2000 5/12/88. CHANGE RAMS TO 5" TEST BOPE TO 3000 PSI. PU BHA. RIH BREAKING EACH CONN. INSPECTING DP. DAILY:S42,628 CUM:$1,206,770 ETD:S1,206,770 EFC:$3,860,000 The above is correct Signature .~ '~ (,,[,~7~.,%_., ,~-' c ~ t ~ .L~ For form prepar.~tion and distribution see Procedures~..~lanual Section 10, Drilling, Pages 86 and 87 ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drdl stem tests sequentially. Attach descriphon of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form, 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field ARCO Alaskaf Inc. TRADING BAY UNIT ICounty or Parish KENAI BOROUGH Lease or Unit K-6/K-6RD IStatI Date and as of 8:00 a.m. 05/14/88 ( 4 TD:11983' ( SUPV:ML 05/15/88 ( 4 TD:11988' ( SUPV:ML o5/16/88 ( TD:12151' ( SUPV:ML 05/17/88 ( TD:12482' ( SUPV:ML o5/18/88 ( TD:12823' ( SUPV:ML 05/19/88 ( TD:13190' ( SUPV:ML 05/20/88 ( TD:13298' ( SUPV:ML 05/21/88 ( TD:13298' ( SUPV:ML The above is correct Complete record for each day while drilling or workover ~n progress KING SALMON 5) 0) RIH, INSPECT DP RIH. INSPECT AND REFACE DP. MW: 0.0 VIS: DAILY;S296,825 CUM:$1,503,595 ETD:S1,503,595 EFC:$3,860,000 5) DRILLING MW: 9.2 VIS: 42 RIH. INSPECT AND REFACE DP. TAGGED TOP OF CMT @ 11215'. DRILLED CMT FROM 11215'-11872'. TESTED 9-5/8" CASING TO 3000 PSI. DRILLED FC, FS AND 5' NEW HOLE TO 11988'. PERFORMED LOT TO 13.5 PPG EMW. DAILY:S18,784 CUM:$1,522,379 ETD:S1,522,379 EFC:$3,860,000 ~7) 63) TIH MW: 9.1 VIS: 49 DRILLED 8-1/2" HOLE TO 12151' PUMPED PILL. TOH & CHANGED BIT. TESTED MWD. TIH. DAILY:S25,181 CUM:$1,547,560 ETD:S1,547,560 EFC:$3,860,000 ) 31) 341) TIH MW: 9.0 VIS: 44 TIH. CUT DRILLING LINE. DRILLED 8-1/2" HOLE TO 12482' INSTALLED REBUILT CAT-HEAD. PCOH. CHANGED OUT BHA. DAILY:S162,052 CUM:$1,709,612 ETD:S1,709,612 EFC:$3,860,000 DRILLING MW: 9.0 VIS: 51 CHANGED BHA. TIH. DP~:~~ "HOLE TO 12823' DAILY:S31,867 CUM:$i. ~ .... ?D:$1,741,479 EFC:$3,860,000 o) 367) DRILLING MW: 9.0 VIS: 47 DRILLED TO 13010'. DROPPED SURVEY. PUMPED PILL. TOH & CHANGED BHA. TIH. WASHED & REAMED 90' TO BOTTOM. CONTINUED DRILLING 8-1/2" HOLE TO 13190' DAILY:S30,775 CUM:$1,772,254 ETD:S1,772,254 EFC:$3,860,000 51) 108) WORKING STUCK PIPE MW: 9.0 VIS: 44 DRILLED 8-1/2" HOLE TO 13298'. DP BACKED OFF. SCREW INTO FISH AND WORK PIPE. DP PARTED WITH 625K PU @ 347'. BACKED OFF DP @ 1530'MD. TOH. LD OVERSHOT. TIH. SCREWED INTO DP @ 1530'. DAILY:S19,882 CUM:$1,792,136 ETD:S1,792,136 EFC:$3,860,000 52) o) POOH MW: 9.0 VIS: 44 PULL ON DP. NO JARRING ACTION. UNABLE TO PULL FREE. DP PULLED OUT OF BOX AT 1068' PU TRI-STATE SCREW IN SUB AND RIH. SCREW INTO PIPE. CIRC. SPOT OIL PILL. WORK PIPE. RIG UP STRING SHOT. PIPE BACKED OFF AT 13094'. RD WIRELINE. POOH. LD BAD JTS. DAILY:S27,688 CUM:$1,819,824 ETD:S1,819,824 EFC:$3,860,000 JWell no. Signature For form preparat~i6~-an'd-disiribution see Procedures M~l/nual Section 10, Drilling, Pages 8~'and 87 IDate [Tdio ,', -~ . L ' ' ." z" ASSOCIATE ENGINEER ARCO Oil and Gas Company Well History - Initial Report- Dail~ Instructiona: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO Alaska, Inc. Field TRADING BAY UNIT Auth. or W.O. no. AD6iT0 Operator ARCO Spudded or W,O. begun ACCEPT Date and depth es of 8:00 a.m. 03/31/88 ( TD: 0'( SUPV:HP 04/01/88 ( TD: 0'( SUPV:HP ICounty. par,sb or 0orough ISta~ KENAI BOROUGH Lease or Unit ADL: 18772 K-6/K-6RD Title ABANDON (K-6)/DRILL & COMPLETE (K-6RD) lWell no. 04/02/88 ( TD: 0'( SUPV:I{P 04/03/88 ( TD: 0'( SUPV:HP Date API: 50-133-20088 (K-6)/50-133-20099-01 (K-6RD) I ARCO W.I. Prior status if a Hour I 18' 0000 W.O. 03/30/88 1000 HRS 04/04/88 ( TD: 0'( SUPV:HP Complete record for each day reported KING SAT,MON NU BOPE MW: 8.8 VIS: FINISHED RIGGING UP. ACCEPTED RIG ~ 1000 HRS, 3/30/88. CUT TUBING @ 10570'. KILLED WELL. ND TREE. NU BOPE. DAILY:S61,975 * CUM:$61,975 ETD:S61,975 EFC:$3,860,000 0) TESTING BOPE MW: 8.8 VIS: . NU BOPE & TESTED TO 3000 PSI. LD TEST PLUG. CIRCULATE HOLE AND MONITORED. POOH. LD 4-1/2"/3-1/2" TUBING. CHANGED TO 5" PIPE RAMS AND TESTED BOPE TO 3000 PSI. DAILY:S16,718 CUM:$78,693 ETD:S78,693 EFC:$3,860,000 RU F/CMT SQUEEZE JOB MW: 8.8 VIS: FINISHED TESTING BOPE. MU 6" BIT & 7" SCRAPER. PU DP. RIH TO 10600' DPM.. CIRCULATE BOTTOMS UP. TOH. MU 7" CMT RETAINER. TIH SET RETAINER @ 10500'. ATTEMPTED TO TEST 9-5/8" & 7" CASING TO 1000 PSI. (FROM 1000 PSI TO 150 PSI IN 15 MINUTES) RU FOR CMT JOB. DAILY:S15,384 CUM:$94,077 ETD:S94,077 EFC:$3,860,000 o) o). ,) 0) LOGGING MW: 8.8 VIS: RU. UNABLE TO INJECT THROUGH RETAINER @ 10300'. SPOTTED 100 SX CLASS G ON TOP OF THE RETAINER. TOH. MU 7" RETAINER, TIH, AND SET @ 9200' DPM. TESTED 9-5/8" CASING AND LINER LAP TO 1000 PSI - OK. MIXED AND PUMPED 100 SX CLASS G CMT. SQUEEZED 4 BBLS THROUGH THE RETAINER; SPOTTED 160 BBLS ON TOP. TOH. RU SOS. RUNNING CNL/4000' TO SURFACE. DAILY:S14,094 CUM:$108,171 ETD:S108,171 EFC:$3,860,000 WORKING ON LOCKDOWN SCREW MW: 8.5 VIS: RAN CNL F/4000' TO SURFACE. TESTED 9-5/8" CASING TO 2500 PSI. TIH. REPLACED DRILLING LINE. LD 5" DP. RU SOS. PERF'D 9-5/8" CASING @ 2150'. REV. CIRC. 9-5/8" ANNULUS CLEAN. SPEARED AND LD 7" SPACER SPOOL. WORKED ON 9-5/8" LDS. DAILY:S42,904 CUM:$151,075 ETD:S151,075 EFC:$3,860,000 RU SOS/APRS MW: 0.0 VIS: TAPPED OUT LDS & REPLACED. SPEARED 9-5/8" CASING. STRETCHED CASING. CALC. FREE POINT @ 2035'. SET 9-5/8" CIBP @ 2550'. CUT 9-5/8" CASING @ 2450'. SPEARED CASING. UNABLE TO PULL CASING FREE. RAN FREEPOINT SURVEY. 100% FREE @ 2190'. STUCK @ 2240' DAILY:S24,088 CUM:$175,163 ETD:S175,163 EFC:$3,860,000 The above is correct For form preparation a~l~ distribution, see Procedures Manual~'Section 10, Signature Drilling, Pages 86 and 87. ASGOOIATE ENGINEER ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, Or Derforating. show formation name in describing work !3erformed. Number all drill stem tests secluenhally. Attach description of all cores. Work [~erformed by Producing Section will be rel3orted on "Interim" sheets until finat complehon. Report official or rel:,resentative test on "Final" form. 1} Submit "Interim" sheets when filled out but not less frequently than every 30 days, or on Wednesday of the week in which oil str~ng is set. Submit weekly for workovers and following sefting of oil strin§ until completion. District ARCO Alaska, Inc. IStateAK County or Parish KENAI BOROUGH Field ILease or Unit TRADING BAY UNIT I K-6 /K-6RD Date and depth Complete record for each day while drilling or workover in progress as of 8:0~3 a.m. KING SALMON Well no. 05/22/88 ( TD:13298'( SUPV:ML 05/23/88 ( TD:13298'( SUPV:ML 05/24/88 ( TD:13298'( SUPV:ML 05/25/88 ( TD:13298' ( SUPV:ML 05/26/88 ( TD:13298' ( SUPV:ML 05/27/88 ( TD:12680' ( SUPV:ML 05/28/88 ( TD:12778' ( SUPV:ML 3) RIH MW: 9.0 VIS: 43 POOH. INSPECTING EACH JT. PREP TO PICK UP FISHING BHA. PU DC AND HWDP AND RIH. CDL. RIH W/ SCREW IN BHA. DAILY:S15,489 CUM:$1,835,313 ETD:S1,835,313 EFC:$3,860,000 4) 0) ATTEMPT TO WORK DP MW: 9.0 VIS: 45 RIH. TAG FISH. WASH 30' TO TOP OF FISH. SCREW INTO FISH. ATTEMPT TO CIRC. RU WL. RIH W/ FREEPOINT. UNABLE TO GET PAST 12000'. POOH. CHANGE TOOLS. RIH. WORK THROUGH BRIDGE. POOH TIGHT. MU WL JARS AND SPANGS AND BIT. RIH WORK TO TOP OF MDC. POOH. ATTEMPT TO WORK JARS. DAILY:S15,239 CUM:$1,850,552 ETD:SI,850,552 EFC:$3,860,000 0) ATTEMP TO BACK OFF MW: 9.0 VIS: 44 WORK PIPE. MU SOS PERF GUNS AND RIH. ATTEMPT T0 PERF DC AT 13151'-13154'. WU LARGER GUNS. WORK PIPE. MU 2-1/8" GUNS. RIH PERF DC F/ 13151'-13154'. POOH. LOST GUN/CCL/SPINNER BARS AND 1/2 ROPE SOCKET. CBU. RU FREEPOINT. lST RUN FAILED. 2ND RUN INDICATED ALL DC STUCK. ATTEMPT 2 BACKOFF SHOTS AT 12864'. NO LUCK. ATTEMPT BACK OFF AT 12834' DAILY:S15,523 CUM:$1,866,075 ETD:S1,866,075 EFC:$3,860,000 6) POOH MW: 9.0 VIS: 44 ATTEMPT BACKOFF AT 12834. CIRC AND WORK PIPE. MU AND RIH W/ SIDE RING CHARGE. CUT HWDP AT 12860' POOH. RIH. SPOT BALANCED PLUG W/140 SX CLASS G AT 12860'- 12550' (APPROX). POOH. DAILY:S290,582 CUM:$2,156,657 ETD:S2,156,657 EFC:$3,860,000 7) 0) RIH MW: 9.0 VIS: 42 POOH INSPECTING DP. TEST BOPE. PU AND MU BHA AND RIH. DAILY:S34,270 CUM:$2,190,927 ETD:S2,190,927 EFC:$3,860,000 0) SIDETRACK W/ MUD MOTOR MW: 9.0 VIS: 49 FIN PU BHA. RIH INSPECTING HWD?. TIH. TAG CMT AT 12575'. DRLD CMT F/ 12575' TO 12622' ORIENT AND SIDETRACK. DRLG W/ MOTOR F/ 12622' TO 12680'. DAILY:S20,384 CUM:$2,211,311 ETD:S2,211,311 EFC:$3,860,000 9) 98) DRILLING MW: 9.0 VIS: 42 DYNADRILL 8-1/2" HOLE TO 12711'. POOH. CHANGE OUT BHA. TIH. DYNADRILL 8-1/2" HOLE TO 12778'. DAILY:S59,295 CUM:$2,270,606 ETD:S2,270,606 EFC:$3,860,000 The above is correct Signature ~¢~, (,/,.~ ,,~,~,/~,,,....~ For form prepar~l, t1~n and distribution see Procedures (M~anual Section 10, Drilling, Pages 86 and 87 ARCO Oil and Gas Company Daily Well History--Interim Inslructions: This form ~s used during drilling or workover operations, If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially, Attach description of all cores, Work performed by Producing Section will be reported on "Interim" sheets until final completion, Report official or representative test on *'Final" form. f) Submit "Interim" sheets when filled out but not less frequently than every 30 days. or (2) on Wednesday of the week in which oil string is set. Submit weekly tor workovers and following sethng of oil strinG until completion. District 1County or Parish 1State ARCO Alaska. Inc. KENAI BOROUGH AK Field ILoase or Unit [Well no. TR~nT~C~ ~A% [3NTT K-6 /K-6RD Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. 05/29/88 ( TD:12886' ( SUPV:ML 05/30/88 ( TD:12892'( SUPV:ML 05/31/88 ( TD:12892' ( SUPV:ML 06/01/88 ( TD:12500' ( SUPV:ML 06/02/88 ( TD:12740' ( SUPV:HP 06/03/88 ( TD:12100' ( SUPV:HP 06/04/88 ( TD:12208' ( SUPV:HP 06/05/88 ( TD:12341' ( SUPV:HP KING SALMON 0) 108) 1) 6) 2) 0) 3) 0) 4) 240) 5) 0) 6) 108) ;7) 133) TIH MW: 9.1 VIS: 46 DYNADRILL 8-1/2" HOLE TO 12882'. TOH. CHANGE BHA. TIH. DAILY:S34,195 CUM:$2,304,801 ETD:S2,304,801 EFC:$3,860,000 TOH MW: 9.1 VIS: 45 DYNADRILL 8-1/2" HOLE TO 12892'. PIPE TORQUED UP. PIPE TWISTED OFF @ 470'. SCREW INTO FISH @ 470'. BACK-OFF DRILL PIPE @ 1012'. TOOH. TIH AND SCREW INTO FISH @ 1012'. JAR PIPE OFF BOTTOM. WORK OUT OF HOLE TO SHOE. TOOH. DAILY:S46,525 CUM:$2,351,326 ETD:S2,351,326 EFC:$3,860,000 TOH MW: 9.2 VIS: 42 TOOH. INSPECTING DP. TIH WITH OEDP. TAG UP @ 12656'. SPOT 180 SX CLASS G CEMENT PLUG F/12340'-12703'. CIP @ 0130 3/31/88. CIRC HOLE VOLUME. TOH. DAILY:S30,498 CUM:$2,381,824 ETD:S2,381,824 EFC:$3,860,000 TIH WITH SIDETRACK ASSY MW: 9.1 VIS: 42 TIH. TAG UP @ 12340'. DRILL CEMENT TO 12500'. TOOH. PU SIDETRACK ASSEMBLY. TIH. DAILY:S24,250 CUM:$2,406,074 ETD:S2,406,074 EFC:$3,860,000 ATTEMPTING SIDETRACK MW: 8.9 VIS: 48 RIH WITH MUD MOTOR. TAG CEMENT @ 12568'. SIDETRACK & DRILL 12568'-12740' DAILY:S22,376 CUM:$2,428,450 ETD:S2,428,450 EFC:$3,860,000 CBU MW: 9.0 VIS: 42 MOTOR FOR SIDETRACK FROM 12740'-12862'. MOTOR AND BHA HANGING UP ON FISH. SIDETRACK UNACCEPTABLE. MIX AND PUMP PILL. pOoH. LD EXCESS HWDP. RIH. TAG FISH @ 12860'. BREAK CIRC. SPOT SIDETRACK PLU( F/12860'-12100'. PULL 12 .STANDS AND CIRCULATE. EST. TOC @ 12100' DAILY:S34,958 CUM:$2,463,408 ETD:S2,463,408 EFC:$3,860,000 DRILLING MW~ 8.9 VIS: 42 FINISHED CIRCULATING. POOH & LD 3-1/2" DP. TESTED BOPE. PU LOWSIDING/PLUG DRESSING ASSEMBLY. RIH. TAGGED PLUG @ 12202'. DRESSED AND ATTEMPT TO LOW SIDE. WORKED AND REAMED. DRILLED WITH MUD MOTOR TO 12208'. DAILY:S27,304 CUM:$2,490,712 ETD:S2,490,712 EFC:$3,860,000 POH FOR BENT SUB MW: 8.9 VIS: 43 DRILLED WITH MUD MOTOR TO 12278'. LD 2 JTS DP. REAMED TO 12278'. DRILLED TO 12341' PUMPED PILL. POH FOR BENT SUB TO MAKE CONFIRMED SIDETRACK. DAILY:S19,340 CUM:$2,510,052 ETD:S2,510,052 EFC:$3,860,000 The above is correct Signature For form prepar~on and distribution see Procedures/~anual Section 10, Drilling, Pages 86 and 87 A~.'.~OOIATE ENGINEER ARCO Oil and Gas Company Daily Well History--Interim Instructione: This form iS used during drilling or workover operations. If testing, coring, or perforahng, show formation name in describing work performed. Number ail drill stem tests sequentially. Attac~ description of all cores. Work performed by Producing Section will be reported on "interim" sheets until final completion· Report official or representative test on "Finel" form, 1} Submit "Interim" sheets when hlled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strinG until completion. District Field ARCO Alaska, Inc. lCounty or Parish KENAI BOROUGH Lease or Unit K-6 /K-6RD IState~ TRADING BAY UNIT Well no. Date and del3tll as of 8:00 a.m. 06/06/88 ( TD:12365' ( SUPV:HP 06/07/88 ( TD:12365' ( SUPV:HP 06/08/88 ( TD:12864' ( SUPV:HP 06/09/88 ( TD:13085'( SUPV:MAL 06/10/88 ( TD:13276' ( SUPV:MAL '06/11/88 ( TD:13276' ( SUPV:MAL 06/12/88 ( TD:13276' ( SUPV:MAL 06/13/88 ( TD:13276' ( SUPV:MAL Complete record for each day while drilling or workover in progresa KING SALMON 8) 24) 9) 0) 0) 499) 1) 221) 2) 191) 3) 0) '4) O) The above is correct '5) 0) ORIENT AND DRILL MW: 9.0 VIS: 43 POH. SERVICED AND CHANGED BIT. RIH. REAMED TO 12341'. SIDETRACKED & DRILLED F/12341'-12353'. REPAIRED SURFACE MWD ELECTRONICS. ORIENT AND DRILLED TO 12365' DAILY:S29,535 CUM:$2,539,587 ETD:S2,539,587 EFC:$3,860,000 RIH DRILLED TO 12446' BHA. RIH. DAILY:S31,645 MW: 9.0 VIS: 42 REAMED. PUMPED PILL AND POH. CHANGED CUM:$2,571,232 ETD:S2,571,232 EFC:$3,860,000 DRILLING MW: 9.0 VIS: 43 REAMED SIDETRACK MOTOR RUN. DRILL & SLIDE TO 12864'. DAILY:S26,892 CUM:$2,598,124 ETD:S2,598,124 EFC:$3,860,000 MAKE SHORT TRIP MW: 9.1 VIS: 43 DRILLED 8-1/2" HOLE TO 12896'. PUMPED PILL. TOH. CHANGED BHA. TIH. REAMED TO 12896' CONTINUED DRILLING 8-1/2" HOLE TO 13085'. DAILY:S26,876 CUM:$2,625,000 ETD:S2,625,000 EFC:$3,860,000 TOH MW: 9.0 VIS: 54 SHORT TRIP TO SHOE (9-5/8") . TIH TO 12638'. REAMED SINGLES TO 13085' DRLD 8-1/2" HOLE TO 13276'. CIRCULATE. DROPPED SURVEY. TOH. DAILY:S32,753 CUM:$2,657,753 ETD:S2,657,753 EFC:$3,860,000 WORK AND JAR STUCK PIPE MW: 9.0 VIS: 54 FIN TOH. CHANGE BHA. TEST BOPE TO 3000 PSI. CUT DRILL LINE. TIH. REAM F/ 12728' TO 13175'. STUCK AT 13175' JAR AND WORK FREE. REAM TIGHT SPOT AT 13175'. STUCK AT 13219'. SPOT MINERAL OIL PILL. WORK AND JAR STUCK PIPE. DAILY:S26,099 CUM:$2,683,852 ETD:S2,683,852 EFC:$3,860,000 WORK AND JAR STUCK PIPE MW: 9.0 VIS: 49 WORK AND JAR ON STUCK PIPE. DP PARTED AT 197'. FLY OUT FISHING TOOLS. PU OS. RIH AND CATCH DP STUB. BACK OFF AT 800'. PU 26 JTS DP. RIH AND SCREW INTO DP AT 800'. JAR ON STUCK PIPE. DAILY:S23,104 CUM:$2,706,956 ETD:S2,706,956 EFC:$3,860,000 PREP TO BACK OFF MW: 9.0 VIS: 41 CIRC AND WORK AND JAR ON STUCK PIPE. SPOT 50 BBLS MINERAL OIL PILL ON BTM. JAR ON STUCK PIPE. RU APRS AND RUN FREE PT SURVEY. FREE TO BTM OF D-JARS. MU STRING SHOT. PREP T0 BACK OFF AT D-JARS. Signature For form prepa/~on and distribution see Procedur~fsJManual Section 10, Drilling, Page~86 and 87 Date ITitle ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. Il testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially, Attach descripuon of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of Oll string until completion. District ICounty or Parish IStatL ARCO Alaska. Inc. KENAI BOROUG~ Field JLease or Unit TR;~nT~C. ~A~ UNIT I K-6 /K-6RD Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. 06/14/88 ( TD: 13276' ( SUPV: MAL 06/15/88 ( TD: 13276' ( SUPV:MAL 06/16/88 TD: 13276' SUPV:MAL 06/17/88 ( TD: 13296' ( SUPV:MAL 06/i8/88 ( TD:13296' ( SUPV: HP 06/19/88 ( TD=13296' ( SUPV:HP 06/20/88 ( TD:13296' ( SUPV:HP 06/21/88 ( TD:13296' ( SUPV:HP ~ING SALMON 6) 0) 7) 0) 8) O) 9) 20) o) 0) :1) o) :2) o) o) PREP TO CUT DS MW: 9.0 VIS: 41 ATTEMPT TO BACK OFF PIPE. NO GOOD. DRL STRING TURNING ON MUD MOTOR. RD SOS/ APRS. ROTATE AND JAR ON STUCK PIPE. RU APRS AND ATTEMPT TO CUT DRL STRING AT 13187'. DAILY:S25,200 CUM:$2,770,781 ETD:S2,770,781 EFC:$3,860,000 TOH MW: 9.0 VIS: 48 SEVER DRL STRING AT 13187'. UNABLE TO PULL FREE. RUN FREE POINT SURVEY. PIPE FREE TO BTM OF UP-JAR AT 13110' WLM. BACK OFF DP AT TOP OF UP-JAR AT 13090' WLM. CIRC OUT MINERAL OIL PILL. TOH. DAILY:S129,248 CUM:$2,900,267 ETD:S2,900,267 EFC:$3,859,762 RIH W/ SCREW IN SUB MW: 9.0 VIS: 45 MAKE gOND RUN TO TOP OF FISH. PU SCREW IN SUB AND JARS. RIH. DAILY:S16,773 CUM:$2,917,040 ETD:S2,917,040 EFC:$3,860,000 PREP FOR BACKOFF ATTEMPT MW: 9.0 VIS: 44 RIH. SCREW INTO FISH. ATTEMPT TO JAR FREE. ATTEMPT TO BACKOFF AND JAR. SET UP FOR 2ND BACKOFF ATTEMPT. DAILY:S21,308 CUM:$2,938,348 ETD:S2,938,348 EFC:$3,860,000 RUNNING LOGS MW: 9.0 VIS: 44 BACK OFF @ 13094'. POOH. LD FISHING BHA. LEFT SCREW IN SUB IN HOLE. NEW TOF @ 13093'. CIRCULATE AND CONDITION HOLE FOR LOGS. RIH WITH DIL SONIC TO 12200'. TOOL FAILURE. POOH. REHEAD LINE. DAILY:S34,795 CUM:$2,973,143 ETD:S2,973,143 EFC:$3,860,000 LOGGING OPEN HOLE MW: 9.0 VIS: 45 ATTEMPT WIRELINE LOGS. UNABLE TO GET BELOW 12200'. RIH WITH DRILL PIPE AND CLEAN OUT TO TOF. REAM TIGHT SPOTS. CIRC. POOH. RU DRILL PIPE CONVEYED LOGS. DAILY:S18,966 CUM:$2,992,109 ETD:S2,992,109 EFC:$3,860,000 LOGGING OPEN HOLE MW: 9.0 VIS: 46 RIH WITH LOGGING TOOLS ON DP. RIH WITH WL. UNABLE TO LATCH UP. POOH WITH WL AND DP. REPAIR CONNECTOR. RIH WITH DP AND LOGGINGS TOOLS. RIH WITH WL FOR LATCH UP. DAILY:S15,633 CUM:$3,007,742 ETD:S3,007,742 EFC:$3,860,000 RU DP CONVEYED LOGS MW: 9.1 VIS: 44 RIH WITH WL. COULD NOT MAKE CONNECTION WITH LOGGING TOOL. POOH WITH WL AND DP. RD WL. CIRCULATE AND CONDITION HOLE FOR LOGS. POOH. RU SOS DP CONVEYED LOGGING TOOLS. DAILY:S15,633 CUM.?$3,023,375 ETD:S3,023,375 EFC:$3,860,000 Well no. The above is correct Signature For form prep~ation and distribution see Procedu~;l Manual Section 10, Drilling, Page§ 86 and 87 [ate ASSOCIATE ENGINEER Ti ti e ARCO Oil and Gas Company Daily Well History--Interim Instruction,: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completton, Report official or representative test on "Final" form. t) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of od string until completion. District ICounty or Parish Stat1 ARCO Alaska. Inc. KENAI BOROUGH Field ILease or Unit T~N~ ~A~ UNITI K-6 /K-6RD Date and deptl~ Complete record for each day while drilling or workover in progress as of 8:00 a.m. 06/22/88 ( TD:13296' ( SUPV:HP 06/23/88 ( TD:13296' ( SUPV:GC 06/24/88 ( TD:13296'( SUPV:GC 06/25/88 ( TD:13296' ( SUPV:GC 06/26/88 ( TD:13296' ( SUPV:GC 06/27/88 ( TD:13296' ( SUPV:GC 4) 0) 5) 0) 6) 0) 7) 0) ~8) 0) ~9) 0) The above is correct Signature / For form prepar~ion and distribution see Procedure~anual Section 10. Drilling, Pages 86 and 87 no. SALMON RIH WITH CLEAN OUT ASSEMBLY MW: 9.1 VIS: 43 RIH WITH DRILL PIPE CONVEYED LOGGING TOOLS. RIH WITH WL. LATCH AND POWER UP LOGGING TOOLS. LOG DIL/SONIC FROM 11958'-12722'. LOST POWER. ATTEMPT TO POOH WITH WIRELINE. WIRELINE STUCK. POOH WITH DRILL PIPE CUTTING WL EACH STAND. RIH WITH SLICK CLEAN OUT BHA. DAILY:S130,633 CUM:$3,154,008 ETD:S3,154,008 EFC:$3,8~:0,000 TIH WITH WIRELINE MW: 9.3 VIS: 45 MADE CONDITIONING RUN. RAISED MW TO 9.2 PPG. POOH. PUMPED PILL @ CASING SHOE. PU SOS LOGGING TOOLS DIL/SONIC. RIH WITH WIRELINE THROUGH SIDE DOOR SUB. DAILY:S20,212 CUM:$3,174,220 ETD:S3,174,220 EFC:$3,860,000 POOH WITH LOGGING TOOLS MW: 9.3 VIS: 45 RIH WITH WL AND LATCHED LOGGING TOOLS. LOG DIL/SDT/GR/PMS FROM 11845'-13069'. COULD NOT GET BELOW 13069'. POOH. RIH WITH WL AND LATCHED LOGGING TOOLS. LOG CNL/DEN/CAL/GR FROM 11845'-12096'. COULD NOT GET BELOW 12096'. UNLATCHED AND POOH FOR WIPER TRIP. DAILY:S15,216 CUM:$3,189,436 ETD:S3,189,436 EFC:$3,860,000 RIH MW: 9.3 VIS: 44 CONTINUED POOH FOR WI?E9 ' ' '~ LOGGING TOOLS. TIH TO 9-5/8" SHOE. CUT DPi:.i.:'. :.EAMED FROM 12200' TO 12360'. CIRCULATE HI-V: . hO EXTRA CUTTING. SHORT TRIP TO SHOE - NO PROBLEMS. POOH - STOOD BACK BHA. PU CNL/DEN/CAL/GR AND TIH. RIH WITH WL TO LATCH TOOLS. DAILY:S17,532 CUM:$3,206,968 ETD:S3,206,968 EFC:$3,860,000 POOH WITH WL & LD SOS MW: 9.3 VIS: 44 CONTINUED RIH WITH WL & LATCHED LOGGING TOOLS. RAN DP AND TOOLS TO 12120' - TOOLS STOPPED. WORKED DOWN TO 13074; CNL/DEN WAS NOT WORKING. LOGGED CAL/GR F/13074' TO CASING SHOE. POOH WITH WL & LD SOS. POH WITH LOGGING TOOLS. LD SAME. REPLACED CNL/DEN/CAL/GR. TIH. LOGGED GR DOWN TO 13072'. LOGGED UP FULL COMBO TO CASING SHOE. POOH WITH WL. LD SIDE DOOR SUB. DAILY:S15,466 CUM:$3,222,434 ETD:S3,222,434 EFC:$3,860,000 RIH W/7" LINER MW: 9.3 VIS: 44 FINISHED POOH WITH WL & LD SIDE DOOR SUB. POOH WITH DP. LD LOGGING TOOLS. PU SAME MOTOR & BIT; TIH TO SHOE. TIH TO 50' FROM BOTTOM. WASHED TO 13093'. CIRCULATE BOTTOMS UP. SHORT TRIP TO SHOE. CIRC. SWEEP AROUND AND SPOTTED PILL IN OPEN HOLE. POOH TO SHOE. PUMPED SLUG. POH & LD MOTOR. RU TO RUN 7" LINER. RAN 32 JT 7", 29~, L-80, BTC CASING. DAILY:S18,536 CUM:$3,240,970 ETD:$3,~4U,9/U ~FC:~,~U,UO~ JDate ,.:? ~']--"' ASSOCIATE ENGINEER . ARCO Oil and Gas Company '~'v Daily Well History--lnterir~ Inalructionl: This form is used during Orilling or workover operations. If testing, coring, or perforating, show formation name in describing work oerformecl. Number all drill stem tests sequentiat~¥. Attach descn~3bor~ of alt cores. Work performed by Producing Section will be reported on "Interim" sheets until final complehon. Report official or representative test on "Final" form. 1) Submit *'Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovera and following setting of oil string until completion. District KENAI BOROUGH Lease or Unit K-6/K-6RD Field ARCO Alaska, Inc. JWell no. TRADING BAY UNIT Date and depth as of 8:00 a.m. 06/28/88 ( 9 TD: 13296' ( SUPV: GC 06/29/88 ( 9 TD:13296' ( SUPV:GC 06/30/88 (9:) TD:13296'( SUPV:HP 07/01/88 ( 9~ TD:13296' ( SUPV:HP 07/02/88 ( 94 TD:13296 PB: SUPV:HP 07/03/88 ( 95 TD:13296 PB:13042 SUPV:HP 07/04/88 ( 9E TD:13296 PB:13042 SUPV:HP Complete record for each day while drilling or workover in progress KING SALMON o) .) o) CHANGE OUT KELLY SPINNER MW: 9.3 VIS: 44 FINISHED RUNNING 7" LINER F/11674'-13089' CEMENTED LINER WITH 60 SX CLASS G & 525 SX CLASS G (LATEX). PACKED OFF. SET LINER WITH 37 BBLS OUT OF SHOE. RELEASED FROM LINER. SQUEEZED 15 BBLS (72 SX CLASS G (LATEX)) INTO LINER LAP. POOH. TESTED BOPE. CHANGED KELLY SWIVEL AND PU SPINNER. DAILY:S42,115 CUM:$3,283,085 ETD:S3,283,085 EFC:$3,860,000 DRILLING CMT IN LINER MW: 9.1 VIS: 43 FINISHED HOOKING UP ON KELLY SPINNER. PU BHA. CUT DRILL LINE. TIH AND TAG CMT STRINGERS @ 10903'. WASHED TO 11380'. DRILLED CMT F/11380'-11668' TAG TOL @ 11668' DPM. CIRCULATE BOTTOMS UP. TOH. LD 48 JT 5" DP. CHANGED BHA. TIH. DRILLED CMT F/11668'-11674' DAILY:S40,905 CUM:$3,323,990 ETD:S3,323,990 EFC:$3,860,000 RIH MW: 8.9 VIS: 34 DRILLED CEMENT F/11674'-12298'. PUMPED PILL AND POH. CHANGED BHA. RIH. DAILY:S15,856 CUM:$3,339,846 ETD:S3,339,846 EFC:$3,860,000 CIRC. & CLEAN HOLE MW: 8.5 VIS: FINISHED TIH. DRILLED CEMENT F/12298'-13042'. CIRCULATE AND DISPLACE HOLE WITH CLEAN FILTERED INLET WATER. DAILY:S15,063 CUM:$3,354,909 ETD:S3,354,909 EFC:$3,860,000 RUNNING GYRO DISPL HOLE TO FRESH WATER. POOH. 13038'. RUN CAL/GR F/ 0-11674' MW: 8.5 FW RUN CET/GR/CCL F/ 11642' TO RUN GYRO F/ 0' - 13038' DAILY:S14,400 CUM:$3,369,309 ETD:S3,369,309 EFC:$3,860,000 RIH W/ RET. MILL MW: 8.5 FW FIN RUNNING GYRO. TEST LNR LAP. RIH. PERF F/ 12650' TO 12652' RIH W/ SQUEEZE RET. SET AT 12630'. UNABLE TO EST INJ OR CIRC FOR CMT SQUEEZE. POOH. PU MILL AND RIH. DAILY:S21,157 CUM:$3,390,466 ETD:S3,390,466 EFC:$3,860,000 RIH W/ RET RIH. MILL RETAINER. CIRC. PERF F/ 12650' TO 12654' MW: 8.5 FW POOH. RE-RUN GYRO. RIH AND RIH W/ RETAINER. DAILY:S14,400 CUM:$3,404,866 ETD:S3,404,866 EFC:$3,860,000 The above is correct Signature ,, For form prepare~{o~ and distribution see Procedures/l~anual Section 10, Drilling, Pages~S& and 87 Date ITitle J', -1'? -?". ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all dnil stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 11 Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set, Submit weekly for workovers and following setting of oil strinG until completion. ARCO Alaska, Inc. I KENAI BOROUGH Field ILease or Unit ~-6/~:-6~ TRADING BAY UNIT Date and depth as of 8:00 a.m. 07/05/88 ( TD:13296 PB:13042 SUPV:HP 07/06/88 ( 8) TD:13296 PB:13042 SUPV:HP 07/07/88 (9) TD:13296 PB:13042 SUPV:GC 07/08/88 (1 O) TD:13296 PB:13042 SUPV:GC 07/09/88 (1(1) TD:13296 PB:13042 SUPV:GC 7/11/88 (102) TD:13296 PB:13042 SUPV:GC 07/10/88 (1(2) TD:13296 PB:13042 SUPV:GC Complete record for each day while drilling or workover in progress KING SALMON RIH W/ RETAINER MW: 8.5 FW RIH. SET RETAINER AND CIRC. SQUEEZE 170 SX CLASS G CMT. CIP AT 1030 HRS 7/04/88. POOH. SHOOT 2ND SQUEEZE PERFS AT 12060' TO 12064' RIH. ATTEMPT TO SET RET. SETTING TOOL MALFUNCTION. POOH. RIH W/ NEW SETTING TOOL AND RET. DAILY:S84,375 CUM:$3,489,241 ETD:S3,489,241 EFC:$3,860,000 RIH W/ 6" BIT MW: 8.5 FW RIH. PERFORM LNR LAP SQUEEZE W/ 170 SX OF CLASS G F/ 12060' TO 11674'. POOH. TEST BOPE. RIH AND CLEAN OUT TO TOP OF LNR. POOH. RIH W/ 6" LNR CLEAN OUT BHA. DAILY:S26,146 CUM:$3,515,387 ETD:S3,515,387 EFC:$3,860,000 POOH AFTER SQUEEZE MW: 8.5 FIW TIH WITH 6" BIT. DRILLED FROM 11668'-11957'. CIRCULATED. TESTED LINER LAP TO 2500 PSI; 650 PSI LOSS IN 10 MINUTES. ATTEMPTED TEST 3 TIMES. POOH. TIH WITH 6 JTS 3-1/2" AND 5" CIRCULATED. MIXED AND PUMPED 125 SX CLASS G PLUG. SQUEEZED. POOH WITH DP. DAILY:S176,341 CUM:$3,691,728 ETD:S3,691,728 EFC:$3,860,000 TIH W/ 5" DP MW: 8.5 FIW POOH. TIH W/ BIT. TEST CSG TO 2500 PSI. GOOD~ TIH. TAGGED CMT AT 11586'. DRLD TO 11674'. TESTED LINER LAP. LEAKED. POOH. TIH W/ 5" MULESHOE TO SQZ AGAIN. DAILY:S15,550 CUM:$3,707,278 ETD:S3,707,278 EFC:$3,860,000 POOH WITH 8-1/2" BIT MW: 8.5 FIW TIH WITH 5" MULESHOE, CIRC. CEMENT 100 SX CLASS G BALANCED PLUG. POOH 10 STDS. SQUEEZE TO 2560 PSI. HELD 5 HRS. 3/4 BBLS CMT IN LAP. POOH. PU 8-1/2" BIT. TIH. TAGGED @ 11517' DRILL CEMENT FROM 11517'-11667'. CIRC. POOH. DAILY:S21,078 CUM:$3,728,356 ETD:S3,728,356 EFC:$3,860,000 POOH WITH 6" BIT MW: 8.5 FIW POOH. TIH WITH 6" BIT. DRILL CEMENT TO 11960'. TESTED LINER LAP TO 2500 PSI. GOOD. DRILL CEMENT AND RETAINER TO 12100' TEST PERFS 12060'-12064' TO 2500 PSI . LEAKED 600 PSI IN 10 MIN 3 TIMES. CIRC. POOH WITH 6" BIT. DAILY:S14,400 CUM:$3,742,756 ETD:S3,742,756 EFC:$3,860,000 TIH WITH 6" BIT MW: 8.5 FIW TOH. TIH WITH EZSV. SET SAME @ 12100'. CIRC. PUMPED 9 BBLS WATER, 21 BBLS CEMENT, 3 BBLS OF WATER, 192 BBLS OF MUD. POOH 10 STANDS. SQUEEZE 7-1/4 BBLS OF CEMENT. HELD 4 HRS. RELEASED AND POOH. TIH WITH 6" BIT. DAILY:S26,411 CUM:$3,769,167 ETD:S3,769,167 EFC:$3,860,000 JWell no. The above is correct For form preparation ~d distribution see Procedures Man~ Section 10, Drilling, Pages 86 and 87 Date ITM ,, ~,&Sa(~CIATE ENGINEER I ~:-/':?-~.':(:D IF.. (' ii,.~ ~ "i:~:i" !t'"' ~,~ ~\L.~.,~ ...... ~, . ..... DEC l 9 ARCO Oil and Gas Company,~,, Daily Well History--Interim instructions: This term is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report olficial or representative test on "Finel" form. 1} Submit "Interim" sheets when hlled out but not less frequently than every :30 days, or (2) on Wednesday of the week in whicl't oil String is set. Submit weekly for workovers and following setting of oH strinG until completion. Distr~ct Field ARCO Alaska, Inc. tCounty or Parish KENAI BOROUGH Lease or Unit K-6 /K-6RD I Stat~.K TRADING BAY UNIT JWell no. Date and depth as of 8:00 a.m. 07/12/88 (1( TD:13296 PB:13042 SUPV:GC 07/13/88 (1( TD:13296 PB:13042 SUPV:GC 07/14/88 (10 TD:13296 PB:13042 SUPV:HP 07/15/88 (1 TD:13296 PB:13042 SUPV:HP 07/16/88 (1 TD:13296 PB:13042 SUPV:HP 07/17/88 (1 TD:13296 PB:13042 SUPV:HP 07/18/88 (11 TD:13296 PB:13042 SUPV:HP Complete record for each day while drilling or workover in progress KING SALMON o) POOH WITH 6" BIT MW: 8.5 FIW TIH. TAGGED @ 11810'. DRILL CEMENT TO 12000'. WOC. DRILL CEMENT TO 12100'. TESTED PERFS TO 2510 PSI FOR 30 MINUTES. DRILLED EZSV AND PUSHED TO 12567'. DRILLED EZSV AND CEMENT TO 12585'. CIRCULATE OUT CEMENT. POOH WITH 6" BIT. DAILY:S30,889 CUM:$3,800,056 ETD:S3,800,056 EFC:$3,860,000 RIH WITH OEDP MW: 8.5 FIW POOH. TEST BOPE. RIH. DRILL CEMENT AND RETAINER. TEST PERFS. LOST 900 PSI IN 30 MIN. RIH. DRILL HARD CEMENT TO 12692'. CIRCULATE HOLE CLEAN. POOH. RIH WITH OEDP. DAILY:S14,400 CUM:$3,814,456 ETD:S3,814,456 EFC:$3,860,000 WOC MW: 8.5 FIW RIH. TAG CEMENT PLUG @ 12692'. PUMP BALANCED CEMENT PLUG. REVERSE CIRCULATE DP CLEAR. SQUEEZE PLUG. POOH. WOC. DAILY:S21,971 CUM:$3,836,427 ETD:S3,836,427 EFC:$3,860,000 POOH MW: 8.5 FIW WOC. TEST CMT FOR HARDNESS. WOC. DRLD CMT. TEST PERF TO 2500 PSI. OK. DRLD TO PBTD AT 13042' CIRC. POOH. DAILY:S15,200 CUM:$3,851,627 ETD:S3,851,627 EFC:$3,860,000 RIH W/PERF TEST STRING MW: 8.5 FIW POH. RIH W/ SCRAPER. CHANGE OUT HOLE TO CLEAN COMPL FLUID. POH. MU PERF AND TEST STRING. RIH. DAILY:S14,480 CUM:$3,866,027 ETD:S3,866,027 EFC:$3,860,000 POH W/ PERF-TEST STRING MW: 8.5 FIW RIH W/PERF TEST-STRING. ATTEMPT TO PERF AND TEST FORM. NO INDICATIONS OF GUNS FIRING. SUSPEND TESTING. POH W/PERF-TEST STRING. DAILY:S14,400 CUM:$3,880,427 ETD:S3,880,427 EFC:$3,859,802 EVALUATE WELL MW: 8.5 FIW POH. REPLACE FAILED TBG ISOLATION VALVE. MU NEW PERF-TEST STRING. RIH. CORRELATE AND SET PKR. RU SURFACE EQUIP FOR TEST. ATT TO FIRE GUNS - NO INDIC. THAT GUNS FIRED. PROCEED WITH TEST TO SEE IF GUNS FIRED. DAILY:S14,400 CUM:$3,894,827 ETD:S3,894,827 EFC:$3,860,000 The above is correct Signature For form prel~'ation and distribution see Procedur~Jl Manual Section 10, Drilling, Pages 86 and 87 ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during (~rllling or workover operations, if testing, coring, or perforating, show formation name in describing work performed. Number all drdl stem tests sequentially. Attach descriphon of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form, 1) Submit "Interim" sheets when filled out but not less frequently than every :30 days, or (2) on We(~nesday of the week in which oil string is set. Submit weekly for workoverS and following setting of oil strincj until completion. District Field TRADING BAY Date and depth as of 8:00 a.m. I County or Parish I KENAI BOROUGH ARCO Alaska, Inc. ILeas. or Unit I UNIT I K-6 /K-6RD Complete record lor each clay while clriHing or workover in progress 07/19/88 (11 TD:13920 PB:13042 SUPV:HP O7/2O/88 TD:13920 PB:13042 SUPV:HP 07/21/88 (1] TD:13920 PB:13042 SUPV:HP 07/22/88 (1 TD:13920 ?B:13042 SUPV:GLC 07/23/88 (1 TD:13920 PB:13042 SUPV:GLC 07/24/88 (1 TD:13920 PB:13042 SUPV:GLC KING SALMON StatL 1) 2) 3) 6) RIH WITH TEST STRING MW: 8.5 FIW TERMINATE TEST, REV. CBU, POH (ALL GUNS FIRED), LD TEST/PERF STRING, RIH WITH BIT AND SCRAPER, CIRC. HIGH VIS. SWEEP (NO FILL RECOVERED), POH, MU TEST STRING, RIH DAILY:S14,400 CUM:$3,908,927 ETD:S3,908,927 EFC:$3,860,000 TESTING WELL WITH JET PUMP RIH W/TEST STRING. SET PKR. (PRODUCING APpRox. 450 BOPD) MW: 8.5 FIW TEST WELL WITH JET PUMP. DAILY:S15,080 CUM:$3,924,007 ETD:S3,924,007 EFC:$3,860,000 POH MW: 8.5 FIW FLOW TEST WELL. SHUT IN FOR PRESSURE BUILD-UP. REV CIRC. RE-TEST ANNULUS. ANNULUS OK FROM 12640' TO SURFACE. REV CIRC. POH. DAILY:S42,567 CUM:$3,966,574 ETD:S3,966,574 EFC:$3,860,000 REV CIRC HOLE CLEAN MW: 8.5 FIW POH. RAN CET. HAD SUFFICIENT HEMLOCK ISOLATION. TEST BOPE. TIH W/BIT. REV CIRC WELL CLEAN. DAILY:S102,314 CUM:$4,068,888 ETD:S4,068,888 EFC:$3,860,000 REPAIRING DRAW WORKS MOTO MW: 8.5 FIW CIRC HOLE CLEAN. POH, LD 3-1/2" DP. RUN WD PKR AND TAILPIPE ASSY. SET PKR @ 11440' (WLM) W/ TBG TAIL @ 11718' (WLM). CIRC AROUND FIW W/ 10 GAL PER 100 BBL C-193. POH. HAD DRAW WORKS MOTOR FAILURE. REPAIR SAME. DAILY:S14,485 CUM:$4,083,373 ETD:S4,083,373 EFC:$3,860,000 ATT TO STING INTO PKR MW: 8.5 FIW FIN REPAIRING DRAW WORKS MOTOR. POH. RAN 3-1/2" COMPLETION. (CAMCO 'TRDP-1A-SSA' SSSV @ 291', OTIS 'WD' PKR @ 11446', & TT @ 11724'.) SPACE OUT AND ATTEMPT TO STING INTO PKR. DAILY:S14,400 CUM:$4,097,773 ETD:S4,097,773 EFC:$3,860,000 lWell no. The above is correct Signature · For form preparF~16n and distribution see Procedures~l~lanual Section 10, Drilling, Pages &6 and 87 IDate ITitle ASSOCIATE ENGINEER ARCO Oil and Gas COmpany Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or ap0rec~at)le length of time. On workovers when an official test ie not required upon completion, report completion and representative test data in blocks prowded The "Final Report" form may be used for reporting [he entire operation if space is available. Accounting cost center code ARCO Alaska, Inc. I KENAI BOROUGH Field I I Lease or Unit Well no. TRADING BAY UNIT Imltle APL: 18772 K-6/K-6RD I Auth. or W.O. no. AD6170 I ABANDON (K-6)/DRILL & COMPLETE (K-6RD) Operator I A. R.Co. I ARCO Spudded or W.O. begun I Date I ACCEPT Date and depth as of 8:00 a.m. 07/25/88 (11' TD:13920 PB:13042 SUPV:GLC Complete record for each day reported KING SALMON API: 50-133-20088 (K-6)/50-133-20088-01 (K-6RD) W.I. ~otal number of wells (active or inactive) on this, Icost center prior to plugging labandonment of this well and 18,0000I I Hour I Prior status if a W.O. 03/30/88 ~ 1000 HRS Old TD New TD Released rig Date FINAL REPORT MW: 8~5 FIW STING INTO PKR. TST TBG & PKR TO 2500 PSI. TST SSSV - OK. SHEARED SOS. ND BOPE. NU & TST TREE - OK. RIG RELEASED @ 1900 HRS, 7/24/88 TO K-18. DAILY:S136,052 CUM:$4,233,825 ETD:S4,233,825 EFC:$3,860,000 PB Depth Kind of r g Classifications (oil, gas, etc.) Ty~,? ,: ?.:-letion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no, Date Reservoir Producing Interval 0~1 or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size TP. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature Date ITitle For form preparati~ and distribution, see Procedures M~ual, Section 10, Drilling, Pages 86 and 87. ,~,SSOClATE ENGINEER Attachment 1 Due to geologic control in the developed area, 12-1/4" open hole log requirements were waived by M. Minder, AOGCC, 5-6-88, in a conversation with Tom Brossfield, ARCO Alaska, Inc. During the 8-1/2" open hole logging run, the Hemlock and "G" Zone were covered. WC5/033.3 SUB.$URFA CE DIRECTIONAL SURVEY [~UIDANCE ~'~ ONTINUOUS ['~OOL Company ARCO ALASKA~ INC. Well Name TBU K-6RD (736' FSLl135' FEL,I,SEC 17~T9N~R13W~SM) Field/Location MCARTHUR RIVER, KENAI, A[,ASKA Job Reference No. 72934 FITTERER/CRYER Oat.....~e SEP 2 8 1988 4-JUL-88 · "a 0il & Gas Cons. C0mmls~' ~ Computed By:. KOHRING Ie ,U ZZ~'ZZZZ ZZZ ggj444444,; L, LJ L[J I.LItJ~ IJ.l Id, J L~II,.LI l,,i.I ZZZZZZZZZZ 3ZZ ~Z U .' t..] I..- Idd ;.t :U ,12.[ Ud U. JIIJ !1 ~ UJ i. LJ I · I · I I · · · t I · t · I t I I t · U,.J I, LI I/J IJ.J U.J L~ J U_.' U~ U.J U ,~ I,,U LLI LI,J U J LI J LL~ U.J LL~ Lt ' IJ J ' LLI LLJ LLI LU LLILIJ LL, U.J U.~ U.I JJJ.:J44JJJ ggJgggjggg · I · I · e I · I · -) · Io I! · Z .d 44 4jJJJJ4 t · 0 · · · · · · · LIJ LM Lift LIJ LL~ I !.~ LIJ ti J LL i I$,1 I · · · · · · · · I J ~Z ,-.~ ~,J ~='~ Z eM: l,-- IA,, L:t~ U.I L.Lfi LAJLt..~ IAI L~j LL) ~' LLJ LI.J ,I,IAJ UJUJ l.,I J 'J.J 0 ..J~" ,,ir.. jjJ44 Ii · · · II ti · III · · · ~ ZZZ'~ ZZ~Z--~ U.J IJ.J LJJ UJ LU U J LIJLU U.J LLJ LL4 ILl LA.: ~ UJ k~J ~ U.J I,i, ILl gjgggJJgJJ u,J u i I..LJ UJ ~lJ U.J I. Ij LLI I, LJU.I ggJggddgg~ LA] Z I 'x ee ti LAJC) ~o ¢~ Z~) I-.40.. · 0 C¥ I-- I.J ? U.J _l C3 ~ LU Z Ct; :]: SCHLUMBERGER D I RECT T ONRL SURVEY COMPANY ARCO ALASKA, INC. WELL TBU K-BRO FIELD MCARTHUR RIVER COUNTRY U.S.A. RUN ONE DATE LOC-OEO 04 - JUL - 88 REFERENCE ?2994 WELL- TBU K-6RD (736' FSL, 135' FEL, SEC 17, TgN, R1 3W, SM) HORIZONTAL PROJECTION NORTH 8000 REF '72994 $CRLE : 1/2000 IN/FT 6000 4000 ~000 -2O0O · ..i.+.~...!...!...!...~...~ ....... I...i...LL.Zi~i]i]ii:Z]I~ ZiZ]~ ~!!i"'I'"'?-t"t-'!'..,-i...!.-.~...~..i ....... !..-!..-!..i...-i...-~...!... ;~.:~.~i'~-'~ ..... ._,. ~ ~ ~ . :~ ~ : '~ ? ~ ~"-~...~..,T...~..-~-..?...~...~...~ ........ ~...~ ~~ . . T t ~.,?...~-., : : ~ ~ ~ : ~ ~ ~ ~ ~i ~ ~ ; ~ [ ~ ~ , ~ ~--~ . ~ : ; i ~ : i : :.~_L.._~] ~"?"'s" ~..~...~ ........ :....~...~_,...~... . , , ............. ~,..v ~ . ~ ~ · , . , . ' ........................... - ....... ~ ................... ...... -... ::-. ........... .:' .... ,. ........ · ........ ~.,,~.,,~.. x , , ~ · : ~ .... '?'T'= r' %", .... ?~~ : , , , . ..?..?..~..? ....... ,,..., ..... , ~,..~.,.~. ..,.., ~ . ; : ~ ~ ~ : : .~ .. .' . ..= . . . ~ .... '']i,~.]]'~[ ........ .... I ......... . ............ ' ................................................... : ................. . . . .., ~ m .... ??.~"??~..~?~?..~r~?~.~.`i...~..~.~.i.~.~...~"..L.~.~.L.~1~..~L..L..L.~ ~._.1...~ "~?~~~t~~i ~ ~ ~ ~ ~ ~ ~-~.. :. ~ ... ~ m , ... · .......... ...~' ~C.~'"q' ' ..... . .,~'1~ i~'YC~'~~ ....... ~-' . · ~ "~C[ ....... · · · '"' ~ '~ ~.C . " " ~' ~ . -~.U3C. ' ~ ~. ~ , . ~ ' ..... . .~ ~ "~ . ~ ......... :~ ........ '"~'~'"::: ....... ] .............. -~ ~eO(~ ~: :'' :'::':'~' i~?~.i~f~.~?~+"~F~.~.~F~.~+~4~`~F~.~~~.j~LL.~L~]]]Z~]~]]]]~Z~.~]~;~tz~t~.+~F+~+.+~+~.~.~`~4.J~.~ ............ i .................... , . . '"? ....... ~ ........ ~'"t .... ?"?'+"~ ~ ~ ~ ~ .... ?"~"'~'~'~"~'"~::':~::~::~ .~:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ?f ~ ,', ~ - ' ...................................... ~ .................. -4000 t-~..+..~_~, .. H'i'+i" r?.-~...?.,.?,, .-L~...~_~.. .?...~...~....f... SOU~H -@ooo ~"'f"f"t'" -4000 WEST · · t..'["]i'"TTM ...... T."'T'"T..'"'!"'.'"',"'?'"T'". ...... '.."-r"v'" ...... ,F.:-.-~...~... ............... t ......... , ............................... "' : ........... : ................ .... - ....... : ....... i ...................... ' 1-:"-: .... L :_i.L.:.£.'Li _:._:_'i £.".'_!...: ~ ~..~...~: ? :l . .... ?":'"'r": '"~ .................. .. · ..... i ::. :'' . :::::::::::::::::::::::::::::::::::::::::::, ."'.":--':'":':' :-~-i-~.'~?.:~.:.-:::--:.-:-?.~.:.,:,:: !. : ,. ;': ...... -;...:, :_ ~ ,. :....~ .: ~.. i_~_~.:..: ~.... :..._ ~_ i .-.,.'....F..*."....~... ~I. :.~: . . .' .................... · '~'"'F+..*: ........... ' ..... ~ '' I ! ~ i t: : : : I · . ~ . . · ' : .".. :"r ~"; · · ~ .'. ' '.: ,'.: ........................ ~. ............ ' .... ' . . i ' .......... ................ ~ ..................... ': .: ;...-'-.-; :..:. :.. .: . ~.. .'. .1 ..:...:..:..: i ..: .:. 1 · ; , · ' ' _ ' ' : · / · · · +-- ~ ~ ~.----- ' '--~-----~_-_-- ..... i i i . : . . 't, ....... ?'"i'"'?'"'~ ...... ?'".~....~...,~ ....... ~....$ 4. ~. ..... .~...4 ~. ........... :../ : : '. i i ; ! : ~ "~"'?'"'~'"',~ ....... i'"":'"'? ........... ,...,... i ~..$,..4..:.. ~ "~'"? ....... ~ ...... ~'"4"+..~ ...... .;. ~ ~ ..... ~i ..... 'r..,-..? ....... r".~...?...~ ................ ~....~ ....... ~ ........ ~. ~ ~ ....... ~ 1~' "t"i i'"~ ...... ~..~. ~ ! ~ ~ .,....i... ::::::::::::::::::::::::::::::::::::::::::: :::~,::::i:::i:::i::: ::::::::::::::::::::::: ::::?"'"'..'"'! ........ i""~'"':', ..... ,'"'?"i : ~ , ,....i ....... :::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::: I ' I' ; ' . ...... I. i ~ --20G0 O 2000 4000 GO00 8000 1000O 12000 EAST WELL · (736' TBU,K-6~RD VERTICAL PROJECTION FSL, 135' FEL, SEC 17, T9N, R13W, SM) ~84, -4000 -2000 0 O 2000 4000 6000 8000 10000 ....... ....... ....... ...... ...... ..... .--'-'-.'--~ ....... +---~-'--i-..~-~+-~--+.+-~--.~ ..... +.-+-'-.~ ...... ~-.~....~...~ ...................... ~ ........................... ~ ........... ~ ....... ~ .......... ~ ........................................... ~...~ ~ ~ ~ ~ ~ ~ ~ ~ ; ~ i ~ ~ ~..~.. ...,.... ....... . ...... ~.~..,...~.-.~.-~....~ ....... ~..~...,..., .................. ~ ........ ~.... .... ~....;..~.;..~..~...~...4. ; ...... ~..., ....... ; ~-~ ; ~ ~. ; ~ ~ , ; ~ ~ ; ; . . ~ - : : . . . ~ ~:.~ ~ ~ ~ ~ ~ ,~: ~: ~, ~ :~. ~, ~ ~ ~ ~, ~ ::~ ~ ~"~'"?",'"': ......... ~...~ ....... ~...??.?.[..~ ...... ,...~.. · -+..~...~-4 ...... ~...~.~.~....~...~...$...~...'...~...~...~..~ ....IL~...~...~...~...¥~...~...i...~ ...... ~...~...~...~...]..~..-L.L.~ ....... ~...~-~...~...~...;...~...~...~ ....... ;...~...~...~ ....... ;...~...;..j ...... i...~...~...~...~...i...i...~...~ ....... :...~....L.Z..~...L.LL..i .... '"~"'~-~'";'" '"~"'~'"~'"~ ...... ~"'~'"~'"; ...... ~'"~"'~'";'" '¥'+"~"'~'"'F';"';'"~'"~ ....... ~""~'"~'"~"'~'"~'"~"'~'"~ ....... ~"'~'"~"'~'"~"'~"'~'"~"-~ ....... ~'"~"'~"'~ ....... ~"'~'"~'"~ ....... ~"'~--~-.~-..~---~--~.--;----; ....... ~-.L.~...~....~...~...~-..~....~ ---~--.~-..~..-~ ........ ~...~...~...~...~....F..~...~...~...~....~".;...~...~.......¥.~...~".~...~...~...~....~...~ ....... ~.-.~...~...~-..~...~...~...~...~ ....... ~...~...~...~...J..-~...~...~...~ ........ ~...~..-~,-.~ ....... ~...~...~...~ ....... ~...~-.i...~...,...~....~....L..~ ...... i...~....L..;....~ ......... L.!....:, .... ~"+"~'"~ ....... ~'"~'--~'"~ ........ ;'-';"+'+'i'-';'"~'"~"'~'":-~m~....%--.; ....... ~..--~...~...~..+-~.-~...~.-.~ ....... ~.-.~-..;.-..P-..J..-~...~...-P-..~ ........ ~...~-..~...~...,..-~.-.~...~...~ ........ ~...~...~--.%.-.~...-;.--.;-.~ ....... %...;....P.-.~...~...~....:...:.-. .... ~'"~'"$"-~'-'~"-'~"'~"-~-"~ ....... ~"'~'"¥';~"'¥'~"'~"'~'"$ ........ ~-'~'¥~'..-~r---~'..-¥~...~ ...... ~.-.~...~...i..'~...~...J...!...~ ....... ~."~'.'~"'~.-'~-'.~-...~..-.i..-~ ........ ~...~...~.,.~...~....~..-~....~.-.; ...... ~...$..-~...~.-.~...~... =?;....~ ....... ~-..$-...~....:...--~..., ....~ ...~...;... ....... :...:...~...:....:....~...~....~....~ ..... ~..~-~...:....~....~...~....~_..~....~...:...z...:....:...~...~ ....... ~...z...:....~...z....~...~....:,..: ........ ~...: ....... :...:....:...:...~....:....:...z...:...i...~...~ ........ : ............... ~.: .i....~...i....:....~ ......... : .... .... F"F'T"~ ....... F"F'T'-[ ...... T"T"?F'?'?'"T-'F"[ ..... T~~]"[~O 3~'"F"F'?'~ ....... T"T?" r'"?'? ........ F'?~'"'F'?T" F'T"]'"T"T"~""F"T"T"~ ....... T"?"F'T"i'"'F"F"~'"~ ....... :'":""~'"'~'"'F'?7"F'? .... .... FT'T"7 ....... F'T"T"? ....... ??'"'F'T'"r'"'['"'F"F"[ ....... ['"?'F'7 ........ [' /"F"F' F'"'F"['"T"T'T'-F"F"F"[ ...... T'"['"'F"[ ....... F'T"T"T ....... F'T'T'T'~ '"T'"F'?"'T ....... T""F"F"F','"?'"'F"h"'~ ....... h"~'"'~'"'F?'"'F"r'"F"C .... .... F']"'T'"? ...... ?'?'?"-~ ....... F"F"F'?"{'"?'"?"'?'[ ...... ~ ....... F"F"r'?"?"F'?""F'~ ...... ~""F'??"{'"'F"F"F"[ ....... F'?"?T"3''''F'?'F'F':'''FT'T'''?'I''i'''I''''~'''~ ....... h'i""h"h'i'"'~'"'~'"'h'? .... .... ~'"'~"'*'"'~ ...... 4....t..-4....~... ~...4...4'"'~'"'~'"~'"'~'"'t"'?'"'~ ...... ?....~-..?...: ....s...?....T...?...C... f.?..~r..-.~....~...?..-? ...... ?"'?'"P'"?'"t ........ ~ ........ ~ ....... ;'" ;""~...4 ...*....~....~...e'..4 ....... ;-..4....~....;...*....;....;....;-..4-.-t ...-;...;....~....~.-.$...~....~-.-~....~ .... ...J.,.L..L..~ ....... L...L.J...J... L.j...~....L...L.Z....L.~....;....~ ...... ~...~....~...~....L..~....:,...~....~... ~...~....~...~...J...~....~....~...J ...... ~...~....L...i...z...~...~....L..1 ....... L...:,....L..J...J...~....L..J...1 ........ L...L.J....L..L.J.-.L...~...J...:....L..J....L..L.i...J....L...~....~ .... ...z...J...~...J...~...2...J-J...z...~....L...~...~.-.~...4....~...~...~...~ ...... ~...~.-.~..-~....~..-.~...~....L...:~ ....... L~...~-..$...~-...~...~...~ ...... ~...~...~....~....[...~....~-;...~ ....... ~...~...~...~...~...~...~...~...~ ....... ~...~....L~...~....~....k.~....~...~....~...~....~....~...~...~....~....~....~ .... .... ....... ??%?? ...... ..... ....... ....... ...... ....... ...... ....... .......... ...... ........ .... ...... ~"'?] ...... ?'}'! ....... :::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~...?....rt...i....?.~....r~...t...~.v..?.¢...~...~ ........ ~-...~...t..., ........ ~.+..?...~ ........ ?..h.?...~...+....?....? ::::: ....... : :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: '+'%+'~'"?~"'i ....... ~'"+'+"?'"~'+'~'m'~ ...... ~""~""~"'~'"'?"'~'"'~'"'~'"'~ ........ ~'"'~'"'~'"~-'"F-'~"'-~""~"'¥'~'~"e~'"'~""~'"'~ ........ ~'"¥'~'-'~ ........ ~'"'~'+'~ ........ ~'"~'-"~""~""['"~'"'~'-"~'"'~ ........ ~'"~ ........ ~.+.:~,,,,;,.,.L..~ .... · "i'"~"'?~ ....... ["'~'"'P". ....... ~'"+'"'?'"~ ........ h"~'"~'"'~ ....... ~'"'~'"'~"'~""r"~""~'"'~'"'~ ........ ~""~'"~'"~ ...... ~""+""~'"~ ........ r" ='"';'"'~ ....... ~'...;....P..+ ........ i...~...4...4 ........ ;...J...4...$ ....... $...J...$...$...4....~....~....L..~ ........ ~...$....;....2 ......... ;...~....~....~ .... '"*?'i"i'"~'"*'"~'"i'"'~ ....... ~'"~'"~'"~ ....... ~"'~"~ ...... ~'"~'"'~'"~'"'~'"'~"'='"'~""~ ....... ~....~..,~...<...L~....~...~....~ ....... ~...~. ~....~...~...~...~....~...~ ........ ~...~....~...~ ....... ~...~....~...~ ........ ~...~...~...~ ...... ~....~....u.~ ........ ~....~....~....~.,..~,.,.',....:.,..:,...:, .... -'? {"' ,'"?", "i"'f'-'[-i ....... ~....?-?.?.}~:...+....?.~.?....F?...~.~..R.T.~..~.u....~-5E.~.~..~..~~?....~.h~.~ ........ ~'"¥'~""~ ........ [""~'"~"'~ ....... ¥'~ ....... ~'"~"'}'+"[""[ ........ ~"'~'-~ ................ ~""~'"'¢ ...~-+.+..+ ........ [-+.-.~....~ ....... ~..+.+-~..+.+~.~ ........ ~..+.+.+-.~...+..+..~...~ ....... +..+.+.+...~...~..+..,...+ ........ +..+...~...~.~..,...,..., ....... ~...,...,..., ........ ~...~.-,..-~ ........ ,...,...,..., ....... ;...~....~...~ ....... ,...,....~....;....k..~ · -..F..~....F..4 ....... F...~.-.;....~ ....... ~.-.~....F.+...u..~....~.~* ....... ~....~....~...~....~....~....~....~....~ ........ ~....~...~...~...~...¢....~...}....[ ........ ,.-~._.L..L.~....~...~...~ ......... L..t...L-.~ ........ L-.L.;....~ ......... L.~....L..~ ........ L.-L...L..~ ........ L...[....L..¢ ........ ;....L..~....L.. ~'-i-'"~-"4 ........ ?'¥-[-'"~ ....... ~'-'{'-"~"-'~ ........ h'-['~-~ ........ ~"+'"h{-t'"'h"h'~'"'~ ....... ~'"-~'-'-~--'-[-'-f...h.-F..~....~ ......... ~....~....~...-~...L..?. r~.[."[~ ........ ~.-.~...}...} ....... }...;....~...¢ ....... ¢....~....~.-.~ ........ ~...¢....~....~....}...+...¢...~...-[... '"*'I [ ~ '? +' ~! ';! ~ '~ *'1 ~' ......... ~--5.~...~.- 5 .~ ~' ' ' + ..... .~ ~ ~ ~ ~ ~ ~ ~ ?. ~ ~ .~ ~ ~ , ~.*..; .h.; ..... g...¢....~-.-[...~ ~ ~ ~"~-':~Y~7"~L'"['"'~""~"" ....... ~...,....~...~ ~ ~ ~ ........ ~ ~'"~'"~"'~ ....... g...~...j,....[[: ~ ~ ....... ¢....~....~...¢~ ~ ~ ~ ....... g...~....~...¢~ ~ ~ ~ ~ ...... ~...¢...~...~...~ .... ~'"~'"~"'~ ........ r'"{'"~"'~ ........ r"?'"r'"'r ........ r"'~'~'r ........ r'"?'"r"':""t'"'r"":'"'r""r ....... ,'"','"','"',"'"'"',"",'"','"', ....... ?'~'"'r'"'r ........ r'"'r""r'"'r'"'~--'r"ta~"r'.', ........ ~'",-"~'"~ ....... ,'"'t'"'r'-r ........ ,"-,"-','"',"'"",'"','",'","' ........... ~ . ~ ........... ~'"*"'?"¢~ : ~ ........ r"~"'?'*~:: ~ ....... ?'~"?"~ ~ : : ....... : :~"?"?'?"~ : : ............ : : : :r'"? ............ ~ : : ~'"'~"? ........ : : : :~'"'r'"~'"~ ........ ?'??""~::: ~ ....... ??"'*"'~ ~ ~ ............~]~ ~ '"*~ ....... ' *"";i ~, ....... ¢i ...... }'"~'"¢'"¢: : : ....... , ¢"'*'"~"';::: : ....... ¢'-;'"'¢'"*'"'~i:: ~ I ~ : ~+"'¢'"*"' .... ~. ~ . :r'? .............. ~ ~* ............ ~"'*.: ~ ~ .................................................................................................... ~ ~ ~ .. r ~ ~ ~ ~ ~ ~ ~ ~ ~ I ................................................ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , ~ ................................. ~ ~ ~ . : ~ ~ : :~ ........... , ........... ~"';'"'~'"; .......... ........ ~...,..,..~ ........... [ ....... ~...~ ............................~ .... t"?"?"~ ....... F?'?"~ ........ r'"T'"T'"T ....... T'"'['~T ........ ,'"','"',"','"',"","","",'"', ........ ['"'r'r"'~ ....... T""[""[""[ ....... T'"~'"T'-['":"T"T'"F'F'""~T~:"T'¢"':"'~'~ ........................ ~...--f...h.f.-?.-.~ ........... ~ ........ { ' i [ ' ' ' ' : : : : ~ : , : : , i ~ : .... +...~..+...~ ...... ¥+...~...~ ....... ~...~.~ ........ ~...~....~...~...j..+...~....~...~ ....... ~...,..+.+...~...~_..~...~...~... ,~,, ,, ....... ~, ,~.~,~, ,,~, ~,,~ ~-'i'"i"'T ...... i--'i'"?-'~ ...... ~"+'"h-i ...... ~-'+-+'"~ ...... *'"~-*'-~ .... .... "'t'i'"?i'" ~"'?i""h'i'" ?i'"?i"' , ..... .... ~'"i'"~"'~ ....... i'"i'"~-i ........ ~'"?,'"~ ........ i'"i'-h'i ......... hi'"i"'i ....... ?-i'"'hi ...... i'"?i"'i ...... ~...4...~....~.......~..+..f.+..~....~..+.~...~ ...... ~ ..... ~ ......... ~...~...~...~ ...... ~...~....~...~ ....... ~...~....~....~...L.~...~...~...~ .... '-?'¢"~"'v ....... +'"~"'?'"' ........ ~"+'+"~ ......... [Tg~ ~?'"FT"~ ....... T"FT"] ...... T'TT"] ...... ~"-~'-~"-~'"~'"-F'+-,'"~'-~"+-4'"~-"~"'h',-e~'"~.i ZOO0.4 ...... ~...~...~.-.J ....... ~...~.--.~-~ ....... ~...~...~-~...~ .... ~...t...~...~ ....... ~...+...4...~ ....... +...~ ....... i ....... 4...+--4.-~ ...... +...~....~...~ ............ ~....~...~ ....... ~....~.-?.~ ...... ~'"'~'"+"'T ...... ~""~""~'"~ ...... ~'-?'"~'"'~ ........ ~'"~'"'t"'+ ...... 4...~...~...+ ....... ~'"'~""g'"?'3 '"~'"'~'"~ ........... ~"'~'"'~ ........... +'"i'''~''''~ .... ~"i"+"4 ........ T"+'+"~ ........ ~'"T"'T"'~ ....... ?"?"?"~ ...... ~-..?.r..~ ........ r...r?..r.. ~"'?6"?'T ...... T'"?"~'"'~ ...... ?'??+" r"?'???-r-'r"?-?~ ...... ?'"?'i-~ ...... T'4'-'r"~ ....... ?'~-"r"i ...... ??r-"r ...... ??.?~ .... .... V"+-~'-~ ....... 4"+'+"~ ........ 'F'+"i'"~ ......... F'"F'-~""~ ....... ~'"~""F"~ ........ ~ ........ ~""F-'"'4'"'F"~"i ...... 'F"~-"F-'~ ...... ~ ........ F"'F"~"'~"-~'"'F"~-'"'"F"';'"'~'"'~ ...... ~""~..+-~ ...... ,...~....}....~.-:...~-.~--~ ........... ~....h-~....~ ....... F-'~-"~"-J .... -.-4...1 ..................... ~...?..-~ ........ ~....~ ................... T'"~ ............................................................................. T'"t ....................................... ? ................................................................ ~ ..................... r"] .......................................... '"?~"'~'"~ ...... ?"+"~"-~ ....... ?'? ....... ~ ........ r ....... ~'"? ........... ~-"~'"~ ............ r-'.r'-.r ...... ?'r"?"~ ....... r'"~ ............... v ............. r ....... r'-?+'-* ....... +'..;'"; ...................... ~ ....... ~-..? .................................................. ~ ......................... · ..$...T...,....t ...... 4-..~...$...~ ........ ,..9...~...4 ....... ~-..4-..~-...~ ...... 4...4....;-.4.......; ........ ~...4 ...... ;...4...4...4 ....... ~ ....... 4...4 ....... $...;...4--..~ ...... 4...4...4-.., .......... 4--.4.--4..-; -..~-.-4--.*...~ ........ ~...4...4...4 ....... *....P..-~.--........-4... '..-.P...~.-.~ ....i....~ ........ ~ ] ] { , } { { ' { : { { ; : ] { ] : : { ' . : } : I : : : { : : : : : : : ' : : ' : : : ~ : T . : ' ~ ' '"'~'-T"T'"~ ...... T"V'"T'"~ ....... T'"T'"$'-'F ....... ~'"?"'t'"'~ ...... ~"'~'"'r"T ....... r'"h"T .......... ~'"~'"~'"+ ....... ~'"'P'"P"V ....... +....~...4...~-..J .-.~...~---4...+ ....... ~..4 ....... 4 ....... 4...4-..~..-4 ........ h-.i-..~-.-4 ....... 4...~....~....~ ........ p..~....p...~ ........ p..~...~-.-J .... '"T"'~'"T"? ....... r"'r''~'''~ ...... T'"T'"T"'" ....... ?"'?"~'"? ....... v{'~'~'~'l ~'r"?'"r"?'< '"?'"~'"'~'"~ ....... ?'"~-'?'-'? ....... ?-'?", ............ ~--?..-? ........... ?'?'"r ........... T"?"'?'T ........ r ....... T'"'~ ........ ~'"? ........ ~ ........ ~'"T'"'~""~ ........ Y ........ t'"? .... · "~'"T'"?'+"q-.4.-4-.i-..~ ...... t'"i'"T'"~'" ,"'~'"?'?"? ....... F..r...F..~...! ..+...~...?..-T ....... +'"f"-r--i ....... ~'-.}"-~'.., ....... ?+.'.~.'..~ ....... ,..+...~...~ ....... i"+'-+'"~ ........ r'+"i'-i ....... +'"i"-?+ ....... +"+'--+'-+ ....... ~-.+-..r-..~ ........ r...~...i....~ .... . , : ' ~ : ~ . ~ : : : : : : : : { , : : / · : : t . : : ~ : : : , : ~ : : : : : : : : : . : ~ : : : : { : : i : { : ~ 4 ~...~ ....... · ..... · ......... ~..~ .......... ~....~....~ ........... ~ .......... ~ .... ~ .... "?"~'"~"'t ....... ~"'~'","'~ .......... .'"?~ ...... ~-?'--r-.'~ ....... ~'"?'-'r'"- ....... r'"r'-.. . ~ . * , , ~ T . . , ~ ~ . : ' ~ ~ T ' ~ ' · ' · ~ · ~ ' ~ · ' T ~ . ~ ~ ~ . .... }-..~.+-~.-....}...~..+...} ....... }...+.-.~..-.} ....... ~...~....}....~ ....... ~....~....F.~ ....... ~....~..+...~ ....... +....}..+-* ....... *.--~--.~-..~ ....... ~..-~..+.-~ ....... ~-.-~.-..~-..~ ....... ~..+..}...~ ....... ~..-~....~...~ ....... .k-.k.-',...~ ........ ~..--F..F..~ ........ k.4..+....Z~L~....~...~.-..~ .... ...t...+....~....~ ....... i...4....p..;...]....; ........ ~ ........... ;....~....~....; ........ ;....~....~....~....}....~ ........ h..J ........ ~...$...~...~ ....... $....L...t...~ ........ i ........ ~....~ ........ ~....~...u...~ ....... ~...~ .~..~ . i..~ j $ .. ~. ~ ~.. . ~.. ~ ~...;.. ~. ~...~.. ~. ~ ....... .... ["T'"F"~ ........ FT"'F"F'~"T"?'"F"F'~""F'~'"'F"~ ........ FT"'["'?"][[]['Y"i'"'~ ........ ~""~'"'~'"'~ ....... T"f'"F"~ ........ F"~'"'F'? ........ ~'"'F"~'"! ........ FT'"c'"~ ........ c'"r"~""~ ........ F"r'"F'? ........ r'?"","'? ........ ?'"'r"?"T'"~'?'"F"~'" "'T ....... ~"'" ........ '"~'"?"~ ...... ?'?'"'r'"~ ........ r'"r"'r'"~ ....... r-'? ........ r'"~-"r'"r"? ............ r'"r'"r"~ ....... ?'??-"~ ....... ?'r"-r--'~ ............ ~ ........ , ........ r'-~ ....... -~ ........ ~ ........ ~'-"~ ...... ~...~---~.'..r.'T...~ ........ P'? ........ ~ ........ ~'"'~'"'~"-~ ............... . ~ : ~ ~ : : : : : : : . : : ~ : : : : : . ~ : : : : : : ~ : : ~ ~ : : ~ : : : : ~ : : : : .. ~ ~ : : : : : : : : : : : : : . : ~ : : .... ........ ~""~"?""~ ....... ~ ........ ~ ............ ~ ~ : :~'"~'"'~ ............ ~ ] ~ ~'"~'"'~'"'~ ........ ~]~ "~ ..... ~ ~ ~ ~""~'"""'~ ........ ~ 2 ~ ~'"'~'""'"~ ........ ~ : ~ ~'"'~'"'~'"'" ....... ?"~'"'~""~:: } ~ ........ ~ ~ ~'"'~'"""'~ .......................... ........ ~'"'~-"'"'~ ........ ~'"'~ ................ ~'"'~""~'"'~ ........ ~ ............ ~ ........ ~"'~ ....... ~""~'"'~ ............. ~"' O "'~'"~'"~"'~ ....... f"f'i-'-~ ....... f"f'-h"i ....... ~'"i'-+"-~ ........ ~-'+'"~"+-'P~'"~'"'~:"-'~ ........ ~"+"'~'"'~ ........ ~'"'~"+"~ ........ ~"+'+'"~ ....... +"+"'~....~ ........ ~...~..-.~...~ ........ ~..+..~...~ ....... ~.-+.-.~....~.-..F..~........~....~ ........ ~...~....~ ........ } ............... ~ ........... ~ , : ~ : : : : .. : : : , : : : : . : . .[ : : : : : : ~ ~ ~ : . ~ : : : : { : ~ : :[ ~ · "~'-'~"-',"'* ........ r'"'r'+"'~ ........ r..?...~....~ ........ r'"r'.'r'..~ ........ r ......... r'"r'"} ......... r"?""~ ........ ~ .............. ~ ........ ~'".,""r"~ ....... :""r"?""~ ........ ~'"'~ ................................................................................... ~ ................................... ~ .......................... ~ ~ : { : : : : : : : : ~ ~ : ~ : : : : . : ~ } ~ ~ ~ ~ ] ~ ~ ~ : [ ~ : . ~ : : : : : : ~ ~ ~ : "'?"T'"?"~ ........ ~"'??"'~ ........ ~'"?"?"'? ........ ~'"'r" "~'"'~ ........ ~""~""~'"?"~-"~" '?" '?'" ? ........ f '"'~'"'~-"~ ........ ~'"'~"?'"T ........ ~""~'"'~'"'~ ........ ~'"'~""~""~ ........ ~'"'~'-'h'"~ ........ h'"~""~""~ ........ ~...~....~ ....~...~....~ .-.~...a....~ ........ ~ ........ ~....~....~ ......... .,....~ ...? · ..~..+...~...~ ....... ~..+..~....~ ........ ~...~....~...~ ........ ~....F...F...~ ........ F..~....~...~....~..+...~....~.....~ ........ ~..+...~....~ ............. F..-~.-..~ ....... ~..-.F...F...~ ........ F...~....F...~ ............ ~.-+..+ ....... ~ .................... ~....L..-F...~....F..~..+...~ ............ ~...~....~....~....~ .................. ~ ~ ~ ~ ~ : : : ~ : ~ ~ : : : : : : : : : : : : : ~ ~ : : : : ~ : : : ~ : : : : . . , -~"~'~"~'"~-'~'-T-~"-W-~ { ~ ~ ~ ~ ~ "~'-,~T ~"~ ~ ~ ~-'~-~W'~-?'T .... ??'~-~-'~-~"~-?'~ ..... .... ~"+"f"~ ....... f'+"f"~ ....... ?"+'"['"~ ....... ~"+'+"'~ ........ P+'"h'"~"+'";'""~'."h"'~ ........ h'+'-'P"~ ........ ~"+'"~-'"~ ......... ~."'h'+'+'+'+'"h."~."~ ........ ~.'.'~.-'.~....~ ........ h"~"+"~ ........ ~"+'+"~"+"'~""~'"-F"'~ ....... ~""~""~""h"F'"~."'~ '.~."'~ ...~.,-~...~ ~ ~ ~ ........... ~, ~ ~'"~"'~"'~ ....... ~...:...;....~ ~ ~ ~ ........ ~ ~ ~ ~L"~'"~ ............ ~ ~ z ~ ~ ~ ~ ~ ~L"'~'"'L'"~ ........ L...~ ..................................... ~ ~ ~ ; [ ~ ~ ~ ~....~ ........ ~ ........ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ........ L...~ ........ ~....~...~ ............ ~ ~ ~ ~h"J ........ L...L.....~...j....~ ~ ~ ~ ....... ~ .. ~ ~ .}..: : : ~~....~ .... ~ '~ ~ ~ : : ; : .} : , : ~~-. ~. ~ ........ '".'"'F'~ ........... ?':'"T""~ ............. ~'"'~ ........ ~'"~ .... ~ ~ [ : ~ ~ ~ : ~. ~ ~ ~ : ~ , ~ ~ : ~ : : : ' ' ' ' ~ ' ' [ ' ' .... ~..-*....~...-~ ........ ~..-~...~...,:, ........ ~...~..+.-.~ ........ p.~....~....~ ........ ~ .: . .' , ,~,., ~,.,,~..,,~ ....... ~ ...................~ ~ ............. ~ ............................~ ~....~.,..~ ............ ~.,,,~ ................ L.,~ ....... ~ ........... ~....L..,~ ............ h..~ .................. ~ ................... 12000 104. PROJECTION ON VERTICAL PLANE 104. - 284. SCALED IN VERTICAL DEPTHS HORI2 SCALE = 1/2DDO IN/FT Unocal Oil & Gas Divisiq Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska District DOCUMENT TRANSMITTAL September 27, 1988 HAND DELIVERED TO' John Boyle FROM: R.C. Warthen LOCATION: Anchorage LOCATION' Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting as Follows: Regarding: Trading Bay Uni<McArthur R~er Field - K-6RD~ One (1) blueline and one (1) sepia of: Continuous Gyro Survey Cement Evaluation Log Multi-Finger Caliper Log One (1) copy of Directional Survey One (1) magnetic tape with listing PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY: DATED: REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ .Plugging~ Perforate ~ Pull tubing Alter Casing ~ Other ~ ABANDON 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 100' Feet 3. Address 6. Unit or Property name P.O. Box 100360, Anchorage, AK 99510-0360 Trading Bay Unit 4. Location of well at surface 736' FSL, 135' FEL, Sec.17, T9N, R13W, SM At top of productive interval 2955' FSL, 1922' FEL, Sec.16, TgN, R13W, SM At effective depth N/A At total depth 2980' FSL, 1546' FEL, Sec.16, TgN, R13W, SM 7. Well number 8. Approval number 8-214 9. APl number 50-- 133-20088 10. Pool McArthur River Field Hemlock 11. Present well condition summary Total depth: measured 11319'MD true vertical 10278'TVD Effective depth: measured 2193'MD true vertical 2099'TVD Casing Length Size Conductor 336' 24" Surface 2146' 1 3-3/8" Producti on 2212 ' 9-5/8" feet feet feet feet Plugs (measured) Ret @ 10500' w/lO0 sx Class G (Top) Ret (~ 9200' w/lO0 sx Class G (4 bbls cmt-below, 16 bbls cmt-top Ret ~ 2550' w/375 sx Class G (Top) Csg Stub ~ 2250' w/225 sx Class G ( Cemented Measured depth True Vertical depth N/A 376'HD 376'TVD 1 760 sx C1 ass G 2186'MD 2088'TVD 990 sx Class G 2250'MD 2151'TVD Perforation depth: measured None Open to Production true vertical None Open to Production Tubing (size, grade and measured depth) None NPoanCekers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (P & A Well Hi.story) Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /Rdy D. Roberts 'Form 10-404 Rev. 12-1-85 Title Environmental Enqir~eer Appr0¥ed by ~.. ¢',~/ (Dani) SW03/026 ,p) Date 9/9/88 Submit in Duplicate ARCO Oil and Gas Company Well History- Initial Report - Dali Prepay1 eno eubmlt the "Initial I~" on Ihe fs~l! WoanasOey allot a wall it BI~JO~O Or wor~[o~r Ol~ratlons ara et&react. Daily work prior to II:I'uadlflg IhOtllO ~ IummlnzOo oli the forwl giving In¢lull~ dalai Only. Dlatmct ARCO Alaska, Inc. Field TRADING BAY UNIT Auth. Of W.O. no. AD6170 KENAI BOROUGH tile or Unit ADL: 18772 K-6/K-6RD Tlue ABANDON (K-6)/DRILL & COMPLETE (K-6RD) API: 50-133-20088 (K-6)/50-133-20099-01 (K-6RD) Operator ARCO S~u(~¢ted or W.O. 13egun ACCEPT Dale end Depth as of 8:00 a.m. 03/31/88 ( TD: 0'( SUPV:HP 04/01/88 ( TD: 0'( SUPV:HP 04/02/88 ( TD: 0'( SUPV:HP 04/03/88 ( TD: 0'( SUPV:HP 04/04/88 ( TD: 0' ( SUPV:HP 04/05/88 ( TD: 0' ( SUPV:HP J ARCO W.I. IDaf'03/30/88 IH°ur 1000 HRS t I 18'°°°° IPr,or ,fetus ,I · W.O. Complete recorO tot e&C~ Oly rlporll~l KING S;LLMON NU BOPE MW: 8.8 VIS: FINISHED RIGGING UP. ACCEPTED RIG ~ 1000 HRS, 3/30/88. CUT TUBING @ 10570'. KILLED W~LL. ND TREE. NU BOPE. DAILY:S61,975 CUM:$61,975 ETD:S61,975 EFC:$3,860,000 TESTING BOPE MW: 8.8 VIS: NU BOPE & TESTED TO 3000 PSI. LD TEST PLUG. CIRCULATE HOLE AND MONITORED. POOH. LD 4-1/2"/3-1/2" TUBING. CHANGED TO 5" PIPE RAMS AND TESTED BOPE TO 3000 PSI. DAILY:S16,718 CUM:$78,693 ETD:S78,693 EFC:$3,860,000 RU F/CMT SQUEEZE JOB MW: 8.8 VIS: FINISHED TESTING BOPE. MU 6" BIT & 7" SCRAPPER. PU DP. RIN TO 10600' DPM. CIRCULATE BOTTOMS UP. TOH. MU 7" CMT RETAINER. TIH SET RETAINER ~ 10500'. ATTEMPTED TO TEST 9-5/8" & 7" CASING TO 1000 Pal. (FROM 1000 PSI TO 150 PSI IN 15 MINUTES) RU FOR CMT JOB. DAILY:S15,384 CUM:$94,077 ETD:S94,077 EFC:$3,860,000 LOGGING MW: 8.8 VIS: RU. UNABLE TO INJECT THROUGH RETAINER @ 10300'. SPOTTED 100 SX CLASS G ON TOP OF THE RETAINER. TOH. MU 7" RETAINER, TIH, AND SET ~ 9200' DPM. TESTED 9-5/8" CASING · AND LINER LAP TO 1000 PSI - OK. MIXED AND PUMPED 100 SX CLASS G CMT. SQUEEZED 4 BBLS THROUGH THE RETAINER; SPOTTED 160 BBLS ON TOP. TOH. RU SOS. RUNNING CNL/4000' TO SURFACE. DAILY:S14,094 CUM: $108,171 ETD:S108, 171 EFC:$3,860,000 WORKING ON LOCKDOWN SCREW MW: 8.5 VIS: RAN CNL F/4000' TO SURFACE. TESTED 9-5/8" CASING TO 2500 PSI. TIH. REPLACED DRILLING LINE. LD 5" DP. RU SOS. PERF'D 9-5/8" CASING @ 2150'. REV. CIRC. 9-5/8" ANNULUS CLEAN. SPEARED AND LD 7" SPACER SPOOL. WORKED ON 9-5/8" LDS. DAILY:S42,904 CUM:$151,075 ETD:S151,075 EFC:$3,860,000 RU SOS/A~RS' MW: 0.0 VIS: TAPPED OUT LDS & REPLACED. SPEARED 9-5/8" CASING. STRETCF. ED CASING. CALC. FREE POINT ~ 2035'. SET 9-5/8" CIBP @ 2550'. CUT 9-5/8" CASING ~ 2450'. SPEARED CASING. UNABLE TO PULL CASING FREE. RAN FREEPOINT SURVEY,.~ ~0~FA~EE~@.),~ .... ~.~,~ 2190'. STUCK ~ 2240'. ~!,~'"' ,, ' ~ ~ r, ~ ~.1"" ~ ~'%~ I ~ ~~ ~ ' ~ ' !' ~ ~' .,-r~ The adore is correct For form 13reparation a~l~ distribution, see ProceOures Manuel/SeCtion 10, Drilling, Pages 86 end 87. IDate I Title welt history forms consecutively i~ege ARCO Oil and Gas Company Daily Well History--lnterin Iflltl-u¢liOnl: This form ii uled Ourlng drilling or workover operatlonl. If telling, coring, or per~orlhng. IhOW fOrmltlOn name in describing work Number Ill ~rill stem tells ~Qulntlatly. At[Ich Oelcrl~t~on ot iii cores. Work ~rforme~ by Producing ~CtlOn will be fl~ome0 ~ "ln~rlm" Iheltl complehon, Repo~ ofhc~ll Or rlprlilntltlve tell On "F~II" lotto, 1) Su~mit "lalerlm" l~lltl when fllie~ out but not les& frequently Ihln eve~ ~ ~lyS. or (2) on Weenel~ly of the week in which oil ltrlng ii Mt. Submit weekly tor worKovem in~ following ~ttlnO Of oil It/InG Until completl~. ARCO Alaska, Inc. I KENAI BOROUGH Field ILease or Unit TR~kDING BAY UNIT J K-6/K-6RD Complete record for each day while clrilhng or workover m progress Date ano depth as of 8:00 a.m. 04/06/88 ( TD: 0'( SUPV:HP 04/07/88 ( TD: 0'( SUPV:M~ 04/08/88 ( TD: 0'( SUPV:ML 04/09/88 ( TD: 2295'( SUPV:ML 04/10/88 ( TD: 3044'( SUPV:ML 04/11/88 ( TD: 3496'( SUPV:ML KING SALMON 7) O) 8) O) 9) 0) O) 295) 1) 749) 2) 452) The above is correct RU FOR CMT JOB MW: 0.0 VIS: RD SOS/APRS. PU 9-5/8" CSG CUTTER. TIH. CUT 9-5/8" CSG@ 2250' MD. CBU. TOH. REDRESSED SPEAR. PU SAM~ AND SPEARED 9-5/8" CSG. PULLED CSG FREE WITH 325M. BREAK OFF CSG HANGER. CIRCULATE BOTTOMS UP. LD 52 JTS 9-5/8" CSG. CHANGED RAMS TO 5'! AND TESTED. TIH. SPEARED CSG STUB @ 2250'. JARRED ON SAME - UNABLE TO PULL FREE. RELEASED SPEAR. TOH. LD SPEAR AND 3 DC'S. PU 3-1/2" STINGER PIPE. TIH WITH OEDP. DAILY:S21,220 CUM:$196,383 ETD:S196,383 EFC:$3,860,000 LOGGING MW: 8.5 VIS: SPOTTED 375 SX CLASS G ON TOP OF RETAINER @ 2550'. PULLED 8 STDS. REV. CIRC. DP. POOH. LDDP. PU CLEAN OUT ASSEMBLY. TIH. WOC. TESTED 13-3/8" CASING TO 1500 PSI. TIH. TAGGED TOC @ 2079'MD. DRILLED CMT F/2079'-2192'. RU SOS. RAN CET F/2150'-SURFACE. DAILY:S19,630 CUM:$216,013 ETD:S237,399 EFC:$3,838,614 CBU MW: 8.5 VIS: FINISHED RUNNING SOS CASING EVALUATION LOG TO 2186'. RD. RIH WITH MOTOR. DRILLED F/2192'-2250'. HIT CASING STUB. CBU. POH. RIH OPEN-ENDED TO 2250'. SPOTTED 225 SX CLASS G ON TOP OF CSG STUB. CIP @ 2030 HRS, 4/7/88. CBU. POH. WOC. TAGGED TOC @ 2195'. PULLED UP. CBU. · DAILY:S24,600 CUM:$240,613 ETD:S261,999 EFC:$3,838,614 RIH W/ NEW BHA MW: 8.5 VIS: POOH. PU MWD AND RIH. PLUGGED & ABANDONED K-6 @ 1130 HRS, 4/8/88. SPUDDED K-6RD @ 1130 HRS, 4/8/88. KICK-OFF & DRILLED 12-1/4" HOLE F/2193'-2295'. PLUGGED BHA.' REV CIRC. POOH. CHANGE BHA. RIH. WORK THRU WINDOW. BHA PLUGGED. ATTEMPT TO CLEAR. POOH. CHANGE B~A. LD MUD MOTOR AND BENT SUB. PU ANGLE BUILD ASSY. RIH. DAILY:S20,469 CUM:$261,082 ETD:S261,082 EFC:$3,860,000 RIH W/ COND ASSY MW: 8.8 VIS: 38 FIN RIH. WASH AND REAM F/ 2228' TO 2295'. CHANGE OVER TO MUD. LEAK OFF TEST. EMW - 15 PPG. DRLD 12-1/4" HOLE TO 3044'. CIRC BTMS UP. PUMP PILL. POOH. PULL WB. TEST BOPE. RIG DOWN TEST TOOLS. DAILY:S42,826 CUM:$303,908 ETD:S303,908 EFC:$3,860,000 RIH W/ MUD MOTOR MW: 9.0 VIS: 40 RIH. WASH AND REAM TO 3044'. CIRC BTMS UP. PUMP PILL. POOH. CHANGE BHA. RIH W/ PACKED.ASSY. DRLD 12-1/4" HOLE TO 3496'. CIRC BTMS UP. PUMP PILL. POOH. ~A~:$22,245 ~uh:$326, i53 ~:~u;$326, i55 EFC;$3,860,000 lWell nO. Signature IDaie For form preparation and di~ribution see Procedures Manual SeWn 10, Drilling, Pages 86 and 87 ASSOCIATE ENGINEER ,~. Nurnuer all ~Hy well htsioty Iorms consecutively as they are predated for each well. Page no. ARCO Oil and Gas Company Daily Well History~lnterir Inatmctl~el: Thll torm is uaect clurmg ¢lrilling Or wOrkO~ o~ratlont. If treating, cormg, or De~ormt~ng ~hOW formation name In 0etcrtbmg work completion. Repo~ official or tep~e~ntallVe fell O~ "F~II" to~. 1) Su~mlt "l~lt~m" sheets wflln fllleO out but not leis frequently Ihan I~ ~ Olyl, Or (2) O~ Weonl~aY of the week in which oil string i& lit. Submit weekly for workove~ ant lollowing ~elt~ng gl oil liraG unlJi co~plet~. Dlstr~ct ICounty or Per~l~'l ARCO Alaska, Inc. I KENAI BOROUGH Field ILllle or Unit TRADING BAY UNIT ~ K-6/K-6RD Date eno oeotn Complete recor~3 lot each ~ly while (trflhng or wort, over in progress is of 8:~o a.m. KING SALMON Iwe]l no. 04/12/88 ( ) PREP TO RIH W/ BRA MW: 9.0 VIS: 40 TD: 3774'( 78) RIH. DRLD 12-1/4" HOLE TO 3775'. CBU. POOH. PU AND MU SUPV:ML BJ{A. DAILY:S29,609 CUM:$355,762 ETD:S355,762 EFC:$3,860,000 04/13/88 ( 14 CH3%NGE BIT AND BHA TD: 4490' ( 6) RIH. WASH AND REAM TO 3774' SUPV:ML CBU. SURV. PUMP PILL. POOH. DAILY:S16,455 CUM:$372,217 04/14/88 ( 15, TD: 4850' ( 370) SUPV:ML 04/15/88 ( 16 TD: 5270'( 4:0) SUPV:ML 04/16/88 ( 17 TD: 5548'( 2"8) SUPV:ML 04/17/88 ( 18] TD: 4835' ( 0) S UP V: ML 04/18/88 ( 19: TD: 5007' ( 15 ) SUPV:ML 04/19/88 (20) TD: 5596' ( S UP V: ML The above is correct MW: 9.0 VIS: 42 DRLD 12-1/2" HOLE TO 4490'. CHANGE BIT AND BHA. ETD:S372,217 EFC:$3,860,000 DRLG MW: 0.0 VIS: 43 POOH. CHANGE BRA. RIH. DRLD 12-1/4" HOLE TO 4850'. DAILY:S36,452 CUM:$408,669 ETD:S408,669 EFC:$3,860,000 DRLG MW: 9.0 VIS: 43 DRLD 12-1/4" HOLE TO 4948' CBU. PUMP PILL. POOH. CHANGE BHA. RIH. REAM F/ 4446' TO 4948'. DRLG 12-1/4" HOLE TO 5270'. DAILY:S35,548 CUM:$444,217 ETD:S444,217 EFC:$3,860,000 POOH MW: 9.1 VIS: 41 DRILL 12-1/4" HOLE TO 5548'. CBU. POOH. TAKE MWD CHECK SURVEYS. LD BHA. RIH WITH OEDP TO 5325'. SPOT 17.5 PPG MUD FROM 5325'-4900'. PULL UP TO 4900'. MIX AND PUMP 250 SX CLASS G CEMENT FROM 4900'-4500' CIP @ 0330 HRS 4/16/88. POOH TO 13-3/8" CASING SHOE. CBU. POOH. DAILY:S24,805 CUM:$469,022 ETD:S469,022 EFC:$3,860,000 DRILLING MW: 9.0 VIS: 44 CBU @ 2186'. FINISH POOH LD EXTRA DP. WOC. PU BRA #9 TEST MWD AND MOTOR. RIH TO 4000'. CBU. RIH TO 4500'. TAG CEMENT PLUG AND POLISH TO 4751'. SIDETRACK HOLE @ 4751' DRILL 12-1/4" SIDETRACK HOLE TO 4835'. DAILY:S51,974 CUM:$520,996 ETD:S520,996 EFC:$3,860,000 REPAIRING MWD TOOL MW: 9.0 VIS: 44 DRILLING 12-1/4" HOLE WITH MUD MOTOR FROM 483'5-4858'. PUMP PILL. POOH. CHANGE OUT BHA. TIH. REAM FROM 4697'-4858'. DRILL 12-1/4" HOLE FROM 4858'-5007'. BIT PLUGGED. POOH. REPAIR MUD. DAILY:S26,684 CUM:$547,680 ETD:S547,680 EFC:$3,860,000 POOH MW: 9.2 VIS: 44 PU LC. TEST MUD. TIH. REAM 60' TO BOTTOM. DRILL 12-1/4" HOLE TO 5226'. ELECT WORK ON MUD PUMP PROBLEM. DRILL 12-1/4" HOLE TO 5235'. ELECT WORK ON MUD PUbIP PROBLEM. DRILL 12-1/4" HOLE TO 5596'. DROP SURVEY. PUMP PILL. POOH. DAILY:$~1,135 CUM:$568.815 FTD:SS~:RI~ ~t$~.R~O,~n For form preparation e~ distribution see Procedures ManulLVSection 10, Drilling, Pages 86 and 87 IDate 1Title ~ -i'~-~.¢'.~ ASSOCIATE ENGINEER INumDer all dally well history forms consecutively as they are prepared for each wall. no. ARCO Oil and Gas Company Daily Well History--lnterir leltllJcfionl 'rl~ll form il Ull(~ Ourlhg ¢lrilhng or workoYar oD~ratlonl. If testing. COring. Or N~Orlllng. IhOW lO,anon comoietlo~. ReDo~ OfhClll or re~rllentltive reit on "Flail" Iota. 1) SuOmit "Interim" l~tell ~l~ tllle~ Oul BUt BUt leis ARCO Alaska, Inc. County or Per,~ KENAI BOROUGH teals or Unit K-6/K-6RD D~ltrict Fiefs JWell no. TRADING BAY UNIT Date eno oe~fn as o! 8:00 a.m. 04/20/88 ( 2 TD: 5816'( SUPV:ML 04/21/88 ( 2 TD: 6445'( ~ SUPV:ML j 04/22/88 ( 2; TD: 6445'( SUPV:ML 04/23/88 ( 2, TD: 7216'( ' SUPV:ML 04/24/88 ( 2! TD: 7652'( SUPV:ML 04/25/88 ( 21 TD: 8194'( SUPV:ML 04/26/88 ( 2 TD: 8412'( SUPV:HP Complete recorO lot each Oay while Orllllng or worKover in Drogrell KING SALMON .) ~20) ~) ;29) ~) o) !) 71) ) 36) ) 42) ) 18) DRILLING MW: 9.2 VIS: 40 LD BHA. REPAIR ELECTICAL FOR J2 MUD PUMP AND DRAWWORKS. BOPE TEST TO 3000 PSI. PU BHA (BATTERY POWER MWD TOOL NOT OPERABLE LD SAME AND PU TURBINE POWERED MWD). TIH. BREAK CIRCULATION. DRILL 12-1/4" HOLE TO 5816'. DAILY:S19,736 CUM:$588,551 ETD:S588,551 EFC:$3,860,000 REPAIR ROTARY TABLE MOTOR MW: 9.2 VIS: 45 DRILL 12-1/4" HOLE TO 6445'. CHECK ELECT PROBLEM WITH ROTARY TABLE. DROP SURVEY. PUMP PILL. POOH. REPAIR ROTARY TABLE MOTOR. DAILY:S22,129 CUM:$610,680 ETD:S610,680 EFC:$3,860,000 RIH MW: 9.1 VIS: 37 REPAIR BRUSHES ON ROTARY TABLE MOTOR. MU BHA. RIH. CHECK ROTARY TABLE. UNABLE TO GET ELECTRIC MOTOR TO WORK. MOTOR FIELD SHORT. CBU AND PUMP PILL. POOH TO CASING SHOE. CHANGE OUT ROTARY TABLE ELECTRIC MOTOR. RIH. DAILY:S20,924 CUM:$631,604 ETD:S631,604 EFC:$3,860,000 DRILLING MW: 9.2 VIS: 42 WASHED AND REAMED TO 6445'. DRILLED TO 6903'. SHORT TRIP. DRILLED TO 7216'. DAILY:S21,405 CUM:$653,009 ETD:S653,010 EFC:$3,859,999 SHORT TRIPPING MW: 9.2 VIS: 41 DRILLED 12-1/4" HOLE TO 7247' CIRCULATE BOTTOMS UP. PUMPED PILL. DROPPED SURVEY. POH. CHANGED BIT & TIH. DRILLED TO 7652'. CIRCULATE & SHORT TRIP FOR HOLE CONDITIONING. DAILY:S31,635 CUM:$684,644 ETD:S684,644 EFC:$3,860,000 DRILLING MW: 9.2 VIS: 48 SHORT TRIP FOR'HOLE CONDITIONING. DRILLED TO 8058'. PUMPED PILL & POH. CHANGED BHA. RIH. DRILLED 12-1/4" HOLE TO 8194'. DAILY:S19,235 CUM:$703,879 ETD:S703,880 EFC:$3,859,999 RIH MW: 9.2 VIS: 42 DRILLED 12-1/4" HOLE TO 8412' CBU. DROPPED SURVEY. PUMPED PILL. POOH. LD BHA. TESTED BOPE TO 3000 PSI. MU BHA & NEW BIT. RIH. DAILY:S28,738 CUM:$732,617 ETD:S732,618 EFC:$3,859,999 The above is correct Signature For form prel:)eratiq~ ar~-d distribuhon see Proceciures M~usl Section 10. Drilling, Pages 86 '/an,~ 87 jDate JTitte ~--I'q-~..,f'.., ASSOCIATE ENGINEER Number all (3alty welJ h,story forms consecutively Jas they are DreOarecl for each weJl. lPage no. ARCO Oil and Gas Company Daily Well History--lnterir nst~uctlonl: Thl~ form I$ used Outing Orili;ng or wOrkOver ol)erltlons. If testing, coring, or peHoret~ng, show formation name in Oelcriblflg work Mdo~ed. com~let on Re~o~ ofhc~a[ or re~re~ntltl~ lilt On "Final" form. li Submit "Interim" ~heet~ when filled out but not le~ frequently Ihln every ~ Oa~S. Or (2) On We~nel~ay Gl the week in which oil itrlng il ~. Submit weekly tot workouts an~ following letting o gl siring until completion. District ICounty or Perish KENA.! BOROUGH Lease or Unit ARCO Alaska, Inc. TRADING BAY 3NIT Well no. as of 8;0~ a.m. 04/27/88 ( 2 TD: 8772'( SUPV:HP 04/28/88 ( 2 TD: 9128'( SUPV:MAL 04/29/88 ( 3 TD: 9388'( SUPV:MAL 04/30/88 ( 3 TD: 9640'( . SUPV:MAL 05/01/88 ( 3 TD:10007' ( i SUPV:MAL 05/02/88 ( 3~ TD:10258' ( ; SUPV:MAL 05/03/88 ( 34 TD:10318' ( SUPV:MAL 05/04/88 ( 35 TD:10601' ( 2 SUPV:MAL 05/05/88 TD:10895' ( SUPV:HP Complete record1 for each O&y While Orilhng or worl<over in progress KING SALMON 3) DRILLING MW: 9.3 VIS: 50 360) DRILLED TO 8772'. CIRCULATE BOTTOMS UP. POH. CHANGED BIT & BHA. RIH. CUT DRILLING LINE. RIH. DAILY:S32,769 CUM:$765,386 ETD:S765,387 EFC:$3,859,999 ~56) POH, CHANGE OUT BIT DRILLED 12-1/4" HOLE TO 9128'. TOH. DAILY:S22,215 CUM:$787,601 MW: 9.3 VIS: 44 DROPPED SURVEY, PUMPED PILL. ETD:S787,601 EFC:$3,860,000 ~) :60) TIH MW: 9.2 VIS: 49 CHANG£D OUT BIT. TIH. DRILLED TO 9388'. POOH FOR BIT. CHARGED OUT STB & BIT. TIH. DAILY:S21,434 CUM:$809,035 ETD:S809,035 EFC:$3,860,000 ,) :52) DRLG MW: 9.2 VIS: 45 TIH AND DRLD 12-1/4" HOLE F/ 9388' TO 9594'. SHORT TRIP. DRLD 12-1/4" HOLE TO 9640'. DAILY:S19,720 CUM:$828,755 ETD:S828,755 EFC:$3,860,000 :) 67) DRLG MW: 9.2 VIS: 49 DRLD 12-1/4" HOLE F/ 9640' TO 9787'. SHORT TRIP. DRLD 12-1/4" HOLE TO 10007' . DAILY:S30,563 CUM:$859,318 ETD:S859,318 EFC:$3,860,000 ) 51) TOH MW: 9.3 VIS: 47 DRLD 12-1/4" HOLE F/ 10007' TO 10101'. SHORT TRIP. DRLD 12-1/4" Fl 10101' TO 10258'. JUMPED BUSHING AND BACKED OFF DP. FISH DP AT 964'. CATCH FISH. TOH. DAILY:S21,206 CUM:$880,524 ETD:S880,524 EFC:$3,860,000 ) 6o) DRLG MW: 9.3 VIS: 47 TOH. LD HWDP. CH~GE OUT MWD. TIH. WASH AND REAM F/ 10091' TO 10258'. DRLD F/ 10258' TO 10318' DAILY:S32,982 CUM:$913,506 ETD:S913,506 EFC:$3,860,000 ) 83) TIH DRLD 12-1/4" HOLE TO 10601' POOH F/ BIT. PULL WEAR RING. SET WEAR RING. TIH. DAILY:S21,024 CUM:$934,530 MW: 9.2 VIS: 45 CIRC. DROP SURV. PUMP PILL. RU AND TEST BOPE TO 3000 PSI. ETD:S934,530 EFC:$3,860,000 DRILLING DRILL 12-1/4" HOLE TO 10895' MW: 9.2 VIS: 42 DAILY:S37,665 CUM:$972,195 ETD:S972,195 EFC:$3,860,000 The adore is correct For form prepa/'J~tion and d~striPutiorl see Procedure~,Nianual Section 10. Drilling, Page~,86 and 87 Date ITitle ~'.~' / ~ ~'~. ASSOCIATE ENGINEER tNumDer all aady well h~s~ory Iorms consecutively Page no. as they are prepared for each well. , ARCO Oil and Gas Company Daily Well History--lnterir Inetr~ctlonl: TII~s form cs use0 Ourmg clrilhng or workove, oO~retlons If testing, coring, or perforal,ng. Ihow formation name m Oescrib~ng work ~dO~ed. Numar ail ~tl~l Item tests ~quentllUy. Attach OeKnpt&On of ali cores Work ~rtorme0 by ProOuclng Section will Oe repo~eo ~ "lh~rlm" Ifl~tl until hall completion. Repo~ ofhclat or reDrllentlhve felt on "Fell" tO~. 1} SuOmH "l~te~lm" I~eeti when fdleO out bul not leal frequently t~ln eve~ ~ Olyt, or (2) on We~nelOay of the week in WhlCfl oil Itrlng il ~t. Submit weekly tot worko~rl and following ~ttmg Of Oii striao until complltl~. District F~eio Dele eno Oepth as of 8:00 a.m. l .County or Psr~sh A/~CO Alaska, Inc. KENAI BOROUGH La&aa or Unit TRADING BAY UNIT K-6 /K-6RD ;Complete recorcl Ior each clay while Orilhng or workover in progress 05/06/88 ( TD:l1416'( SUPV:HP 05/07/88 ( TD:11632'( SUPV:HP 05/08/88 ( TD:11735' ( SUPV:HP 05~09/88 ( TD:11807' ( SUPV:HP 05/10/88 ( TD:11895' ( SUPV:HP 05/11/88 ( TD:11983' ( SUPV:HP 05/12/88 ( TD:11983' ( SUPV:ML o5/13/88 ( TD:11983' ( SUPV:M~ 7) 521) 8) 216) ,9) 103) o) 72) 1) 88) 2) 88) 3) o) 4) o) KING SALMON I StlteAK POOH MW: 9.2 VIS: 57 DRLD 12-1/4" HOLE TO 11229'. SHORT TRIP. DRLD 12-1/4" HOLE TO 11416'. CIRC. POOH. DAILY:S25,486 CUM:$997,681 ETD:S997,681 EFC:$3,860,000 DRLG MW: 9.2 VIS: 46 POOH. CHANGE BHA. RIH. REAM F/ 5521' TO 5722' DRLD 12-1/4" HOLE TO 11632' DAILY:S41,642 CUM:$1,039,323 ETD:S1,039,323 EFC:$3,860,000 DRILLING MW: 9.2 VIS: 50 DRILL 12-1/4" HOLE TO 11716'. CBU. POOH. PU DRILEX MOTOR. RIH. ATTEMPT TO DRILL. HAVING SIGNAL PROBLEMS WITH M~'D. DRILL 12-1/4" HOLE TO 11735'. DAILY:S27,637 CUM:$1,066,960 ETD:S1,066,960 EFC:$3,860,000 DRILLING MW: 9.2 VIS: 48 DRILL 12-1/4" HOLE TO 11771'. UNABLE TO DEBUG SIGNAL PROBLEM WITH MWD. POOH. CHECK MWD. TEST MOTOR AND MW'D. DRILL 12-1/4" HOLE TO 11807'. DEBUG MWD SIGNAL AND PROCEED. DAILY:S26,307 CUM:$1,093,267 ETD:S1,093,267 EFC:$3,860,000 REAMING MOTOR RUN MW: 9.2 VIS: 44 DRILL 12-1/4" HOLE WITH MUD MOTOR TO 11895'. POOH LD MUD MOTOR. RIH TO SHOE. TEST MWD. REAM MOTOR RUN. DAILY:S25,121 CUM:$1,118,388 ETD:SI,II8,388 EFC:$3,860,000 POOH FOR CASING MW: 9.2 VIS: 45 FINISH REAMING FROM 11700'-11895'. DRILL 12-1/4" HOLE TO 11983'. PUMP PILL. SHORT TRIP TO SHOE. RIH. CIRC AND CONDITION FOR CASING. DROP SURVEY. PUMP PILL . POOH FOR CASING. DAILY:S24,232 CUM:$1,142,620 ETD:S1,142,620 EFC:$3,860,000 MU CASING HANGER MW: 9.2 VIS: 44 POOH LD BHA. CHANGE TO 9-5/8" PIPE RAMS. RU TO RUN 9-5/8" CASING. RIH WITH 9-5/8" CASING TO 11958'. MU CASING HANGER. DAILY:S21,522 CUM:$1,164,142 ETD:S1,164,142 EFC:$3,860,000 RIH' INSPECTING DP MW: 9.4 VIS: 45 FINISH RUNNING 9-5/8" CASING. RAN 48 JTS OF 53#, S-95, BTC 9-5/8" CASING AND 248 JTS OF 47#, L-80, BTC 9-5/8" CASING. FC @ 11872'. FS @ 11958'. CEMENT CASING WITH 1050 SX 15.8 PPG CLASS G CEMENT. CIP @ 2000 5/12/88. CHANGE RAMS TO 5". TEST BOPE TO 3000 PSI. PU BHA. RIH BREAKING EACH CONN. INSPECTING DP. DAILY:S42,628 CUM:$1,206,770 ETD:S1,206,770 EFC:$3,860,000 The above is correct Dale ITitle For form prepar/A~ion an0 clistriOution see Procedures~anual Section 10, Drilling, Pages 86 an0 87 ASSOCIATE ENGINEER NumDer at; 0,3ily well r~islory forms consecutively 1Paoe. no. es they are prepare~ tot each well. I ARCO Oil and Gas Company Daily Well History--lnteri~ Ihstr~cttone: This form is use¢l ¢lurlng 0tilting or workover ooerehons If leafing, coring, or Derloranng. enow formation name in deacrlbi~,g work I)erfoll'l~ed. Number Ih 0rill Item Ilst~ leQuentlllly. Attach Oelcrlptlon OI all cores Work ~rtormed by Producing ~chon will ~ repo~e~ on "ln~rlm" ~HII until final District ARCO Alaskar Inc. I KENAI BOROUGH I Lease or Unit I F~eld TRADING BAY UNIT IWeJl no. Date aha oepm as of 8;00 a.m. 05/14/88 ( TD:11983' ( SUPV:ML 05/15/88 ( TD:11988' ( SUPV:ML 05/16/88 ( TD:12151' ( SUPV:M~ 05/17/88 ( TD:12482' ( SUPV:ML 05/i8/88 ( TD:12823' ( SUPV:ML 05/19/88 ( TD:13190' ( SUPV:ML 05/20/88 ( TD:13298' ( SUPV:SfL 05/21/88 ( TD:13298' ( SUPV:M~ Complete record tot each 0ay while drilling or workover in progress KING SALMON 5) RIH, INSPECT DP MW: 0.0 VIS: 0) RIH. INSPECT AND REFACE DP. 7) 163) 8) 331) 9) 341) o) 367) 51) 108) 52) O) DAILY:S296,825 CUM:$1,503,595 ETD:S1,503,595 EFC:$3,860,000 DRILLING MW: 9.2 VIS: 42 RIH. INSPECT AND REFACE DP. TAGGED TOP OF CMT @ 11215'. DRILLED CMT FROM 11215'-11872' TESTED 9-5/8" CASING TO 3000 PSI. DRILLED FC, FS AND 5' NEW HOLE TO 11988'. PERFORMED LOT TO 13.5 PPG EMW. DAILY:S18,784 CUM:$1,522,379 ETD:S1,522,379 EFC:$3,860,000 TIH MW: 9.1 VIS: 49 DRILLED 8-1/2" HOLE TO 12151' PUMPED PILL. TOH & CHANGED BIT. TESTED MWD. TIH. DAILY:S25,181 CUM:$1,547,560 ETD:S1,547,560 EFC:$3,860,000 TIH MW: 9.0 VIS: 44 TIH. CUT DRILLING LINE. DRILLED 8-1/2" HOLE TO 12482'. INSTALLED REBUILT CAT-HEAD. POOH. CHANGED OUT BHA. DAILY:S162,052 CUM:$1,709,612 ETD:S1,709,612 EFC:$3,860,000 DRILLING MW: 9.0 VIS: 51 CHANGED BHA. TIH. DRILLED 8-1/2" HOLE TO 12823' DAILY:S31,867 CUM:$1,741,479 ETD:S1,741,479 EFC:$3,860,000 DRILLING MW: 9.0 VIS: 47 DRILLED TO 13010'. DROPPED SURVEY. PUMPED PILL. TOH & CEANGED BHA. TIH. WASHED & REAMED 90' TO BOTTOM. CONTINUED DRILLING 8-1/2" HOLE TO 13190' DAILY:S30,775 CUM:$1,772,254 ETD:S1,772,254 EFC:$3,860,000 WORKING STUCK PIPE ~6:9.0 VIS: 44 DRILLED 8~1/2" HOLE TO 13298'. DP BACKED OFF. SCREW INTO FISH AND WORK PIPE. DP PARTED WITH 625K PU @ 347'. BACKED OFF DP @ 1530'MD. TOH. LD OVERSHOT. TIH. SCREh~D INTO DP @ 1530'. DAILY:S19,882 CUM:$1,792,136 ETD:S1,792,136 EFC:$3,860,000 POOH MW: 9.0 VIS: 44 PULL ON DP. NO JARRING ACTION. UNABLE TO PULL FREE. DP PULLED OUT OF BOX AT 1068' PU TRI-STATE SCREW IN SUB AI~D RIH. SCREW INTO PIPE. CIRC. SPOT OIL PILL. WORK PIPE. RIG UP STRING SHOT. PIPE BACKED OFF AT 13094'. RD WIRELINE. POOH. LD BAD JTS. DAILY:S27,688 CUM:$1,819,824 ETD:S1,819,824 EFC:'$3,860,000 The adore is correct For form prepareti, e/'~'an"0-clis{rit3unon see Proceclures ~ghual Section '10, Drilling, Pages 86'and 87 tDate ITifle ASSOCIATE ENGINEER Number all (3alW well history forms consecutively as ney are prepared for each well. IPage no. ARCO Oil and Gas Company Daily Well History--lnterir Instr~cftona: This form is uled dunng ¢lnlling or workover ODerefiona If tear,no, coring, or 13ertorehng. ahow formehon name in describing work ~Ho~ed. NumDer ali drill stem lasts leqUentlaily. Attach Oelcrl~hOn of iii cores. Work ~rformed by ProOuclng SeChon will be reOo~ed on "l~rim" Ih~tl u~tii tlnll comDletlOn. ReDort official or rlpresentltlve feat on "~lflll" lore. 1) SuDmlt "interim" ineetl when fillea out Put not le~ frequently Ihln I~ ~ ~lyl. Or (2) on Wednesday of the week In WhlCfl o;I Itr~ng il ~t. Submit w~kly for workovlri and Iollowmg letting ol Oll ItrlflG untli completion. Distr~ct County or Per,Ih I State ARCO Alaska, Inc. KENAI BOROUGH I AK F~elO Leaae or Unit TRADING BAY UNIT K-6 /K-6RD Complete record tot each (~ay while drllhng or workover in progress KING SALMON Date an(3 depth aa of 8;00 a.m. 05/22/88 ( TD:13298' ( SUPV:ML 05/23/88 ( TD:13298' ( SUPV:ML 05/24/88 ( TD:13298' ( SUPV:ML 05/25/88 ( TD:13298' ( SUPV:ML 05/26/88 ( TD:13298' ( SUPV:ML 05/27/88 ( TD:12680' ( SUPV:ML 05/28/88 ( TD:12778' ( SUPV:ML 3) 0) 4) 0) 5) 0) 6) o) 7) 0) ) 0) 9) 98) RIH MW: 9.0 VIS: 43 POOH. INSPECTING EACH JT. PREP TO PICK UP FISHING BHA. PU DC AND HWDP AND RIH. CDL. RIH W/ SCREW IN BHA. DAILY:S15,489 CUM:$1,835,313 ETD:S1,835,313 EFC:$3,860,000 ATTEMPT TO WORK DP MW: 9.0 VIS: 45 RIH. TAG FISH. WASH 30' TO TOP OF FISH. SCREW INTO FISH. ATTEMPT TO CIRC. RU WL. RIH W/ FREEPOINT. UNABLE TO GET PAST 12000' POOH. CHANGE TOOLS. RIH. WORK THROUGH BRIDGE. POOH TIGHT. MU ~ JARS AND SPANGS AND BIT. RIH WORK TO TOP OF MDC. POOH. ATTEMPT TO WORK JARS. DAILY:S15,239 CUM:$1,850,552 ETD:S1,850,552 EFC:$3,860,000 ATTEMP TO BACK OFF MW: 9.0 VIS: 44 WORK PIPE. MU SOS PERF GUNS AND RIH. ATTEMPT TO PERF DC AT 13151'-13154'. WO LARGER GUNS. WORK PIPE. MU 2-1/8" GUNS. RIH PERF DC F/ 13151'-13154'. POOH. LOST GUN/CCL/SPINNER BARS AND 1/2 ROPE SOCKET. CBU. RU FREEPOINT. lST RUN FAILED. 2ND RUN INDICATED ALL DC STUCK. ATTEMPT 2 BACKOFF SHOTS AT 12864'. NO LUCK. ATTEMPT BACK OFF AT 12834'. DAILY:S15,523 CUM:$1,866,075 ETD:S1,866,075 EFC:$3,860,000 POOH MW: 9.0 VIS: 44 ATTEMPT BACKOFF AT 12834. CIRC AND WORK PIPE. MU AND RIH W/ SIDE RING CHARGE. CUT HWDP AT 12860'. POOH. RIH. SPOT BALANCED PLUG W/140 SX CLASS G AT 12860'- 12550' (APPROX). POOH. DAILY:S290,582 CUM:$2,156,657 ETD:S2,156,657 EFC:$3,860,000 RIH MW: 9.0 ViS: 42 POOH INSPECTING DP. TEST BOPE. PU AND MU BHA AND RIH. DAiLY:S34,270 CUM:$2,190,927 ETD:S2,190,927 EFC:$3,860,000 SIDETRACK W/ MUD MOTOR MW: 9.0 VIS: 49 FIN PU BHA. RIH INSPECTING HWDP. TIH. TAG CMT AT 12575'. DRLD CMT F/ 12575' TO 12622'. ORIENT AND SIDETRACK. DRLG W/ MOTOR F/ 12622' TO 12680'. DAILY:S20,384 CUM:$2,211,311 ETD:S2,211,311 EFC:$3,860,000 DRILLING MW: 9.0 VIS: 42 DYNADRILL 8-1/2" HOLE TO 12711'. POOH. CHANGE OUT BHA. TIH. DYNADRILL 8-1/2" HOLE TO 12778'. DAILY:S59,295 CUM:$2,270,606 ETD:S2,270,606 EFC:$3,860,000 Well no. The adore is correct For form oreDar~on and distribution see Procedures~nual Section 10, Drilling, Pages 86 anc~ 87 iDate ASSOCIATE ENGINEER INumber all dally well hlslOry forms consecuhvely as they are prepared for each well. Page no. ARCO Oil and Gas Company Daily Well History--lnterir lelll~ctlenl: This form ii ulet'j (~urln~) drilling or worKove~ o~rlhonl. If teltlng. coring, or Dedorlt~ng. ihow to.ilion name in aescrlblng work ~ormea, Number iH Orlll Item lelts sequentlll~y. AITiC~ Oelcrlpt~on Of ali cores Work ~rtorme~ Dy ProouCmg ~Ct*On will be reDOneO on "lnmrim" I~letl until hnal CO~DleIIO~. ReDO~ otflC~ll or representative tell O~ "Flail" term. 1) Submit "lMerl~" Iheetl wfllh hileO Out but eel JaBS frequently thin every ~ ol~. or (2) on Wednesday of the week in which oil string i1 let. Submit wleRly for workouts ina Ionowmg Setting o1 Oil itr~n; until comDlet)on. D~strict F,eld as of 8:00 a.m. I County or Pariah ARCO Alaska. Inc. K~NAI BORO~ I Loa~e or Umt T'JI~. m 'T' ~{-6 /K-6RD Complete record for elc~ day wn~e ardhng or wor~over in progress 05/29/88 ( TD:12886' ( SUPV:ML 05/30/88 ( TD:12892' ( SUPV:ML 05/31/88 ( TD:12892'( SUPV:ML 06/01/88 ( TD:12500' ( SUPV:ML 06/02/88 ( TD:12740' ( SUPV:HP 06/03/88 ( TD:12100' ( SUPV:}{P 06/04/88 ( TD:12208' ( SUPV:}{P 06/05/88 ( TD:12341' ( SUPV:}{P ~TNG EALMON o) lO8) 1) 6) 2) 0) 3) 0) 240) 5) o) 6) 108) 7) 133) 1 State. k.~ Well no. TI}{ MW: 9.1 VIS: 46 DYNADRILL 8-1/2" }{OLE TO 12882' TOH. CHANGE BHA. TIH. DAILY:S34,195 CUM:$2,304,801 ETD:S2,304,801 EFC:$3,860,000 TO}{ MW: 9.1 VIS: 45 DYNADRILL 8-1/2" HOLE TO 12892'. PIPE TORQUED UP. PIPE TWISTED OFF @ 470'. SCREW INTO FIS}{ @ 470'. BACK-OFF DRILL PIPE @ 1012'. TOOH. TI}{ AND SCREW INTO FIS}{ @ 1012'. JAR PIPE OFF BOTTOM. WORK OUT OF HOLE TO SHOE. TOO}{. DAILY:S46,525 CUM:$2,351,326 ETD:S2,351,326 EFC:$3,860,000 TOH MW: 9.2 VIS: 42 TOO}{. INSPECTING DP. TIH WITH OEDP. TAG UP @ 12656'. SPOT 180 SX CLASS G CEMENT PLUG F/12340'-12703'. CIP @ 0130 3/31/88. CIRC }{OLE VOLUME. TO}{. DAILY:S30,498 CUM:$2,381,824 ETD:S2,381,824 EFC:$3,860,000 TIH WITH SIDETRACK ASSY MW: 9.1 VIS: 42 TIH. TAG UP @ 12340'. DRILL CEMENT TO 12500'. TOOH. PU SIDETRACK ASSEMBLY. TI}{. DAILY:S24,250 CUM:$2,406,074 ETD:S2,406,074 EFC:$3,860,000 ATTEMPTING SIDETRACK MW: 8.9 VIS: 48 RI}{ WIT}{ MUD MOTOR. TAG CEMENT @ 12568'. SIDETRACK & DRILL 12568'-12740'. DAILY:S22,376 CUM:$2,428,450 ETD:S2,428,450 EFC:$3,860,000 CBU MW: 9.0 VIS: 42 MOTOR FOR SIDETRACK FROM 12740'-12862'. MOTOR AND BHA HANGING UP ON FISH. SIDETRACK UNACCEPTABLE. MIX AND PUMP PILL. POOH. LD EXCESS HWDP. RIE. TAG FISH @ 12860'. BREAK CIRC. SPOT SIDETRACK PLU¢ F/12860'-12100'. PULL 12 STANDS AND CIRCULATE. EST. TOC @ 12100'. DAILY:S34,958 CUM:$2,463,408 ETD:S2,463,408 EFC:$3,860,000 DRILLING MW: 8.9 VIS: 42 FINIS}{ED CIRCULATING. POOH & LD 3-1/2" DP. TESTED BOPE. PU LOWSIDING/PLUG DRESSING ASSEMBLY. RI}{. TAGGED PLUG @ 12202' DRESSED AND ATTEMPT TO LOW SIDE. WORKED AND REAMED. DRILLED WIT}{ MUD MOTOR TO 12208'. DAILY:S27,304 CUM:$2,490,712 ETD:S2,490,712 EFC:$3,860,000 POH FOR BENT SUB MW: 8.9 VIS: 43 DRILLED WITH MUD MOTOR TO 12278'. LD 2 JTS DP. REAMED TO 12278'. DRILLED TO 12341'. PUMPED PILL. POH FOR BENT SUB TO MAKE CONFIRMED SIDETRACK. DAILY:S19,340 CUM:$2,510,052 ETD:S2,510,052 EFC:$3,860,000 The above iS correct Signature For form prepare'{~n and distribution see ProceJ3ures ~lanual Section 10, Drilling, Pages 86 and 87 jDate JTitle ~ ./~ -~ A~OCIATE ENGINEER Number all 0Slay well hlslory forms consecutively as they ate prepared for each well. Page rio. ARCO Oil and Gas Company Daily Well History--lnterif InltnlcliOnl: This form ii u~el:l t~urlng orlliing or workover o~)~ratlon$, tf telling, coring, or ~rlorlhng. show form8tl~ fllme in descrtD~ng work ~Ho~ed. NumDer i11 Grill Ilea Illll ~Qulntlllly. Attach OIICrlDtlOn Ut ill cores Work ~rfo~ by ProOuclng ~ctlon will OI ~Donla ~ "lfllrlm" I~eetl unlil final completion. ReDo~ Official or rlprelentltlve telt on "Finll" 1o~. 1} Submit "interim" iheetl when fllleo out but not less frequently than e~ 30 Olyl, Or (2) On Weoneloay of the week in which Oil airing ii ~t. ~ubmll weekly for workovem In~ following letting Ut Oil strinG until completion. I COunty or ARCO Alaska, Inc. [ KENAI BOROUGH I Lelle or Unit TRADING BAY UNIT I K-6 /K-6RD Complete recoro lot each Oay wh,e ~3rllhng or workover in progresl KING SALMON 06/06/88 ( TD:12365' ( SUPV:HP 8) 24) 9) 0) Distnct F~eld Date an0 oeptn as of 8:00 a.m. 06107188 ( TD:12365' ( SUPV:HP 06/08/88 ( TD:12864' ( SUPV:HP 06/09/88 ( TD:13085' ( SUPV:MAL 06/10/88 ( TD:13276' ( SUPV:MAL 06/11/88 ( TD:13276' ( SUPV:MAL 06/12/88 ( TD:13276' ( SUPV:MAL 06/13/88 ( TD:13276' ( SUPV:51AL The above is correct 0) 99) .) 221) 2) 191) 3) 0) 4) 0) 5) 0) IstateAK ORIENT AND DRILL MW: 9.0 VIS: 43 POH. SERVICED AND CHANGED BIT. RIH. REAMED TO 12341'. SIDETRACKED & DRILLED F/12341'-12353'. REPAIRED SURFACE MWD ELECTRONICS. ORIENT AND DRILLED TO 12365' DAILY:S29,535 CUM:$2,539,587 ETD:S2,539,587 EFC:$3,860,000 RIH MW: 9.0 VIS: 42 DRILLED TO 12446'. REAMED. PUMPED PILL AND POH. C~LANGED BHA. RIH. DAILY:S31,645 CUM:$2,571,232 ETD:S2,571,232 EFC:$3,860,000 DRILLING MW: 9.0 VIS: 43 REAMED SIDETRACK MOTOR RUN. DRILL & SLIDE TO 12864'. DAILY:S26,892 CUM:$2,598,124 ETD:S2,598,124 EFC:$3,860,000 MAKE SHORT TRIP MW: 9.1 VIS: 43 DRILLED 8-1/2" HOLE TO 12896'. PUMPED PILL. TOH. CHANGED BHA. TIH. REAMED TO 12896'. CONTINUED DRILLING 8-1/2" HOLE TO 13085'. DAILY:S26,876 CUM:$2,625,000 ETD:S2,625,000 EFC:$3,860,000 TOH MW: 9.0 VIS: 54 SHORT TRIP TO SHOE (9-5/8"). TIH TO 12638'. REAMED SINGLES TO 13085'. DRLD 8-1/2" HOLE TO 13276'. CIRCULATE. DROPPED SURVEY; TOH. DAILY:S32,753 CUM:$2,657,753 ETD:S2,657,753 EFC:$3,860,000 WORK AND JAR STUCK PIPE MW: 9.0 VIS: 54 FIN TOH. CHANGE BHA. TEST BOPE TO 3000 PSI. CUT DRILL LINE. TIH. REAM F/ 12728' TO 13175'. STUCK AT 13175'. JAR AND WORK FREE. REAM TIGHT SPOT AT 13175'. STUCK AT 13219'. SPOT. MINERAL OIL PILL. WORK AND JAR STUCK PIPE. DAILY:S26,099 CUM:$2,683,852 ETD:S2,683,852 EFC:$3,860,000 WORK AND JAR STUCK PIPE MW: 9.0 VIS: 49 WORK AND JAR ON STUCK PIPE. DP PARTED AT 197'. FLY OUT FISHING TOOLS. PU OS. RIH AND CATCH DP STUB. BACK OFF AT 800' PU 26 JTS DP. RIH AND SCREW INTO DP AT 800' JAR ON STUCK PIPE. DAILY:S23,104 CUM:$2,706,956 ETD:S2,706,956 EFC:$3,860,000 PREP TO BACK OFF MW: 9.0 VIS: 41 CIRC AND WORK AND JAR ON STUCK PIPE. SPOT 50 BBLS MINERAL OIL PILL ON BTM. JAR ON STUCK PIPE. RU APRS AND RUN FREE PT SURVEY. FREE TO BTM OF D-JARS. MU STRING SHOT. PREP TO BACK OFF AT D-JARS. DAILY:$S0,625~-~.~,745,~ ......... ,.~.~,~.~,~=*~ .... ~.~*~,~, Signatu,e For torm ptepl~tion and distribution see Procedure's/Manual Section 10. Drilling. Page%/86 and 87 ASSOCIATE ENGINEER Dale ]Tilie lweli no. INumOer all oalW welt h~story Iotas consecullVely IPage no, as they are prepared for each well. I ., ARCO Oil and Gas Company Daily Well History--lnterin Inlfl'tlctmnl: Thll form e& Ula(~ Outing ¢lrllhng or wOrkover OI)erltlonl If lelhn~ coring, or ~rtorltJno, Ihow tormlll~ name in OesCrlblng work Num0ar a;I 0nil Item tests sequentially. AttaCh Oelcrlpllon Of all coral Work ~rlor~ by ProOuc~ng Section will be ~poned on "la.tim" Iheatl until fall complebon. Repo~ offic~ll or ~p~elentat*ve lilt on "Flail" Iota. 1} SuDmiI "Interim" sheets when Illied OUt but not lass frequently than e~ty ~ ~lyl, on Wednesday el the week in which oil itrtng il ~t. Su~mit weekly Ior workovlrl an~ Iollow~ng ~ett*ng of oil Itr~n~ until District F~eld T~ADTN~ Date eno oeptn as of 8:00 a.m. I County or Panih ARCO Alaska. Inc. K~NAI BOROUGH I Lelte Or Unit K-6 /K- 6RD Complete recor~ for each day white Orllhng or workover in progress 06/14/88 ( TD: 13276' ( SUPV:MAL 06/15/88 ( TD:13276' ( SUPV:MAL 06/16/88 ( TD:13276' ( SUPV:MAL 06/17/88 ( TD:13296' ( SUPV:MAL o6/18/88 ( TD:13296' ( SUPV:HP 06/19/88 ( TD:13296' ( SUPV:HP 06/20/88 ( TD:13296' ( SUPV:HP 06/21/88 ( TD:13296' ( SUPV:HP 6) 0) 7) 0) 8) o) 9) 20) 0) 0) 1) o) 2) o) 3) o) KING SALMON IStat~ PREP TO CUT DS MW: 9.0 VIS: 41 ATTEMPT TO BACK OFF PIPE. NO GOOD. DRL STRING TURNING ON MUD MOTOR. RD SOS/ APRS. ROTATE AND JAR ON STUCK PIPE. RU APRS AND ATTEMPT TO CUT DRL STRING AT 13187'. DAILY:S25,200 ' CUM:$2,770,781 ETD:S2,770,781 EFC:$3,860,000 TOH MW: 9.0 VIS: 48 SEVER DRL STRING AT 13187' UNABLE TO PULL FREE. RUN FREE POINT SURVEY. PIPE FREE TO BTM OF UP-JAR AT 13110' WLM. BACK OFF DP AT TOP OF UP-JAR AT 13090' WLM. CIRC OUT MINERAL OIL PILL. TOH. DAILY:S129,248 CUM:$2,900,267 ETD:S2,900,267 EFC:$3,859,762 RIH W/ SCREW IN SUB MW: 9.0 VIS: 45 MAKE COND RUN TO TOP OF FISH. PU SCREW IN SUB AND JARS. RIH. DAILY:S16,773 CUM:$2,917,040 ETD:S2,917,040 EFC:$3,860,000 PREP FOR BACKOFF ATTEMPT MW: 9.0 VIS: 44 RIH. SCREW INTO FISH. ATTEMPT TO JAR FREE. ATTEMi~T TO BACKOFF AND JAR. SET UP FOR 2ND BACKOFF ATTEMPT. DAILY:S21,308 CUM:$2,938,348 ETD:$2,938,348 EFC:$3,860,'000 RUNNING LOGS MW: 9.0 VIS: 44 BACK OFF @ 13094'. POOH. LD FISHING BHA. LEFT SCREW IN SUB IN HOLE. NEW TOF @ 13093'. CIRCULATE AND CONDITION HOLE FOR LOGS. RIH WITH DIL SONIC TO 12200'. TOOL FAILURE. POOH. REHEAD LINE. DAILY:S34,795 CUM:$2,973,143 ETD:S2,973,143 EFC:$3,860,000 LOGGING OPEN HOLE MW: 9.0 VIS: 45 ATTEMPT WIRELINE LOGS. UNABLE TO GET BELOW 12200'. RIH WITH DRILL PIPE AND CLEAN OUT TO TOF. REAM TIGHT SPOTS. CIRC. POOH. RU DRILL PIPE CONVEYED LOGS. DAILY:S18,966 CUM:$2,992,109 ETD:S2,992,109 EFC:$3,860,000 LOGGING OPEN HOLE MW: 9.0 VIS: 46 RIH WITH LOGGING TOOLS ON DP. RIH WITH WL. UNABLE TO LATCH UP. POOH WITH WL AND DP. REPAIR CONNECTOR. RIH WITH DP AND LOGGINGS TOOLS. RIH WITH WL FOR LATCH UP. DAILY:S15,633 CUM:$3,007,742 ETD:S3,007,742 EFC:$3,860,000 RU DP CONVEYED LOGS MW: 9.1 VIS: 44 RIH WITH WL. COULD NOT MAKE CONNECTION WITH LOGGING TOOL. POOH WITH WL AND DP. RD WL. CIRCULATE AND CONDITION HOLE FOR LOGS. POOH. RU SOS DP CONVEYED LOGGING TOOLS. DAILY:S15,633 CUM:$3,023,375 ETD:S3,023,375 EFC:$3,860,000 IWell no. The at3ove is correct For form prel~ratlon eno distribution see Proce0u~J~ Manual Sechon 10, Drilling, Pagd§ 86 and 87 Date~ Title ' /9 -~ ASSOCIATE ENGINEER NumDer all OaHy well history forms consecutively as tiqey are prepared for each well, Page no. ARCO Oil and Gas Company Daily Well History--lnterin Inlll'u¢ll~ltl: Thll Iorm Is use~3 Outing (:lrllilng or workovet o~)erltion&. If lilting, CO,mE. or DedOrlt~flg. Ibow Iormltl~ name in Oelcribing ~OFK ~mo~. Number ail ~rill Item teltl ~Qulnt~llly. AttaCh OelcrlDllon Of all Cores Work ~rtormed ~y Producing Section will ~ ~DO~ed ~ "l~rl~" Iheetl until final complehon. ReDo~ official or reptlllnllhve tilt On "Final" form. 1) Submit "lateri~" sheets when lllieO out Out hal lilt l~Quentiy thin i~ry On Weonel~ly of the week i~ w~ch OH Itrmg ~1 ~t. Submit weekly for wor~ove~ and fol[owmg ~ttmg of oil Itrm~ unhl completion. [;hst riot __ F~elCl TRADINC. BA~ Date anti oeDth ss of 8:00 a.m. County or Pan$l~ ARCO Alaska. Inc. I KENAI BOROUGH I Laass or Ur~d. UNIT [ K-6 /K-6RD Complete recorO for each flay wh~le -rilhng or wa,Kava, in progress 06/22/88 ( TD:13296' ( SUPV:HP 06/23/88 ( TD:13296'( SUPV:GC 06/24/88 ( TD:13296' ( SUPV:GC 06/25/88 ( TD:13296' ( SUPV:GC 06/26/88 ( TD:13296' ( SUPV:GC The above is corre:t 06/27/88 ( TD:13296' ( SUPV:GC KING SALMON J SIIll~[K RIH WITH CLEAN OUT ASSEMBLY MW: 9.1 VIS: 43 RIH WITH DRILL PIPE CONVEYED LOGGING TOOLS. RIH WITH WL. LATCH AND POWER UP LOGGING TOOLS. LOG DIL/SONIC FROM 11958'-12722'. LOST POWER. ATTEPIPT TO POOH WITH WIRELINE. WIRELINE STUCK. POOH WITH DRILL PIPE CUTTING WL EACH STAND. RIH WITH SLICK CLEAN OUT BHA. DAILY:S130,633 CUM:$3,154,008 ETD:S3,154,008 EFC:$3,860,000 TIH WITH WIRELINE MW: 9.3 VIS: 45 MADE CONDITIONING RUN. RAISED MW TO 9.2 PPG. POOH. PUMPED PILL @ CASING SHOE. PU SOS LOGGING TOOLS DIL/SONIC. RIH WITH WIRELINE THROUGH SIDE DOOR SUB. DAILY:S20,212 CUM:$3,174,220 ETD:S3,174,220 EFC:$3,860,000 7) POOH WITH LOGGING TOOLS MW: 9.3 VIS: 45 RIH WITH WL AND LATCHED LOGGING TOOLS. LOG DIL/SDT/GR/PMS FROM 11845'-13069'. COULD NOT GET BELOW 13069'. POOH. RIH WITH WL AND LATCHED LOGGING TOOLS. LOG CNL/DEN/CAL/GR FROM 11845'-12096'. COULD NOT GET BELOW 12096'. UNLATCHED AND POOH FOR WIPER TRIP. DAILY:S15,216 CUM:$3,189,436 ETD:S3,189,436 EFC:$3,860,000 RIH MW: 9.3 VIS: 44 CONTINUED POOH FOR WIPER TRIP. LD LOGGING TOOLS. TIH TO 9-5/8" SHOE. CUT DRILLING LINE. REASfED FROM 12200' TO 12360'. CIRCULATE HI-VIS PILL; NO EXTRA CUTTING. SHORT TRIP TO SHOE - NO PROBLEMS. POOH - STOOD BACK BHA. PU CNL/DEN/CAL/GR AND TIH. RIH WITH WL TO LATCH TOOLS. DAILY:S17,532 CUM:$3,206,968 ETD:S3,206,968 EFC:$3,860,000 POOH WITH WL & LD SOS MW: 9.3 VIS: 44 CONTINUED RIH WITH WL & LATCHED LOGGING TOOLS. RAN DP AND TOOLS TO 12120' - TOOLS STOPPED. WORKED DOWN TO 13074; CNL/DEN WAS NOT WORKING. LOGGED CAL/GR F/13074' TO CASING SHOE. POOH WITH WL & LD SOS. POH WITH LOGGING TOOLS. LD SALVE. REPLACED CNL/DEN/CAL/GR. TIH. LOGGED GR DOWN TO 13072' LOGGED UP FULL COMBO TO CASING SHOE. POOH WITH WL. LD SIDE DOOR SUB. DAILY:S15,466 CUM:$3,222,434 ETD:S3,222,434 EFC:$3,860,000 9) RIH W/7" LINER MW: 9.3 VIS: 44 FINISHED POOH WITH WL & LD SIDE DOOR SUB. POOH WITH DP. LD LOGGING TOOLS. PU SAME MOTOR & BIT; TIH TO SHOE. TIH TO 50' FROM BOTTOM. WASHED TO 13093'. CIRCULATE BOTTOMS UP. SHORT TRIP TO SHOE. CIRC. SWEEP AROUND AND SPOTTED PILL IN OPEN HOLE. POOH TO SHOE. PUMPED SLUG. POH & LD MOTOR. RU TO RUN 7" LINER. RAN 32 JT 7", 29j, L-80, BT¢ CASING. DAILY:S18,536 CUM:$3~240,970 ETD:~,24g,~IU JWIII no. For form preps~ion and distribution see Procedure~LA4anual Section 10, Drilling, Pages 86 and 87 jDale IT,tie ASSOCIATE ENGINEER Number all oaily well h~story iorms conseculively as they are preps,ed for each well. lPage no. ARCO Oil and Gas Company Daily Well History--lnterir lnltr&lcllOnl: This fol/n is UllO Ounng drilling or worKovlr oo~retlon$, tf lilting, coring, Or ~dOrlllng, IhOW formation nlml In OelCrlbiflg work NumDer III ~rill Illin lists ~Quentlllly. Attach Oelcr~phon Of III cores Work ~rlo~d by ProOucing Section will be repo~le on "In.rim" ~eetl unlH hnll comptebon. RiDO~ official or rep~lentative lilt on "Flail" form. 1) Submit "lallrim" Iheetl when IiIll~ out ~uI not Ills frequently than evt~ ~ ~ayl. or on WaOnaldl~ of the week in which oil Itring ii ~t. Su~mit ~elkly for worKo~ri Ind toliowmg lilting OI oil strinG unlii complltlO~. D~strlct F~eld ARCO Alaska, Inc. KENAI BOROUGH Lea~e or Unit K-6/K-6RD TRADING BAY UNIT Well no, Date and oeom as of 8:00 a.m. 06/28/88 ( 9~ TD: 13296' ( S UPV: GC 06/29/88 ( 9 TD:13296'( SUPV:GC 06/30/88 TD:13296' ( SUPV:HP 07/01/88 ( 9] TD:13296' ( SUPV:HP 07/02/88 ( 94 TD:13296 PB: SUPV:HP 07/03/88 ( 95 TD:13296 PB:13042 SUPV:HP 07/04/88 ( 96 TD:13296 PB:13042 SUPV:HP Complete recorO for each oay while drilling or workover in progresl KING SALMON o) ) o) o) CJLkNGE OUT KELLY SPINNER MW: 9.3 VIS: 44 FINISHED RUNNING 7" LINER F/11674'-13089,. CEMENTED LINER WITH 60 SX CLASS G & 525 SX CLASS G (LATEX). PACKED OFF. SET LINER WITH 37 BBLS OUT OF SHOE. RELEASED FROM LINER. SQUEEZED 15 BBLS (72 SX CLASS G (LATEX)) INTO LINER LAP. POOH. TESTED BOPE. CHANGED KELLY SWIVEL AND PU SPINNER. DAILY:S42,115 CUM:$3,283,085 ETD:S3,283,085 EFC:$3,860,000 DRILLING CMT IN LINER MW: 9.1 VIS: 43 FINISHED HOOKING UP ON KELLY SPINNER. PU BHA. CUT DRILL LINE. TIH AND TAG CMT STRINGERS @ 10903'. WASHED TO 11380'. DRILLED CMT F/11380'-11668'. TAG TOL @ 11668' DPM. CIRCULATE BOTTOMS UP. TOH. LD 48 JT 5" DP. CHANGED BHA. TIH. DRILLED CMT F/11668'-11674'. DAILY:S40,905 CUM:$3,323,990 ETD:S3,323,990 EFC:$3,860,000 RIH MW: 8.9 VIS: 34 DRILLED CEMENT F/11674'-12298' PUMPED PILL AND POH. CHANGED BHA. RIH. DAILY:S15,856 CUM:$3,339,846 ETD:S3,339,846 EFC:$3,860,000 CIRC. & CLEAN HOLE MW: 8.5 VIS: FINISHED TIH. DRILLED CEMENT F/12298'-13042'. CIRCULATE AND DISPLACE HOLE WITH CLEAN FILTERED INLET WATER. DAILY:S15,063 CUM:$3,354,909 ETD:S3,354,909 EFC:$3,860,000 RUNNING GYRO DISPL HOLE TO FRESH WATER. POOH. 13038'. RUN CAL/GR F/ 0-11674' MW: 8.5 FW RUN CET/GR/CCL F~ 11642' TO RUN GYRO F/ 0' - 13038'. DAILY:S14,400 CUM:$3,369,309 ETD:$3,~69,309 EFC:$3,860,000 RIH W/ PET. MILL MW: 8.5 FW FIN RUNNING GYRO. TEST LNR LAP. RIH. PERF F/ 12650' TO 12652'. RIH W/ SQUEEZE RET. SET AT 12630'. UNABLE TO EST INJ OR CIRC FOR CMT SQUEEZE. POOH. PU MILL AND RiH. DAILY:$21,157 CUM:$3,390,466 ETD:S3,390,466 EFC:$3,860,000 RIH W/ RET MW: 8.5 FW RIH. MILL. RETAINER. CIRC. POOH. RE-RUN GYRO. RIH AND PERF F/ 12650' TO 12654'. RIH W/ RETAINER. DAILY:S14,'400 CUM:$3,404,866 ETD:S3,404,866 EFC:$3,860,000 The eOove iS correct Signature For form prepar~o~ and Oislribution see Procedures./~anual Section 10, Drilling, Pages~Bf, and 87 IDate ITitle ASSOCIATE ENGINEER NumDer all oally well hlslOry torres consecutively as they are prepare0 lot each well. Page no. ARCO Oil and Gas Company Daily Well History--lnteri Ii,lltrtlcl~llll: Thll torm Il Uled Ounng ¢lrtlllng or workover oPerltlonl. If telling, coring, or Derforltlng. Ihow IormltlOn nlml in OalCrlbing work D~rfol'~l~. Numoer ill drill stem lestl leQUlnllell),. AtllCh oescrlI::,IiOn Of Ill cores Work iI)ertorme8 by PtOOUClng Section will be rlPortlCl On "tn/rim" "haiti until Ilnll complehon. Repo~ ofhclsl or reprelenfahva till on "Final" form. 1) Submit "leterll~°' sheets when hill0 Out but not Itll fl'eQuently thin nwery 30 ,~lys. or (2) on Weone$,~ay of the week in which oil st,ag is set. Submit weekl), lo, workovera anti following settmg Of Oil at,ag unlil coml:)lettOn. District Date sno oeotn as of 8:00 a.m. County or Plrilh ARCO Alaska, Inc. I KENAI BOROUGH I Lee~e or Unit TRADING BAY UNIT J K-6 /K-6RD Complete record Ior each cia), while ~3rillmg or workover Jn progress 07/05/88 ( TD:13296 PB:13042 SUPV:HP 07/06/88 ( TD:13296 PB:13042 SUPV:HP 07/07/88 ( TD:13296 ?B:13042 SUPV:GC 07/08/88 (1 TD:13296 PB:13042 SUPV:GC 07/09/88 (1 TD:13296 PB:13042 SUPV:GC 7/11/88 TD:13296 PB:13042 SUPV:GC 07/10/88 (1( TD:13296 PB:13042 SUPV:GC KING SALMON ISialI no. 2) RIH W/ RETAINER MW: 8.5 FW RIH. SET RETAINER AND CIRC. SQUEEZE 170 SX CLASS G CMT. CIP AT 1030 HRS 7/04/88. POOH. SHOOT 2ND SQUEEZE PERFS AT 12060' TO 12064' RIH. ATTEM]PT TO SET RET. SETTING TOOL MALFUNCTION. POOH. RIH W/ NEW SETTING TOOL AND RET. DAILY:S84,375 CUM:$3,489,241 ETD:S3,489,241 EFC:$3,860,000 RiH W/ 6" BIT MW: 8.5 FW RIH. PERFORM LNR LAP SQUEEZE W/ 170 SX OF CLASS G F/ 12060' TO 11674'. POOH. TEST BOPE. RIH AND CLEAN OUT TO TOP OF LNR. POOH. RIH W/ 6" LNR CLEAN OUT BHA. DAILY:$26,146 CUM:$3,515,387 ETD:S3,515,387 EFC:$3,860,000 POOH AFTER SQUEEZE MW: 8.5 FIW TIH WITH 6" BIT. DRILLED FROM 11668'-11957'. CIRCULATED. TESTED LINER LAP TO 2500 PSI; 650 PSI LOSS IN 10 MINUTES. ATTEMPTED TEST 3 TIMES. POOH. TIH WITH 6 JTS 3-1/2" AND 5". CIRCULATED. MIXED AND PUMPED 125 SX CLASS G PLUG. SQUEEZED. POOH WITH DP. DAILY:S176,341 CUM:$3,691,728 ETD:S3,691,728 EFC:$3,860,000 TIH W/ 5" DP MW: 8.5 FIW POOH. TIH W/ BIT. TEST CSG TO 2500 PSI. GOOD. TIH. TAGGED CMT AT 11586'. DRLD TO 11674'. TESTED LINER LAP. LEAKED. POOH. TIH W/'5" MULESHOE TO SQZ'AGAIN. DAILY:S15,550 CUM:$3,707,278 ETD:S3,707,278 EFC:$3,860,000 POOH WITH 8-1/2" BIT MW: 8.5 FIW TIH WITH 5" MULESHOE, CIRC. CEMENT 100 SX CLASS G B~LANCED PLUG. POOH 10 STDS. SQUEEZE TO 2560 PSI. HELD 5 HRS. 3/4 BBLS CMT IN LAP. POOH. PU 8-1/2# BIT. TIH. TAGGED @ 11517'. DRILL CEMENT FROM 11517'-11667'. CIRC. POOH. DAILY:S21,078 CUM:$3,728,356 ETD:S3,728,356 EFC:$3,860,000 POOH WITH 6" BIT MW: 8.5 FIW POOH. TIH WITH 6" BIT. DRILL CEMENT TO l1960'._.TESTED LINER LAP TO 2500 PSI. GOOD. DRILL CEMENT AND RETAINER TO 12100'. 'TEST PERFS 12066%-12'06~' TO 2500 PSI . LEAKED 600 PSI IN 10 MIN 3 TIMES. CIRC. POOH WITH 6" BIT. " ., DAILY:S14,400 CUM:$3,742,756 ETD:S3,742,756 EFC:$3,860,000 TIH WITH 6" BIT MW: 8.5 FIW TOH. TIH WITH EZSV. SET SAME @ 12100'. CIRC. PUMPED 9 BBLS WATER, 21BBLS CEMENT, 3 BBLS OF WATER, 192 BBLS OF MUD. POOH 10 STANDS. SQUEEZE 7-1/4 BBLS OF CEMENT. HELD 4 HRS. RELEASED AND POOH. TIH WITH 6" BIT. DAILY:S26,411 CUM:$3,769,167 ETD:S3,769,167 EFC:$3,860,000 The above is correct For form preparatfon,,~d ¢Hslrlbuhon see ProceOures Mam~l Section 10. Drilling. Pages 86 and 87 Dale }Title ASSOCIATE ENGINEER Number ell oalJ¥ well hiS[Dry to,ms consecutively as they are Oreparec~ for each welJ. Page no, ARCO Oil and Gas Companyv"~' Daily Well History--lnteri~ Inllll.lctlonl; Thll form is uleO 0urlng Orllhng or wOrl~over operations, If leltlng, coring. Or I>e~forllmg. ShOW lormltlon name In Oescribmg work I)ertonl~ed. NumDer ill ~rlll stem leSll sequentially Attach OescrlptlOn Ut ill cores Work ~rlo~ed by ProOuclng SeCtiOn will be repo~ed On *'In.rim"' Ifleets until bna1 complehon. ReDO~ official or reDrl~ntlhve tell on "Flnl~" form. 1) Sunred "l~tlt~" Iheetl w~l~ IdieO out ~ut not leis t~eOue~tly then every 30 on ~lones~ly o~ the week in which OH ltrlng ii let. Submit weekly tot workovem an~ followmg letting gl OH lirtn~ until completion. District tCounty or P .... h ARCO Alaska, Inc. I KENAI BOROUGH F~eld Lease or Unit TRADING BAY UNIT K-6 /K-6RD Complete recurs for each oaf while erdhng or worl~ovsr in progress Data eno oepth as of 8:00 a,m. 07/12/88 (1¢ TD:13296 PB:13042 SUPV:GC 07/13/88 TD:13296 PB:13042 SUPV:GC 07/14/88 TD:13296 PB:13042 SUPV:HP · 07/15/88 (1¢ TD:13296 PB:13042 SUPV:HP 07/16/88 (lC TD:13296 PB:13042 SUPV:HP 07/17/88 (lC TD:13296 PB:13042 SUPV:HP 07/18/88 (11 TD:13296 PB:13042 SUPV:HP KING SALMON POOH WITH 6" BIT MW: 8.5 FIW TIH. TAGGED @ 11810'. DRILL CEMENT TO 12000'. WOC. DRILL CEMENT TO 12100'. TESTED PERFS TO 2510 PSI FOR 30 MINUTES. DRILLED EZSV AND PUSHED TO 12567'. DRILLED EZSV AND CEMENT TO 12585'. CIRCULATE OUT CEMENT. POOH WITH 6" BIT. DAILY:S30,889 CDM:$3,800,056 ETD:S3,800,.056 EFC:$3,860,000 RIH WITH OEDP MW: 8.5 FIW POOH. TEST BOPE. RIH. DRILL CEMENT AND RETAINER. TEST PERFS. LOST 900 PSI IN 30 MIN. RIH. DRILL HARD CEMENT TO 12692' CIRCULATE HOLE CLEAN. POOH. RIH WITH OEDP. DAILY:S14,400 CUM:$3,814,456 ETD:S3,814,456 EFC:$3,860,000 WOC MW: 8.5 FIW RIH. TAG CEMENT PLUG @ 12692'. PUMP BALANCED CEMENT PLUG. REVERSE CIRCULATE DP CLEAR. SQUEEZE PLUG. POOH. WOC. DAiLY:S21,971 CUM:$3,836,427 ETD:S3,836,427 EFC:$3,860,000 POOH MW: 8.5 FIW WOC. TEST CMT FOR HARDNESS. WOC. DRLD CMT. TEST PERF TO 2500 PSI. OK. DRLD TO PBTD AT 13042'. CIRC. POOH. DAILY:S15,200 CUM:$3,851,627 ETD:S3,851,627 EFC:$3,860,000 RIH W/PERF TEST STRING MW: 8.5 FIW POH. RIM W/ SCRAPER. CHANGE OUT HOLE TO CLEAN COM~L FLUID. POH. MU PERF AND TEST STRING. RIM. DAILY:S14,480 CUM:$3,866,027 ETD:S3,866,027 EFC:$3,860,000 POH W/ PERF-TEST STRING MW: 8.5 FIW RIH W/PERF TEST-STRING. ATTEMPT TO PERF AND TEST FORM. NO INDICATIONS OF GUNS FIRING. SUSPEND TESTING. POH W/PERF-TEST STRING. DAILY:S14,400 CUM:$3,880,427 ETD:S3,880,427 EFC:$3,859,802 EVALUATE WELL t.f,,;: 8.5 FiW POH. REPLACE FAILED TBG ISOLATION VALVE. MU NEW PERF-TEST STRING. RIM. CORRELATE AND SET PKR. RU SURFACE EQUIP FOR TEST. ATT TO FIRE GUNS - NO INDIC. THAT GUNS FIRED. PROCEED WITH TEST TO SEE IF GUNS FIRED. DAILY:S14,400 CUM:$3,894,827 ETD:S3,894,827 EFC:$3,860,000 IWell no. The aDove is correct For form pre.align and distribution see Procedum.,j Manual Section 10. Drilling, Pages 86 and 87 Date ITitle ~,,-/~ -~,e~ ASSOCIATE ENGINEER Number all daily well h~story forms consecu[iveiy as hey are prepared lot each well. iF'age no. ARCO Oil and Gas Company Daily Well History--lnterir Inet~lCt~onl: Th~s form is useCl Outing OrHl~ng Or wOrkOVer OI3~r&ttona, t! letting, Cor~ng. or Derlorat~ng. ~how formation name ~n ~etcrlbing work ~rtormed. humoer III orlli Item tests leOuentlally Attach Oelcrlot~on Of ell cores. Work Derto~ed Dy Proouclng Section will be reported on "lnmrlm" sheets until hnll COmptehon. Repo~ ofhc~ll or reprelenllt~ve tilt on "Flail" form. 1) Submit *'l~tlrl~" sheets whe~ fllieO out but ~ot less treQuently thin every ~ ~lyl. or (2) on We~nelOay of the wee~ in which oil Itring il ~t. Submit weekly for workoverl an~ tollow~ng setting of oil itri~G until District Date eno oeoIn as of 8:00 a.m. I Counfy or Perish ARCO Alaska, Inc. I KENAI BOROUGH I Lease or Unit TRADING BA: UNIT I K-6 /K-6RD Complete racor(l for each Oay whl~e Oull,ng or worl~over in progress 07/19/88 (1: TD:13920 PB:13042 SUPV:HP 07/20/88 TD:13920 PB:13042 SUPV:HP 07/21/88 (1 TD:13920 PB:13042 SUPV:HP 07/22/88 (1 TD:13920 PB:13042 SUPV:GLC 07/23/88 TD:13920 PB:13042 SUPV:GLC 07/24/88 (1: TD:13920 PB:13042 SUPV:GLC [Stet~ no. KING SALMON RIH WITH TEST STRING MW: 8.5 FIW TERMINATE TEST, REV. CBU, POH (ALL GUNS FIRED), LD TEST/PERF STRING, RIH WITH BIT AND SCRAPER, CIRC. HIGH VIS. SWEEP (NO FILL RECOVERED), POH, MU TEST STRING, RIH DAILY:S14,400 CUM:$3,908,927 ETD:S3,908,927 EFC:$3,860,000 TESTING WELL WITH JET PUMP RIH W/TEST STRING. SET PKR. (PRODUCING APPROX. 450 BOPD) MW: 8.5 TEST WELL WITH JET PUMP. FIW DAILY:S15,080 CUM:$3,924,007 ETD:S3,924,007 EFC:$3,860,000 POE MW: 8.5 FIW FLOW TEST WELL. SHUT IN FOR PRESSURE BUILD-UP. REV CIRC. RE-TEST ANNULUS. ANNULUS OK FROM 12640' TO SURFACE. REV CIRC. POH. DAILY:S42,567 CUM:$3,966,574 ETD:S3,966,574 EFC:$3,860,000 REV CIRC HOLE CLEAN MW: 8.5 FIW POH. PJ~N CET. HAD SUFFICIENT HEMLOCK ISOLATION. TEST BOPE. TIH W/BIT. REV CIRC WELL CLEAN. DAILY:S102,314 CUM:$4,068,888 ETD:S4,068,888 EFC:$3,860,000 REPAIRING DRAW WORKS MOTO MW: 8.5 FIW CIRC HOLE CLEAN. POH, LD 3-1/2" DP. RUN WD PKR AND TAILPIPE ASSY. SET PKR@ 11440' (WLM) W/ TBG TAIL @ 11718' (WLM). CIRC AROUND FIW W/ 10 GAL PER 100 BBL C-193. POH. HAD DRAW WORKS MOTOR FAILURE. REPAIR SAME. DAILY:S14,485 CUM:$4,083,373 ETD:S4,083,373 EFC:$3,860,000 ATT TO STING iNTO PKR MW: 8.5 FIW FIN REPAIRING DRAW WORKS MOTOR. POH. RAN 3-1/2" COMPLETION. (CAMCO 'TRDP-1A-SSA' SSSV @ 291', OTIS 'WD' PKR@ 11446', & TT @ 11724'.) SPACE OUT AND ATTEMPT TO STING INTO PKR. DAILY:S14,400 CUM:$4,097,773 ETD:S4,097,773 EFC:$3,860,000 The above is correct Signature For form prepars'~(~n and distn~ut~on see Proceclures!k~anual Section 10, Drilling, Pages ~ anc~ 87 ASSOCIATE ENGINEER Number all c~e~ly well history form5 consecutivel)~ as they are Dre;~are(~ for each well. IPage no ARCO Oil and Gas Company Daily Well History-Final Repot Iflll~,l¢liO. nl: PweDere anti lubmit the "Fl.e&l Rel~)l"l" on the fl~t WlOnelOly I~tr allowable his ~n iIIignt~ or well II Plugged, AblnOOnld. or ~l~, "Fall Rt~" IhOUld ~ lubml~lO II~ wh~ o~rltiofll I~ lul~naeO for In mdehn~le o~ lpDrlC~lbll length of hal. On wor~ve~ when in OffiCial tilt II riot ~u~red upon completion, ~ c~lo~ ~n~ ~p~tlt*~ tell ~atl i~ btoc~l prowded. The "F~iI RI~" Iorm may bi u~a for reposing the t~ti~ o~ratlon i[ apace ~s available. D*$tnct ARCO Alaska, Inc. Fiele TRADING BAY UNIT Aulh. or W.O. no. AD6170 Operator ARCO Accountlllg colt center ICounly or PInSh State KENAI BOROUG}{ AK Lease or Unit I Well no. I ADL: 18772 K-6/K-6RD Tilde ABANDON (K-6) /DRILL & COMPLETE (K-6RD) SpuOoecl or W.O. begun ACCEPT Dale an00eblh Is O! 8:00 a.m. 07/25/88 (11' TD:13920 PB:13042 SUPV:GLC J AR.Co. w.I. Date 50-133-20088 (K-6)/50-133-20088-01 (K-6RD) TacOtal number of wells (active or inactive) ors this est cartier prior to plugging banOonment of this well and 18. 0000 IHour I Prior ,,latua I! a W.O. 1000 }{RS Complete recorO for each gay raDorteO KING SALMON 03/30/88 FINAL REPORT MW: 8.5 FIW STING INTO PKR. TST TBG & PKR TO 2500 PSI. TST SSSV - OK. SHEARED SOS. ND BOPE. NU & TST TR~E - OK. RIG P~ELEASED ~ 1900 HRS, 7 24~.~.~TO K-18. DAILY:S136,052 CUM:$4,233,825 ETD:S4,233,825 EFC:$3,860,000 Old TD New TD PB Depth Re~eased rig Date K nO o rig Classifications (oH. gas, etc.) Type completion (single, {3ual. etc.) Producing metho(~ Official reservoir name(l) Polenhal lest ciasa Well no. :Date Reservoir Producing interval git or geeTest time ProOuction Oil on test [Gas per gay Pump size, SPM X length Choke size T,P, C,P. Water % IGOR Gravity Allowable Effective Olte corrected , , The above is correct Drilling, Pages 86 and 87. ASSOCIATE ENGINEER Number ell daily well history terms Consecullvely I Pegs no, n~ ~hr'v nra ~?~'r)~r~,?~ t~? nnnh w~i~ Unocal Oil & Gas Divisi(~" Unocal Corporation~. PO. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska District DOCUMENT TRANSMITTAL July 29, 1988 HAND DELIVERED TO: William Barnwell FROM: R.C. Warthen LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting as Follows: Regarding: Trading Bay Unit, McArthur River Field - K-6 RD well One sepia and one blueline of logs' ~"~2" BHC Sonic SP Gamma Ray ~2" True Vertical Depth Neutron Density ~5" True Vertical Depth BHC SR GR ~2" True Vertical Depth Bulk Density REF ~2" Dual Induction SR Gamma Ray ~5" Dual Induction SR Gamma Ray ~5" Bulk Density REF '~5" BHC Sonic SR Gamma Ray "~epth Control Gamma Ray ~'5" True Vertical Depth Bulk Density REF ~5" True Vertical Depth DIL SR GR ~2" Compensated Neutron Litho Density ~5" Compensated Neutron Litho Density "~5" True Vertical Depth Neutron Density ~2" True Vertical Depth DIL SR GR ~2" True Vertical Depth BHC SR GR ""~'2" Bulk Density REF ~One copy of LIS tape with verification listing PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU' r"~:~ RECEIVED BY: DATED: ARCO Alaska, Inc. Cook Inlet/New Ventures Engineering Log Transmittal TO: Commissioner FROM: Tom Wellman, ADDRESS: A3333 DATE: ~,,,/¢:P-_~ ,,/~' WELL: K-6~D Field Prints Please find the following logs enclosed: Name of Log' E~U'~ Sepia Sepia Mylar Line Folded Rolled I~lylar,~ll'aDe 2" TRUE VERTICAL DEPTH BULK DENSITY x 5" TRUE VERTICAL DEPTH BULK DENSITY x ' 2" TRUE VERTICAL DEPTH NEUTRON DENSITY x 5" TRUE VERTICAL DEPTH NEUTRON DENSITY x 2" BULK DENSITY PEF x 5" BULK DENSITY PEF x 2" COMPENSATED NEUTRON LITHO DENSITY x , 5" COMPENSATED NEUTRON LITHO DENSITY x 2" TRUE VERTICAL DEPTH BHC SP GR x , 5" TRUE VERTICAL DEPTH BHC SP GR x 2" TRUE VERTICAL DEPTH DIL SP' GR ........ x , 5" TRUE VERTICAL DEPTH DIL SP GR x 2" DUAL INDUCTION SP GAMMA RAY x 5""bUAL INDUCTION , , ~ , , 11 Receipt Acknowledgment: Date: Return Receipt to' ARCO Alaska, Inc. Attn: Judy Boegler, ATO-139( P. O. Box 100360 Anchorage, AK 99510 JIJL 0il & Gas Cons. C0mmiss[0.n '",-_Anchorage March 30, 1988 Mr. Roy D. Roberts Environmental Engineer Union Oil Company of California P. O. Box 190247 Anchorage, Alaska 99502 Telecopy: (907) 276-7542 Re: Trading Bay State K-6 RD Union Oil Company of California Permit No. 88- 28 Sur. Loc. 736'FSL, 135'FEL, Sec. 17, T9N, R13W, SM Btmhole Loc. 1324'FNL, 2538'FWL, Sec. 22, T9N, R13W, SM Dear Mr. Roberts Enclosed is the approved application for .permit to re-drill the above referenced well. The permit to re-drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface. casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below, the shoe of the conductor pipe. Ve tr~u Z rs ~_ C. V. C atter~on.,~ Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COt~ISSION dlf Enclosure cc: DePartment of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Bill H. Lamoreaux STATE OF ALASKA .' ALASKA~ _,lb AND GAS CONSERVATION d_ .vlMISSlON PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill F~ Redrill ~1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen, Service ,'~ Developement Gas [] Single Zone [] Multiple Zone ~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool UNOCAL (ARCO Alaska. Inc. is sub-ooerai;:or} RKB 10~' feet McArthur River Field 3. Address 6. Property Designation Hemlock Pool P.O. Box 190247, Anchorage, AK 99519 ADL 18772 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 A^C 25.025) 736'FSL, 135'FEL, Sec.17, TSN, R13W, SM Trading Bay Unit Statewide At top of productive interval 8. Well nurpber Number 1100'FNL, 1900'FWL, Sec.22, TSN, R13W, SM K-6 Redrill (32-16) #8088-26-27 At total depth 9. Approximate spud date Amount 1324'FNL, 2538'FWL, Sec.22, TSN, R13W, SM 03/28/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(b~D and TVD) property line 13659 'MD 2742' feet 56' @ 3640'TVD feet :)840 (10263'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) ~L,/~.~,~¢¢ 0 Maximum surface psig At total depth (TVD) psig Kickoff depth ?~,n ) feet Mr) Maximum hole angle,, .~ ~ 978 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 18" 13-3/8' 61.0~ J-55 BTC 2146' 40' 40' 2186' 2088' 1760 sx Class 12-1/4' 9-5/8" 47.0¢ L-80 BTC 12049' 38' 38'112087' 9175' 550 sx Class G (min) 8-1/2' 7" 29.0,t L-80 BTC 1872' 11787' 8967'13659' 10263' 400 sx Class G (rain) I~ lC i~ ~ ~ ~ 'E 19. To be completed for Redrill, Re-entry, and Deepen Operations. I~ ~, ~. ~ I~ l Present well condition summary Total depth: measured 1 1 31 9 ' feet Plugs (measured) 11 202 ' M D ~,,.~ ,'!. ~:') ¢~ L.: '~ [-~ true vertical feet ~¥'~"~:',i ~ ,:- . 10278' ' uas O0ns. C0m~iss Effective depth: measured 11 202 ' feet Junk (measured) 111 47 ' MI~?'I;3'S!':~:~ 0i! & o, true vertical 1 01 79 ' feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor :~36 ' 24" Yes 376 ' MD 376 ' TVD Surface 2146' 13-3/8" 1760 sx Class G 2186'MD 2088'TVD Intermediate Production 11281' 9-5/8" 990 sx Class G 11319'MD 10278'TVD Liner Perforation depth: measured See attached sheet true vertical See attached sheet 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling progCam [] Drilling fluid pr~sg~ [] Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby ~¢:tify/hat the foxing is_.true a.nd correct to the best of my knowledge Signed .~~.¢¢,¢,~ j Title / ~,f'~'/~//p~/F/7~) ' Reqional Drillinq Enqin~er Date I 50-'7':~.:¢- ~0o¢,~,-o / 03/30/88 for other requirements Conditions of approval Samples required [] Yes [~ No Mud Icg required L--3 Yes [] No Hydrogen sulfide measures [] Yes [2F No Directional.survey required ~ Yes [] No Required worki~~O~~[] 5M; [] 10M; F1 15M Other: by order of Approved by L "'/' k ~ I~'/~"~/~'~~1~ Commissioner the commission Date Form 10-401 Rev. 12-1-85 triplicate PERMIT TO DRILL TRADING BAY UNIT K-6 REDRILL (32-16) Perforation depths: 10670'-10730' 10748'-10767' 10894'-10964' 10984'-11097' 11097'-11216' 11226'-11236' TVD 9730'-9781' 9796'-9812' 991~'-9979' 9995'-10091' 10091'-10192' 10200'-10209' ?D2/82a 3/23/88 · :[.:;::'i :LEI~4, SLOT 30[, t~ELL~...,*.: K-6RD' PROPOSED VERTICAL SECTION PLANE S 75 DEG 55 HIN E 3000. KOP= (TIE-IN POINT) 24' ?' TVD-2197 THD-2$O0 DEP-355 as~ 2;~' 30~ N 55' 50' E ::,8' aS' 31:'42' 2.5 DEO / I~ FT D~EG ~'1~' ~' 3'EOC TVD-3406 THD=3752 DEP-1094 4000 m 5000. m ~ .... 6000. 7000. AVERAGE ANGLE 46 DEG 12 ........ 1..tO00., 9 5/8' CSG PT TVD=~I?5 THD=I208? . T/ G-1 SNDS TVD 9185 THD-12101 OEP ?095 TARGET (T/ HEMLOCK) TVB=9615 TMD. 12723 DEP 7542 T/ W FORELAND TVD"10125 TMD-13459 DEP-8oTI TD / ?' LINER' TVD-10263 TMD-13659DEP-8215 1000 2000 I I I I I 3000 4000 5000 6000 ?000 VERTICAL SECTION. I 8000' I 9001 0 0 o 0 0 0 o I n-,C CI he,, ILLI z 0 z~ -JO ~-4C)_j 0 0 0 /" o LJ.J C.) 0 ZLU C:) I o o o c) c) c:) o c:] c:) o NORTH-SOUTH 0 0 0 00 _ 0 0 0 ~x. . 0 0 0 o o o o / ol I I o/ ! ! I I o o o · ~ ! I I i I 0 C) 0 0 0 0 0 0 0 0 0 · . 0 0 0 0 0 0 0 0 CD -CD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1~. 0 0 0 0 L~ I I 0 o o / / / 0 0 0 0 0 0 0 0 o/ o°/ 0 0 o 0 0 0 ............ iOl~ 0 0.__ CD / I I . 0 0 0 i 0 0 0 0 0 0 0 0 1. ~Ru ARCO Rig #58. 2. HIRU ~L unit. Perforate tubing between packers. Shoot off tubing above top-packer or approxinmtely 10,500'±. 3. CircUlate and kill well. ND tree. NU BOPE. 5. POOH and LD completion assy. 6. M/U 8½" bit and 9-5/8" casing scrapers. PU DP and RIH. C/O to tubing stub. POOH. 7. M/U 7" cement retainer on DP. RIH and set above tubing stub. Establish injection rate. Cement squeeze Hemlock formation with 22 bbls slurry. Dump 4 bbls slurry on top of retainer. POOH. 8. MU 9-5/8" RTTS with 6 stands 3½" tailpipe. Test casing above top of liner. Spot 300' balanced plug 100' below to 200' above top of liner and squeeze as required. POOH. WOC. Pressure test casing to 2500 psi. 9. M/U 9-5/8" bridge plug. RIH and set @ 2550'±. POOH. 10. M/U 9-5/8" casing cutter. RIH and cut 9-5/8" casing @ 2450'±. POOH. 11. POOH and LD 9-5/8" casing. 12. RIH w/OEDP. Lay kickoff plug from 2550' to 2000'±. 13. Dress off plug. 14. Sidetrack well @ 2300' MD. 15. Directionally drill 12¼" hole to the top of the G-1 sand or approximately 12,087' MD. 16. Run open hole logs. Condition hole for 9-5/8" casing. 17. Run and cement 9-5/8" casing. 18. Directionally drill 8½" hole to .200' MD below Base of Hemlock or approximately 13,659' MD. 19. Run open hole logs. Condition hole for liner. 20. Run and cement 7" liner. 21. Clean out well to PBTD. Displace well to completion fluid. 22. Perforate required zones with 4½" tubing conveyed guns if a producer. 23. Complete well per open hole logs with 3½" or 4½" tubing as either: a. an injector - 4½" ITC tubing b. a producer with 3½" GLMs 24. ND BOPE. NU tree. sR/155 ih 25. Release rig. (Perforate well with thru tubing guns if an injector.) General Purpose Worksheet File ' ' - ~i ""-~ ~ Of /o ~, ¥- %% /oe~¥ - II AR3B-1473-D /04 ~,o- ?.70 ,~ il e._ l/Iv)'" DRILLING FLUID PROGRAM Kick-Off to 9-5/8" Casing Point 9-5/8" Csg Pt to TD Density 8.8-10.0 9-4-9.6 PV 10-20 15-20 YP 10-25 10-15 Viscosity 35-50 Initial Gel 3-5 35-50 3-5 10 Minute Gel 6-12 5-8 Filtrate API 10-12 pH 8.5-9.0 8.5-9.0 % Solids 10± 8-10 Drilling Fluid System: - Dual Tandem Shale Shaker - Desander, Desilter - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 11.1 ppg EMW (King Salmon expected leak-off) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will utilize 3000 psi BOP equipment and test accordingly. As indicated the K-6RD will be within 56' of the K-13RD at 3640' TVD (4090' MD). The K-13RD wellbore will be shut-in and monitored until the crossing has been made. There are no closer wellbores downhole. LW~5 / ih General Purpose Worksheet IFile ' - - ,.J ~ ' - ,/ /f- ~ J% d'.,// IPage No. ~__~ °' O , AR3B-1473-D t" ,WACO I- D F IA E (3 Bt ...8 r'sooo PS1 DIAPHRA(3M C CHOKE LINE ADJ. CHOKE tK N X S Q HYDRIL ,> PIPE RAMS BLIND RAMS CHECK VALVE CHOKE MANIFOLD & KILL LINE W/B,.O.P. ON KING PLATFORM 10-3-77 13-5/8" 3000 PSI BOP STACK ANNULAR PREVENTER 6 PIPE RAMS 5 BLIND RAMS 4 1. FMC TYPE III UNIHEAD 2.13-5/8" 5000 PSI HUB X 3000 PSI FLANGE ADAPTER 3.13-5/8" - 3000 PSI DRILLING SPOOL 4.13-5/8" - 3000 PSi BLIND RAMS 5.13-5/8" - 3000 PSI PIPE RAMS 6.13-5/8" - 3000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HO~:)q3OWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7.. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. i 1. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGh AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. JG NOVEMBER 9, 1987 (FOR TBU WELLS) 58C --"--- 58 B 58 51 58 57'"-'-- $48~5 4B~ 4 .. 5F CHRISTMAS TREE ASSEMBLX 14A 5lA 52 67 SF I iE ..... , p#O~_ gW1.1,· OIL, CENTER TOOL. CO.o INc:.' ,&?l'"Ot,.'t"7'e'7.. 'l. ' '' ' '1 ' ' O1#,OI' U/)i~ ; : ', ,~ ..:,. ......,. I Il ' s '"* ' ' ~' , PPRqI'IP, . . ~'. , , , ,, CHECK LIST FOR NEW WELL PERMITS Company 63AYOC/$i_ (/P~iO) Lease & Well No. 7-~°, ~f ITEM APPROVE DATE YES NO (1) Fee ,.~_~ ~ ~/~q[8~ 1. Is the permit fee attached .......................................... ,~3~ - 6s (2 thru 8) (3) Admin ~ $/~/8~ 9. (9 thru 13) 10. (10 and 13) 12. 13. (4) Casg (14 thru 22) (s) o P E (23 thru 28) 2. Is well to be located in a defined pool ............................. d~ 3. Is well located proper distance from property line .................. ~_ 4. Is well located proper distance from other wells .................... 5K 5. Is sufficient undedicated acreage available in this pool ............ d~ 6. Is well to be deviated and is wellbore plat included ................ ~3 7. Is operator the only affected party ................................. ~ 8. Can permit be approved before fifteen-day wait ...................... ~ Does operator have a bond in force ................................... 5~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... 14. 15. 16. i7. 18. 19. 20. 21. 22. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of_~N~.,~-~ BOPE attached. Does BOPE have sufficient pressure rating - Test to .~Od)~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. th H2S b bl Is e presence of gas pro a e ................................. (6) OTHER (6) Add: (29 thru 31) For 29. 30. 31 32. exploratory and Stratigraphic wells: ./~ Are seismic analysis data presented on shallow gas zones .... If an offshore loc., are survey results of seabed conditions Additional requirements ' leee$®eeeeeeeeeeeeeeeeeeee eeeeeelee®eleeeeee Geology: EngiDee~iug: rev: 02/17/88 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , ,u~'2C)/~O P~-t J.,c.r~ ~m o l Zo70 .OEr/= Additional Remarks: o mm Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. COMP~.J'Y NAt,~E : 1RCO ALASKa, INC,. WELL N~ME : TaU FIELD N~ME : MC~RTHU~ ST.&T E ' AL,~SK~ ~IOROUGH : KENA~ AP~ NU~, ~'~ R : RE~E'R~NC,E NO : 7293~ ZS TAPE VER!FZC,:~TT. Oq LISTZN'.; 2.9-SE.D-"~ 9'.~5 12:23 SERVIC~ N,~l~ : GCT D,~,T ~ ' .78f09/20 C'DISIN : =LIC REEL ~AME ' 72934 CORT~",~U~.TZO'N ~ DREVZqUS ~E'EL : SERVICE N~,~,~E ' GCT D,'~T: : 38f0 DR Y'Si "'~ : =ti ~ T~iD= ,-,~ N~aE 729~4 C3NTINUAT!qN ~ : 1 PREV!SUS TAPE : ,.~ L,~', .~ a .-" ~' S TqU a~'cO T:U '-'50- 73 ~- 10,0,8 ~-O 1 FILE N~"~E : GCT .001 ~'=RVI,. '~ ' :L'IC VYRSIDN : ~01B32 EAT= : ~9199/,Z0 FILE TYDp " L9 C.SMP&qY NAD~E: a. RCO AL~SK:.~, !KIC.. WELL: K-SRD FIELD: ~C&RTHUR R'.IVER B~ ROUGH: ~ EN ~ I S'TA TE: AL,~ SK.~ ..... E~ .... ~0 ~8-0 I LOC~TION: 7.~6' :FSL, 135' FFL S'~CTi,i3bI' 1'7 TOWNSH:IP' 9~ R :I N 'S E: P .F. R .!'~ A N E N T [.', A T U M: M t t W t ,F,,~ G M E A S U R E q 'F ~:' ::'] D~ ~,? K ~ t 3w !S T~aE V".r'.RZFZC~TI8"~ LiSTTNS CHLUM.gEqGCR ,~ L .a S K ..'~ 2'I SF-D-la° 12'23 EL~VATI,JNS K,~: 1O0.n GL: N/,~ DATe LD~G'=D: 04-JUL-8~: RUN NUM~,S~: TM'RF= T~ 3RILL~q: 13Og~.O T'? LOgGeR: !3qTO.P PLUG-3ACK D::PTH = 1304.2' C~SZN~' !: 9. C~SiNS 2' 13.003" E, iT SZZ= 1: l?.lS" BIT SiZ': 2: '~.50" Tn lla6~' D°ILLER TO 1338:?' .rO'?ILL"'P TYPE =LUIC' IN HOL':: ~RiN~ D~qSiTY: B.q LF~/G L 3GGI ~'IG D!S'TR ICT: 4513IK~N.~I L'3GGING ENGTN'--_~R: ':ITT~R=R/CRY=R WZT"~.F. SS.: H., PETYmSSN 'TOOL NUMBERS'.'- CCSM 26 CCC~ 2B96 GCI O-S 53 GCLM 752 DATE JS.~ STIRTE:}: 20-SE°-88 JOB R~EF:ER ,?:NC~ NO: 72~'3.4 LDP/A,NA: J. KCHRIN'~ AZItflUTH OF PLANN~:3, VER'TIC,AL PLa, NE: S 75 "~:"~,,,....~ 55,,. M~,E~.~SUqE'D ~ZIM!,-ITH DEPARTURE ,'~T DRILLF-R'S DEPTH,: St. JRF~CE LOCa, TiON: T3,6' FSL, 135' FYL~, SEC. 17, LO SG -R LOGG--R MTN E (!Og.O~ DEG) S 7:5 ,g,.~., 47 MiNE (lO~'& 9,2 D~G) 'TgN, R13W, S~W,~RD .MERiDIaN TABLE TYP'..~ : CONS T IJN I V ,,~ L U O F.,-n I FN WN N ..,~ T i S'TA T C gUN S ',:_CT TOWN R A N G FL OR E:~ S COMPANY NAME FI ELD N 4ME W'EL.L NA~AE N A T l O N STA'TE OR PROVINCE CgUNTY S .~ C T I9 N T g W N :S H 'I ~ RANGE ~.l YLD LDC~ITION OPE2ATOR' S S'ERVI2E D2D:~R NUM IS 'TAPE V,EREFIC.~T"OH LISTIt,!; TUll C'ENT 9n-SF=-l~OR V -~L~J I~:23 T ~,BLE TYP-~ : D~.CT DqPTH CHA'qN':'-L N,~,~'c GDEO GYP.'] 3~PTq VOEt° TqU": VF.":;'*TiC"L D~UPTH ~,S CH~t',i'",l~L <TVTCi::'I> HLAZ D "--VIAT I ON ~ Z l'ag'TH g EV I D ''= V I,~'T I 3N NSDR NORTH S-r) UTH O~iFT EWB~ E&ST WEST DPlF~r CO,'.,'~PONENT DSt VF:RTIC,aL DEPTH 2EL.~.TIVE T? G.c',']U',ID L:..VEL C':J$,.'-.R' S R=F-R=_NCE) DEPT G D.... E P HLAZ D E V I .N S g .R FORUAT SPC,...CiFIC.&TT..f].N 'RECORD ..... ,,- TYDr" R'--PR ~ODE V,1LUc SL:.'RV UN!T SE:RV!C_= API ~PI a:PI ~PI ,f=ILE ORDF:~ :~ Lr~G TYF..~: CL~.SS ?qO3 :KIUk~'B NUmB "qU'4B S'ZZE REDR PROCE.SS 0090000000 O000OO00OO O00000OO00 9000OOOO00 OOOOOOOOOO gOOOOO00OO O000OOO000 I$ TADE V~R:F=C~T'32C, N ,LISTIN3 20-$FP-I~,38 I.Z:,73 CHLUM~ER!;=R AL~SK, ~ ~, ".'3 "P UT".N S,, {' r'qT '--[,, NAP~: SE:?V UNIT SE'~ViC= A I ~PZ A-~'r :~°i =iLE NiJM3 13 "lRgE~' ~. L3G TYP= CL&SS ."!~g ',JU',4~; S~,.~'~P 'qU '~2, SIZ'T- ~R'EPR PDC, CESS 5L :M Cgg E CH'" X) DGL -CT f= '"' '~4 77 ,.']I gg'5 2"" _I 71 !. ........... I 4 53 90,90 30OOOO * ~-' D A T A =',: .",'- OEP'T. 65~32.500 GDEP.GCT 0.090 D~VI.~CT O.00O NgDD.r-c''' 0.030 DEPT. ~.~5S0.090 5DED.GCT 700.2:0 DEVi. :L;CT ~.qSE N S_P.'~. GE.~ -1.Z38 DEPT. &FqO0.00O GS'EP.C-CT DEV~.SCT ~8.810 bi SDS. C.,C T D'LZPT A':: 3 nO D =,V'Z. GC T '35.8.g8 NSD~.SCT -1248.373 DEPT. 63278.500 g .L3, E ~. GC T 1303Z.145 D:EVI.GCT ~5.202 NSDR.GCT V '"). E o. ,SC T EWDe. L~CT vDEP.3CT ~WD~ · gC T V'gEO .,'..-CT EWDR.GCT 'V D E P. G C T E !4DR. GC T VgEP .GCT -8.0,90 0.000 ~ '~9.6 59 5031 31Q7 897 5 . 1 ',.:, 2 ,5873 .589 9868.7],7 7353. 845 HLAZ.gCT o ~. ,:. C T HL~Z. ;CT DGL.,3CT HLA~.I~CT 'DGL. GC T P L A Z. $C 'r 3GL. gC T H L ~. Z . g C T 'DGL. gCT 0.090 0.090 3.717 g~. 259 9.424 131 .411 4.5')8 142.91(, 3.208 * "'"' "' F ~' L ': F IL,r:! S E R V I C E V '-E R S Z ~ N D A T E MAX REC SZZE F~LE TYPE L ,,~ ',S T :TLE **** TAPE SERVICE N,~ME D,~TE ORIGIN TAPE N A. ~4E C gN TINUAT PREViSUS T~P'~ COM~4ENT T R ,~ T L 'E R * ,'.t,.' * · GC'T : FLtC : 9 0 1 A ',9 2 : 10 24. : LO : ~P, CO 'TBU 29-SSP-19!~ 12: Z3 ~CO T3U K-6qm, .-"- 5 0- 7 3 3- 'Z',_ 0 O ~ ,~ -.31 LIS TAPE VBSRIFICATi[3N LISTING LVP 010,HO2 VERIFICATION LISTING PAGE ** REEK HEADER ** SERV{CE NAME {EDIT DATE 588/07/11 ORIGIN 5 REEh_NAME 5?282? CONTINUATION # PREVIOUS REEb COMMENTS IEDIT hIS,ARCO MCARTHUR RIVER ?BU K-6RD,50-733-20088-0! SERVICE NARE 5EDIT PATE 5B8/07/il OR1G{N' {7282 TAPE NAME 1 ¢"~TINUATXON # lOX [ ~VIOU$ TAPE ~ COMMENTS ~EDIT bIStARCO MCARTHUR RIVER TBU K-6RD,50-?33,,20088-01 [I:~E:NAME. iEDIT ,i001 VERi{ZON# DATE { MAX{:MUM ~ENGTH I 1,024 FI E YP~ PR~Vi:~US'FIb,E *. INFORMA?IO'N RECORDS '* MN~M CONTENTS ~CARTHU:R RiVeR )A':NGI ~3NW ' ~A A ~TAT', U~,ASK MN:EM CON:TEN'T8 ~0::0 0:' :0 000 OgO 000 PRg$~ ~: ' o'oo o0o GOt °sS ** 'COMMEN'T,S ************************************************************************************* LVP 010.H02 VERIFICATION LISTING PAGE 2 * 5CHbUMBERGER * AOASKA COMPUTING CENTER COMPANY m ARCO AbASKA ZNC W~LL z TBU K-ERD Ap! # m 50~733-20088-0~ ~IEbO a MCARTHUR RIVER COUNT) = NORTH SbDPE BOROUGH 8TAT~ = AbASKA dOB NUMBER AT AKCC= 72827 RUN ~ DATE bOGGEDI 2~-~UN-88 bDPl }CK KRUWEbb C~8ING VISCOSITY FLUXD LOSS = 9,625" e tI958'CDRILLER) "BlT SIZE = 8,5" TO 23093'CDRIbbER) m E-Z MUD PObYMER 66 DF = .~ C3 RM AT BHT I l, MATRIX'SANDS?ONE COMPUTING CENTER REMARKS1 bVP 0t0,H02 VERIFICA?I, ON LISTING PAGE L T O0 ON A NS DATA OF HASO DUA NDU ?['N DT[ . BOREHOL 2.,)ALL DATA HA6 BEEN OEP?H CORRECTED ?0 DEPTH CONTROL GA A AY LOGGED CASING ON 13 d N 988 RUN #5 SCHLUMBERGER LOG6 INCLUDED WITH THIS MAGNETIC PHASOR OU'Ab. iNDUCTXON bOG (.OTIS) DATA AVAIbABb~l ~0~8 TO ~958' BOREHObE COMPEN,ATED SONIC DA~A AVAI~Alb~, ~3008' TO 11958 LITHO O NSlTY 0 PE~SATEO LOG DATA AVAIbABbEI 13054 TO It958* COMPENSATED NEUTRON bOG (.CNL) · ' DATA AVAILABLEI, i302?' TO NATURAL GAMMA SPECTROMETRY DATA AVAXLABLE'I Z30i9' 'TO 11958 LvP OlO,H02 VERIFICATION LISTING PAGE *$ DATA FORNAT RECORD ENTRY BbOCK8 TYPE SIZE REPR CODE ENTRY 1 66 0 ~ATU~ ~P~CIF~CATXO~ ..z. s~.vxc~ szRvxc~ u.x~ A~Z ApZ ~x ~x 000 O0 0 0 4 oo ~ooo 0 O00 0 I oo iii °I!° o , 0 0 0'0 0 0 ~R~S D~ OH~ O0 0 0 MTE~ DEGF i~~ 00 0 0 ~ 0 0 B'H{ GAPX 0 0 0 M:: il, :$ .BH~: DHMM :::~ ' 0 0 0 SIZE SPL REPR CODE 0 0 ~4 0 0 ~:0 0 CPS O0000 O0 0 0 O0 0:00 0:0 .0 0 oo °o,~ ~ 4 4 4 4 44 PROCE'$$ o,oooooo,~.o~oo~ oooooooooooooo ooooooooo,ooooo oooooooooooo,oo oooooooooooooo oooooooooo, oooo oo ooo o oo oooooooooooooo 0 000 O0' O0 }0 68 ~00 6, O0 0000000( O0 0000000000000000000000000000 , ~ 00000000000000 ~oooooooooooooo ~:i: oooooooooooooo ~::~ oooooooooooooo 00000000000000 68 00000000000000 68 : 00000o00oo00o0 ~:::~o0o000o0o0000o 00000000000000 68:0,0:00::0000:000:000 LVP OIO,H02 VEIlIFICATION LISTING PAGE 5 MTEM bDT NPH! NRRT RNRA CNId NCNb SGR TEN8 CNE H'T~N CNE ~NG URAN ~ENS DEGF O0 660 CPS 3 0 oo ill ° O0 I' ~0 ~ O0 ? 9 [~ oo · O0 oo O0 50 50 50 Oi $0 $0 0 0 0 0 0 0 0 0 0 0 0 0 .0 0 0 0 0 N,:~A,T W3NG U,R A N TENS XMPH !500 HTEN IFtq~ HTEN R~.OB ~:: 0:0:00 S:FL U DRHO 00000008000000 oo, ooooo oooooo oooooooooooooo 000000000,000,00 ti oooooooooo, oooo 00000000000000 000000000000,00 ooo, ooooo,oooOOOo oooo o~oooo~8~~ 00000 0 0 0 ooooo o. o o oooo ooooooooo oooolooooooooo oooooooooooooo oooo ooooooooo oooo~ooooooooo , )~ oooooo oooooo , .o oooooo88oooooo ,~.oooooooooooooo oooooooo, ooo,ooo 00000000000000 oooooooooooooo II oooooooooooooo -999 O0 :N )50 O0 LVP 010,H02 VERIFICATION LISTING PAGE 6 -999 NpH! -999 ~C~b -999, ~4~G .'999 THOR -999, CGR .'999 ~T~ .'999 8GR ~TEN W4NG THOR CGR' DE~:T RH,O ¢ -999 2500 8GR -999 2500 Lb !500 bITH -999 1500 OaS -999 2500 HTEN -9 25,00 NRAT 8GR -999 URAN '999 5 0 I 999 t,~o ~' bSHV -999 , RNRA -999 ~50~ TENS -999.,999 -9 :00 POTA -9~ 2500 HTEN -999 -999 2500 bU -99'_9. 2500 2500 -999. 2500 ~lJ~V 2,500 -999.2500 ~500 FCN'b 2500 ,TEN -999;1!00 2500 WSNG -999. $ 0 ,{5~0 WiNG -999. 8GR "999. ' 2500 MRES -99902500 !Ii ,.,,.,, 44 ~738S ! ~ 0 0 MRES ~66 12'50 66.681'5 SP 500 T~N$ 1215000,00 777 5000 SGR 44,~73~8 MRE$ '. 89~ MTEM ~e&.'.~2$O 66,0000 .o.,oo... ~il" ~:'~!~ ~.~ ,,, o., o 5224,0000 796,0000 4,-:,2'03 11;8516 W2NG W'~NG 134,~50 39. 87'5 T~NS 86000000 t'?0,8750 MRES 2.291.0 32,1 4191 I¸: 9 ZDPH M.R:::ES TENS 31' 500 12800','0000 ~g.,oo~ 65' :0.0::00 4570 DRHO 2 DPH:! IIi, ~.4,,96 ,21 ! IDPH ~P ':~:96 t265.0000 165,0000 2,8730 bVP 010,HO2 VERIF'ICATXON bISTING PAGE 7 CALI L$ ~EN_S NCNb ]: M~ 8,6641 'SGR 63,6875 bb 155 5000 bU 283 0000 ti ~ . °° ??',~oo 0000 ! mO~O005 0~0244 bSHV ~070,0000 HTEN MTEM 745,0000 MRE$ RNRA 0000 : UR~N 0-~60 . eO000 NRBa 2 ~402 oo,oo 50'00 NRA? ,U 1050 94, ?656 ZHPH ~79 ZM [o,[o, , ~,0! )4 DPH! i :0 bL! N2N'G P'D~A '00 HTEN DP,H! NS HTE'N ,tS,8594 ]DPH i }00 5'9'B 3? ,0 856,0000 Mk,::E8 105 iooo i:DF:H .,:'! 0 8 ~0 200'0000 5808309 t61,8750 837,0000 2,080'1 DPH! '3¸ ,Jill, bVP 010,H02 VERIFICATION blS?lNG PAGE 8 CAb! TENS NCNL MRE$ ~4NG 16 0156 SGR O0 TH 10~:5 0000 H~EN 8 ~?-"93 NRAT SR 1780 0000 M~,~M 6 ,~ URAN I 7 LSHV 90 50 0 MRE,$ 0469 RNRA 166 ' ~ 2) 4 W2NG 9 POTA 1095: 0000 H~EN 289 750'0 bU 2 0 14~8 8750 $$2 0000 $SHV ,99 OOOO W'SNG 4375 WtNO 0254 8GR 0000 MRE$ 501 7500 335 2500 157'6 0000 SrLU DRSO NRAT SR W3NG URAN TENS 16,0781 IMPH ~ ~187 ZDPH 6,3906 6,3320 IbM ,220.0000 89.3225MR~PE$ -9~ 1750 ?EN$ 1220,0000 57,2002 t 1545 MTEM 160o. 8750 59,8750 bb 316,0000 -0,0t46 bSHV 59,8750 5,09:38 1 ,, ,$ 6:,2:5 59,8,750 2325.0'000 TENS 1~ W2NG PO:?A 10.1 HTEN XDPH lO0 MRES 4 ) 0 '00 ~'00 2 163 00:"0:0 · ~U DT SG:R: D :R, H 0 , 0'* -10 I ,,10 ~0 ~4 LVP 010.H02 VERIFICATION bISTING PAGE CAL'! i0.0156 SGR 5,6 ,0'220 085 1 "2'5,00 M?'EM W3NG THOR . 0-000 SrbU 0000 ZbD $000 5527 DRHO blTH 0190 !170;0000 H. TEN NRA? 30..t:~'? 0 S R !872.0 O0 MGEMT 5:24; OR,HO ~H URAN 'SFLU )3!3 bb LB SS1 )0 45 bSHV )750 MRE& RNRA )9,57 )313 W2NG )89'4 POTA 0000 HTEH ?,5506 IMPH ?,6367 IbM 1040,0000 HTEN 73.6875 8 97.607! 0,0088 DPH! 86.2500 117 bSHV 97~;0000 HRgS 86.2500 9: 9' ?. , W2N, G: :PO:TR 665 0000 HTE'N -:! ~' : "99 ' DPHZ iii., oo .1250 SS2 ! .0000 SSHV .2500 MIEN .2109 FC'N,b 900.0000 HTEN 1377,0000 WSNG 5~,125,0 WING 816,6602 SGR .3750 MRES 7,1660 IDPH ?,1445 SP ~36,5000 MR'E8 23.5625 TENS .1,9111 MTEM 5,85~4 PEF O0 rCN'b ,, 0000 :6}~0 W!NO MRE'8 SG:W. 77~ '500 NRES 299 7500 3 0000 2 ;0000 3750 32:O 3 11~ 7500 03.13 2 2500 ? 6953 ! 0000 7500 5,80 240 ~7~.0 286 0000 1573 0000 161 8?50 61:t,;,0,000 974.0000 4;5039 2.1'~,6250 8:6:,,2:'500 2,244! 793 ,,,¸9 bVP OlO,H02 VERfFICATION LISTING PAGE CAL! TE'_NS NPHI ~4N~G THOR DEPT IFRE M~EM N ~875 1575 )000 965.0000 HTEN 814.~ 50~"RES t :I~I000 rcNhMT'EM ,!'~ 19,09i6 NR~T 2, ~95 RNRA ' 2,26.95 MTEM 16O,2LO0 ..NS 0,62'8! NING 11.4!i9 N2NG 3.} 4689 MiNG 90 [500 :.I.~ ~"~ ,0~.o,oo 1855.0000 SFLU :999.2S00 iMPH -999,2'500 IDPH :999,1500 i;! ' 1'ii°°" . . ,,,~ ,,,.,',oo ~,,, .I1... Sg $OR -999,250.0 MRES ~999.2500 0 ~U , ,-999,1 ' 9 , 0 . -999;.2509 ,TEN -99.,:.,500 RNRA"RES 9§i,~d~ -99 ; 50 -~9,. 'o MT'gM: .~; oo . -999,1S0o N3NG .-~e,. O0 W2NG - ... . 0 -..,00 ,999. ] o~ N~NG 999,a~00 iRAI;b!CR ANE I::EO'! NAME # ,001 b, ENGTH I ~024 CE .1:.:~ ,, EOF hZR ** ti:ED:! T ~:I6:~,A:R:CD ~C:ARTHUR RZV~:,R TBU :K..6RD,50'?:3 ** R~I/:L TR.AIbl/R ** VERIFICATION LISTING PAGE ERVICE NAME )EDIT ORIGIN I REEL NA~E CONTINUATION # NEXT REEL NAME COMMENTS IEDIT LISeARCO ~CARTHUR RIVER TBU K-6RD,$O-?33-20088-Oi
