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Home My WebLink About199-070 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas❑ SPLUG ❑ Other ❑ Abandoned 2 Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL❑ No.of Completions: _0 Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska,LLC '.and: 7/30/2012 199-070/312-207 • 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 September 26, 1999 50-733-20457-60-00 4a.Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 970'FNL,516'FWL,Sec 33,T9N,R13W,SM,AK October 8, 1999 TBU M-31 L1 Top of Productive Interval: 9.Ref Elevations: KB: 160 17. Field/Pool(s):McArthur River Field N/A GL: BF: Middle Kenai G Oil&Hemlock Oil Pool Total Depth: 10.Plug Back Depth MD/TVD: 18. Property Designation: 4046'FSL,2446'FWL,Sec 28,T9N,R13W,SM,AK 11,268'MD/8,879'TVD ADL 018730 4b.Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 214140 y- 2499532 Zone- 4 11,268'MD/8,879'TVD N/A TPI: x- y- Zone- 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 216161 y- 2504556 Zone- 4 N/A N/A 5. Directional or Inclination Survey: Yes ❑(attached) No Q 13.Water Depth, if Offshore: 21.Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 183 (ft MSL) 10,234'MD/8,856'TVD 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 SCANNED i'llA1-n 2 ai? RECEIVED SE , 0 9 2016 23. CASING,LINER AND CEMENTING RECORD AOGCC WT.PER SETTING DEPTH MD , SETTING DEPTH ND - AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 75# K-55 Surface 1,345' Surface 1,345' 22" 2030 SX 13-3/8" 68#,61# K-55 Surface 3,722' Surface 3,524 17-1/2" 1600 SX 9-5/8" 47# N-80 Surface 9,927' Surface 8,676' 12-1/2" 1650 SX 7" 29# L-80 9,748' 11,188' 8,597' 9,204' 8-1/2" 385 SX 2-7/8" 6# L-80 10,184' 11,265' 8,828' 8,879' 3-3/4" "Pre-Drilled(Slotted)"Liner 24.Open to production or injection? Yes ❑ No El 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): N/A AY /A*4100Ni 1Nj eA A:11 E'L7i YhL 26.ACID,FRACTURE,CEMENT SQUEEZE,ETC. A. -41-50 j i I— Was hydraulic fracturing used during completion? Yes❑ No Q Per 20 AAC 25.283(i)(2)attach electronic and printed information VERIFIED L` DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period —► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate m•0. Form 10-407 Revised 11/20 CONTINUED ON PAGE Submit ORIGINIAL only Pj2J t 2:b/15- /`' /2 -/3._ir ��7 RBDMS L4— SEP 12 2016 v 28.CORE DATA Conventional ore(s): Yes ❑ No ❑✓ Sidewall Cores: Yes ❑ 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 ❑✓ 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. G4 Sand 10,254' 8,865' Formation at total depth: 31. List of Attachments: Activity Reports,Wellbore Schematic Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Cody Dinger Email: cdinger at7hilcorp.com Printed Name: Cody 'inge, A Title: Drilling Tech /'?Signature: / Phone: 777-8389 Date: I J INSTRUCTIONS General: This form - d the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and ND for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation:Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results,including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • Steeell:lhead M-31 Pla/ L1tform . II • W SCHEMATIC Last Completed: 8/16/2001 Ilile•„r•„Alaska.HA: PTD: 193-190/ 199-070 (L1) CASING DETAIL Orig.KB Elev.:160' Size Wt/Grade/Conn Top Btm II 26 73#/X-56/Weld Surface 979' zs' 16 75#/ K 55/ Butt Surface 1345' 13-3/8" 68&61#/ K-55/ Butt Surface 3722' 16" 9-5/8" 47#/ L-80/ Butt Surface 9927' 7" 29#/L-80/8RD LTC TKC 9748' 11188' 2-7/8" 6#/L-80/AB-STL 10184' 11265' ,4 4 w 13-3/8" Perf Details w/Reperfs Top MD Btm MD Status 9935' 9995' Closed Tcc@9,186' 9988' 9998' Closed 10027' 10077' Closed " 7 7,..‘ 10045' 10075' Closed 10085' 10095' Closed oli?" '.t. 10146' 10216' Closed Cmt 9,827—10,145' 10156' 10216' Closed 9-5/8 , $ 10250' 10310' Closed 10251' 10305' Closed = 10408' 10418' Closed 10416' 10476' Closed 10508' 10548' Closed '+''\' ._______4 = 2 7/8' L1 TD=12,018'(MD)/TD=9,207(TVD) PBTD=12,018'(MD)/PBTD=9,207'(TVD) Created By:CD 9/2/2016 • Hilcorp Energy Company Composite Report Well Name: M-31 Field: McArthur River County/State: ,AK (LAT/LONG): evation(RKB): API#: Spud Date: 7/30/2012 Job Name: 1211168 Redrill Steelhead M 031A&Run ESP Contractor Kuukpik#51 AFE#: AFE$: Activity Date Ops Summary 7/21/2012 Install handrails,stairs and remove rig skid jacks.;Finish R/U lines to circulate well and test @ 2000 psi.;Circulate 8.8+ppg/34 vis KWF mud out of well and over shakers to remove solids;as much as possible.7.5 BPM/1300 psi.Circulated 2 complete volumes before;displacing with FIW.Had to dispose of 750 bbls of mud stored in pits from M-29A;to make room for 659 bbls of old mud from M-31 which will be broke before;shipping to TBPF.;Blow down and rig down circulating lines from tree.;Set BPV.Nipple down tree.;lnstall risers and N/U BOPE.Change out upper pipe rams to 4 1/2",lower pipe;;rams to 5".;M-29A:Gross 6586,Cut 92.8%, Net 474,Hertz 46.0,Amps 783,BHP 1706,Tbg 81;psi,Csg 24 psi,Intake temp 192,Motor temp 209,Vibration 1.697,Discharge;3855 7/22/2012 Finish changing pipe rams.Install flow nipple.M/U 4 1/2"test joint.;L/D test joint out of derrick.M/U 4 1/2"test joint.;Fill stack and test joint.Test annular @ 250L/2500H.Attempt to test top pipe;rams.Leaking off.Troubleshoot system for Ieaks.;Pull test joint.Drain stack.Pull BPV.Set two-way check.M/U test joint.;Test upper 4 1/2"pipe rams,kill manual and kill HCR,IBOP,choke HCR and;all choke manifold valves @ 250L/4000H.Jeff Jones(AOGCC)witnessed test.;Pull 4 1/2"test joint and M/U 5"test joint.;Lower pipe rams failed to test as well as accumulator times.Attempt to retest.;No joy.;Pull test joint and attempt to test blind rams several times.Failed.Pull;two-way check,inspect,and reset same.,Changing out lower manual IBOP valve while attempting to test blind rams. 7/23/2012 Change out lower manual IBOP valve.;Refill stack and test blind rams.Good test.Test lower IBOP,dart valve and;floor valve @ 250L/4000H.Good test.M/U test joint and retest 5"pipe rams @;250L/4000H.Good test.Charge all N2 bottles to 1000+psi.Check suction screens;.Koomey draw down test:200 psi/40 seconds. Full pressure 165 seconds.Canrig;technician recalibrated pit sensors and tutored drillers on system functions.;Electrician replaced and tested remote manifold pressure gauge on rig floor.;Housekeeping and deck organization while waiting on AOGCC inspector.;Test lower 5"pipe rams,IBOP,floor valve and blind rams @ 250L/4000H.Perform;accumulator draw down test.200 psi/45 seconds.Full pressure 182 seconds.Tests;witnessed by Jeff Jones(AOGCC).;Pull two-way check.Hole is static.B/D L/D test joint.R/U Weatherford;equipment.M/U landing joint with TIW valve.;Back out lock down screws.Pull tubing hanger with 225K up weight and lay down;one joint.String u-tubing.M/U floor valve and head pin.;Circulate well bore @ 7.5 BPM/1200 psi while mixing dry job.Pump same. 7/24/2012 Pump Slug.R/D circulating hose and Head Pin.;L/D Landing Joints.Terminate Control Lines&disconnect ESP cable.L/D Hanger;L/D 5 jts.R/U Sheaves and Slobber Hose to contain drips.;POOH laying down 4 1/2 IBT singles&spool ESP cable f/9595 t/8037;Install closed end thread protectors.Pressure Wash pipe and Cable.;Check NORM readings on all components.4-8 background uR/hr only.;Cut cable @ splice and change Spools.Spool#1 =1657';Continue to POOH with 4 1/2 TBG and ESP assy f/8018'to 5098;POOH laying down tubing from 8037 to splice @ 5625'.Max NORM @ 12 uR/hr;Change spools.extra time taken to bleed pressure from control lines @ splice.;POOH from 5625 with Tubing and ESP assy.Well taking calculated hole fill.;Off Line:Begin building 2% KCL/Clayseal/Gem GP mud system.;Verified 9 5/8 x 13 5/8 was still @ 0 psi. 7/25/2012 POOH with 4 1/2 Production tubing and ESP assembly.L/D GLMs&spool power cable;Repair Hydraulic leak on Pipe Skate.;Continue to POOH,laying down Tubing.No NORM encountered above background.;Terminate cable and L/D sheave.L/D perforated joint.;Spool MLE and Chem lines.Pressure wash and inspect ESP assembly.;Found 7 of 8 bolts between Disacharge Head and Pump broken.;Both pumps were locked and full of dehydrated mud.Motor and Seal turned freely;Motor was grounded.No faults found in cable.;Full Recovery:38 Bands,9 Flat Guards,3 protectolizers, 162 Cannon Clamps;Break and L/D ESP Components.No NORM readings above background of 8-10 uR/hr;RD Weatherford and clear floor of excess equipment.Pressure wash Floor.;Change Upper Rams from 4 1/2"to 5";Safety Stand Down meeting with Chris Myers and Keith Elliott.;Review Hilcorp"Core Values"and Cook Inlet strategy with Rig Crew.;Make up Test Stand and install Test Plug.;Reconfigure test stand due to wrong spaceout.Test Upper Rams to 250L/4000H;R/D test equip.Set Test Plug.;Install Wear Bushing.Rack back Test Stand in Derrick.;Service Rig.Change Dies in Pipe Handler/Grabber;Make up BHA:2 7/8 stinger w/cut Mule Shoe,XO,XO=15.0;TIH w/Cleanout Assembly from surface to 7200' 7/26/2012 TIH w/cleanout stinger from 7200 to 9580;Wash down from 9580 to 9670 @ 2 bpm.;CBU @ 20 bpm.;B/U recovered thick partially dehydrated drlg mud.Divert mud to isolated pit.;Wash down from 9670.Witness enter of Packer top @ 9716.Clean out to 9728.;CBU @ 20 bpm.B/U recovered diluted drilling mud.;Attempt Injectivity Test.Shut in and pressure up to 500 psi.(0 psi bleed);Increase pressure to 1000 psi.(0 psi bleed);Increase to 1500 psi.(pressure bled to 1200 psi in 10 min);Troubleshoot SCR Relay.Assignment#11.;POOH from 9716 with 5"Dp and 2 7/8"short stinger.;Break XOs and Mule shoe from DP.Make up same to Jt of 2 7/8 Tbg;TIH picking up(24)2 7/8"IBT singles for Cement Stinger.;Change elevators.TIH with 2 7/8 Cement Stinger on 5"Dp from 765 to 9716.;Wash down from 9716 to 10,145 @ 1 bpm.Reverse circ each stand @ 7 bpm,980 psi.;B/U recovered heavy mud from each stand.Divert mud to isolated pit.;Pull to 9716. Attempt injection test unsuccessfully(1/4 bpm @ 1500 psi)TIH;R/U Cmt lines.CBU(long way)PJSM and cement procedure review.Prime SLB Pump;Pump 12 bbl, 15.3 ppg Balanced plug and displace with Rig Pump.;Spot across pert interval from 10,145 to 9822.CIP©06:03 7/27/2012 POOH f/10,145 to 9705.Pulled slowly and with no issues.;Mix and pump 38 bbl 15.3 ppg Balanced plug&spot across interval f/9705 to 9186;Displace @ 6 bpm while holding 900 psi back pressure with Choke.CIP @ 08:20;R/D Cement lines&POOH from 9705 to 8726;Install Dp Wiper Ball and circ down pipe to clear residual cement from I.D.;CBU x 3 @ 15 bpm.Circ an additional 200 bbls to balance system.;POOH with Dp and Cement Stinger from 8726 to 765';L/D(24) joints of 2 7/8 IBT Cement Stinger.Clear rig floor of excess tools;Pressure test 9 5/8"Casing against top of Cement Plug @ 9186,calc.depth.;Monitor 9 5/8 x 13 3/8 psi.0 psi bleed in 30 min&no change on 9 5/8 annulus;Make up Baker Oil Tool"Casing Patch"Mill assembly as per Baker Rep.;Make up Stand of Dp and tag Patch @ 157'.;Mill on Casing Patch f/157'to 177'.String wt 75k,60 rpm,2k tq,8 bpm,50 psi;Work mills through patch area several times(10k drag).9 5/8 x 13 3/8 @ 0 psi;POOH.Rack back stand of DP&DC.L/D Jars and Mills.Recovered 11 lbs of metal;Pressure test 9 5/8 casing to 1000 psi for 30 min.;0 psi bleed and no change on 9 5/8 x 13 3/8 annulus. 7/28/2012 Make up String Mill Clean Out BHA;8 1/2 Bit,Boot Basket,Bit Sub,8 1/2"String Mill,Bump Sub,Oil Jar,XO 4 DCS;Unable to pass Csg Patch @ 157'w/Mill. Ream Patch interval until able to pass;Re-test casing to 1,000 psi for 30 min.25 psi bleed in 30 min.;Pick up remainder of BHA:(5)DCs,XO and(18)5"HWDP= 848.86;Service Rig;Trip in hole slow with String Mill Clean Out Assembly from 848'to 8709;Fill pipe every 3,000 and circulate Dp Volume @ each fill.;TIH f/8709. Tag cement stringer @ 8970.Wash and ream stringer to 8985'.;50 rpm, 13k tq,3 bpm,500 psi.Set down 10k on hard cement @ 8985.;POOH f/8985 to 7200;CBU @ 7200.;POOH from 7200.Rotate&Recip interval from 6800 to 6910 f/Whipstock set.;Continue to POOH f/6800'to BHA @849.;Stand back HWDP and DCs in Derrick.Lay down Jars,Mill and Bit.;Rig up Schlumberger E-Line Unit and make up tool string.;RIH w/USIT tools on E-Line f/surface to 7,000' • 7/29/2012 RIH with SLB E-Line tools to 7,000'.;Correlate to Digital Perf Correlation Log provide by Project Engineer;Pull USIT Log from 7,000'to surface @ 1,800 ft/hr.RD USIT tools.;Found good cement bond across WHipStock setting interval.;PJSM.MU Baker K-1 CIBP to SLB setting Tool.;RIH with CIBP on E-Line to 7,000'.;Correlate to USIT Log and check aginst GR f/Correlation Log.;Park CIBP @ 6916 in tension.Attemp to fire Setting Tool.;No good indication of detonation. Attempt to tag unsuccessfully;POOH to inspect tool string;Found short between transfer rod x detonator.;Clean and rebuild Firing Head.Test tools for continuity. Assemble w/same CIBP;RIH with CIBP on SLB CPST setting tool to 7,000.Correlate to USIT Log.;Park CIBP in tension @ 6916. 19:38 set plug with good indication of detonation.;Pick up,then tag to verify set.POOH and RD SLB E-line;Pressure test casing against CIBP to 1,000 psi for 30 min.25 psi bleed.;M/U Whipstock Mills&BHA to UBHO.M/U std of Dp and test MWD.Rack back Dp Std.;Make up Whipstock w/Trip Anchor to Window Mill.(Anchor pinned with 3 shear pins;TIH with(3)stds of 6 1/2 DCs.2-5k drag passing thru csg patch interval;TIH w/6 stds of HWDP.M/U std#1 and fill pipe.;TIH slowly from 1021 to 5,000 with Whipstock assembly on 5"Dp 7/30/2012 TIH to 6700.Break circulation and Orient Whipstock;Make up stand#64.UP 288k,DN 190k,slack off and witness Anchor shear w/15k.;Slack off to shear Attachment Bolt w/35k.;Whipstock set @ 27 deg Azi.CIBP @ 6912(DP measurement)TOW @ 6890&BOW @ 6907;Displace Well Bore to 9.2 ppg,2% KCL/Clayseal/GEM GP Drilling Mud;Divert Spent FIW returns to isolated pit and ship to Trading Bay Facility.;Mill Window in 9 5/8"47#casing from 6,890 to 6,907;UP 250k,DN 200k,ROT 220k,9k tq off btm, 10-13k on btm,9 bpm=700 psi;Mill Window and drill formation f/6907 t/6930.WOB 5-15k.;Mostly Sandy retuns,with trace of Coal and Claystone.No Cement observed.;Pump High Vis Sweep.Circulate to surface while working mills thru Window.;F.I.T.to 12 ppg EMW,6907 MD,6230 TVD,9.1 ppg test MW,950 test pressure;Flow check Well.Pump Slug.POOH f/6930 to BHA @ 890.;Rack back HWDP.Lay down DCs, Jars and Mills.;lnspect Mills for wear.Window Mill 1/4"Under gauge&80%used.;Lower Mill 50%used.Upper Mill was 5%used.;Pull Wear Bushing.M/U Test Stand&set Test Plug.Fill BOP&purge air f/system;Test BOP and related equipment to 250 L/4000H.Hold each test f/5 min;Test Annular to 250L/3000H.Chart record all tests.;Perform Accumulator Pre-Charge test.Test audible and visual alarms on H2S&LEL;No failures to report. Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~ - ~.~7~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: .~.~' [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA n Diskettes, No. [] Other, No/Type OVERSIZED r~ Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Mildred Damth N~n Lowell Date: 4/7 ,si ~ TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha ~Lowell Is~ • • (7i:.) E r ALAS /NPARNELLGOVERNOR IFU ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Paul Mazzolini Drilling Manager Q Hilcorp Alaska, LLC 9' 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99524 Re: McArthur River Field, Middle Kenai G & Hemlock Oil Pool, TBU M -31L1 Sundry Number: 312 -207 Dear Mr. Mazzolini: MN DJUC' 9 ZOIZ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / Cathy . Foerster Chaff DATED this /4 ' d ay of June, 2012. Encl. • • RECEIVED STATE OF ALASKA JUN 0 6 01 ALASKA OIL AND GAS CONSERVATION COMMISSION OTC 611 APPLICATION FOR SUNDRY APPROVALS AQGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill El ' Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations [fP A . i L Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ v Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Development 0 , Exploratory ❑ 99 -70 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: 3800 Centerpoint Drive, Anchorage AK, 99524 50- 733 - 20457 -60 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No in Trading Bay Unit M -31 L1 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0018730 Steelhead Platform McArthur River Field / Middle Kenai G Oil & Hemlock Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,268' (3 -3/4" hole) 8880' (3 -3/4" hole) 11,268' (3 -3/4" hole) 8880' (3 -3/4" hole) None 10,184' (Split 2 -7/8" TOL) Casing Length Size MD TVD Burst Collapse Structural 904' 26" 979' 979' 3,010 psi 1,440 psi Conductor 1270' 16" 1345' 1345' 2,630 psi 1,010 psi Surface 3647' 13 -3/8" 3722' 3524' 3,090 psi 1,540 psi Intermediate Production 9852' 9 -5/8" 9927' 8678' 6870 psi 4760 psi Liner 1440' 7" 11,188' 9173' 8160 psi 7030 psi Slotted Liner 1084' 2 -7/8" 11,268' 8880' slotted slotted Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,350' - 10,740' 8880' - 8888' 4 -1/2" 12.6#, L -80 9675' 11,110' - 11,210' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker 96A4 -60 SC-1LR Packer 9712' MD / 8554' TVD 12. Attachments: Description Summary of Proposal 151 13. Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Development n ' Service n 14. Estimated Date for 15. Well Status after proposed work: / 15- Jul -12 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ® ■ 7- ( v 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned .a b Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name -P 4 q , L G L M »ZZ© L - i , i ] Title I -I LLI,U G /"ll4, ufrfc e - Signature� LA /) P e D 7 te, /24 r � /1 1 r COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 6' 2, "' 2. Plug Integrity BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ ,' Other: B CP fc'S L id' UO p5i , /1/a // � i v) 5 f >tc I ` b r - {' S • > r1 C� l � f P 4/1 vii a1rpl✓ pMee itorfri'1 itic/ ftSi / 0 rt5S ">©. et.ppro veova p I-r L20 A,4C • //l t! L ) Subsequent Form Required: W ) I Z APPROVED BY Approved by1 P COMMISSIONER THE COMMISSION Date: ,y "i 7ii Form 10 -403 evised /2010 ® J' . Submit in Duplicate DMS JU 15 1011 (`� °1 G1N AL G.izr -(z,, p) .9/ �� 1 :t6 Em Iiiicorp Paul myca Drilling Mazzolini Man P. Box 24402 LLC Anchorage, AK 99524 -4027 Tel 907 777 8369 6/5/2012 Email pmazzolini @hilcorp.com Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7 Avenue Anchorage, Alaska 99501 RECEIVED Re: Steelhead Platform, Trading Bay Unit M -31 L1 JUN 0 6 2012 AOGCC Dear Commissioner, Enclosed for review and approval is the "Application for Sundry Approval" to permanently plug and abandon the M -31 L1 lateral previously drilled from the parent wellbore M -31 on the Steelhead platform in Oct, 1999. The M -31 L1 lateral will be 99 lu ed & abandoned along with the parent wellbore M-31, to facilitate re- P 9 p drilling of the well. - Plug and abandon operations are expected to commence July 15, 2012 immediately following the drilling and completion of M -29A. If you have any questions, please don't hesitate to contact myself at 777 -8369 or Luke Keller at 777- 8395. Sincerely, Paul Mazzolini Drilling Manager Hilcorp Alaska, LLC Page 1 of 1 • • Trading Bay Unit Well # M -31 Hilcorp 6/5/2012 Locity Lumpa;7 Obiective: • Pull current completion. • Plug & abandon G -zone perforations from 9,927'md to 10,548'md in 7" prod liner. Plug & - abandon 2 -7/8" slotted liner f/ 10,307'md to 11,265'md. • Prepare wellbore for re- drill. • Procedure Summary: 1. Circulate residual oil out of wellbore & load well with filtered inlet water. 2. Set BPV in tubing hanger. N/D tree, install & test 16 -3/4" 5M BOP (schematic attached). Test rams to 250/5000 psi, annular to 250/3500 psi. Remove BPV. A. BOP configuration f/ top down: 16 -3/4" Hydril GK 5M annular /16 -3/4" 5M Cameron U Double Ram /Mud cross /16 -3/4" 5M Cameron U single ram i. Double Ram: 3 -1/2" x 7" VBR in top cavity, blind ram in bottom cavity ii. Single Ram: 7 -5/8" fixed ram for running 7 -5/8" tieback . 3. Pull production tubing & Centrilift ESP. 4. TIH w/ tapered mill and ream out 1/8" HOMCO casing patch @ 157' to 177'. 5. Make a trip with 8 -1/2" bit & csg scraper to setting depth of RTTS. 6. Run & set RTTS, test casing to 1500 psi across reamed out section. Squeeze section w/ cmt if test unsuccessful - (set .EZSV below). Drill out cent & EZSV. Re-test casing to 1500 psi. 7. RIH w/ 8 -1/2" bit & casing scraper down to top of packer @ 9712'. Circ & clean up wellbore. 8. RIH w/ RTTS to above SC -1R packer, establish injection rates through packer. A. able to inject at sufficient rate: i. TOH, M/U & RIH w/ 9 -5/8" cmt retainer and set immediately above packer t ii. Attempt to squeeze 100 bbls cmt through retainer, balance remaining volume 06 - on top of retainer. Need a minimum of 75' cmt on top of retainer. iii. TOH, tag TOC after appropriate set time (24 hrs). iv. Test plug/ .cmt .to 1551_01.,psi for 30 min (notify AOGCC to witness). B. If unable to inject at sufficient rate through packer i. TOH, M/U 2 -3/8" stinger, TIH and sting through packer. Wash down to top of 2- o r( 7/8" liner top. ii. Balance 30 bbl 15.4 ppg cmt from 10184' to 9373'. iii. TOH, Tag TOC after appropriate set time (24 hrs). iv. Test plug / cmt to 1500 psi for 30 min (notify AOGCC to witness). 9. Run USIT to evaluate 9 -5/8" wear and cmt bond. A. If good cement bond behind 9 -5/8 ": i. Set CIBP at 7270'. B. If no cement bond behind 9 -5/8 ": i. Perf casing @ 7330' and 7130' ii. Run RTTS and set @ 7320', circ & clean up 9 -5/8" annulus from 7330' to 7130'. iii. Run and set EZSV @ 7320', circ cement up 9 -5/8" annulus from 7330' to 7130', unsting and balance 10 bbls cmt on top of EZSV. AOGCC M -31 P &A Summary 1 of 1 June 5, 2012 • Well Trading # M - Ba31 y Unit Hilcorp 6/5/2012 � scam. iv. WOC 24 hrs, dress off cmt down to 7275' with 8 -1/2" bit Q v. Set CIBP. PO\ 10. Run & set Baker Hughes G2 Window Master Whipstock on TM bottom trip anchor. Note: M -31 to be re- drilled as M -31A per the following procedure: A. Mill 8 -1/2" window in 9 -5/8" casing f/ 7250' to 7266'. Directional drill 8 -1/2" x 9 -1/2" hole section f/ 7266' to 13,041' MD / 9833' TVD in a SW direction (227deg) using a 9.6 ppg 2% KCI /Clayseal /GEM water based mud system. B. Run & cmt a 7 -5/8" 29.7# L -80 Hydril 523 prod liner f/ 13,041' to 7050' with a Baker I, Hughes ZXP liner top packer. C. Run a 7 -5/8" 29.7# L -80 Hydril 523 tieback assy. 1 �_ D. Selectively perforate G -zone & Hemlock intervals. E. Run a Centrilift ESP on 3 -1/2" 9.3# L -80 EUE prod tubing to '"11,000'. AOGCC M -31 P &A Summary 1 of 1 June 5, 2012 Maximum Anticipated Surface Pressure Calculation Plug & Abandonment Hilcorp Steelhead Platform Well M -31 Cook Inlet, Alaska M -31 Pressure Data (From 2001 Shut in BHP Survey) Reservoir MD TVD PP Grad EMW Gauge Reading 9700 8547 2900 0.339 6.53 G -zone Datum 10600 9038 3085 0.341 6.56 Extrapolated Gradient 12018 9207 I 3154 0.343 6.59 For 6" hole Fracture Pressure at 7" shoe (9173') Max estimated frac pressure at 7" liner shoe = 9173(ft) x 0.866(psi /ft)= 7,944 psi MASP from pore pressure Max pore pressure at TD (12,018' MD / 9,207' TVD) MASP (Wellbore evacuated to gas column) 9207(ft) x 0.343(psi /ft)= 3,154 psi 3154(psi) - [0.1(psi /ft) *9207(ft)] =I :21233 psi`'I • • , , Steelhead Platform ALASKA DRILLING Well # M -31L1 U N ®CAL. 76 Completion Date 8/16/01 RKB = 75.1.5' Rig Floor to TBG Hanger Casing and Tubing Detail SIZE WT GRADE CONN ID MD MD 1 TOP BTM. N' 1 0 2 6" 73 X -56 Surf. 979' s 16" 75 K -55 Buttress 15.124 Surf. 1,345' "14 2 13 -3/8" 68,61 K -55 Buttress 12.415/12.515 Surf. 3,722' _t' NA , 9 -5/8" 47 L -80 Buttress 8.681 Surf. 9,927 7" Liner 29 L -80 8rd LTC TKC 6.184 9,748' 11,188' 2 -7/8" Liner 6.4 L-80 Buttress 2.441 10,184' 10,306' r 1 " 2 -7/8" LNR 6.4 L -80 AB -STL 2337 10307' 11,265' ` predrilled 1 Tubing: 4VI r 4 -1/2" 12.6 L-80 AB Mod -BTC 3.958 Surf' 9,131' . I 4 -1/2" 12.6 L -80 AB Mod -BTC 3.958 9131' 9,597' it 4 1 ;a Jewelry NO Depth II) Item 1 75.15' 3.900" FMC TC -B -EC-ENS 16 3/4" TBG Hanger, 4 -1/2" Mod Bullheaded AIL 1 BTC btm x 4'//" BTC top, CIW'H' BPV 630 sxs cement 2 8274', 7878', 2.867" 3 -1/2" Camco SFO-1 BK -2 Latch SPM with 61 Vs @ down 1 7396', 6813', Note: Ran under -sized 3'h" SPMs due to csg patch @ 13 318 "x9 - 5/8" 6232', 5379', 155', with 3'/:" x 4'/�" X -overs above /below, plus they 3807', 1930' have 10' x 4' /z" pup joints above /below TOC @ .� 4 SJ 9,000' r3 � SS . i 3 9,597' 3.958" 4'/:" 12.6 ppf L -80 imp. BTC tubing -I- Note: Bottom 15 jts are spec. clear. cplg, rest are 5 q fOL @ standard " 6 9,748' 4 9,675' N/A Centrilift ESP 171 hp 5.62" mtr, 5.13" tandem seals, v f.. 'l' 4.00" tandem pumps (4' /x" Cannon clamps) y ', S n ' . ` r c. 5 9,712' 4.75" Baker 96A4 -60 SC -1LSC-1111 Retrievable Packer ` mmlisif 7 6 9,717' 4.75 Baker seal -bore extension (L = 9.36 ") 7 9,726' 4.130" Baker knockout isolation valve � !; ci 5 8 9,744' 3.813 Baker X Nipple i ' / 61417 ' 9 9,755' 4.00" Baker'' /2 muleshoe 5 / / j 10 157' -177' 3.841" Romeo Casing Patch (1/8" wall thickness) Top of 2 -7/8" ° / Fish /Fill Information: Liner @ A. Ran; RO" C R m ton of 2 7 /8" liner (14 10 18.4' on 3/29/(11 10,184' CTMAT 1 i Perforations , 1 1 Date Zone Top BTM Comments 4 ' . 1 1 1 10L Split 3/19/98 G -1 9,927' 9,967' 2 -7/8" HC 6 spf/ 60 deg 1 2/1/00 10/20/99 G -1 9,928' 9,948' 2 -7/8" HC 6 spf/ 60 deg 1 /03 °4- 8/27/94 G -1 9,935' 9,995' 3 -3/8" HC 6 spf 4 41 I 10/20/99 G -1 9,962' 9,982' 2 -7/8" HC 6 spf/ 60 deg 4 . O. 1 I 1 3/19/98 G -1 9,980' 9,990' 2 -7/8" HC 6 spf/ 60 deg 3 - 3/4" hole TD 10/20/99 G -2 10,013' 10,063' 2 -7/8" HC 6 spf/ 60 deg @ 11 26R' 3/19/98 G -2 10,018' 10,068' 2 -7/8" HC 6 spf/ 60 deg 8/26/94 6-2 10,045' 10,075' 3 -3/8" HC 6 spf .' 1 3/19/98 6-2 10,076' 10,086' 2 -7/8" HC 6 spf/ 60 deg . 3/19/98 6-3 10,137' 10,207' 2 -7/8" HC 6 spf/ 60 deg 10/20/99 G -3 10,146' 10,177' 2 -7/8" IIC 6 spf/ 60 deg 8/25/94 G -3 10,156' 10,216' 3 -3/8" HC 6 spf 6 open 3/19/98 G -4 10,241' 10,301' 2 -7/8" IIC 6 spti 60 deg hole 8/24/94 G -4 10,251' 10,305' 3 -3/8" HC 6 spf 3/19/98 G -5 10,398' 10,408' 2 -7/8" HC 6 spf/ 60 deg 8/23/94 6-5 10,416' 10,476' 3 -3/8" IIC 6 spf TD = 12,018' MD 8/22/94 LG -5 10,508' 10,548' 2 -1/8" HC 4 spf In Slotted Liner 23 @ 1,800'; 58 @ 10,400'; 89 @ 11,255' 9/4/00 G -4 10,350' 10,740' 2" TCP 4spf/ 60 deg 9/4/00 G -4 11.110' 11.210' 2" TCP 4snf/ 60 den M -31L1 Schematic Updated 9- 29- 09.doc Updated by: CVK Date: 9/29/09 • II • Steelhead Platform • 16 3 /4 5M BOP (Oil Leg) M -27, 29, 31 fine"''' Aua.k., tac 3/16/2012 N.. eocwamarm ice it azr 22" pipe for air boot flanges 942 A. uooewa0 .manor 313 /.21 3131 5.10' Fy4r�1 ' 5.46' cmwmaewwe wwawawmo.0153.96 TopeM mpOWa. p!V ( " � 1 0 3.00' tat 31 31 31 1 ;1 — 3.58' DSA16 Yr10M X16 %5M i 66 lat Ie to n, �, t er New sa.aawr•W !m .rewW Riser. 1614 5M API hub X 163/4 IOM FE uw..w oo-emayson cNmo 63.� Sow I Riser, 16 %.. 5M FE X 16'/. 5M API hub w.0*00nw uw e4 q nS.c psi zxne It t:Ig� ®� A tr .11+ _ i E'. � °4 ?id a 4E11 ilier R • • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected Stephen F DOA From: Davies, Step e (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve y D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily_Document Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 • \/~~ Francisco Castro Chevron North America Exploration and Production Technical Assistant 3800 Centerpoint Dr. Suite 100 `~, _ ,?=~" Anchorage, AK 99503 ~~ Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com DATE Tune 28, 2010 °, ~ ;, ,°~~, To: AOGCC Mahnken, Christine R r ,~ ~~j ~(~ 333 W. 7t" Ave. Ste#100~y~~~"~"' ~~'~~~ ~~ j Anchorage, AK 99501 ~ ~ ~ ~ ~ Transmitted herewith is one DVD containing the following data. • D-48L1 Formation evaluation logs -LAS ~ ~ .~~L~ /gj~ (~~ l • Gamma ray logs -LAS • K-12RD2 ~' ~~~-~5~~ ~ ~"~G7~ • K-12RD2_Final_Survey.xls ~ ~ ~ l 4 • K-12RD2_Tops.xlsx ! ~~~ _D~ • MPR-Gamma ray logs -LAS, CGM, PDF j 9 ~ C~ K-18RD • ~~~ _!~~ • K-18RD_Final_Survey.doc • Density Neutron logs -LAS ~ b j _ !`~ ! j ~ ~Sd ~S • K-18RDPB1 • UBI log -LAS, PDS, DLIS ~d ~ ~ ~1 y ~ ~b • survey.xls • K-24RD2 f 9 ~ ~ ~ ~ZS3-/~a • Density Neutron logs -LAS • Final Mudlog Report -LAS, DOC c~0~ "!~ ~ I ~ ~S1/ M-06 • Final logs; Depth, Formation Evaluation, Realtime, Time -LAS, PDS, DLIS • M-10 ~~~ ~!~ a `~ ~!~ • M-lOTops.xlsx • USIT log -PDS c~G9 -os3 !`~ ~,~ • Final logs; Depth, Formation Evaluation, Realtime, Time -LAS, PDS, DLIS • M-10PB1 • Final logs; Depth, Formation Evaluation, Realtime, Time -LAS, PDS, DLIS • M-16RD / Q l c~ ~ • M-16RD_Tops.xlsx _ Div j ~ • -Final logs; Cement Bond Log, Completion Record -PDS • M-17 • M-17_Tops.xlsx • M17_MWD_Survey.pdf • Final Mudlog Report -LAS, DOC, DBF, MDX, PDF, DAT • Final logs; Depth, Formation Evaluation, Cement Bond, Plug Setting, Perforation - LAS, PDS, DLIS, TIFF Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: Date: is STATE OF ALASKA ..... ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: X Alter casing: Repair well: Other: Install ESP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 160' KB ABOVE MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247, Anchorage, AK 99519 Service: Trading Bay Unit 4. LocalJon of well at surface Leg B-1 Slot & Steelhead Platform 8. Well number 970' FNL, 522' FWL, Sec 33-9N-13W-SM M-31 L1 At top of productive interval 9. Permit number/approval number 3,198' FSL, 2,254' FWL, Sec 28-gN-13W-SM 99-70 At effective depth 10. APl number 4,096' FSL, 2,446' FWL, Sec 28-9N-13W-SM 50- 733-20457-60 At total depth 11. Field/Pool McArthur River Field 4,096' FSL, 2,446' FWL, Sec 28-gN-13W-SM G Zone and Hemlock 12. Present well condition summary Total depth: measured 11,268' feet Plugs (measured) None true vertical 8,879' feet Effective depth: measured 11,268' feet Junk (measured) None true vertical 8,879' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1,345' 16" 2030 sx 1,345' 1,344' Surface 3,722' 13-3/8" 1600 sx 3,722' 3,524' Production 9,927' 9-5/8" 1650 sx 9,927' 8,679' Orig. Prod. Liner 1,440' 7" 385 sx 9,748' to 11,188' 8,575' to 9,173' Slotted Liner 1,081' 2-7/8" N/A 10,184' to 11,265' 8,826' to 8,880' Perforation depth: (no perfs added - refer to attached wellbore schematic diagram for existing perfs) Tubing (size, grade, and measured depth) 4-1/2" 12.6 Ib/ft L-80 IBTC S.C.C. @ 9,042' (base of ESP) Packers and SSSV (type and measured depth) Production packer: N/A (well on artificial lift, No-Flow status approved by AOGO) Other packers in well: (1 .) Baker SB-3 @ 9,088' (2.) Baker Model DB @ 10,100' 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatmerit description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Anch0r~e OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 7-30-01 348 50 848 891 131 Subsequent to operation 9-24-01 285 110 580 76 78 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: N/A Daily Report of Well Operations: X Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: S ig n e(~J~/~~ ~~ .~~~a., n Willia mso n Title: Drilling Manager Date: //~ ""- ,.~. o"t- ~ / Form 10-404 Rev 06/15/88 ORIGINAL SUBMIT IN DUPLICAT~ UNOCAL RKB = 75.15' Rig Floor to TBG Hanger 5 TOL ~ 9,748' Top of 2-7/8" Liner (~ 10.184' CTM 3-3/4" hole TD hole TD = 12,018' ~ 23° ~ 1,800'; 58° ~ 10,400'; 89° @ 11,255' M-31 Schematic 8-16-01 .doc Steelhead ~.tform Well # M-31RD Completion Date 8/16/01 Casing and Tubing Detail SIZE WT GRADE CONN ID MD MD TOP BTM. 16" 75 K-55 Buttress 15.124 Surf. 1,345' 13-3/8" 68,61 K-55 Buttress SurL 3,722' 9-5/8" 47 N-80 Buttress 8.835 Surf. 9,927' 7" Liner 29 L-80 Buttress 6.184 9,748' 11,188' 2-7/8" Liner 6.4 L-80 Buttress 2.441 10,184' 10,306' 2-7/8" LNR 6.4 L-80 AB-STL 2.337 10,307' 11,265' predrilled Tubing: 4-1/2" 12.6 L-80 AB Mod-BTC 3.958 Surf' 9,131' 4-1/2" 12.6 L-80 AB Mod-BTC SCC 3.958 9131' 9,597' Jewelry NO Depth ID Item 75.15' 3 9597' 4 9675' 9,712' 9,717' 9,726' 9,744* 9,755' 155'-175' 3.833" FMC TC-B-EC-ENS 16 3/4" TBG Hanger, 4-1/2" Mod BTC btm x 4 ½" BTC top, CIW 'H' BPV 2.992" 3-1/2" Camco SFO-I BK-2 Latch SPM with GLVs ~ 8282', 7886', 7403', 682U, 6240', 5387', 3815'~ 1937' Note: Ran under-sized 3 ¼' SPMs due to csg patch ~ 155', with 3 ½" x 4 ½' X-overs above/below, plus they have 10' x 4 ½" pup joints above/below 3.958" 4 ½" 12.6 ppf L-80 imp. BTC tubing Note: Bottom 15 jts are spec. clear, cplg, rest are standard N/A Centrilift ESP 171 hp 5.62" mtr, 5.13" tandem seals, 4.00" tandem pumps (4 ~" Cannon clamps) 4.75" Baker 96A4-60 SC-ILR Retrievable Packer 4.75 Baker seal-bore extension (L = 9.36") 4.130" Baker knockout isolation valve 3~813 Baker X Nipple 4.00" Baker ¼ muleshoe 3.841" Homco Casing Patch (I/8" wall thickness) Fish/Fill Information: A. Ran 3 80" GR 1o top of 2 7/8" liner ~f 10 184' Ol/3/29/0t Perforations Date Zone Top o ~ ~v~ Commen[s 8-27-94/3-19-98 G-I 9,935' 9,995' 3-3/8" HC 6 spt~ 2-7/8" IIC 6 spf/60 deg 3-19-98 G-I 9,988' 9,998' 2-7/8" HC 6 spf/60 deb 3-19-98 G-2 10,027' 10,077' 2-7/8" HC 6 spf/60 deb 8-26-94 G-2 10,045' 10,075' 3-3/8" HC 6 spf 3-19-98 G-2 10,085' 10,095' 2-7/8" HC 6 spf/60 deg 3-19-98 G-3 10,146' 10,216' 2-7/8" [lC 6 spf/60 deg 8-25-94 G-3 10,156' 10,216~ 3-3/8" HC 6 spf 3-19-98 G-4 10,250' 10,310' 2-7/8" HC 6 spf/60 deg 8-24-94 G-4 10,251' 10,305' 3-3/8" HC 6 spf 3-19-98 G-5 10,408' 10,418~ 2-7/8" HC 6 spf/60 deg 8-23-94 G-5 104,16' 10,476' 3-3/8" HC 6 spf 8-22-94 LG-5 10,508' 10,548' 2-7/8" 1lC 4 spf DRAWN BY: JFB Date: 10/01/01 STATE OF ALASKA ALASKA OIE"AND GAS CONSERVATION CO~MMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: X Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: Scale Clean Out 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 160' RKB MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247, Anchorage, AK 99519 Service: Trading Bay Unit 4. Location of well at surface Leg B-l, Slot 12, Steelhead Platform 8. Well number 907' FNL, 522' FWL, Sec 33, T9N, R13W, SM M-31 L1 At top of productive interval 9. Permit number/approval number 3,198' FSL, 2,254' FWL, Sec 28 T9N, R13W SM 99-70 At effective depth 10. APl number 4,096' FSL, 2,446' FWL, Sec 28, T9N, R13W SM 50- 733-20457-60 At total depth 11. Field/Pool 4,096' FSL, 2,446' FWL, Sec 28, T9N, R13W SM McArthur River - G-Zone/Hemlock 12. Present well condition summary Total depth: measured 11,268' feet Plugs (measured) true vertical 8,879' feet Effective depth: measured 11,245' feet Junk (measured) true vertical 8,879' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1,345' 16" 2,030 sx 1,345' 1,344' Intermediate 3,722' 13-3/8" 1,600 sx 3,722' 3,522' Production 9,927' 9-5/8" 1,650 sx 9,927' 8,678' Liner 1,440' 7" 385 sx 9,748'-11,188' 8,576'-9,173' Scab Liner 1,081' 2-7/8" (Pre-Drilled) N/A 10,184'-11,265 8,836'-8,879' Perforation depth: measured See Attached true vertical See Attached Tubing (size, grade, and measured depth) 4-1/2" 12.6#, L-80, Buttress @ 9,755' REuE.. ED Packers and SSSV (type and measured depth) Baker" SC-ILR 9-5/8" Packer @ 9,712', Camco TRDP-4A0 Tubing Retrievable SSSV ¢__, 462' 13. Stimulation or cement squeeze summary SEP 1 4 2000 See Attached Summary Intervals treated (measured) .,A~i C";~ & Gas Cc;is, ~mmissi0n See Attached Treatment Intervals Treatment description including volumes used and final pressure See Attached Treatment Summary 14. Representative Daily Average Production or Iniection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 8/18/00 24 0 66 753 98 Subsequent to operation 9/8/00 277 140 981 840 102 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: i6tNAL Sig ne~0~j~)~¢~~ Williamson Title: Drilling Manager Date: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Work Summary Coiled Tubing Steelhead Platform, Well No. M-31L 8-25-00 to 9-4-00 DAY 1 (8/25/00) RU COILED TUBING UNIT W/1.75" CT. SHUT DOWN FOR NIGHT. PRESSURE TEST BOPE 250 PSI LOW/3,500 PSI HIGH. GOOD TEST. DAY 2 (8/26/00) MAKE UP BHA NO. ONE 3.75" MILL, 2-7/8" MUD MOTOR. RIH WITH WELL ON GAS LIFT. CLEAN OUT TUBING THROUGH TAIL TO 9,790'. POOH. MAKE UP BHA NO. 2- 2-3/8" HYDRAULIC JDC. WITH WELL ON GAS LIFT RIH TO TUBING TAIL. UP ClRC RATE TO 2.1 BPM RUN OUT OF TUBING TAIL. TAG AT 9,845' WORK DOWN TO 9,868'. HARD TAG, UNABLE TO WORK DEEPER. PUMP SWEEP. POOH. SOME SAND NOTED IN RETURNS. DAY 3 (8/27/00) POOH WITH BHA NO. 2. NO RECOVERY OF FISH. RU SLICKLINE. RIH WITH 3.5" LIB TO 9,857'. POOH. IMPRESSION SHOWS SOME MARKS ON SIDE, NONE ON FACE. RIH W/2.5" LIB TO 9,865' TAG. POOH. NO IMPRESSION ON FACE. MARKS ON SIDE. RD SLICKLINE. MU INJECTOR HEAD. SHELL TEST. RIH W/BHA. NO. 5 - CHISEL TIP WASH NOZZEL. TAG AT 9,868'. WASH TO 9,874'. BREAK THROUGH AND WASH DOWN INTO 2-7/8" LINER TOP AT 10,184'. CONT. TO 11,167'. PU TO 11,145'. UNABLE TO GO BACK DOWN. POOH TO LINER TOP AT 10,184. PUMP 27 BBL HIGH VIS SWEEP. POOH. SECURE COIL. RU SLICKLINE. RIH W/BHA NO. 6 -3.75" JDC. UNABLE TO PASS 9,897'. RIH W/BHA NO. 7- 3.5" LIB. TO 9,897' IMPPRESSlON OF SCALE. DAY 4 (8/28/00) RIH W/BHA NO. RIH W/BHA NO. RIH W/BHA NO. RIH W/BHA NO. RIH W/BHA NO. RIH W/BHA NO. 8 -2.5" GAUGE RING. TAG 9,927' BREAK THROUGH RIH TO 10,176'. 9 - 2.85" GR. TAG AT 9,923' BREAK THROUGH RIH TO 10,176'. 10 - 3.25" GR SET DOWN 9,912' BREAK THROUGH RIH TO 10,176'. 11 - 3..55" GR SET DOWN 9,908' BREAK THROUGH RIH TO 10,176'. 12 - 3.75" GR SET DOWN 9,910' BREAK THROUGH RIH TO 10,176'. 13 - 3.5" LIB SET DOWN 10,176'. IMPRESSION OF ROPE SOCKET. RIH W/BHA NO. 14 - SKIRTED JUC. TAG AT 10,176' POOH. RECOVER 1-3/4" BAILER FISH FROM WELL. COVERED WITH ½"-3/4" SCALE SHEATH. RD SLICKLINE. MU COILED TUBING BHA NO. 15.3.45" UNDERREAMER (5-3/4" x 6" BLADES). RIH TAG TOP OF LINER AT 10,184'. UNDERREAM FROM 10,174' TO 9,800'. RIH UNDERREAMING TO 10,174'. POOH TO TUBING TAIL AT 9,767'. RIH UNDERREAMING TO 10,174'. PUMP 25 BBL. HIGH VIS SWEEP. CHASE OUT OF HOLE. POOH AND SECURE COIL. DAY 5 (8/29100) OPERATIONS SUSPENDEED WAITING FOR ACID. DAY 6 (8/30/00) RE-ACTIVATE COILED TUBING. MU BHA NO. 16 - 2.3" O.D. WASH NOZZEL. RIH AND TAG AT 10,205'. WASH HARD FILL FROM 10,205'-10,305'. PENETRATION RATE INCREASED, CONT. WASHING TO 11,080'. POOH TO LINER TOP AT 10,184'. RIH AND TAG 10,930'. POOH TO 10,384'. LINE UP AND PUMP 15.3% HCI ACID TO CLEAN SCALE FROM CASING AND TUBING. DAY 7 (8/31/00) EXTRACT COIL AND PUMP AT A 1:1 RATIO SPOTTING 32.5 BBLS OF ACID FROM 10,384'- 8,900'. POOH TO 8,479' AND ALLOW ACID TO SOAK FOR 3 HOURS. RIH TO 10,400' AND DISPLACE WELL TO 3% KCl WATER. POOH. RIG BACK INJECTOR HEAD. RELEASE WELL TO PRODUCTION FOR SCALE INHIBITION TREATMENT. DAY 8 (9/1/00) PUMP SCALE INHIBITION TREATMENT. DAY 9 (9/2/00) CONT. PUMP SCALE INHIBITION TREATMENT. RE-ACTIVATE COILED TUBING. MU BHA NO. 17 - 2.3" O.D. TAPPERED MILL AND 1-11/16" MOTOR. RIH AND RE-ENTER LINER AT 10,184'. NOTED LITE MOTOR WORK AT 11,050'. CONT. RIH TO 11,245'. POOH TO LINER TOP. RIH AND TAG 11,245'. POOH. DAY 10 (9/3/00) LAY DOWN BHA. BLEED GAS LIFT GAS FROM WELL. MU 100' OF 2", HSD, P J, 4SPF, 60 DEG PHASED PERFORATORS. MU ON COILED TUBING. RIH AND PERFORATE PRE- PERFORATED LINER (IN LATERAL) FROM 11,210'-11,110'. POOH. DAY 11 (9/4/00) LD GUNS. MU 230', HSD, P J, 4 SPF, 60 DEG; 120' HSD, P J, 2 SPF, 60 DEG; 40' HSD, P J, 4 SPF, 60 DEG. (390' TOTAL) RIH. PERFORATE FROM 10,740'-10,350'. POOH. RELEASE WELLL TO PRODUCTION. RIG DOWN COILED TUBING. Steelhead M-3'I L1 Treatment Interval Measured Depth True Vertical Depth Zone Top Btm Top Btm Amt Comments G-1 9,935' 9,995' 8,684' 8,717' 60' Perforated G-2 10,045' 10,075' 8,747' 8,765' 30' Perforated G-3 10,156' 10,216' 8,811' 8,846' 60' Perforated G-4 10,215' 10,305' 8,867' 8,899' 90' Perforated G-5 10,416' 10,476' 8,956' 8,987' 60' Perforated LG-5 10,508' 10,548' 8,998' 9,016' 40' Perforated G-3/4 10,184' 11,265' 8,826' 8,879' 1,081' Lateral L1 HB-1 11,188' 12,018' 9,173' 9,207' 830' Open Hole 2,251' Steelhead M-3'I L'I Treatment Summary Scale Inhibition Treatment Pumped 9/1/00 Fluid Volume Start Pres. Final Pres. Preflush (Fresh H20, 165 gal Tretolite WAW520-Mutual Solvent) 47bbls 0i 770 psi. Scale Inhibitor Pill (Fresh H20,495 gal Tretolite SCW4004-phosphonate/polymer scale inhibitor) 94 bbls 770 psi. 770 psi. Overflush (3% KCI H20) 470 bbls 770 psi. 800 psi Steelhead M-31 Lt Perforations added 9/3/00. The Lateral 1 2-7/8" Liner Predrilled w/1/2" holes, 16 ea/ft was perforated in two runs with Coiled Tubing Conveyd Perforators in the following intervals Measured Depth True Vertical Depth Zone Top Btm Top Btm Amt Comments L1 G-4 10,350' 10,390' 8,883' 8,883' 40' 2", HSD Power Jet, 4SPF, 60 deg L1 G-4 10,390' 10,510' 8,883' 8,886' 120' 2", HSD Power Jet, 2SPF, 60 deg L1 G-4 10,510' 10,740' 8,886' 8,887' 230' 2", HSD Power Jet, 4SPF, 60 deg L1 G-4 11,110' 11,210' 8,879' 8,879' 100' 2", HSD Power Jet, 4SPF, 60 deg 490' UNOC.AL ) RKB = 75.15' Rig Floor to TBG Hanger TOL ~ 9,748' Damaged TOL ® 10,184' 10 6" open Scale Inhibition Treatment 9/2/00 TOW ~ 10,234' DIL CT Clean Out To 11,245' 9/2/OO TD = 12,018' MD 23° ~ 1,800'; 58° ~ 10,400'; 89° ~ 11,255' M-31 dwg 10-11-99 Steelhead Platform Well # M-31 Completed 10/11/99 Casing and Tubing Detail SIZE WT GRADE CONN ID MD TOP MD BTM. 16" 75 K-55 Buttress 15.124 Surf. 1,345' 13-3/8" 68,61 K-55 Buttress Surf. 3,722' 9-5/8" 47 N-80 Buttress 8.835 Surf. 9,927' 7" 29 L-80 Buttress 6.184 9,748' 11,188' 10,234' DH~ 10,254' DIL WINDOW Milled in 7" Liner (10,222'CT1Vo (10,242'CTM) 2-7/8" Liner 16.4 IL-80 I~SSTL I 2.441 10,184' 11,265' Tubing: 4-1/2" 12.6 L-80 AB Mod- 3.958 Surf' 9,755' Buttress Jewelry NO Depth ID Item I 40' 4.00" 2 462' 3.812" 3 1,754' 3.833" 3,125' 3.833" 3,763' 3.833" 4,402' 3.833" 5,039' 3.833" 5,665' 3.833" 6,310' 3.833" 6,951' 3.833" 7,588' 3.833" 8,255' 3.833" 8,901' 3.833" 9,641' 3.833" 9,710' 3.875" 9,712' 4.75" 9,717' 4.75 9,726' 4.130" 9,744' 3.813 9,755' 4.00" Btm 10,248' 4 5 6 7 8 9 10 FMC TC-1A-EN 16" TBG Hanger, 4-1/2" Mod Butt connection W/CIW type H BPV profile Camco 4.5" TRDP-4AO SCSSSV flapper type, (3.812" X-profile) # 1 4-1/2" Camco MMG GLM with 1-1/2" Valve # 2 4-1/2" Camco MMG GLM with 1-1/2" Valve # 3 4-1/2" Camco MMG GLM with 1-1/2" Valve # 4 4-1/2" Camco MMG GLM with 1-1/2" Valve # 5 4-1/2" Camco MMG GLM with 1-1/2" Valve # 6 4-1/2" Camco MMG GLM with 1-1/2" Valve # 7 4-1/2" Camco MMG GLM with 1-1/2" Valve # 8 4-1/2" Camco MMG GLM with 1-1/2" Valve # 9 4-1/2" Camco MMG GLM with 1-1/2" Valve # 10 4-1/2" Camco MMG GLM with 1-1/2" Valve # 11 4-1/2" Camco MMG GLM with 1-1/2" Valve # 12 4-1/2" Camco MMG GLM with 1-1/2" Valve Baker GBH locator seal assembly (L = 18.94') Baker 96A4-60 SC-1LR Retrievable Packer Baker seal-bore extension (L = 9.36") Baker knockout isolation valve Baker X Nipple Baker 1/2 mule shoe Through Tubing Whipstock Perforations Date Zone Top BTM Comments 8-27-94/3-19-98 G-1 9,935' 9,995' 3-19-98 G-1 9,988' 9,998' 3-19-98 G-2 10,027' 10,077' 8-26-94 G-2 10,045' 10,075' 3-19-98 G-2 10,085' 10,095' 3-19-98 G-3 10,146' 10,216' 8-25-94 G-3 10,156' 10,216' 3-19-98 G-4 10,250' 10,310' 8-24-94 G-4 10,251' 10,305' 3-19-98 G-5 10,408' 10,418' 8-23-94 G-5 104,16' 10,476' 8-22-94 LG-5 10,508' 10,548' Lateral Perforated in the following intervals: 9/3/00 L1 G-4 10,350' 10,390' 9/3/00 L1 G-4 10,390' 10,510' 9/3/00 L1 G-4 10,510' 10,740' 9/3/00 L1 G-4 11,110' 11,210' 3-3/8" HC 6 spf, 2-7/8" HC 6 spff 60 deg 2-7/8" HC 6 spf/60 deg 2-7/8" HC 6 spff 60 de# 3-3/8" HC 6 spf 2-7/8" HC 6 spf/60 deg 2-7/8" HC 6 spff 60 de# 3-3/8" HC 6 spf 2-7/8" HC 6 spff 60 deg 3-3/8" HC 6 spf 2-7/8" HC 6 spf/60 de# 3-3/8" HC 6 spf 2-7/8" HC 4 spf 2", HSD Power Jet 4 SPF, 60 Deg 2", HSD Power Jet 2 SPF, 60 De# 2", HSD Power Jet 4 SPF, 60 Deg 2", HSD Power Jet 4 SPF, 60 Deg UPDATED BY: TCB DATE: 9/11/00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: X Plugging: Perforate: Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 160' RKB MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247, Anchorage, AK 99519 Service: Trading Bay Unit 4. Location of well at surface 8. Well number 907' FNL, 522' FWL, Sec 33, T9N, R13W, SM M-31L At top of productive interval 9. Permit number/approval number 3,198' FSL, 2,254' FWL, Sec 28 T9N, R13W SM 99-70 At effective depth 10. APl number 4,096' FSL, 2,446' FWL, Sec 28, T9N, R13W SM 50- 733-20457-60 At total depth 11. Field/Pool 4,096' FSL, 2,446' FWL, Sec 28, T9N, R13W SM McArthur River Field - G-Zone 12. Present well condition summary Total depth: measured 11,268' feet Plugs (measured) true vertical 8,879' feet Effective depth: measured 11,268' feet Junk (measured) true vertical 8,879' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface Intermediate Production Liner 1,081' 2-7/8" (Pre-Drilled) N/A 10,184'-11,265 8,836'-8,879' Scab Liner Perforation depth: measured Slotted Liner true vertical Tubing (size, grade, and measured depth) ' _ Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) 10,250'- 11,268' Treatment description including volumes used and final pressure Xylene Scald Sodium Hypochlorite (see attached) 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1/16/00 461 30 400 923 96 Subsequent to operation 2/21/00 512 130 529 892 108 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: iSigne~~)/4/ i~~~~~. /~ Williamson litle: Drilling Manager Form 10-404 Rev 06/15/88 SUBMIT IN .,L DUPLICATE~ Work Summary Coiled Tubing Stimulation Steelhead Platform, Well No. M-31L 2-5-00 to 2-7-00 DAY 1 (2/5/00) RU COILED TUBING UNIT W/1.75" CT. SHUT DOWN FOR NIGHT. DAY 2 (2/6/00) PRESSURE TEST BOPE 250 PSI LOW/4,000 PSI HIGH. GOOD TEST. MAKE UP BHA NO. ONE 2-1/8" MILL, 1-11/16" MUD MOTOR. STAB INJECTOR HEAD AND TEST TO 250/4,000 PSI. GOOD TEST. RIH TO TOP OF LINER AT 10,184'. ENTER LINER. WITH WELL ON GAS LIFT, CONT. IN HOLE WASHING WITH FILTERED INLET WATER W/3% KCL. WASH TO BOTTOM OF LINER AT 11,259'. POOH TO 10,250'. SI GAS LIFT. RIH CHANGING OVER TO XYLENE. CONT. IN HOLE TO 11,259'. POOH LAYING IN XYLENE. STOP AT 10,250'. ALLOW XYLENE TO SOAK DAY 3 (2/7/00) ALLOW XYLENE TO SOAK TOTAL OF 8 HOURS. BRING WELL ON GAS LIFT. RIH TO 11,259' WASHING WITH 3% KCL. POOH TO 10,250. PUMP 25 BBL HIGH VIS SWEEP, DISPLACE WITH 3% KCL. SHUT IN GAS LIFT. RIH WASHING WITH 3% KCL. POOH FROM 11,259' SPOTTING 35 KCL MIXED WITH 15% SODIUM HYPOCHLORITE. POOH. RD COILED TUBING. RETURN WELL TO PRODUCTION. RKB = 75.15' Rig Floor to TBG Hanger TOL @ 9,748' Damaged TOL @ 10,184' 10 TOW @ 10,234' DIL 6" open TD = 12,018' MD 23° @ 1,800'; 58° @ 10,400'; 89° @ 11,255' CT Clean Out To 11,265' 2/7/00 Steelhead Platform Well # M-31 Completed 10/11/99 Casing and Tubing Detail SIZE WT GRADE CONN ID MD TOP MD BTM. 16" 75 K-55 Buttress 15.124 Surf. 1,345' 13-3/8" 68,61 K-55 Buttress · Surf. 3,722' 9-5/8" 47 N-80 Buttress 8.835 SurL 9,927' 7" 29 L-80 Buttress 6.184 9,748' 11,188' 10,234' DIL 10,254' DIL WINDOW Milled in 7" Liner (10,222'CTM) (10,242'CTM) 2-7/8" Liner 16.4 IL-S0 lABS STL I 2.441 10,184' 11,265' Tubing: 4-1/2" 12.6 L-80 AB Mod- 3.958 Surf' 9,755' Buttress Jewelry NO Depth ID Item 4 5 6 7 8 9 10 40' 4.00" 462' 3.812" 1,754' 3.833" 3,125' 3.833" 3,763' 3.833" 4,402' 3.833" 5,039' 3.833" 5,665' 3.833" 6,310' 3.833" 6,951' 3.833" 7,588' 3.833" 8,255' 3.833" 8,901' 3.833" 9,641' 3.833" 9,710' 3.875" 9,712' 4.75" 9,717' 4.75 9,726' 4.130" 9,744' 3.813 9,755' 4.00" Btm 10,248' FMC TC-1A-EN 16" TBG Hanger, 4-1/2" Mod Butt connection W/CIW type H BPV profile Camco 4.5" TRDP-4AO SCSSSV flapper type, (3.812" X-profile) # 1 4-1/2" Camco MMG GLM with 1-1/2" Valve # 2 4-1/2" Camco MMG GLM with 1-1/2" Valve # 3 4-1/2" Camco MMG GLM with 1-1/2" Valve # 4 4-1/2" Camco MMG GLM with 1-1/2" Valve # 5 4-1/2" Camco MMG GLM with 1-1/2" Valve # 6 4-1/2" Camco MMG GLM with 1-1/2" Valve # 7 4-1/2" Camco MMG GLM with 1-1/2" Valve # 8 4-1/2" Camco MMG GLM with 1-1/2" Valve # 9 4-1/2" Camco MMG GLM with 1-1/2" Valve # 10 4-1/2" Camco MMG GLM with 1-1/2" Valve # 11 4-1/2" Camco MMG GLM with 1-1/2" Valve # 12 4-1/2" Camco MMG GLM with 1-1/2" Valve Baker GBH locator seal assembly (L = 18.94') Baker 96A4-60 SC-1LR Retrievable Packer Baker seal-bore extension (L = 9.36") Baker knockout isolation valve Baker X Nipple Baker 1/2 mule shoe Through Tubing Whipstock Fish/Fill Information: A. Tag Fill @ 10,455' 2/11/98 Perforations Date Zone Top BTM Comments 8-27-94/3-19-98 3-19-98 3-19-98 8-26-94 3-19-98 3-19-98 8-25-94 3-19-98 8-24-94 3-19-98 8-23-94 8-22-94 G-1 9,935' 9,995' G-1 9,988' 9,998' G-2 10,027' 10,077' G-2 10,045' 10,075' G-2 10,085' 10,095' G-3 10,146' 10,216' G-3 10,156' 10,216' G-4 10,250' 10,310' G-4 10,251' 10,305' G-5 10,408' 10,418' G-5 104,16' 10,476' LG-5 10,508' 10,548' 3-3/8" HC 6 spf, 2-7/8" HC 6 spff 60 deg 2-7/8" HC 6 spf/60 deg 2-7/8" HC 6 spf/60 de# 3-3/8" HC 6 spf 2-7/8" HC 6 spf/60 de# 2-7/8" HC 6 spf/60 deg 3-3/8" HC 6 spf 2-7/8" HC 6 spff 60 deg 3-3/8" HC 6 spf 2-7/8" HC 6 spf/60 deg 3-3/8" HC 6 spf 2-7/8" HC 4 spf M-31 dwg 10-11-99 UPDATED BY: SLT STATE OF ALASKA ALASKA O L:'AND GAS CONSERVATION UOMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: X''~zl GAS: SUSPENDED: ABANDONED: X SERVICE: 2. Nam~ o¥ Operator 7. Permit Number UNION Oil Company of California (UNOCAL) 99-70 3. Address 8. APl Number P.O. Box 19624, Anchorage, AK 99519 ~.' ;;"~.~'~ i :'~,'l~ir'.i ;~ 50- 733-20457-60 4. Location of well at sudace ; ~'.` ~.Z)~ i 9. Unit or Lease Name 970' FNL, 522' FWL, Sec 33, T9N, R13W, SM . ;r~'~~. Trading Bay Unit At Top Producing Interval ~, ~.~]~¢~ .:~- 10. Well Number 3,198'FSL, 2,254'FWL, Sec289N-13WSM~. .,~!~~ M-31 L1 At Total Depth~) 14.1~.2- : ........ ' .......... ?'.¢,. ~'~-'%' 11. Field and Pool 4~16' FSL,, 'FWL, SEC 28 aN-laW SM No~ McArthur River Filed '-5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial I . Gzone/Hemlock 160' KB ADL -18730 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No; of Completions I 9/26/99 10/8/99 10/10/99 187 feet MSL 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 119. Directional Survey 20. Depth where SSSV set ]21. Thickness of Permafrost 11,268'/'/8879 11,268'/'/8879I Yes: X No: feet MDI NA 22. Type Electric or Other Logs Run NA 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 2-7/8" 6 L-80 10,184' 11,265' 3-3/4" Pre-drilled Liner 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) PeRorations are abandoned. NA 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 10/11/99I Gas lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 11/9/99 24 TEST PERIOD => 590 15 210 Full openI 25 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 104 862 24-HOUR RATE => 590 15 210 32.8 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NA RECEIVED t OV i8 1999 Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. G4 Sand top 10,254' 8,865' 31. LIST OF ATTACHMENTS Wellbore diagram, surveys and operations summary. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item '16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 UNOCAL RKB = 75.15' Rig Floor to TBG Hanger TOL ~ 9,748' Top of 2-7/8" Liner @ 10,184' CTM 3-3/4" hole TD ~ 11,268' 6" open hole TD = 12,018' MD 23° ~ 1,800'; 58° ~ 10,400'; 89° ~ 11,255' M-31 L1 10-10-99.doc.doc Steelhead~atform Well # M-31 L1 Actual Completion 10/10/99 SIZE WT Casing and Tubing Detail GRADE CONN ID MD TOP MD BTM. 16" 13-3/8" 9-5/8" 7" Liner 2-7/8" Liner 2-7/8" LNR predrilled Tubing: 4-1/2" 75 68,61 47 29 6.4 6.4 12.6 K-55 Buttress 15.124 Surf. 1,345' K-55 Buttress Surf. 3,722' N-80 Buttress 8.835 Surf. 9,927' L-80 Buttress 6.184 9,748' 11,188' L-80 Buttress 2.441 10,184' 10,306' L-80 AB-STL 2.337 10,307' 11,265' L-80 AB Mod- 3.958 Surf' 9,755' Buttres~ NO Depth Jewelry Item 40' 4.00" 462' 3.812" 1,754' 3.833" 3,125' 3.833" 3,763' 3.833" 4,402' 3.833" 5,039' 3.833" 5,665' 3.833" 6,310' 3.833" 6,951' 3.833" 7,588' 3.833" 8,255' 3.833" 8,901' 3.833" 9,641' 3.833" 9,710' 3.875" 9,712' 4.75" 9,717' 4.75 9,726' 4.130" 9,744' 3.813 9,755' 4.00" FMC TC-1A-EN 16" TBG Hanger, 4-1/2" Mod Butt connection W/C1W type H BPV profile Camco 4.5" TRDP-4AO SCSSSV flapper type, (3.812" X-profile) # 1 4-1/2" Camco MMG GLM with 1-1/2" Valve # 2 4-1/2" Camco MMG GLM with 1-1/2" Valve # 3 4-1/2" Camco MMG GLM with 1-1/2" Valve # 4 4-1/2" Camco MMG GLM with 1-1/2" Valve # 5 4-1/2" Camco MMG GLM with 1-1/2" Valve # 6 4-1/2" Camco MMG GLM with 1-1/2" Valve # 7 4-1/2" Camco MMG GLM with 1-1/2" Valve # 8 4-1/2" Camco MMG GLM with 1-1/2" Valve # 9 4-1/2" Camco MMG GLM with 1-1/2" Valve # 10 4-1/2" Camco MMG GLM with 1-1/2" Valve # 11 4-1/2" Camco MMG GLM with 1-1/2" Valve # 12 4-1/2" Camco MMG GLM with 1-1/2" Valve Baker GBH locator seal assembly (L = 18.94') Baker 96A4-60 SC-1LR Retrievable Packer Baker seal-bore extension (L = 9.36") Baker knockout isolation valve Baker X Nipple Baker 1/2 mule shoe Fish/Fill Information: A. Tag Fill @ 10,455' 2/11/98 Perforations Date Zone Top BTM Comments 8-27-94/3-19-98 G-1 9,935' 9,995' 3-3/8" HC 3-19-98 G-1 9,988' 9,998' 2-7/8" HC 3-19-98 G-2 10,027' 10,077' 2-7/8" HC 8-26-94 G-2 10,045' 10,075' 3-3/8" HC 3-19-98 G-2 10,085' 10,095' 2-7/8" HC 3-19-98 G-3 10,146' 10,216' 2-7/8" HC 8-25-94 G-3 10,156' 10,216' 3-3/8" HC 3-19-98 G-4 10,250' 10,310' 2-7/8" HC 8-24-94 G-4 10,251' 10,305' 3-3/8" HC 3-19-98 G-5 10,408' 10,418' 2-7/8" HC 8-23-94 G-5 104,16' 10,476' 3-3/8" HC 8-22-94 LG-5 10,508' 10,548' 2-7/8" HC 6 spf, 2-7/8" HC 6 spf/60 deg 6 spf/60 deg 6 spf/60 deg 6 spf 6 spf/60 deg 6 spf/60 deg 6 spf 6 spf/60 deg 6 spf 6 spf/60 de# 6 spf 4 spf DRAWN BY: MWD Revised 10/18/99 Schlumberger Survey Client: Field: Structure: Well: Borehole: UWIIAPI#: Date: Grid Convergence: Scale Factor: Location: : Coordinate System: Unocal Trading Bay Steelhead M-31 M-31 L1 50-733-20457-60 October 08, 1999 -1.39900204° 0.99999298 N 60 49 55.196, W 151 36 7.437 N 2499525.969 ftUS, E 214141.189 ftUS NAD27 Alaska State Planes, Zone 4, US Foot Survey Computation Method: DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference: Magnetic Declination: Total Field Strength: Dip: Declination Date: Magnetic Declination Model: North Reference: Coordinate Reference To: Minimum Curvature Lubinski 357.070° N 0.000 ft, E 0.000 ft RKB 160.0 ft above MSL 21.316° 55239.594 nT 73.518° October 08, 1999 BGGM 1999 True North Well Head Tie-In Interp Azimuth _ Interp Azimuth 10200.00 54.04 31.5 8836.54 10248.36 59.88 35.9 8862.90 10276.26 73.40 38.4 8873.94 10290.70 79.55 39.8 8877.32 10321.70 85.19 40.1 8881.43 10351.42 87.85 42.7 8883.24 10378.82 89.55 39.2 8883.86 10401.36 91.30 35.7 8883.69 10441.72 88.53 33.8 8883.75 10471.44 85.95 31.9 8885.18 4037.27 4069.75 4089.28 4099.70 4122.21 4143.42 4163.16 4180.32 4212.25 4236.33 4130.07 4163.74 4184.09 4194.98 4218.53 4240.77 4261.45 4279.34 4312.49 4337.42 1709.86 4470.02 22.5 33.4 G 1732.37 4509.75 22.6 14.26 10.4 G 1747.83 4534.48 22.7 49.18 11.9 G 1756.68 4547.94 22.7 43.49 3.7 G 1776.40 4577.29 22.8 18.23 44.5 G 1796.02 4605.41 1813.97 4631.46 1827.68 4653.30 1850.69 4692.82 1866.80 4722.09 23.0 23.1 23.1 23.2 23.3 12.53 -64.5 G 14.36 -63.1G 17.16 -145.5G 8.32 -143.0 G 10.88 -82.7 G 30' Survey Report.xls Page 1 of 2 10/19/99-10:14 AM 10519.24 86.33 28.9 8888.40 4276.16 4378.54 1890.94 4769.41 10551.65 87.72 28.4 8890.08 4303.72 4406.94 1906.48 4801.64 10581.48 88.55 28.5 8891.05 4329.17 4433.15 1920.69 4831.34 10611.60 88.57 27.4 8891.81 4355.01 4459.74 1934.81 4861.35 10641.35 89.15 26.7 8892.40 4380.77 4486.22 1948.35 4891.04 10671.34 90.70 25.5 8892.44 4406.98 4513.14 1961.56 4920.99 10687.72 91.55 25.1 8892.12 4421.40 4527.95 1968.56 4937.36 10715.81 95.05 24.4 8890.50 4446.23 4553.41 1980.30 4965.39 10742.85 95.25 21.3 8888.08 4470.48 4578.22 1990.76 4992.32 10772.59 93.22 17.1 8885.88 4497.94 4606.22 2000.53 5021.89 10801.42 91.70 12.1 8884.64 4525.39 4634.08 2007.80 5050.34 10831.59 89.25 7.7 8884.39 4554.80 4663.79 2012.99 5079.67 10861.46 87.88 2.5 8885.14 4584.35 4693.52 2015.63 5108.02 10891.44 89.90 357.9 8885.72 4614.28 4723.49 2015.73 5135.61 10918.69 91.00 353.7 8885.51 4641.51 4750.66 2013.75 5159.84 10941.64 92.98 351.2 8884.71 4664.37 4773.39 2010.75 5179.61 10971.52 93.05 349.3 8883.14 4694.00 4802.80 2005.70 5204.78 11001.42 93.65 347.3 8881.39 4723.49 4832.02 1999.64 5229.44 11031.69 91.97 345.1 8879.91 4753.18 4861.38 1992.43 5253.84 11062.01 89.63 342.7 8879.48 4782.70 4890.51 1984.02 5277.63 11091.79 88.40 340.1 8879.99 4811.37 4918.73 1974.54 5300.25 11121.43 90.20 340.4 8880.36 4839.74 4946.62 1964.52 5322.44 11151.46 87.70 338.0 8880.91 4868.30 4974.68 1953.85 5344.62 11181.53 90.25 335.2 8881.45 4896.47 5002.27 1941.91 5365.98 11211.48 92.18 334.4 8880.81 4924.18 5029.37 1929.18 5386.67 11231.33 90.05 334.8 8880.42 4942.52 5047.29 1920.67 5400.38 Pr~ected to TD 11265.00 92.20 332.0 8879.76 4973.34 5077.39 1905.59 5423.20 23.4 6.17 -20.5 G 23.4 4.58 4.8 G 23.4 2.79 -88.9 G 23.5 3.55 -50.4 G 23.5 3.06 -37.3 G 23.5 6.50 -28.9 G 23.5 5.93 -10.8 G 23.5 12.69 -86.1 G 23.5 11.37 -115.7 G 23.5 15.65 -106.9 G 23.4 18.04 -118.5G 23.3 16.98 -104.9 G 23.2 17.90 -66.1G 23.1 16.60 -75.3 G 23.0 15.93 -51.6 G 22.8 13.89 -87.9 G 22.7 6.52 -73.1 G 22.5 6.91 -127.1 G 22.3 9.19 -134.9G 22.1 10.94 -115.3G 21.9 9.66 7.3 G 21.7 6.12 -136.4G 21.4 11.49 -47.2 G 21.2 12.47 -22.5 G 21.0 6.98 170.7 G 20.8 10.87 -52.3 G 20.6 10.44 --- 30' Survey Report.xls Page 2 of 2 10/19/99-10:14 AM Steelhead M-3'I L1 Operations Summary: 10110.10111199: Complete Demobilizing CT drilling unit. 10104-10110199: Drill 3-3/4" hole from 10,719' to 11,268' and TD well--(Test BOPE). RIH with 2- 7/8" predrilled liner. Change well over to 3% KCL and spot Mudzyme in open hole. RIH with chemical cutter on coil. Latch top of liner and cut coil @ 10,184'. POOH and LD BHA. Turn well over to production. Begin demobilizing CT drilling unit. 9127-10103199: Drill 3-3/4" hole from 10,295' to 10644'. Crimped coiled tubing while POOH. Changed out entire 2" reel of coiled tubing. RIH with new coil and BHA. Orienter failed while attempting to get through window. POOH and change out orienter. RIH and drill to 10,719'. 9120.9126199: RU Riser and BOPE on M-31. Fill annulus with FIW. RU Dowell 2.0" Coiled Tubing Drilling Unit. Pressure test BOPE. MU milling BHA #1. RIH and mill window 10,234'-10,241' with FIW. Change well over to FLO-PRO 8.7 PPG mud. POOH and PU BHA #2. RIH and dress window and mill to 10,248'. POOH and PU drilling BHA. RIH and drill to 10,29.5'. 9/12/9 9-9/19/99: Rig up coiled tubing drilling equipment. M-31 L1 Operations Summary.doc 10/19/99--9:51 AM ANADRILL SCHLUMBERGER Survey report Client ................... : UNOCAL Field .................... : McAuthur River Well ..................... : M-31 L1 API number ............... : 50-733-20457-60 Engineer ................. : jeroen bosse Platform: ................ : Steelhead State: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : RA tag at 10239.9 ft DIL GL above permanent ....... : -196.40 ft KB above permanent ....... : Coiled Tubing Drilling DF above permanent ....... : 160.00 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 357.07 degrees 8-0ct-1999 10:49:04 Page 1 of 3 ORiGiNAL Spud date ................ : 26 September 1999 Last survey date ......... : 08-Oct-99 Total accepted surveys...: 37 MD of first survey ....... : 10200.00 ft MD of last survey ........ : 11265.00 ft Geomagnetic data ................. Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 25-Sep-1999 Magnetic field strength..: 1104.85 HCNT Magnetic dec (+E/W-) ..... : 21.32 degrees Magnetic dip ............. : 73.52 degrees MWD survey Reference Criteria Reference G .............. : 1002.03 mGal Reference H .............. : 1104.90 HCNT Reference Dip ............ : 73.52 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 21.33 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 21.33 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)1999 Anadrill IDEAL ID6 0C 04] ANADRILL SCHLUMBERGER Survey Report 8-Oct-1999 10:49:04 Page 2 of 3 Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) Gyro Tie In Point 1 10200.00 54.04 31.45 0.00 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) 8836.54 4037.27 4130.07 1709.86 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) lOOf) type type 4470.02 22.49 0.00 TIP 2 10248.36 59.88 35.88 3 10276.26 73.40 38.44 4 10290.70 79.55 39.75 5 10321.70 85.19 40.12 48.36 27.90 14.44 31.00 8862.91 8873.94 8877.32 8881.43 4069.76 4163.75 1732.36 4089.29 4184.10 1747.81 4099.71 4194.99 1756.67 4122.22 4218.54 1776.38 4509.76 22.59 4534.48 22.67 4547.94 22.72 4577.29 22.84 14.31 49.18 43.49 18.23 6-axis 6-axis 6 10351.42 87.85 42.73 7 10378.82 89.55 39.18 8 10401.36 91.30 35.73 9 10441.72 88.53 33.83 10 10471.44 85.95 31.88 29.72 27.40 22.54 40.36 29.72 8883.24 8883.86 8883.69 8883.75 8885.18 4143.43 4240.78 1796.01 4163.17 4261.46 1813.96 4180.33 4279.35 1827.66 4212.26 4312.49 1850.68 4236.33 4337.43 1866.78 4605.41 22.95 4631.47 23.06 4653.30 23.13 4692.83 23.23 4722.09 23.29 12 14 17 8 10 .53 .36 .16 .32 .88 SHARP SHARP SHARP SHARP SHARP 11 10519.92 86.30 30.90 12 10551.65 87.73 28.43 13 10581.48 88.55 28.50 14 10611.60 88.58 27.43 15 .10641.35 89.15 26.73 48.48 31.73 29.83 30.12 29.75 8888.46 8890.11 8891.08 8891.84 8892.43 4276.28 4378.72 1891.98 4302.98 4406.25 1907.66 4328.43 4432.46 1921.87 4354.26 4459.05 1935.99 4380.02 4485.54 1949.53 4769.98 23.37 4801.48 23.41 4831.18 23.44 4861.19 23.47 4890.88 23.49 .14 .97 .79 .55 .06 MWD SHARP SHARP SHARP SHARP 16 10671.34 90.70 25.55 17 10686.72 91.55 25.08 18 10715.81 95.05 24.41 19 10742.85 95.25 21.33 20 10772.59 93.23 17.13 29.99 15.38 29.09 27.04 29.74 8892.47 8892.17 8890.50 8888.07 8885.87 4406.23 4512.46 1962.74 4419.78 4526.36 1969.31 4445.49 4552.73 1981.47 4469.74 4577.54 1991.93 4497.20 4605.54 2001.69 4920.83 23.51 4936.20 23.51 4965.23 23.52 4992.16 23.52 5021.73 23.49 6.50 6.32 12.26 11.33 15.65 SHARP SHARP SHARP SHARP SHARP 21 10801.42 91.70 12.16 22 10831.59 89.25 7.65 23 10861.46 87.88 2.48 24 10891.44 89.90 357.93 25 10918.69 91.00 353.73 28.83 30.17 29.87 29.98 27.25 8884.63 8884.38 8885.13 8885.71 8885.50 4524.65 4633.40 2008.97 4554.05 4663.11 2014.16 4583.61 4692.84 2016.79 4613.53 4722.80 2016.90 4640.77 4749.98 2014.92 5050.18 23.44 5079.51 23.36 5107.86 23.26 5135.44 23.13 5159.67 22.99 18.04 16.98 17.90 16.60 15.93 SHARP SHARP SHARP SHARP SHARP 26 10941.64 92.98 351.23 27 10971.52 93.05 349.28 28 11001.42 93.65 347.31 29 11031.69 91.98 345.08 30 11062.01 89.63 342.73 22.95 29.88 29.90 30.27 30.32 8884.70 8883.13 8881.39 8879.90 8879.48 4663.63 4772.71 2011.92 4693.26 4802.12 2006.87 4722.75 4831.34 2000.81 4752.44 4860.70 1993.59 4781.96 4889.82 1985.19 5179.44 22.86 5204.60 22.68 5229.26 22.50 5253.65 22.30 5277.44 22.10 13.86 6.52 6.91 9.19 10.94 SHARP SHARP SHARP SHARP SHARP [(c)1999 Anadrill IDEAL ID6 0C 04] ANADRILL SCHLUMBERGER Survey Report 8-Oct-1999 10:49:04 Page 3 of 3 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) lOOf) type type 31 11091.79 88.40 340.13 29.78 8879.99 4810.63 4918.05 1975.71 5300.06 21.89 9.66 SHARP - 32 11121.43 90.20 340.36 29.64 8880.35 4838.99 4945.94 1965.69 5322.24 21.67 6.12 SHARP - 33 11151.46 87.70 337.98 30.03 8880.90 4867.56 4974.00 1955.01 5344.41 21.46 11.47 SHARP - 34 11181.53 90.25 335.23 30.07 8881.44 4895.72 5001.58 1943.07 5365.76 21.23 12.47 SHARP - 35 11211.48 92.18 334.43 29.95 8880.81 4923.44 5028.68 1930.34 5386.45 21.00 6.98 SHARP - 36 11231.33 90.05 334.78 19.85 8880.42 4941.78 5046.61 1921.83 5400.16 20.85 10.87 SHARP - Final Survey Projected to total depth for the well 37 11265.00 92.20 332.00 33.67 8879.76 4972.60 5076.70 1906.75 5422.97 20.59 10.44 MWD [(c)1999 Anadrill IDEAL ID6 0C 04] TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION Julv 23. 1999 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dan Williamson Drilling Manager Unocal Corporation P O Box 190247 Anchorage, AK 99519-0247 Re: Trading Bav Unit M-31L 1 Unocal Corporation Permit No: 99-70 Sur Loc: 970'FNL. 522'FWL. Sec. 33. T9N. R13W. SM Btmholc Loc. 4047'FSL. 1984'FWL. Sec. 28. T9N. R13W. SM Dear Mr. Williamson: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The permit is for a new wellbore segment of existing well Trading Bay Unit M-3 l. Permit No. 93 190. API_ 0-7.~.~-_04>7. Production should continue to be reported as a function of the original APl number stated above. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission at 279-1433. . P. E~-~ Chairman BY ORDER OF THE COMMISSION dlffEnclosures CC; Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation xv/o encl. TONY KNOWLES. GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 12, 1999 ADMINISTRATIVE APPROVAL NO. 80.75 Re: The application of Union Oil Company of California (UNOCAL), operator of the Trading Bay Unit (TBU), to drill and complete the TBU D-31L 1 well as part of the pressure maintenance project approved by Conservation No. 80. Mr. Kevin A Tabler Landman UNOCAL Corp P. O. Box 190247 Anchorage, AK 99502-0247 Dear Mr. Tabler: Your application dated June 15, 1999 for a "Permit to Drill" TBU well M-31 L1 is proposed to recover additional oil from the Middle Kenai "G" oil pool. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling and completion of the TBU M-31 L 1 well pursuant to Rule 5 of Conservation Order No. 80. Anchorage, Alaska and dated July 12, 1999. Camill~ Oechsli David W~ohnston Commissioner Commission Robert ~.hristenson, P.E. Chairman BY ORDER OF THE COMMISSION Unocal Alaska Re., Unocal Corporation ....... 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL , June 15, 1999 Mr. Robert N. Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 TRADING BAY UNIT Well M-31 APPLICATION TO DRILL AND COMPLETE ADL- 18730 Dear Chairman Christenson: Union Oil Company of California, as operator of the Trading Bay Unit, hereby requests approval to drill, complete and produce Trading Bay Unit State well M-31 in the McArthur River Field "G Zone" pursuant to Rule 5, Conservation Order No. 80. The proposed completion of the well will result in additional recovery of Tyonek Production. Your approval of this request is appreciated. If you require additional information, please contact Dan Thomas at 907-263-7624, or Hal Martin at 907-263-7675. Very truly yours, Daniel B. Thomas Enclosures M31 Subject: M31 Date: Mon, 19 Jul 1999 16:13:04-0700 From: "Thomas, Daniel B" <thomasd~unocal.com> To: "Wondzell, B lair E" <B lair_Wondzell~admin, stat¢.ak.us> Blair- Just a quick note to confirm our conversation of this morning. The application for M31 is intended to request authorization from your office for the recompletion of the M31 well with a lateral drill. Unocal expects to produce from the currently existing perforations and the lateral whipstock. Thanks for your call and the opportunity to clear up this ambiguity. If I can be of further help please let me know. Dan Dan Thomas Unocal Corporation Land Advisor Telephone: 907-263-7624 Fax: 907-263-7698 E-Mail: thomasd@unocal.com Dan Thomas Unocal Corporation Land Advisor Telephone: 907-263-7624 Fax: 907-263-7698 E-Mail: thomasd@unocal.com 1 ~el "7lOll/CIO "/."10 STATE OF ALASKA ALASKA-.,IL AND GAS CONSERVATIO -,COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill: Redrill: X lb. Type of well Exploratory: Stratigraphic Test: Development Oil: X Re-Entry: Deepen: Service: Developement Gas: Single Zone: Multiple Zone: X 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool UNOCAL 160' RKB feet McAuthur River Field 3. Address 6. Property Designation G-Zone/Hemlock P.O. Box 19-0247 Anchorage, AK. 99519-0247 ADL-18730 4. Location of well at surface Leg B1 Slot # 12 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 970' FNL, 522' FWL, Sec. 33 9N-13W-SM Trading Bay Unit At top of productive interval 8. Well number ~ Number U62-9269 3,198' FSL, 2,254' FWL, Sec 28 9 N-13W0-SM M-31 /~ ~ At total depth 9. Approximate spud date Amount $200,000 4,047' FSL, 1,984 FWL, Sec 28 9N-13W-SM 6/15/99 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1233 feet 500 feet 3840 11,230'/8,873' MD &' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: ~ feet Maximum hole angle: 93 Maximum surface 1,931 psig At total depth ('rVD) 2800 psig 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) 3.75 2-7/8" 6.4 L-80 STL None--slotted liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 12,018 feet Plugs (measured) true vertical 9,207 feet 0 ! ?' ! ;' ,' Effective depth: measured 12,018 feet Junk (measured) true vertical 9,207 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1345' 16" 2,030 SX 1,345' Surface 3,722' 13-3/8" 1,600 SX 3,722' !?~i.. ~ ,..~,___., Intermediate Production 9,927' 9-5/8" 1,650 SX 9,927' Liner 1,440' 7" 385 SX 11,188' ,..i ~j L ('' ¢'~ Perforation depth: measured true vertical ~A,J~?~ 01~ & Gas 60n8, 20. Attachments: Filing fee: X Property Plat: X BOP Sketch: X Diverter Sketch: Drillingf~Jf~l"~CfP..'X Drilling fluid program: X Time vs. depth plot: X Refraction analysis: Seabed report: 20 AAC 25.050 requirements: 21.1 herby certify that the foregoing is true and~~~,~correct~ ~ "'~'\'t° thj; best~ of my knowledge: ~//[¢//¢ Signed: ,-M,'; ....... ..2.~-F~, Dan Williamso~r~;'~t~ Ddlling Manager Date: .- - Commission Use Only PermitNumber 1APl number I Approval e/,/ ¢¢1Seecoverletter ~',-.. ~::~ 50- ,~'_~'~R' '" ,2. ~ ~ ~,~'" ~ dat__ ,~ ~.,., for other requirements Conditions of approval Samples required: [ ] Yes j~ No Mud Icg required: [ ] Yes [~ No Hydrogen sulfide measures [ ] Yes lJ~ No Directional survey required j~ Yes [ ] No Required working pressure for DOPE [ ]2M; [~3M; [ ] 5M; [ ] 10M; [ ] 15M Other: ORIGINAL SIGNED-BY by order of.~ ~.~.~-,~, Approved by i~m_k__,-,.~_ _~ ~H_-_'_- ...... Commissioner the Commission Date: --'" Form 10-401 Rev. 12-1-85 Submit in triplicate Unocal Alaska Business Uni, Steelhead Platform Well # M-31RD AFE # 134609 Prepared by: Mtichell Damm Date:3/29/98 Revision #1 Estimate to drill short radius lateral with coiled tubing. No. Preliminary Procedure Prep tubing and casing for redrill 1 Cleanout tubing with coiled tubing 2 Run underreamer and cleanout casing 3 Run slickline casing caliper Set whipstock and mill window 1 Run whipstock on e-line 2 Mill window with coiled tubing unit. Prep rig for Redrills (Separate AFE will be prepared) 1 Activate Steelhead rig. 2 Install solids control equipment. 3 Skid rig from previous well Drill and Complete Short Radius Lateral 1 RU 2" coiled tubing drilling unit and equipment 2 Test tree and BOPE 3 MU BHA 4 RIHwithBHA. 5 Drill 10 ft. 6 Perform LOT 7 Drill 3-3/4" hole. (75 ft/day) 8 Circulate and condition hole 9 POOH with BHA. 10 LD BHA. Run 2-7/8" Predrill Liner 11 RU casing crews for liner 12 Change casing rams and test BOPE 13 RIH with liner. 14 Continue to RIH with liner on coiled tubing. 15 Circulate and condition hole 16 Drop liner off on bottom by releaseing running tool. 17 POOH with setting tool 18 ND BOPE. 19 Turn well over to Production. 20 RD coiled tubing unit and associated equipment M-31RD Coil RD Cost Est1 .xls Page 1 of 1 6/'1/99 UNOCAL~ 10,400 10,500 Steelhead M-31 Coiled Tubing Redrill Depth Versus Time AFE -- -- _ ~Actual Optimum _ _ _ 10,600 10,700 10,800 10,900 ~1,000 11,100 11,200 11,300 11,400 11,500 11,600 M-3~ ~D Coil RD Cost Est~ 8 9 10 11 12 13 14 15 16 17 18 19 20 21 Time (Days) 6/1/99/2:22 PM 22 UNOCAL ) Steelh~d Platform Well # 31 Completed: 7/15/94 RKB = 75.15' Rig Floor to TBG Hanger TOL ~ 9,748' 6" open hole TD = 12,018' MD 23° ~ 1,800'; 58° ~ 10,400'; 89° ~ 11,255' Casing and Tubing Detail SIZE WT GRADE CONN ID MD TOP MD BTM. 16" 75 K-55 Buttress 15.124 Surf. 1,345' 13-3/8" 68,61 K-55 Buttress Surf. 3,722' 9-5/8" 47 N-80 Buttress 8.835 Surf. 9,927' 7" 29 L-80 Buttress 6.184 9,748' 11,188' Tubing: 4-1/2" 12.6 L-80 AB Mod- 3.958 Surf' 9,755' Buttress Jewelry NO Depth ID Item 1 40' 4.00" 2 462' 3.812" 3 1,754' 3.833" 3,125' 3.833" 3,763' 3.833" 4,402' 3.833" 5,039' 3.833" 5,665' 3.833" 6,310' 3.833" 6,951' 3.833" 7,588' 3.833" 8,255' 3.833" 8,901' 3.833" 9,641' 3.833" 9,710' 3.875" 9,712' 4.75" 9,717' 4.75 9,726' 4.130" 9,744' 3.813 9,755' 4.00" FMC TC-1A-EN 16" TBG Hanger, 4-1/2" Mod Butt connection W/CIW type H BPV profile Camco 4.5" TRDP-4AO SCSSSV flapper type, (3.812" X-profile) # 1 4-1/2" Camco MMG GLM with 1-1/2" Valve 4-1/2" Camco MMG GLM with 1-1/2" Valve #2 #3 #4 #5 #6 #7 #8 #9 # 10 #11 # 12 4-1/2" Camco MMG 4-1/2' Camco MMG 4-1/2" Camco MMG 4-1/2" Camco MMG 4-1/2" Camco MMG 4-1/2" Camco MMG 4-1/2" Camco MMG GLM with 1-1/2" Valve GLM with 1-1/2" Valve GLM with 1-1/2" Valve GLM with 1-1/2" Valve GLM with 1-1/2" Valve GLM with 1-1/2" Valve GLM with 1-1/2" Valve 4-1/2" Camco MMG GLM with 1-1/2" Valve 4-1/2" Camco MMG GLM with 1-1/2" Valve 4-1/2" Camco MMG GLM with 1-1/2" Valve Baker GBH locator seal assembly (L = 18.94') Baker 96A4-60 SC-1LR Retrievable Packer Baker seal-bore extension (L = 9.36") Baker knockout isolation valve Baker X Nipple Baker 1/2 mule shoe Fish/Fill Information: A. Tag Fill @ 10,455' 2/11/98 Perforations Date Zone Top BTM Comments 8-27-94/3-19-98 G-1 9,935' 9,995' 3-3/8" HC 3-19-98 G-1 9,988' 9,998' 2-7/8" HC 3-19-98 G-2 10,027' 10,077' 2-7/8" HC 8-26-94 G-2 10,045' 10,075' 3-3/8" HC 3-19-98 G-2 10,085' 10,095' 2-7/8" HC 3-19-98 G-3 10,146' 10,216' 2-7/8" HC 8-25-94 G-3 10,156' 10,216' 3-3/8" HC 3-19-98 G-4 10,250' 10,310' 2-7/8" HC 8-24-94 G-4 10,251' 10,305' 3-3/8" HC 3-19-98 G-5 10,408' 10,418' 2-7/8" HC 8-23-94 G-5 104,16' 10,476' 3-3/8" HC 8-22-94 LG-5 10,508' 10,548' 2-7/8" HC 6 spf, 2-7/8" HC 6 spf/60 deg 6 spf/60 deg 6 spf/60 deg 6 spf 6 spf/60 deg 6 spf/60 deg 6 spf 6 spf/60 deg 6 spf 6 spf/60 deg 6 spf 4 spf M-31 7-15-94.doc REVISED: 3/29/99 DRAWN BY: MWD UNOCAL RKB = 75.15' Rig Floor to TBG Hanger t~ TOL ~ 9,748' 6" open Steelh'~d Platform Well # M-31 Proposed Casing and Tubing Detail SIZE WT GRADE CONN 1D MD TOP MD BTM. 16" 75 K-55 Buttress 15.124 Surf. 1,345' 13-3/8" 68,61 K-55 Buttress Surf. 3,722' 9-5/8" 47 N-80 Buttress 8.835 Surf. 9,927' 7" 29 L-80 Buttress 6.184 9,748' 11,188' Tubing: 4-1/2" 12.6 L-80 AB Mod- 3.958 Surf 9,755' Buttress Jewelry NO Depth ID Item I 40' 4.00" 2 462' 3.812" 3 1,754' 3.833" 3,125' 3.833" 3,763' 3.833" 4,402' 3.833" 5,039' 3.833" 5,665' 3.833" 6,310' 3.833" 6,951' 3.833" 7,588' 3.833" 8,255' 3.833" 8,901' 3.833" 9,641' 3.833" 9,710' 3.875" 9,712' 4.75" 9,717' 4.75 9,726' 4.130" 9,744' 3.813 9,755' 4.00" FMC TC-1A-EN 16" TBG Hanger, 4-1/2" Mod Butt connection W/CIW type H BPV profde Camco 4.5" TRDP-4AO SCSSSV flapper type, (3.812" X-profile) # 1 4-1/2" Camco MMG GLM with 1-1/2" Valve # 2 4-1/2" Camco MMG GLM with 1-1/2" Valve # 3 4-1/2" Camco MMG GLM with 1-1/2" Valve # 4 4-1/2" Camco MMG GLM with 1-1/2" Valve # 5 4-1/2" Camco MMG GLM with 1-1/2" VaNe # 6 4-1/2" Camco MMG GLM with 1-1/2" Valve # 7 4-1/2" Camco MMG GLM with 1-1/2" Valve # 8 4-1/2" Camco MMG GLM with 1-1/2" Valve # 9 4-1/2" Camco MMG GLM with 1-1/2" Valve # 10 4-1/2" Camco MMG GLM with 1-1/2" VaNe # 11 4-1/2" Camco MMG GLM with 1-1/2" Valve # 12 4-1/2" Camco MMG GLM with 1-1/2" Valve Baker GBH locator seal assembly (L = 18.94') Baker 96A4-60 SC-1LR Retrievable Packer Baker seal-bore extension (L = 9.36") Baker knockout isolation valve Baker X Nipple Baker 1/2 mule shoe Fish/Fill Information: A. Tag Fill ~ 10,455' 2/11/98 Perforations Date Zone Top BTM Comments 8-27-94/3-19-98 G-1 3-19-98 G-1 3-19-98 G-2 8-26-94 G-2 3-19-98 G-2 3-19-98 G-3 8-25-94 G-3 3-19-98 G-4 8-24-94 G-4 3-19-98 G-5 8-23-94 G-5 8-22-94 LG-5 9,935' 9,988' 10 ~027' 10 ~045' 10.085' 10.146' 10,156' 10.250' 10,251' 10,408' 104,16' 10,508' 9,995' 3-3/8" HC 6 spf, 2-7/8" HC 6 spf/60 deg 9,998' 2-7/8" HC 6 spf/60 de# 10,077' 2-7/8" HC 6 spf/60 deg 10,075' 3-3/8" HC 6 spf 10,095' 2-7/8" HC 6 spf/60 deg 10,216' 2-7/8" HC 6 spf/60 deg 10,216' 3-3/8" HC 6 spf 10,310' 2-7/8" HC 6 spf/60 deg 10,305' 3-3/8" HC 6 spf 10,418' 2-7/8" HC 6 spf/60 deg 10,476' 3-3/8" HC 6 spf 10,548' 2-7/8" HC 4 spf M-31 Proposed.doc DRAWN BY: MWD UNOCAL/DOWELL CTD RIG PIPING ,, , HAND CHOKE VENT LINE 2" 1502 5K PSi CHOKE LINE KILL AND CHOKE LINE VALVES TO BE FLANGED TO FLOW CROSS HAND CHOKE 2" 1502 HIGH PRESSURE LINES S , , RELiE. F.vAL.~E...LiN.E...' P.OPOi~ ~"'""~ BLEEDER LINE ~..~~ "L" PUMP ]~ ~ "G" PUMP D/SC.PUMP ~~ ~ ~ 7500PSI ;~ ; 10,O00PIS BHI CHOKE MANIFLOD READOUT LEGEND [] HIGH PSI LINE [] LOW PSI CHARGE [] LOW PSI LINE VALVE ® ~ CAP HAND CHOKE ~ CHECK VALVE --~) PSI GAUGE {~ C PUMP '~ MICRO MOTION ~ HO~ AGITATOR OAL Of Stack Up = 37.416' Wellhead to Rig Floor = 35.5' 6.735" ID 5M Lubricator 8.0' BX155 x CO62 Thread X-Over 4 1/16" Annular 0.583' 2.083' CO62 Nut x BX155 X-Over 4 1/16" 10M TOT Quad BOPE 6.0' 1.50' 2" Blind]Shear 2" Blind]Shear 2" Pipe Rams 2" Slip Rams BX 155 x BX 155 StuddedF]ow Tee 0.75' 2" ID Outlets BX 155 x BX 155 Riser Spool 17.0' R~39 x BX 155X*Over Spool 1.50' ,( D26 CT RD SPERRY-SUN DRILLING SERVICES PROPOSAL Customer ...: UNOCAL Platform ...: 1 SlotNVell ..: Bl12/M-31 MEASURED ANGLE DIRECTION TVD NORTHINGS DEPTH DEG DEG FEET EASTINGS VERTICAL DOG TOOL FEET SECTION LEG FACE 10,230.00 54.61 32.03 8,854.03 4,150.79 N 1,722.68 E 4,150.79 - - 10,250.00 58.95 27.08 8,864.99 4,165.35 N 1,730.91 E 4,165.35 30.0 315.0 10,275.00 64.39 21.20 8,876.86 4,185.42 N 1,739.87 E 4,185.42 30.0 315.0 10,300.00 71.89 21.20 8,886.16 4,207.04 N 1,748.26 E 4,207.04 30.0 - 10,325.00 79.39 21.20 8,892.36 4,229.60 N 1,757.01 E 4,229.60 30.0 - 10,360.00 89.89 21.20 8,895.62 4,262.04 N 1,769.59 E 4,262.04 30.0 - 10,400.00 89.89 9.20 8,895.70 4,300.57 N 1,780.06 E 4,300.57 30.0 270.0 tl,000.00 92.16 321.24 8,884.31 4,863.83 N 1,631.59 E 4,863.83 8.0 273.0 11,100.00 92.69 313.26 8,880.08 4,937.13 N 1,563.82 E 4,937.13 8.0 274.0 11,200.00 93.22 305.26 8,874.91 5,000.28 N 1,486.56 E 5,000.28 8.0 274.0 11,230.00 93.39 302.86 8,873.18 5,017.06 N 1,461.75 E 5,017.06 8.0 274.0 THE DOGLEG SEVERITY IS IN DEGREES PER 100.00 FEET. N/E COORDINATE VALUES GIVEN RELATIVE TO WELL SYSTEM REFERENCE POINT. TVD COORDINATE VALUES GIVEN RELATIVE TO WELL SYSTEM REFERENCE POINT. THE VERTICAL SECTION ORIGIN IS WELL HEAD. THE VERTICAL SECTION WAS COMPUTED ALONG 0.00 (TRUE). CALCULATION METHOD: MINIMUM CURVATURE. Trading Bay Unit Steelh~.ead P~aff°rm Well M 3t CT Lateral PROPERTY PLAT KING 2O ADL-17594 Unocal Forcenergy 21 M-Si M-31 -~.~/ Lateral ~/ 29 I / 88 GRAYLING ~ STEELHEAD ~ ADL-J 8729 Unocal Forcenergy 33 T9N - TSN - R13W R13W Trading l Bay Unit Boundary ADL-18772 Unocal a7 ADL-18730 Unocal Forcenergy 34 o 1,ooo SCALE IN FEET ADL-17579 Unocal ISO 9001 Certified UNOCAL STEELHEAD PLATFORM WELL M-31 DEPTH INTERVAL WHIPSTOCK @ 10230' MD DRILL TO 11230' MD MUD TYPE FLO-PRO MUD ADDITIVES FLO-VIS, KCL, FLOTROL, CAUSTIC SODA, NACL, LO-WATE, {LUBETEX} POTENTIAL PROBLEMS HOLE CLEANING, HIGH TORQUE, DIFFERENTIAL STICKING, LOST CIRCULATION, GAS KICKS COST PER BARREL $26.75**-46.75 ESTIMATED ** Does not include lubricant or fluid loss control additive TM9913 (6/99) . . o o , o , o TREATMENTS/PROCEDURES Build mud with fresh water, FIo-Vis, KCL, and caustic soda and Greencide 25G. Displace well to new mud after setting whipstock. Higher hole angles increase the probability of cuttings bed formation. Monitor LSRV of the drilling fluid with a Brookfield Viscometer. Maintain a 1 minute LSRV of > 50,000 with FIo-Vis additions. Control solids by running the finest shaker screen size possible. Run centrifuge for removal of fine solids... Keep mud weights as Iow as possible. Mud weights should range from 8.55 ppg to 8.75 ppg. Note: Higher mud weights may be required. Report drill solids analysis on mud check sheet. Report hydraulics calculations on mud check sheet. Lo-Ware should be used as needed for a bridging agent to control seepage losses. NOTE: Maximum recommended Lo-Wate concentration for discharge purposes is 75 ppb. Flotrol should be used as needed for fluid loss control. NOTE: Maximum recommended Flotrol concentration for discharge purposes is 3 ppb. If torque is a problem. Lubetex should be added. Monitor decrease in torque with each % addition of Lubetex. NOTE: Maximum recommended KCL concentration for discharge purposes is 3% (10.33 ppb) NOTE: DISCHARGE IS GENERALLY NOT PERMISSABLE IF A LUBRICANT IS ADDED TO THE SYSTEM! TM9913 (6/99) 3 314" Hole Mud Formulation Fresh Water FIo-Vis 2.75 ppb KCL 10.33 ppb Caustic Soda .25ppb Grencide 25G 0.04 ppb Lo-Wate As needed for seepage losses Flotrol As needed for fluid loss control Lubetex As needed for torque reduction ANTICIPATED MUD PROPERTIES Mud Density 8.55 PPG LSRV 1 minute 50,000 cps Plastic Viscosity 8- 10 cps Yield Point 40 - 45 #/100ft2 Gels 25/27/30 #/100ff2 APl Fluid Loss 6 - 8 cc pH 8.5 -9.5 MBT <2.5 ppb Drilled Solids <15ppb Note: This mud program is a guideline only. Hole conditions should dictate actual mud properties. DO NOT EXCEED Recommended M.A.C. of products or use products not approved in the old discharge permit. TM9913 3 (6/99) UNOCAL STEELHEAD PLATFORM WELL M - 31 ESTIMATED FLUID COST Estimated drilling fluid cost based on 8.55 mud weights Estimated cost with 3% Lubetex Estimated cost for polymer breaker (per bbl) $17,066 $30,716 $15.75 TM9913 (6/99) ....... VENDOR NO. DATE CHECK NO. ..... 1031548 16-JUN-9S 2003569 DATE INvoICE/cREDIT MEMo NO. vOuCHER NO. GROSS - DiscOUNT "NET .... ..... 15-JUN-99 DRILLPERMITM31 06993000247 100.00 100.00 ! FORM 4-2B181 (REV, 11-95) PRINTED IN U.S.A. I TOTAL I~' 100. O0 100. O0 ,"~..~',..,~ ~ ~ ... [ ,.. : ~ ,, ..~ : , ,I CITIBANK DELAWARE 62-20 A Subsidiary of Citicorp 311 ONE PENN'S WAY NEW CASTLE, DE 19720 Union Oil Company of California Accounts Payable Field Disbursing UNOCAL,z ) P~ One Hundred Dollars And 00 ****************************** 2003569 To the order of STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DR ANCHORAGE, AK 99501 Date CheckAmount V 16-JUN-99 *****100.00 Void after six months from above date. WELL PERMIT CHECKLIST COMPANY ~/',/D/~.,,,~ d_.. WELL NAME ,/~- ,~ / ~ .Z' PROGRAM: exp dev ,~ redrll ~ serv ~ wellbore seg ann. disposal para req ~ INIT CLASS ---~/~p~,' ~ --,~,'/' GEOL AREA ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING APPR DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~r,,~r~',, psig. 27. Choke manifold complies w/APl RP-53 ~'~y ~) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... UNIT# /~__ ~'O ON/OFF SHORE N Y N Y N Y N Y N Y N Y N Y N Y N Y N N (~_~N Y N C.~N (~N ,~(~N N ANNULAR DISPOSAL APPR DATE 31. Data presented on potential overpressure zones ....... 'Y''~'/.~p_~x,~~J,~ 32. Seismic analysis of shallow gas zones ............. Y N 33. Seabed condition survey (if off-shore) ............. y~]YY iY N v 34. Contact name/phone for weekly progress reports [exploratory 35. With proper cementing recor~')plan (A) will contain waste i/[~_ suitab,~,e receiving.~j~e; ....... Y U (B) will not contaj:~fiate fresh~ter; or c, aus'~rilling waste... Y N to surfac.~e,;/ // / ,/ (C) will n/oHmpair mecha)zical i~rity of t~ll used for disposal; Y N (D) will/not damage pro u¢_.~' formation or impa~--~CTec~a-- Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N co,v,,,,,,ss,o,,,: JDH ~ Comments/Instructions: c:\msoffice\wordian\diana\checklist Well # M-3tRD UNOCAL~ Comple,i,m Da,e 8/16/91 Rig Floor to TI](; Hanger Cas~r~g and Tnbh~g Detail SIZE WT GRADE CONN tD MD MD ~ 16" 75 K-55 Buttress 15.124 Surf. 1,345' ~ 13-3/8" 68,61 K-55 B~ttress SurL 3,722' 2 )-./8 47 N-80 Buttress 8.835 Surf. 9,927' 7" Liner 29 L-80 Buttress 6.184 9,748' 11,188' ~ 2-7/8" Liner 6.4 L-80 Battress 2.441 10,184' 10,306' ~~ Tnb[ng:predrilled2-7/8" LNR 6.4 L-80 AB-STI. 2.337 10,307' 11,265' 4-1/2" 12.6 l,-80 AB Mod-BTC 3.958 Surff 9,131' 4-U2" 12.6 L-80 AB Mod-B FC SCC 3.958 9131' %597' ~ NO Depth H) Item ~. I 75.15' . .83 FMC TC-B-EC-ENS 16 3/4" TBG Ilanger, 4-1/2" Mod ~2 4 BTC btm x 4 ~" BT( top~(1W '11' BPV ~ 2 2.992" 3-1/2" Camco SPO-I BK-2 I,a~ch SPM ~ith GLVs ¢t ~ 8282'~ 7886', 7403', 682 l', 6240', 5387', 3815', 1937' ~ Note: Ran m3der-sized 3 V2" SPMs due to csg patch 7 > 155', with 3 ~" x 4 %" X-o;ers above/belo~, phis they have 10' x 4 %" pup joints above/below 3 9597' 3.958" 4 ~" t2.6 ppf L-80 imp. BTC tubing Note: Bottom 15 jts are spec. clear, cplg, rest are standard 4 9675' N/A Centrilift ESP 17t hp 5.62" mtr,..13 tandem seals, 4.00" ~/ tandem pumps (4 %" (annon clamps) 5 ,712 4.75 Baker 96A4-60 S(-I LR Retrievable Packer 93" ~ 6 9,717' 4.75 Baker seal-bore extension {1, .~ 6 ) 9 7 9,726' 4.130" Baker knockom isolation xalve 9 9,755' 4.00" Baker ~ muleshoe ~) 155~-175' 3.84F' ltomco Casing Patch (1/8" wall thickness) ]qsh/FHl lnlbrmaOon: Perf~nmtions ~ ~ ~ Commems 8-27-94/3-19-98 G-I 9~935' 9,995* 3-3/8" HC 6 spL 2-7/8" HC 6 spff 60 deg 3-19-98 G-l 9,988' 9 998' 2-7/8" HC 6 spt7 60 deg 3-19-98 G-2 I(k027' 10,07T 2-7/8" HC 6 spff 60 deg ~Yll)I 8~26-94 G-2 10,045' 10,075~ 3-3/8" HC 6 spf 3-19-98 (3-2 10,085' 10,095' 2-7/8" tiC 6 spU 60 deg 3-19-98 G-3 10~146' 10,216' 2-7/8" llC 6 spt7 60 deg 8-25-94 G-3 10,t56' 10.216' 3-3/8" H( 6 spf 34%98 G4 l{L250' 10. 10 2-7/8" HC 6 spff 60 deg 8-24-94 G-4 10~251' 10,305' -./8 H( 6 spf 3-19-98 G-5 10,408' 10,4t8' 2-7/8" H( 6 spff 60 deg 8-23-94 G~5 104,16' I~k476' ~-~/8 HC 6 spf 8-22-94 LG-5 10~508' 10,548' 2-7/8" HC 4 spf RKB = 75.15' TOL ¢: 9~748' lop I0.184' CFM TD = 12,0t8' SteeI~head hati;~rm We~} # .M-31 RD Comp{et[o~ [)ate 8/16/{}t RKO1 = 75.15' Rig FIm~r to I'BG ttanT, er Casing and Tubi~g De~a~l GRADE CONN ID M D M D TOP 8TM. Stedhead ~r~ Rig Floor to TBG Hanger Top of 2-7/8" Liner (di l 0.184' CTN4 9,748' 23° (~ 1,8@@'; 58° ~) 10,40@'; 89° ~4} 11,255' SIZE $¥T GRADE CONN ID ~ D MD TOP BTI~. 16" 75 13-3/8" 68,61 K~55 9-5/8' 47 7" Liner 29 2-7/8" Liner 6.4 L-80 2-7/8" LNR 6~4 L-80 predril}ed T=bing: 4-1/2" 12.6 L-gO 4-1/2" 12.6 Buttress 15.124 Sn rL 1,345' Buttress SarL 3,722' Buttress 8.835 Surf. 9,927' Buttress 6.184 9~748~ 11~I88' Buttress 2.441 10,184' 10,306' AB-STL 2.337 10,307' 11,265' AB ~Mod~BTC 3.958 St~rP 9,131 ' A[g PVlod-BTC SCC 3.958 9131' 9,597' NO Depth ID JeWelry Item 1 75.15' 3.833' 2 2.992' 3 9597' 3.958" 4 9675' N/A 5 9,712' 4~75" 6 9,717~ 4.75 7 9~726~ 4A3@' 8 9,744 3~813 9 9,755' 4.00" FMC TC-B-EC~ENS 16 3/4" TBG Hanger, 4-1/2" N{od BTC btm x 4 95" BTC top, C1¥¥ ~H' BPV 3-1/2" Camco SFO-1 BK-2 Latch SPrvl with GLVs ~} 8282', 7886', 7403', 6821', 6240', 5387', 3815', 1937' Note: Ran under-sized 3 95" SPMs due to csg patch ¢~} 155', with 3 %" x 4 Vz" X-overs above/below, pins they have I0~ x 4 ~" pup joints above/be[ow 4 Pi" 12.6 ppf L-80 imp. BTC tubing Note: Bottom I5 its are spec. clear, cplg, rest are standard Ceatrilift ESP 171 h p 5.62" mtr, 5.13" tandem seals, 4.00" tandem pumps (4 55' Cannon clamps) Baker 96A4-60 SC-ILR Retrievable Packer Baker seal-bore extension (L = 936'} Baker knockout isolation valve Baker k5 mt~leshoe Ran 3.80" GR to top o{'2 7/g" liner ~f! 10. IS4' on 3/29/0t Perforations 8-27-94/3-19-9g G~I 9,935 3-19-98 O-1 9,988' 9,998' 2-7/8" 3~i9~98 8-26-94 3-19-98 3-19-98 0-3 10~146~ 10,216~ 2-7/8" 8-25-94 O-3 3-19-98 G-4 1 8-24-94 3-19-98 8~23-94 O-5 104~16' t0~476~ 3-3/8" N4-31 Schematic 8-16-01 .doc DR.A%~N BY: JFB Date: 1 0/01/01