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199-097
• • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 0 4 2017 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a.Well Status: Oil ❑ Gas SPLUG ❑ Other ❑ Abandoned ❑✓ • Suspended 1b.Well -3 GCrN 20MC 25.105 20AAC 25.110 Development Em i Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL❑ No. of Completions: _ Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp.,or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC . Aband.: 7/23/2017 , 199-097/317-241 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive, Suite 1400,Anchorage,AK 99503 November 15, 1999 50-733-20462-01-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 969' FNL, 527'FWL, Sec 33,T9N, R13W, SM,AK January 16,2000 TBU M-32RD Top of Productive Interval: 9. Ref Elevations: KB: 160' 17 Field1//F ool(s,: 14.444,r_ m I) ` N/A GL: BF: 72' �� cAr Poole, River Id 1 4. Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: / 110'FSL,2382'FEL, Sec 21,T9N, R13W, SM,AK 7,209'MD/6,846'TVD ADL018730 , 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 214171 y- 2499504 Zone- 4 13,835'MD/9,660'TVD N/A TPI: x- y- Zone- 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 216648 y- 2505955 Zone- 4 N/A N/A 5. Directional or Inclination Survey: Yes U (attached) No E 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) 7,209'/6,846' 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 AA-32- Raz /O o'7 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 26" K-55 Surface 981' Surface 980' Driven 16" 75# K-55 Surface 1,347' Surface 1,346' 22" 1933 sx 13-3/8" 61# L-80 Surface 3,767' Surface 3,766' 17-1/2" 2244 sx 9-5/8" 53.5# L-80 Surface 7,209'(TOW) Surface 6,846' 12-1/4" 2607 sx 24. Open to production or injection'? Yes ❑ No ❑✓ 25.TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number; Date Perfd): N/A PSANDOwoo 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. .COMPLCTIOi- .- DATE Was hydraulic fracturing used during completion? Yes ❑ No ❑✓ ,scAtitiED JAN1,I2�f D Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH 0 20 I� VERIFIED 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 ....0. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 24-Hour Rate i. Form 10-407 Revised 5/2017 048 ` J /`-7 a /2 2`l'f 7CONTINUED ON PAGE 2/f/KittDMS t OCT - 5 20 ubmit ORIGINIAL onl & 28.CORE DATA Conventional Core(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. N/A Formation at total depth: 31. List of Attachments: Schematic, Decomplete Reports Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Paul Mazzolini Contact Name: Cody Dinger Authorized Title: Drilling Manager Contact Email: Cdinger(C hIICOrp.00111 Authorized ^ yJ/JD Contact Phone: 777.8389 Signature: f/q,w� / '/ Date: • °31?•a/7 ( INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection, Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 19: Report the Division of Oil&Gas/Division of Mining Land and Water: Plan of Operations(LO/Region YY-123), Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only • • 11 Trading Bay Unit/Steehead Platform Well #: M-32RD Hi!corn Alaska.LLC Abandoned Schematic Abandoned: 7/23/17 RKB=75.15'Rig Floor to TBG Head Casing&Tubing Detail Size Type Wt Grade Thrd ID Top Btm Hole 26" Conductor Surf 981' Driven 4 16" Surf Csg 75 K-55 BTC 15.1 Surf 1,347' 22" C; 13-3/8" Csg 61 K-55 BTC 12.5 Surf 3,767' 17.5" 9-5/8" Prod Csg 54 L-80 BTC 8.535 Surf TOW 12.25" r 7" Liner 29 L-80 Butt&KC 6.184 9,301' 10,731' 8-1/2" •' 1 4-1/2" Slotted Liner 12.6 L-80 IBmod AB 3.958 10,694' 13,835' 6" r A .i JEWELRY DETAIL ys _'t NO. Depth Depth ID Item ,r TOW@7,209 (MD) (ND) BOW@ 7,226 1 7,235' +6,873' CIBP set for whipstock '" _y CIBP @ 7,235 ' ' .4".:41)..." W" ;,`,./A,r''..,'; i. '. roc @ 7,286 /tr * st:, t:",y 0 '' / 4 '"="4". t'„ - � 'C 6a 8,001' 7,460' Neo Plug+27'cement on top 6b 8,038' 7,488' 560'Section of Cut Pipe TOC @ If I i« ' „ "' 1 C. 7a 8,690' 7,990' N/A Neo Plug 53'of cmt+12'sand 8,001 _ .'Ba +35'cmt 7b 8,720' 8,013' N/A Neo Plug 7c 8, ' , ' Plug w/8140 "i! F5A 7d 9,064890' 88,275142' N/AN/A Plug w/ 'cementofcement(TOC 8983') ' 6b TTS umbrella plug w/cement on 4 8 9,284' 8,440' N/A 7 top TOC @ .,t IY 9 9,572' 8,641' N/A EZSV Cement Retainer 8,596'ELM TOC@ e � wL ° F11C 8,63TELM rs+ - 7a xi Ca 7b (ir F 13 B roc @ Fl 8,830 ELM , '�k -e. ,,.) _ ,.7G roc@ ,- F15B 8,983 ELMTi;.` t 1 S. www. Fl SC 9,015 ELM , •}*, 4 .,.+ - 7d e3i F16 TOC @ . + 1 9,172'ELM .�,fif�, ,. �• t gyp.,�y 7 ',1',....4... G 01 7. :.,--,,.,,,-.4 TOC @ �� kA-r .J� �' a �. 9,252'SLM» 8 Collapse Csg csg window:— .. 9,299'(+1-) (u?9392' , Integrity Breach 5'.. G05 9245'to 9515' . Top of fill @ 9522' 11-16-09 i^ 'p Top of Cmt @ 9547' ..0,"; '9 YA *44174,...., , 4 Milled BP" `,.3 _ G-1,2 ,t4'4i' _., i. G-4,5 itR+.„„',.,:.,,-L..,..0.,4.,,,, . 4 B-1 2Collapse in 4-1/2”Slotted o Liner@ 10825' A' N§ Updated By CJD 10/3/17 TD=13,835'MD/9667'TVD • • Hilcorp Energy Company Composite Report Well Name: MRF M-32RD2 Field: McArthur River Field County/State: CIO,Alaska (LAT/LONG): ?Nation(RKB): API#: Spud Date: Job Name: 1712187P M-32RD2 PreDrill Contractor AFE#: AFE$: /IICLIit d.:te ::. :::,, <:G"�`„.....�: .,;�.,,;�..........:.:...... Q .'�►lIY111i �:<:;:.[:�::::." ...:... :':......... ...... ....,.x,....... .::>::.�t'aka:...,,..��.y.?:C Y,L:::.,A,a.\»\,.:. ::.. .. .:.....:� :.:: l �:...o:::<.:v//:...... ..:.......:: .... 9',...M:::<:::.... ::.:::: 7/12/2017 Finish unhooking all service lines from upper wellbay.Pull up skirting around sub base. Remove handrails&moveable stairs in path of skid.Retracted diverter lines.Unplug rig power&hook up umbilical.Remove earthquake clamps&install guide plates.Install moving cylinders&hydraulic clamps.,Skid rig from M-06 to center deck.,Crane hatch covers from NW wellbay to NE wellbay.Crane all interconnect lines from NE wellbay to NW wellbay.Begin to move jacks from west side to east side. 7/13/2017 Cont Moving Grabbers To Drillers Side Of Rig,Cont Skidding Rig -Pull Upper Wellbay Hatch-Install Guard Rails- Center Up On M-32,Install&Tighten Earthquake Clamps-Install Hand Rails-Hooked Up Air And Water Lines-Hook Up Low Pressure Mud&SaltWater Rebuilt Stand Pipe Valve Installed Flow Line to Flow Line Trough,Well Pressure Tree=0,9 5/8 by 4 1/2 Annulus=650, 13 3/8 by 9 5/8 200,16 by 13 3/8 110,26 by 16 135-Pull Tree Cap-Rig Up Pollard Slick Line-Pressure Test Lubrication-Swab Valve Packing Leaking-Fix Same-Pressure Test Lubricator to 1,500psi,RIH With 3.60 Gage Ring To 7,020 slm(159'Below Packer,805'Above Tubing Tail)-Pick Back Up And Lost Hole to 6,945s1m(84'Below Packer,805'Above Tubing Tail-Trip Wire And Pick Up A 2.85 Gage Ring-RIH With Same And Tagged At 6945 slm-Trip Out With Wire-Close Swab,Hook Up High Pressure Mud Line To Rig-Rigged Up Lines In Wellhead Room For Circulating Well,Continue rigging up lines in wellhead room.Line up high pressure mud line to NW leg with production.Fluid pack all lines&test to 500/2500 psi.,Bullhead down tubing at 1 bpm,catching pressure at 5 bbls away.Continue pumping at 1 bpm,at 17 bbls away observed a pressure drop f/2050 psi to 1650 psi.Pumped 18.3 bbls away&observed pressure drop f/1950 psi to 1750 psi.Shut down pump at 1900 psi,check surface equipment&annulus pressures.Continue pumping to 20.4 bbls away we/2500 psi.Monitor then bleed off pressure.,Run a 2.85 gage ring, RIH and tagged at 7300 slm.Trip out with wire and close swab.Rig down slick Iine.,Rigging up e-line for tubing punch run.,M-32RD2 wellhead pressures 4-1/2X9-518=630psi,9- 5/8X13-3/8=200psi,13-318X16=110psi,16X26=135psi. 7/14/2017 Continue rig up of e-line.Pressure test lines to 250/2500 psi,good.,RIH with e-line to punch 4.5"tubing.Get on depth&shoot holes in the bottom of the 1st full joint above the packer f/6845'-6847'ELMD. Pressure up tubing to 500 psi,IA 150 psi.Confirm shots w(pressure equalize.Attempt to circulate,issue w/ pumps.TOH w/e-line&trouble shoot pump issue.,Line up&pump down the tubing taking returns from the IA to production Group Sep-Worked Rate Up to 4Bbl/min With A Slow Increase In Tubing Pressure From 450psi to a Final Press Of 900psi 465Bbl Pumped,Check Shut In Pressures While Rigging Down E Line Lubricatior-Bleed Down From 150psi To OPsi-Tubing&Annulus Dead-,Install Back Pressure Valve,Remove 18"Section From Stand Pipe-Work On Handrail Change In Sub Deck-Repair Hole In Flow Box,Check Hanger Void For Pressure-Nipple Down Production Tree-Dress Hanger For BOP Test- Function Lock Down Screws,Make up 16-3/4"X 20'riser to wellhead.Mobilize gray lock clamp to upper wellbay.Position upper 16-3/4"X 20'riser in upper wellbay.,Continue nipple up of BOPE.Continue to torque bolts on lower riser.Install gray lock clamp on hub connection between risers.Nipple up 16-3/4"5M X 16-3/4"10M DSA&single gate rams.Bolt up manual&HCR valves on mud cross.,M-32RD2 wellhead pressures 4-1/2X9-5/8=Opsi,9-5/8X13-318=155psi,13- 318X16=200psi,16X26=90psi,26x31=135. 7/15/2017 Nipple up BOPE.Make up manual&HCR valves on mud cross.Install mud cross on single gate.Observe obstruction for operation of double gate ram doors. Remove mud cross&single gate.Install 34"spacer spool&set mud cross with single gate.Pick up&install double gate rams.,Continue nipple up of BOPE. Install Koomey hydraulic lines to stack.Install air boot flange to annular. Bolt up Kill&Choke hoses to the valves on the mud cross.,Pick up&make up annular. Continue hooking up Koomey lines to BOPE.Install flow box cover.,Set flow riser.Energize accumulator unit&function BOPE.,Pick up test tools.Air up boots on flow riser.Fold Skate into place.Pick up&make up 4.5"test joints.Flood all lines with water for testing.Function test annular to condition new element.,Shell test BOP's to 250 psi,found leak from choke hose flange.Retighten&test again staging up pressure to 3200 psi.Found leak at top rams at the doors. Begin tightening doors.,M-32RD2 wellhead pressures 4-1/2X9-5/8=0psi,9-5/8X13-3/8=150psi,13-3/8X16=180psi,16X26=95psi,26X31=130. 7/16/2017 Attempt to shell test BOPE after tightening upper ram doors,still leaking.Open doors,changeout door seals,&tighten doors up.,Attempt to sheel test&door seals not leaking.Observe tail stem packings leaking from choke&kill HCR valves.Blow down stack.Change out stem packing seals.Pressure up again and still bleeding off.Close top rams,kill&choke NCR's valves with pressure still bleeding off.,Remove test sub from hanger&lay down with test joints.,Pull BPV& install TWC.Test blinds to 250/3500 psi for 5 minutes each,good test.,lnstall 4.5"test joint.Attempt to shell test,observe pressure drop&returns from IA. Determine that chemical injection port damaged causing communication.Confer with engineer¬ified AOGCC of plans to conduct rolling test on annular& �� upper 4-1/2"rams as per Sundry requirements.,Rig up&test choke manifold valves 1-10, 12,13,14;upper&lower IBOP;FOSV;dart vavle to 250/3500 psi �� for 5 minutes each charted.Perform accumulator test Initial System Pressure 2950 psi,After Closure 1100 psi,200 psi Attained in 50 seconds,&Full Pressure G Attained in 207 seconds. Nitrogen Bottles:8 averaged at 2460 psi.Test gas alarms,pit level gain/loss,&flow show.,Line up&perform rolling test on the annular to 250 psi @.176 bpm;increase to 3500 psi @.176 bpm for 5 minutes each.No leaks observed at annular. Did see leak from upper ram door seal on ODS.,Open upper ODS ram door.Clean,inspect&change out door seal.Could not find anything to cause leak.Make up ram door.Talk to BOP vendor& reference Cameron spec sheet to determine door bolts need to be torqued to 7331 fUlbs.,Wait on wrench to to tighten ram doors.SIMOPS Perform derrick inspection,install guard/softner on kelly hose,&housekeeping.,Torque bolts on all ram doors to 7331 ft/lbs per Cameron spec.'s.,Line up&perform rolling test on the 4-1/2"solid body upper rams to 250 psi @.176 bpm;increase to 3500 psi©.176 bpm for 5 minutes each,charted. No leaks observed at rams or any other part of BOPE.Rig down test equipment.,Pull TWC from hanger.,Rig up handling equipment to pull hanger to the rig floor. BOLDS.,Pull hanger&packer free at 235K PU.Line up to circulate through the gas buster.Close upper rams&circulate at 2-5 bpm,120-650 psi. Experiencing intermittent packing off around the packer.,M-32RD2 wellhead pressures 4-1/2X9-518=0psi,9-5/8X13-3/8=150psi,13-318X16=180psi, 16X26=95psi,26X31=130. • III . 7/17/2017 Continue circulating down the tubing taking returns through the choke manifold,ICP 2 bpm=240 psi,4 bpm=400 psi,6 bpm=600 psi.After pumping 190 bbls experience packing off around the hanger. Rig up high pressure hole from annulus to choke manifold.Continue circulating FCP 3 bpm=170 psi,4 bpm= 330 psi.Monitor well,static.,Pull hanger to the rig floor;PU 150K,SO 140K.Terminate control lines from hanger.Plug control line ports.Change out hanger yseals.Blow down circulating line.Rig up power tongs.Check torque on landing joints on the way in to land hanger.,Drain stack,land hanger&RILDS.,Install cf two way check.,Rig up 4.5"test joints&test equipment.Perform shell test to 250/3500 psi,good.,Test BOPE with 4-112"test joint to 250/3500 psi 5 minutes kb each test,charted.Test annular,upper 4-1/2"pipe rams,blind rams, HCRs kill/choke,manuals kill/choke,and kill line demco.Monitor IA while testing.Test witnessed by AOGCC Adam Earl. Blow down lines&rig down test equipment.,Make up landing joint,change out elevators to 4-1/2".Pull hanger to the rig floor, PU 150K.Lay down hanger&blow down lines.Monitor well,static.,TOH laying down 4-112",12.6#,L-80,TCII tubing from 7750'-5340'MD,PU 117K,pulled 456'of 1/4"&2010'of 3/8"control lines,recovered 79 stainless steel clamps.,TOH laying down 4-1/2",12.6#,L-80,TCII tubing from 5340'-2120'MD,PU 75K.,M-32RD2 wellhead pressures 4-1/2X9-5/8=0psi,9-5/8X13-3/8=160psi,13-3/8X16=180psi,16X26=95psi,26X31=130. 7/18/2017 TOH laying down 4-1/2",12.6#,L-80,TCII tubing from 2120'-410'MD.,TOH laying down 4-1/2",12.6#,L-80,TCII tubing from 410'to surface.Tubing full of Poly Plug Clear Gel from previous squeeze job.,Rig down handling equipment&send down to the top deck.Clean rig floor of Poly Plug.,Make up test tools& set test plug.Close blind rams for upper ram change.,Change out upper rams from 4.5"to 4"solid body rams.,Test upper rams&annular WI 4"test joint to 250 /3500 psi for 5 minutes,charted. Lay down 4"test joints&make up 5"test joints.Test lower 5"X7"VBR's with 5"test joints to 250/3500 psi for 5 minutes each,charted.,Lay down test equipment&pull test plug.Install 15"ID wear bushing, RILDS.,Test high pressure mud lines from mud pumps to top drive,to 3500 psi.One small leak observed at newly install pop off valve on mud pump.Union tightened&tested good.,Make up clean out assembly BHA 1:8-1/2"Bit. Casing Scraper,Bit Sub w/Float,Pup Joint, Upper Window Mill, 1 joint of 5"HWDP.,Repair Iron Roughneck.Hose for backup grabber failed.Made new hose &installed,tested good.,Continue picking up BHA 1, 14 joints of 5"HWDP&XO 4-1/2"IF X 4"HT38.Total length 482.48'MD.,TIH w/cleanout assembly N 482'-6000'MD,PU 156K,SO 148K.,M-32RD2 wellhead pressures-9-5/8=0psi,9-5/8X13-318=155psi,13-3/8X16=190psi, 16X26=105psi,26X31=130psi. 7/19/2017 TIH w/BHA 1 f/6000-6065'MD, PU 156K,SO 148K.Tagged up at 6004'MD&went through w/10K drag each way.Worked 2 times&continued in tagging up at 6065'MD,setting 15K WOB.Picked up to 6035'MD to change out saver sub to 4"HT38.,Change out saver sub from 4-1/2 IF to 4"HT38.,Change out grabber lift ram&pin block on Top Drive.,Continue changing out saver sub&inspect top drive.,TIH f/6035'-7640'MD,PU 175K,SO 160K,cleaned up tight spot at 6070'MD.,CBU at 7640'MD,PU 175K,SO 160K,5 bpm,360 psi.Shaker screens blinded off with ploy plug gel.Work pump rate 1-3 bpm to keep fluid on the shakers.Transfer poly plug returns to totes.Max gas 550 units.,Wash down f/7640'-7998'MD,tagging TOC w/10K, PU 180K,SO 165K,4 bpm,220 psi,FO 34%.,CBU at 7998'MD, PU 180K,SO 165K,6 bpm,500 psi.Shaker screens blinded off with ploy plug gel.Work pump rate 1-3 bpm to keep fluid on the shakers.Transfer poly plug returns to totes.Stage pumps up to 14 bpm,2430 psi for second BU to ensure casing clean.,Rig up test casing,fluid pack lines &line up to pump.Pressure up to 510 psi,in 11 strokes,1.1 bbls.Shut in&observe pressure,for 10 minutes,decrease to 490 psi.Bled back 1 bbl to the trip tank.Blow down top drive&kill line. SCR @ 7998'MD,FIW 8.5 PPG;MP#1 ©30=150;@ 40=240 psi;MP#2 @ 30=160;@ 40=240 psi,Service top drive,drawworks,&ST80.,TOH laying down 4"DP from 7998'-4248'MD,PU 132K,SO 132K.,M-32RD2 wellhead pressures-9-5/8=0psi,9-518X13-3/8=160psi,13-3/8X16=180psi, 16X26=95psi, 26X31=135psi. 7/20/2017 TOH laying down 4"DP f/4248'-482'MD.,TIH with 9 stands of 4"DP stood back in the derrick from 482'-1330'MD,PU 95K,SO 95K.,TOH laying down 4"DP f/1330'-482'MD,PU 82K,SO 82K.,TOH standing back 5"HWDP&laying down BHA1, from 482'to surface.,Clear&clean rig floor of 3rd party tools&4" Vhandling equipment.,Rig up e-line&mobilize tools to rig floor.,Run CBL on a-line from 3050'to 7992'ELM.,Log f/7992'-3050'ELM Rig down e-line r , equipment.,Change saver sub from 4"HT38 to 4-1/2IF.,Make up&TIH with 2-718"cement stinger;22 joints of 2-7/8",6.5#,L-80,8RD EUE tubing,&2 XO's to lj 698'MD, PU 66K,SO 66K.,TIH picking up 5"DP ft 698'-1265'MD,PU 70K,50 70K.,Service drawworks,ST-80&top drive.,TIH picking up 5"DP ft 1265'- 4460'MD, PU 130K,SO 130K.,M-32RD2 wellhead pressures-9-5/8=0psi,9-5/8X13-3/8=160psi, 13-3/8X16=180psi, 16X26=95psi,26X31=135psi. 7/21/2017 TIH w/cement stinger picking up 5"DP f/4460'-7820'MD. PU 205K,SO 195K.,Service top drive,drawworks,&ST-80.,TIH w/cement stinger picking up 5" DP ft 7820'-8021'MD,PU 210K,SO 200K,calculated displacement 64.3,actual 56.5 bbls.,Pick up to 7982'&wash back down to 8021'MD,tagging up w/ 10K,10 bpm,800 psi,FO 58%. No increase in pressure observed.Pick up to 8010'MD.,Rig up E-line&gyro tools.Test tool&monitor well.,TIH w/gyro in 5" citDP,logging in to 7275'ELM&out of the hole.,Lay down logging tools&e-line equipment.,Circulate&condition 5-9 bpm,200-640 psi,FO 37-57%.Rig up cement line on rig floor&flood lines.,PJSM,pump 10 bbls of H2O at 3 bpm,180 psi.Shut in&PT lines to 200/3000 psi,good.Batch up 15.0 ppg cement. Pump 52.1 bbls of 15.1 ppg cement at 3 bpm,310 psi,FO 34%.Pump 5 bbls of H2O at 4.5 bpm,260 psi.Swap to rig pump at 12.5 bpm,catching pressure at 82 bbls away.Reduce rate to 7-8 bpm,300-450 psi,FO 53%.Pump 123 bbls total displacement. Estimated TOC 7262'MD.CIP @ 22:33 hrs.,TOH f/8010'- 6752'MD,at 30-50 fpm,PU 185K,SO 180K.,Load wiper ball in drill pipe&circulate surface to surface at 5-12 bpm,220-860 psi.Had to reduce rate for short time,as small amount of poly plug material returned to shakers.No cement observed at bottoms up.Monitor well,static.,TOH f/6752'-698'MD, PU 66K,SO 66K.,TOH laying down 2-7/8"cement stinger,698'to surface.,M-32RD2 wellhead pressures-9-5/8=0psi,9-5/8X13-3/8=160psi, 13-318X16=180psi, 16X26=100psi,26X31=135psi. 7/22/2017 Rig up a-line w/8.25"gauge ring&junk basket.TIH to 7286'ELM,tagging cement.TOH&lay down same.,WOC,SIMOPS replace track for service loop on skate,service both vac units,service drawworks,service/CO dies on ST-80,rig up GeoSpan w/Sperry&housekeeping.,Rig up equipment to test 9-518" / casing&cement plug.Flood lines&close blind rams. Pressure to 2500 psi with 5.1 bbls,chart for 30 minutes.Bled back 5 bbls to trip tank.Rig down test (\ equipment&blow down lines.,Rig up a-line equipment&make up 8.125 cast iron bridge plug.,TIH w/Baker CIBP to locate CCL depth at 7223'.Set top of CIBP 12'from CCL at 7235'ELM.Good indicators of set.TOH&rig down a-line equipment.,Remove wear bushing.,Mobilize Whipstock BHA to rig floor.Pick up anchor(3 screws @ 6630#each,down shear to SET @ 19890#),Whipstock Slide Gen II,window mill(install brass bolt w/shear at 47K),lower watermelon mill,flex joint,upper watermelon mill, 1 HWDP,TM collar, DM collar,float sub,&15 HWDP.BHA 555.49'MD,PU 85K,5.3086805 K.SHT MWD 350 gpm,450 ,gln psi,good test.,TIH wr/Whipstock BHA f/555'-2827'MD,PU 136K,SO 130K,5,0-60 fpm.,TIH w/Whipstock BHAP ft 2827' MDS ,50-60 fpm.,Fill pipe, pressure test GeoSpan 250/3000 psi,good.,TIH w/Whipstock BHA f/3860'-7081'MD,50-60 fpm.,Orient&set whipstock.Fill pipe at 411 gpm,825 psi,12L. TIH ft 7081'-7229'MD orienting w/left hand turn to 68L,PU 205K,SO 215K.Tag CIBP at 7231'MD wl 6K.Turn pumps off,pick up 5'&set down 15K to shear set anchor. PU to 225K(10K over)to confirm anchor set.SO to 165K(40K)to shear brass bolt.PU 5'w/215K to confirm free travel.Top of slide at 7209' , MD&bottom of slide at 7226'MD.,Obtain parameters with FIW PU 215K,SO 205K,ROT 210K,30&40 rpm,Tq 5K,425 gpm 890 psi.,Start shipping FIW nr from pit system to Trading Bay.Prepare to displace well to 8.9 ppg OBM.,M-32RD2 wellhead pressures-9-518=0psi,9-5/8X13-3/8=160psi, 13-3/8X16=190psi, C?a 16X26=95psi,26X31=140psi. t/ / i • • 7/23/2017 Displace well to 8.9 ppg,110 vis OBM. Pump 25bb1 spacer&chase w/OBM @ 425 gpm,ICP 940 psi,FCP 1420 psi,50 rpm,Tq 5K,reciprocating.Caught 20 bbls of spacer&fully displaced pumping 479 bbls.,Rig up to test BOPE.Rack back 1 stand&pull 2 singles 7060'MD.Make up test plug,space out pups,& valves.Set plug&hang off string.Flood all lines&line up for shell test.,Perform shell test on BOPE to 250/3500 psi.Change out fitting on test hose. Tightened up flange on top of annular.Retest good.,Test BOPE w/4"&5"jts,to 250/3500 psi,for 5 min each,charted.Test annular&upper 4"rams;annular &lower 5"X7";blinds;CV#1-14;upper&lower kelly valves;FOSV;Dart valve;choke line valves,kill line valves,HCR valves;hyd&man chokes.Acc.test: initial system pressure 3000 psi;pressure after closure 1200 psi;200 psi attained in 49 seconds;full pressure attained in 239 seconds.8 bottles at 2500 psi.,Pit level indicators,trip tank,&flow indicators tested.Witness waived by AOGCC Rep.Jim Regg.,Rig down test equpment,blow down lines,drain stack of H2O, &lay down test plug.,TIH f/7060'-7209'MD,PU 215K,SO 200K.,Mill window per Baker Rep f/7209'-7218'MD,PU 215K,SO 200K, ROT 200K,100 rpm,Tq on 8K,Tq off 5.5K,400 gpm,1270 psi,FO 58%.,Mill window per Baker Rep ft 7218'-7231'MD, PU 215K,SO 200K,ROT 200K,80 rpm,Tq on 5.5K,Tq off 5.5K,4250 gpm,15600 psi,FO 42%.Milling started slowing 7228'MD.Samples showing a hard large sand conglomerate formation. TOW 7209'MD,6846'TVD;BOW 7226'MD,6859'TVD.,M-32RD2 wellhead pressures-9-5/8=0psi,9-5/8X13-3/8=165psi,13-3/8X16=195psi, 16X26=95psi, 26X31=140psi. / Fluid loss 24hrs:Obbls Total:0 bbls �(\ Metal recovered 24hrs:280 lbs Total:280 lbs 32 c� • SOF T� ,40"-\\v/7, . THE STATE Alaska Oil and Gas •� "tai, ofA T cKA Conservation Commission 2 : 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS�� Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Managero i 2017 Hilcorp Alaska, LLC SCOW 3 800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: McArthur River Field,Hemlock,Middle Kenai G, and Middle Kenai Gas Pools, TBU M-32RD Permit to Drill Number: 199-097 Sundry Number: 317-241 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this 1S day of June,2017. RBDMS V-- JUN 2 6 2017 II • RECEIVED STATE OF ALASKA JUN 12 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION 07 5* G I t S APPLICATION FOR SUNDRY APPROVALS AOGC( 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill 0 0 Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number Hilcorp Alaska,LLC Exploratory ❑ Development E • 199-097 ' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20462-01 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑/ Trading Bay Unit M-32RD ' CS+rr11Ltw..() 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018730 . McArthur River Field/Hemlock Oil,Middle Kenai G Oil&Middle Kenai Gas Pools • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13,835 9,667 " 8,001 • 7,460 ' 1,043 psi 8,001 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 981' 26" 981' 981' Surface 1,347' 16" 1,347' 1,347' 2,630 psi 1,020 psi Intermediate 3,767' 13-3/8" 3,767' 3,766' 3,090 psi 1,540 psi Production 10,588' 9-5/8" 10,588' 9,206' 7,930 psi 6,620 psi Liner 1,430' 7" 10,731' 9,266' 8,160 psi 7,020 psi Liner 3,141' 4-1/2"(slotted) 13,835' 9,668' sotted slotted Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic ,, See Schematic 4-1/2" 12.6#/L-80 5,450 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): HES PHL Ret.Packer&SCSSV/TRSV , 6,861'(MD)6,571'(TVD)&456'(MD)456'(TVD) , 12.Attachments: Proposal Summary 2 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development E N Service ❑ 14. Estimated Date for 15.Well Status after proposed work: 7/1/2017 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended E 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: ❑ Op Shutdown ❑ Abandoned ❑ GINJ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W.Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlOWe@Q hllCOrp.COm � [ \ �, 1 Contact Phone: (907)283-1329 Authorized Signature: 1TM*•w Date: O( / 12,/201-7 201 __COMMISSION USE ONLY 3 1- I 4-14 fj Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ❑ [11/ ❑ ❑ FCII II5ill Plug Integrity BOP Test Mechanical Integrity Test Location Clearance /1 Other: IG 3.5 C) j� /.1. � F— Post Initial Injection MIT Req'd? Yes No RBDMS (,t,JUN 2 6 2017 Spacing Exception Required? ❑ ❑ ' Yes ❑ No l" Subsequent Form Required: 10 -410 Cx APPROVED BY Approved 7.4 r7T �i. COMMISSIONER THE COMMISSION f /�JDate:: tr►"-/S" 17 4`� + " RIGINA L+� / 7 y�1 Submit Form and Form 10-403 R ised 4/2017 O for 12 months from the date of a royal. Attachments in Duplicate 1f //7 Lvalid 0 • 11 Well Work Prognosis Well: M-32rd Hilcorp Alaska,LLCDate: 06/08/2017 Well Name: M-32rd API Number: 50-733-20462-01 Current Status: SI Gas Producer Leg: Leg B-1 (NW Corner) Estimated Start Date: July 01, 2017 Rig: Hilcorp Rig 51 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 199-097 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Monty Myers (907) 777-8431 (0) (907) 538-1168 (M) Current Bottom Hole Pressure: 1,740 psi @ 6,969 TVD 0.250 lbs/ft(4.80 ppg)SIBHP survey '''' Maximum Expected BHP: C.,L4_12NisLi 6,969 TVD 0.250 lbs/ft(4.80 ppg)SIBHP survey Maximum Potential Surface Pressure: ,043 psUsing 0.1 psi/ft gradient per 20AAC25.280(b)(4) Brief Well Summary M-32rd is a depleted Gas Producer completed in 2009. This workover will plug back the existing completion and prepare the well to sidetrack into the West Foreland Sands.he,' fie/ A,C0reeit , j ('OACOr• tor few grey/191i p101i 7p /per „e Last Casing Test: n0 m4 6vT w'4"C-- Afj,;>, r4.e weft Car /c!//” .S1'a' v 10/08/2009 tested at 6,861'to 2,000 psi for 30 minutes on chart MPrO—t ,. c4, 0A- I Mcs4 Procedure: //Cad/ i 4 r4i f'/74,0h of J'.e At- ' 1. MIRU Rig. , 2. RU wire pull lowest GLV or punch tubing above packer at 6,861' and circulate any �/(/ hydrocarbons off well. Work over fluid will be FIW. BOP's will be closed as needed to circulate the well. 3. ND Wellhead, NU BOP and test to 250psi low/3,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. Monitor well to ensure it is static. ' :e' 4.1-- ES esL) 5. Unseat hanger and POOHncith completion. ----. . /"`'��Y e, 6 ��/ 6. RIH with bit and scraper to±7,300, circulate clean. POOH. 7. RU and run CBL log to+7,300' -----, 6>,^u_,,,_0-.' Mc . _ let ex-v'c`c''• 8. Attempt to establish injection rate sufficient for cement squeeze a. If favorable injection rate established VC-- i. RIH with cement retainer and set at±7,270' ii. RIH and sting into cement retainer. iii. RU cementing equipment and establish an injection rate with FIW. 1. Mix and pump 27 barrels cement to isolate existing completion. Un- sting from retainer and circulate hole clean. 2. POOH w/work string. Ct If favorable injection rate not established i. RIH with work string to ±8,000' " ii. Spot 27 bbl balanced plug iii. POOH to±7,250' and circulate hole clean /�� J��lt'+ iv. POOH w/work string. N y y5f'1 9. Pressure_T_est_casing to 2,500 psig for 30 minutes and chart,..-- 10. RU e-line and RIH w/CIBP to ±7,250', ±5' above casing connection. POOH 11. PU whipstock and mills and RIH to CIBP. 12. Orient and set whipstock in 9-5/8". • Well Work Prognosis Well: M-32rd Hileorp Alaeka,LLC, Date: 06/08/2017 13. Swap well to OBM drilling fluid. 14. Mill 8-1/2" window and 20' of new formation. POOH and LD mills. tcL� F - ***Remaining Procedure to be included on the Permit to Drill Sundry for the sidetrack*** General sequence of operations pertaining to drilling procedure: (informational only) 1. PU directional BHA and TIH to window. 2. Drill 8-1/2" hole to West Forelands sands. 3. Run and cement 7" casing. 4. Swap to completion sundry. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form n 0 • SCHEMATIC Trading Bay Unit/Steehead Platform Well #: M-32RD lliltorn Alaska.iii: Completed: 10/17/10 RKB=75.15'Rig Floor to TBG Head Casing&Tubing Detail [ Size Type Wt Grade Thrd ID Top Btm Hole 1 26" Conductor Surf 981' Driven 16" Surf Csg 75 K-55 BTC 15.1 Surf 1,347' 22" ll 3a 13-3/8" Csg 61 K-55 BTC 12.5 Surf 3,767' 17.5" . 2 A IMF s 9-5/8" Prod Csg 54 1-80 BTC 8.535 Surf 10,588' 12.25" •Ee . 3b Pi 7" Liner 29 1-80 Butt&KC 6.184 9,301' 10,731' 8-1/2P " io" ) 3c IBTC AB " 4-1/2" Slotted Liner 12.6 L-80 3.958 10,694' 13,835' 6" ,f 4 litak',�3d 4 mod ?` t� TUBING DETAIL/75.15'RKB to Tbg Hngr a• IllW 113e V'_ , 4-1/2" 12.6 L-80 TCII 3.96 Surf 5,450' tR . 113f • -1."'' R ziz V, 'i3g ° PKC JEWELRY DETAIL VI o 'r I I I 4 CEMENT DETAIL `5= - NO. Depth ID Item Cmt Cmt Top t 1 456' 3.813" SCSSV(TRSV) 3a 1,563' 3.833" GLM(SFO-2) 1,933 sx Cmt to Surf Calc TOC@ surf- (q ;' assmd 20%loss ,. E7 2 2,010' 3.833" Chemical Injection Sub Returns to Surf Bumped Plug. u 3b 2,643' 3.833" GLM(SFO-2) 2,244 sx Calc TOC @"'671'assmd 20% TOC @ 3c 3,633' 3.833" GLM(SFO-2) loss ,a +_ •. 3d 4,553' 3.833" GLM(SFO-2) Returns to Surf.Calc TOC + _r' 6a 3e 5,355' 3.833" GLM(SFO-2) 2,607 sx @-2611'assmd 20%loss 3f 6,062' 3.833" GLM(SFO-2) Calc TOC to liner top,w/assmd FSA 3g 6,797' 3.833" GLM(SFO-2) 72 bbls 20%loss 6b ..-at 4 6,861' 3.850" HES PHL Retrievable Packer 2-1/2"x 1/16"slots,48/ft 5 6,922' 3.813" X-Profile Nipple TOC% 5a 6,973' 3.70" Mech as37'ELM ,• Tbg Release elease(BOT Gun Drop Sub)' • 4. Toc@ '; F 7. F11C 6 7,750' 3.958 Tubing Tail 6a 8,001' Neo Plug+27'cement on top ?` 'fib 6b 8,038' 560'Section of Cut Pipe I: F13B 7a 8,690' N/A Neo Plug 53'of cmt+12'sand+35'cmt r F14A 7b 8,720' N/A Neo Plug 7c 8,890' N/A Plug w/40'of cement 0,830'ELM 7c 7d 9,064' N/A Plug w/81'cement(TOC 8983') TOC @ IL, Fl 5B 8 9,284' N/A TTS umbrella plug w/cement on top 8,983 ELM) ": P. ;+` ' 1 i 9 9,572' N/A EZSV Cement Retainer 'ha,r'- " _. Fl 5C T @ Pressure Test Details as of 12/2/08 9,015 ELM At'.M # h 7d ` A r+Y{ Depot Results TOC @ . ,' ' 'I.,°T."I.s :..•or F16 Good Test 2000 psi to surface.55'above top of liner. 9,nz ELM i ° ' " 9,245' 9-%"csg tested good.Could not get pkr to set in csg TOC @ 1 •<",n G01 between 9245'&TOL. 9,252'SLM ..;.. ,• 8 9,350' Bad.No test above or below. 9,400' Bad.No test between pkr&BP. Collapse Csg 9,480' Bad.No test between pkr&BP. 92' w.;_ 9,299'(+/-) 9,515' Good Test to 2000 psi.Between pkr&BP @ 9560'. 19392' Integrity Breach. Goy 9,545' Good Test to 2000 psi.Between pkr&BP @ 9560'. 9245'to 9515' ; }rop of fill @ 9522' 1 f-16-09 Cmtl ` Brief Details&Info. i Top oof @954T t yt . ',#" i '" ` r 9 Spudded M-32RD on 11/15/99.Completed on 01/25/00. M-32RD was a drill out of M-32(window in the 9-5/8" Milled BP« 1. rr' '-- G-1,2 "'9392'). 5 fish Were left in sidetrack holes while drilling the well: #1 @ 9682'^'1226'fish. #2 @ 9564'"1088' '' •r ' fish. #3 @ 12418'"5'fish.#4 @ 11650'^300'fish. #5 @ 9943'(in the M-32RD section)"'780'fish. 3t, "", ,,,,""r. G-4,5 •Hole Section MWT: •Approximate Rotating hrs: ay1, 4k k 's 0 17-1/2"to 1347'9.0 to 9.5 ppg , o 16"120 hrs l4 1:c- 6 B-1 o 12-1/4"to 10588'9.3 to 10.1 ppg o 13-38"560 hrs B-2 0 8-1/2"to 10731'9.0 to 10.5 ppg o 9-5/8"694 hrs ;r x Q •'at o 6"to 13835'9.5 to 10.5 ppg o 7"272 hrs •A',l . yy` . Collapse in4-112"Slotted Perforation Details Part 1 Ej'''1.--.71.„,,,,.",T%':.='. Liner@ 10825' cZone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Perf.Date Status Notes E7 7,372' 7,392' 6,969' 6,985' 20' 6 05/10/14 Sqz'd 3-1/8"HC Updated On/By 06/10/14 JLL TD=13,835'MD/9667'TVD SCHEMATIC STrading Bay Unit/Steehead Platform Well #: M-32RD Hili orn Alaska.LLC Completed: 10/17/10 Perforation Details Part 2 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Perf.Date Status Notes F5A 8,042' 8,056' 7,491' 7,502' 14' 6 4/26/2012 Isolated F11C 8,625' 8,645' 7,940' 7,955' 20' 6 3/19/2012 Isolated 3-1/8"SDP F13B 8,732' 8,756' 8,022' 8,040' 24' 6 2/4/2012 Isolated 3-1/8"SDP F14A 8,778' 8,793' 8,057' 8,068' 15' 6 7/17/2011 Isolated 2-7/8PJ Omega F15B 8,944' 8,974' 8,183' 8,206' 30' 6 5/24/2011 Isolated 3-1/8"SDP Expro F15C 9,008' 9,014' 8,232' 8,237' 6' 6 5/7/2011 Isolated 3-1/8"SDP Expro 2-7/8" PowerJet F16 9,072' 9,092' 8,281' 8,296' 20' 6 3/16/2011 Isolated Omega 1/29/11& 3/16/11 2-7/8" F16 9,092' 9,112' 8,296' 8,312' 20 6 3/17/2011 Isolated PowerJet Omega 3/17/11 2-1/2" 001 9,212' 9,248' 8,387' 8,413' 36' 5 10/19/2010 Isolated PowerSpiral guns 10/19/10 2-1/2" 005 9,500' 9,521' 8,593' 8,607' 21' 5 11/17/2009 Isolated Powe rSpiral guns 11/17/09 4-5/8"TCP 01/2000& G-1 9,625' 9,665' 8,676' 8,700' 40' 18 12/14/2006 Isolated 12/2006 (perPd 9645'- 9665') 4-5/8"TCP 01/2000& 0-2 9,697' 9,737' 8,700' 8,743' 40' 18 12/14/2006 Isolated 12/2006 (perPd 9714'- 9734') 4-5/8"TCP 01/2000& 0-4 9,915' 9,990' 8,847' 8,890' 75' 18 12/14/2006 Isolated 12/2006(perPd 9933'-9953'& 9970'-9990'1 4-5/8"TCP 01/2000& 0-5 10,060' 10,210' 8,931' 9,015' 150' 18 12/14/2006 Isolated 12/2006(perPd 10700'-10090', 10120'-10135'& 10180'-101951 4-5/8"TCP 01/2000& 8-1 10,430' 10,480' 9,131' 9,156' 50' 18 12/14/2006 Isolated 12/2006 (perPd 10430'- 10445') 4-5/8"TCP 8-2 10,510' 10,530' 9,170' 9,180' 20' 18 12/14/2006 Isolated 01/2000& 12/2006 8-2 10,560' 10,570 9,193' 9,198' 10' 6 12/14/2006 Isolated 4-5/8"TCP 12/2006 83-137 10,694' 13,835' 9,227' 9,668' 3141' 1/1/2000 Isolated Slotted Liner Updated On/By 06/10/14_ILL 11 411) • PROPOSED Trading Bay Unit/Steehead Platform Well #: M-32RD Ililearn Alaska.LLC Completed: FUTURE RKB=75.15'Rig Floor to TBG Head Casing&Tubing Detail Size Type Wt Grade Thrd ID Top Btm Hole 26" Conductor Surf 981' Driven 16" Surf Csg 75 K-55 BTC 15.1 Surf 1,347' 22" C.'. 13-3/8" Csg 61 K-55 BTC 12.5 Surf 3,767' 17.5" 9-5/8" Prod Csg 54 L-80 BTC 8.535 Surf 10,588' 12.25" �e �R 7" Liner 29 L-80 Butt&KC 6.184 9,301' 10,731' 8-1/2" N 0 A /+; IBTC AB L,3"' ,.� 4-1/2" Slotted Liner 12.6 L-80 mod 3.958 10,694' 13,835' 6" U n P` TUBING DETAIL/75.15'RKB to Tbg Hngr e ,',,tA E U �t . t 2 •t: JEWELRY DETAIL CEMENT DETAIL a Depth Depth a' 1 PO NO. (MD) (TVD) ID Item Cmt Cmt Top o ." ' ue"` CIBP t7 250 Cmt to Surf Calc TOC@ surf- 1 ±7,250' ±6,873' CIBP set for whipstock 1,933 sx 1. lir EZSV 17,270' assmd 20%loss q 2 ±7,270' 16,889' EZSV Cement Retainer(Optional) 5 KT 1ri,"W Returns to Surf Bumped Plug. '�'`; d airr ' t E7 2,244 sx Calc TOC @^'671'assmd 20% loss TOC @ . ".` t' 6a 8,001' 7,460' Neo Plug+2Tcement on top2,607 sx Returns to Surf.Calc TOC 8,001' x 6a @^'2611'assmd 20%loss 7'p 6b 8,038' 7,488' 560'Section of Cut Pipe Calc TOC to liner top,w/assmd Neo Plug 53'of cmt+12'sand 72 bbls 20%loss /r '. F5 7a 8,690' 7,990' N/A +35'cmt k+ Cc t� 5� 7b 8,720' 8,013' N/A Neo Plug 2-1/2"x 1/16"slots,48/ft e_ 7c 8,890' 8,142' N/A Plug w/40'of cement roc @ - 7d 9,064' 8,275' N/A Plug w/81'cement(TOC 8983') roc@ s a '.4'• " " F11C 8 9,284' 8,440' N/A TTS umbrella plug w/cement on 8,637'ELM ,78 "' top a 7b 9 9,572' 8,641' N/A EZSV Cement Retainer I: F 13 B TOC @ i ,ie C Fl 4A Pressure Test Details as of 12/2/08 8,830'ELM 'g . a. . 'a Set TOC@ .1! F15B Depth Results 8,983 ELM '..4-,1,, -,y;i Good Test 2000 psi to surface.55'above top of liner. TOC @ .e. 9,245' 9-%"csg tested good.Could not get pkr to set in csg 9,015'ELM t ''' a r 't s between 9245'&TOL. "7d 9,350' Bad.No test above or below. 9,400' Bad.No test between pkr&BP. roc @ p F16 9,480' Bad.No test between pkr&BP. 9,172'ELM ak2 �, 9,515' Good Test to 2000 psi.Between pkr&BP @ 9560'. @ ' ""R 1 G01 9,545' Good Test to 2000 psi.Between pkr&BP @ 9560'. TOC 9252'SLM `+`. 'IL''. G' •.y. B Collapse Csg Brief Details&Info. Csg Window= _ 9,299'(+/-) Spudded M-32RD on 11/15/99.Com Completed on 01/25/00. M-32RD was a drill out of M-32(window in the 9-5 8 X9392' PP / „ Integrity Breach ,j e.: G05 9392'). 5 fish Were left in sidetrack holes while drilling the well: #1 @ 9682'-1226'fish. #2 @ 9564'-1088' 9245'to 9515' . .e lop of rill @ 9522' fish. #3 @ 12418'"'5'fish.#4 @ 11650'"'300'fish. #5 @ 9943'(in the M-32RD section)`780'fish. 11-16-09 Top of Cmt @ 9547' •Hole Section MWT: •Approximate Rotating hrs: -""" ''' "_�., 9 0 17-1/2"to 1347'9.0 to 9.5 ppg o 16"120 hrs q t." ▪`" e G-1 2 0 12-1/4"to 10588'9.3 to 10.1 ppg o 13-38"560 hrs Milled BP w_.i. c 0 8-1/2"to 10731'9.0 to 10.5 ppg o 9-5/8"694 hrs . "C G-4,5 0 6"to 13835'9.5 to 10.5 ppg o 7"272 hrs ''5 o.., i."-° -f e B-2 fi. u: Q Perforation Details Part 1 ;� . a1 Zone To ".Collapse in 4-112"Slotted PlMD) Btm(MD) To p(TVD) Btm(TVD) Amt SPF Pert.Date Status Notes to . }t Liner 10825'f 4v▪V E7 7,372' 7,392' 6,969' 6,985' 20' 6 05/10/14 Sgz'd 3-1/e HC Y .�`�•` r itt- �'.�1"<�.` T Updated By JLL 06/08/17 TD=13,835'MD/9667'TVD PROPOSED Trading: 2t/ay UniSteehead Platform Well #: RD Hilcoro Alaska.LLC Completed: FUTURE Perforation Details Part 2 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Perf.Date Status Notes F5A 8,042' 8,056' 7,491' 7,502' 14' 6 4/26/2012 Isolated F11C 8,625' 8,645' 7,940' 7,955' 20' 6 3/19/2012 Isolated 3-1/8"SDP F13B 8,732' 8,756' 8,022' 8,040' 24' 6 2/4/2012 Isolated 3-1/8"SDP F14A 8,778' 8,793' 8,057' 8,068' 15' 6 7/17/2011 Isolated 2-7/8"PJ Omega F15B 8,944' 8,974' 8,183' 8,206' 30' 6 5/24/2011 Isolated 3-1/8"SDP Expro F15C 9,008' 9,014' 8,232' 8,237' 6' 6 5/7/2011 Isolated 3-1/8"SDP Expro 2-7/8"PowerJet F16 9,072' 9,092' 8,281' 8,296' 20' 6 3/16/2011 Isolated Omega 1/29/11& 3/16/11 F16 9,092' 9,112' 8,296' 8,312' 20 6 3/17/2011 Isolated 2-7/8 PowerJet Omega 3/17/11 G01 9,212' 9,248' 8,387' 8,413' 36' 5 10/19/2010 Isolated 2-1/2"PowerSpiral guns 10/19/10 G05 9,500' 9,521' 8,593' 8,607' 21' 5 11/17/2009 Isolated 2-1/2"PowerSpiral guns 11/17/09 4-5/8"TCP 01/2000& G-1 9,625' 9,665' 8,676' 8,700' 40' 18 12/14/2006 Isolated 12/2006(perf'd 9645'-9665') 4-5/8"TCP 01/2000& G-2 9,697' 9,737' 8,700' 8,743' 40' 18 12/14/2006 Isolated 12/2006(perf'd 9714'-9734') 4-5/8"TCP 01/2000& G-4 9,915' 9,990' 8,847' 8,890' 75' 18 12/14/2006 Isolated 12/2006(perf'd 9933'-9953'&9970'- 9990') 4-5/8"TCP 01/2000& 12/2006(perf'd G-5 10,060' 10,210' 8,931' 9,015' 150' 18 12/14/2006 Isolated 10700'-10090', 10120'-10135'& 10180'-10195') 4-5/8"TCP 01/2000& B-1 10,430' 10,480' 9,131' 9,156' 50' 18 12/14/2006 Isolated 12/2006(perf'd 10430'-10445') B-2 10,510' 10,530' 9,170' 9,180' 20' 18 12/14/2006 Isolated 4-5/8"TCP 01/2000& 12/2006 B-2 10,560' 10,570 9,193' 9,198' 10' 6 12/14/2006 Isolated 4-5/8"TCP 12/2006 B3-B7 10,694' 13,835' 9,227' 9,668' 3141' 1/1/2000 Isolated Slotted Liner Updated By JLL 06/08/17 Steelhead Platform M-32 Current Hilnnrp Alaska,LIA 06/09/2017 Steelhead Platform Tbg hanger,FMC-TC-1A-EN- M-32 CCL,16%5M X 4%Hydra 26 X 16 X 13 3/8 S 9 5/8 X 563 lift and susp,w/4"Type 41/2 H BPV profile,2-3/8 continuous control line, 41055 material BHTA,Bowen, 41/16 5M FE X 7-5SA Bowen top '"1 Valve,Swab,WKM-M, 41/165M FE,HWO,DD f " Valve,wing,WKM-M, 41/16 5M FE,HWO,DD IDS'S" Valve,upper master,SSV, 41/16 5M FE,w/15"Safeco 1} O \' operator,EE 1 11= 0.41111.111 C„../9„, Valve,Master,WKM-M, O� ,, Valve,wing, 4 1/16 5M FE,HWO,DD „$f .9,j 41/16 5M FE,w/15"Safeco operator,EE nInd r WM101 Tubing head,FMC-TC-60,spec for �r Trill.ne.„ unihead,16%SM FE top X 16%SM -'a•_r ) ■stdd bottom,w/2-21/16 SM SSO t 1 Unihead,FMC Type 2,16%5M Valve,FMC-120, 21/165M FE,HWO,AA FE top X21%2M FMCspeedlock bottom,w/4-21/16 SM SSO till • III Adapter spool,FMC-A-5-S 30"MSS tdd bottom %2M speedlock tp2/2-2 FMC Lt"`" _ speedlock top,w/2-2"LPO 111M. Starting head,FMC, d MSS i'� - Mal FE X 26"butt weld NI 26" 16" 13 3/8" 9 5/8" 4 1/2 • Steelhead Platform 16 3/4 5M BOP (Oil Leg) M-32 HArorp Alaska.I.U; 06/09/2017 Rig toot 9pn 3.43• xv Moonol..ol rla it lin 111113131 5.10' • Hydril 0 131 133 1311311#! .1111111. Ial 11111p Yat 1.1 Cl�n�y�j 5.46' 16%-5000 _ w.YM1W,ponne;:gsw 31 tit lit 131111 Top olittonpoolita sw' Kill Side 31/85M ill 11,111 111 - Choke side �p Manual and HCR �''�r ti} } 3.00' 3 1/8 5M III nu 111���.••ww✓��'' Manual and HCR -1ii til .. 1a1 ogr Iai 16%5000..< .._a•..«... ,x _ 3.58' 11111111/111111 DSA 16%10M X 16%5M .66' upv.,w.m..ti Reim mxVwkc,nnl 11 t1 1.011inww. Vweramg Mg wk rating 19.98' Riser,16%5M API hub X 16 3/4 10M FE s.9p•ownv+tio../nor . tippw*ilia morn foot Weft*floor it 1.1.er head 1I Riser,16%SM FE X16%5M API hub }Itil Lly Wellhead @ 8.15' • 0 • A 2i31Sf18 svo 1-11111.- 0 U 0 II II • _\ �_1, iI w U ON w 0_ 0 cnU a Y v U N0 OD 0cC w D4 A A < w> U O N M ON DI: 0 V r —J v.cn LL U Z#NM/1dlbl U U fLn <L #)1NV1 dial. V < U 2rI I-- Y 0 vQ L _ F- JF\,0��\NE 0 m m A IP 3 A w a_c, ..,c7 = C4 [5.91 ,, IV - O• _i w • ` ^ iN W F- d U 3�N 11W O Q U U co E _ coco VJ a CO w a. U Li., m D a_ O U 0 W c O U Li 1 V N N N • • 111 Steelhead Rig#51 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Steelhead Rig # 51 WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Production Vessel that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Circulate down tubing taking returns to production off of the annulus and sweep gas and oil to production until returns are clean. 4) Confirm that well is static Monitoring for any pressure Build Up Or if Well Is Still On A Strong Vacuum ( I do not think that We Often Shoot Fluid Levels) Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV, ND Tree 2) Clean/Inspect/And Confirm By Screwing Into Lift Threads(Counting Turns) Remove Sub—Check all Lock Down Pins to Ensure they Will Back Out Far Enough To Clear Hanger—Plug Penetrations Through Hanger—Put a Sealing Cap On Penetrator—Leave BPV Installed & If Needed Install Adaptor to Test Joint, Might Be Using a Left Hand Blank Ported Sub or a Combo Tool Of Various Types NU BOP. 3) MU landing joint With On/Off Tool Adaptor. 4) Set slips, mark same. Test per standard Steelhead Rig#51 Test Procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, establish static fluid level. 2) Once the fluid level is established to be static, notify Hilcorp Anchorage Operations Engineer. 3) Proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a BPV, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) MU Left Hand Blanking Plug d) Plug penetrations in hanger. For ESP wells- Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 4) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz(AOGCC-guy.schwartz@alaska.gov) and Mr. • Steelhead Rig#51 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 Jim Regg(AOGCC-jim.regg@alaska.gov)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness.As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection,etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile /penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 5) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 6) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Note: BOPE high test pressures will be determined upon Approved Sundry.Test joint sizes will be determined upon well work. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Pull Wear Bushing, Make up Test Plug and Test Joint—Land Same Measuring in the hole getting a Good Mark when Landed . a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after Isolation Plug is Set) 1) Make up Test Joint as per diagram. Insure all connections above test plug are torque. 2) Pull Wear Bushing and install Test Plug 3) Make up Side-Entry Sub, (2)TIW valves and IBOP to top of Test Jt. 4) Make up Test Hose#1 to Side-Entry Sub and Test Hose#2 to Top Drive Test Sub. 5) Verify Annulus valve is open and monitored. 6) Fill BOP and Choke Manifold with water. Purge air from system through Choke manifold top valve and IBOP. • Steelhead Rig#51 BOP Test Procedure Hihorp Alaska,LLC Attachment#1 7) Close Annular and set closing pressure to 800 psi. (pressure can be increased as necessary to seal element) Perform full body BOP test to check integrity of system. Note: When testing, pressure up with pump to desired pressure,close MP1 and/or MP2 to trap pressure and read same with chart recorder. 8) Referencing the attached schematics test BOP as per Permit and Regulations as follows. a) Close W1 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Open W1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves,to 250 psi low and 3,000 psi high,for 5 minutes each,as follows: (Valve numbers are in reference to Flow Diagram) d) Test#1-Annular, IBOP, Upper TD Valve, Kill Line Demco, C1, C2, C3,C12, C13, C14. e) Test#2—Test VBRs,Top TIW, Lower TD valve, HCR2,C4, C5, C6. f) Test#3—Test VBRs,W2, C7, C8, C9 g) Test#4.—Test Lower Pipe Rams, Bottom TIW. h) STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (I.E. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre-charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/-3,000 psi). Note: Make sure the electric pump is turned to "Auto", not "Manual" so the pumps will kick-off automatically. j) Back out Test joint and pull to rig floor. Connect test hose to C13. Pressure up on Manual and Hydraulic Chokes to 1,000 psi. Function Chokes to bleed pressure and verify operation. k) Test#5. —Test Blinds and C10, C11. I) Make up 2nd Test Joint if running two string sizes m) RIH with 2nd Test Joint and test plug. Make up Side-Entry Sub, (1)TIW valve and IBOP to Test Joint. Connect#1 Test Hose to Side-Entry Sub and#2 Test Hose to suspended TIW w/test sub. w • II Steelhead Rig#51 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 Purge air from system. (always verify lengths needed when compared to RKB and add pups if necessary) n) Test#6-Test Annular, IBOP, suspended TIW and HCR1. o) Test#7-Test VBRs, Upper TIW and Manual Choke. p) Rig down test equipment. Blow down lines. Close Annulus valve. Pull test plug. Install Wear Bushing. Rig down, or stand back Test Stand. q) Back out test joint& pull,close blinds, close valves C7, C8, C9, open HCR1, and W1 r) Open all rams and annular and close HCR2 to place BOPE back into operating position for well work. s) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. 0 • �� ct / �> 2 0QCa— a c 7,3 2 E (o (a / / 2k ° = � a E oE 03 2 / § 10. $ f ƒ < / / flI �/ .0X �ro Arc> = I 05 a 0. 2 § / n -0 '44.! ■ 2 e 2 ._ 2 Cu G / a) = 0 Zc 1,7 CU / L. 2 0 L. & y x- k ƒ f \ 0 2 al >� U. CNA CD % co L» c Cu13) — .r � U 0 k / % 2 k \ k E G ° i. = 2 0 $ S .$ 2 \ / _ c 43 ƒ / E a) »7 Cua) c/ / Cl) = U c -0 mg C LU % 2 $ 0 0 Q 2 § � a @ 0 O. a e a L 4 / ) o . 4 t 2 x % $ § o.0 w) q Q § 0 R » ■ I- q k -< / x 2 � ca U Q 2 ■ 2 0 � � / � 2 p .. _ % \ U ° � ' ,c F 2 >,0 0 k 2 2 k 0 o. 2 410 Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend"boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon"box is checked in Box 15 (Well Status after proposed Ge logist work) the initial reviewer will cross out that erroneous entry and initial / then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill"comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They ar~ available in the original file and viewable by direct inspection. / ??-~ 0E/¢ 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 Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of vadous kinds [] Other COMMENTS: Scanned TO RE-SCAN Notes: Dianna Vincent Nathan Lowell klati .....'v •••• 'a o-"wub'd u' 4.J9WL.:n"vi,YJL:'].�.aG uli:,li:"•_••"•.••s.4at"",., at N..ve 5-n1•c`saiGtlit i;-:f faw'.•x,�ye � ti4\�� I//7„''';' h 5'1t i E A r 1< . a-_-_c::_ i, d _ I'-'1i1:11'4:5,7-.::;4---:1 K,,,, c;-7,,..,"6 � 14 / ciovvRNoR SEAN 'ARN 11•f333�i sSeventh enu Anchoroc Alaska 99501 3572 1 `in• 9n7 770 1433 SCAMP AUG o 7 2014 Ted Kramer Sr. Operations Engineer j I 0�� D 17 Hilcorp Alaska, LLC `� 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil, Middle Kenai G Oil & Middle Kenai G Gas Pools, Trading Bay Unit M-32RD Sundry Number: 314-275 Dear Mr. Kramer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, (/ Cathy P. oerster Chair I St-- DATED this 1 day of May, 2014. Encl. RECEIVED STATE OF ALASKA APR 30 20,14 ALASKA OIL AND GAS CONSERVATION COMMISSION S 5 Ji /dc-- APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25280 1.Type of Request: Abandon❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well❑ Change Approved Program 0 Suspend❑ Plug Perforations 9 •• Perforate El Pull Tubing❑ Time Extension❑ Operations Shutdown 0 Re-enter Susp.Well 0 Stimulate❑ Alter Casing 0 Other Pump Poly Plug 0i 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number Hilcorp Alaska,LLC " Exploratory ❑ Development 0. 199-097 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic El Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20462-01 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Trading Bay Unit M-32RD Will planned perforations require a spacing exception? Yes ❑ No❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018730 • McArthur River Field/Hemlock Oil,Middle Kenai G Oil&Middle Kenai G Gas Pools . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13,835 • 9,667 - 8,001 _ 7,460 • 8,001 N/A Casing Length Size MD TVD Burst Collapse Conductor 981' 26" 981' 981' Surface 1,347' 16" 1,347' 1,347' 2,630 psi 1,020 psi Intermediate 3,767' 13-3/8" 3,767' 3,766' 3,090 psi 1,540 psi Production 10,588' 9-5/8" 10,588' 9,206' 7,930 psi 6,620 psi Liner 1,430' 7" 10,731' 9,266' 8,160 psi 7,020 psi Liner 3,141' 4-1/2"(slotted) 13,835' 9,668' slotted slotted Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 4-1/2" 12.6# L-80 5,450' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): HES PHL Retrievable Packer&TRSV SCSSV ' Packer 6,861'(MD)6,571'(TVD)and SCSSV 456'(MD)456'(TVD) 12.Attachments: Description Summary of Proposal 0 • 13.Well Class after proposed work: Detailed Operations Program El BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 5/2/2014 Commencing Operations: Oil ❑ Gas 0 J WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ El WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramer(ahilcorp.com Printed Name Ted Kramerra , Title Sr.Operations Engineer Signature - .1‹._ v'.--'� Phone 907-777-8420 Date 4/30/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -2k4-(._ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RsDMS'. AY 0 $ 2014 Spacing Exception Required? Yes ❑ No EZ Subsequent Form Required: / t) y 0 APPROVED BY Approved by: COMMISSIONER THE COMMISSION qua SIIy Date: 5.._/ -/41 Form 10-403(Revised 10/2041 pproveQ,���DU GJaN,krLthe from the dapproval. Submit Form and Attachments in Duplicate, Well Work Plan Well: M-32RD Ililcora Alaska,Lia Date:4/30/2014 Well Name: M-32RD API Number: 50-733-20462-01 Current Status: Gas Producer Leg: Leg B1, NW Corner Slot#10 Estimated Start Date: May 2, 2014 Rig: Steelhead Rig 51 Reg.Approval Req'd: May 2, 2014 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 199-097 First Call Engineer: Ted Kramer (907)777-8420 (0) (985)867-0665 (M) Second Call Engineer: James Young (907)777-8404(0) AFE Number: Current BHP: 1,874 psi @ 6,985ft TVD/7,396ft Based on static MD BHP survey (9/27/12) Maximum Expected BHP: 1,874 psi @ 6,985ft TVD/7,396ft Based on static MD BHP survey (9/27/12) Max. Anticipated Surface 410 psi MBHP-0.66*ND Pressure: *0.1 psi/ft+ 0.33 * ND *0.435psi/ft Brief Description M-32RD was completed in its current configuration as an E-7 zone gas producer in September of 2012. The completion plan for this well was to set a plug and perforate the well in the E7 zone to determine if it was productive for gas. This completion was executed as planned but the well tested wet. Closer inspection of the results suggested that water may be migrating up from a lower interval behind pipe due to a bad cement job on the 9-5/8" production casing string. ./ This Sundry approval is to pump a 'Poly Plug®' gel pill down the completion tubing to seal off the E-7 perforations and squeeze off the channel preventing further water migration. Procedure: 1. Rig up pump, and tanks. 2. Pressure test all treating lines to 1,500 psi. 3. Clean all hoses and lines prior to tying into tubing. 4. Mix and pump 38bbls of ®Clear Gel' (8.61b/gal): Component Volume Filtered Inlet Water +/-37bbls Ultra Seal-XLR® 45ga1 Ultra Seal-XLD®(Defoamer) 5gal Poly Plug®Clear Gel 36 pails (1 pail = 22.5Ibs) Ultra Seal Plus 4 sacks(1 sack=40Ibs) 5. Displace gel with +/- 112 bbls. of filtered inlet water leaving +/-6bbls of gel on and above the perforations. 6. Shut down pumps, clear lines, and secure the well. 7. Turn well over to production. II Well Work Plan Well: M-32RD • xi!co`°Kaska,LL Date:4/30/2014 Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Wellhead Diagram 1 ng Bay Unit/Steehead Platform II SCHEMATIC Well #: M-32RD xa�enrn Amok:�.ta.c Completed: 10/17/10 RKB=75.15'Rig Floor to TBG Head Casing&Tubing Detail Size Type Wt Grade Thrd ID Top Btm Hole 1 26" Conductor Surf 981' Driven b, 16" Surf Csg 75 K-55 BTC 15.1 Surf 1,347' 22" ' i1 3a ii 13-3/8" Csg 61 K-55 BTC 12.5 Surf 3,767' 17.5" C 2 9-5/8" Prod Csg 54 L-80 BTC 8.535 Surf 10,588' 12.25" 8 i11 3h 1'g 1 7" Liner 29 L-80 Butt&KC 6.184 9,301' 10,731' 8-1/2" ii,o 3c L ax� mod 4-1/2" Slotted Liner 12.6 L-80 IBTC B 3.958 10,694' 13,835' 6" 3d 3e "`r TUBING DETAIL/75.15'RKB to Tbg Hngr 4-1/2" 12.6 L-80 TCII 3.96 Surf 5,450' E 9��9 -4 3f U " 1 ' Ems ; 13g .� E 7 JEWELRY DETAIL CEMENT DETAIL a x`,9NO. Depth ID Item Cmt Cmt Top 0 a K 1 456' 3.813" SCSSV(TRSV) Cmt to Surf Calc TOC@ surf- Sa 3a 1,563' 3.833" GLM(SF0-2) 1,933 sx assmd 20%loss Old E7 2 2,010' 3.833" Chemical Injection Sub Returns to Surf Bumped Plug. 6 3b 2,643' 3.833" GLM(SFO-2) 2,244 sx Calc TOC @"'671'assmd 20% TOC @ 3c 3,633' 3.833" GLM(SFO-2) loss 8,001' e., 3d 4,553' 3.833" GLM(SFO-2) Returns to Surf.Calc TOC • 6a 3e 5,355' 3.833" GLM(SFO-2) 2,607 sx @-2611'assmd 20%loss 3f 6,062' 3.833" GLM(SFO-2) Calc TOC to liner top,w/assmd «;',, ; F5A 3g 6,797' 3.833" GLM(SFO-2) 72 bbls 20%loss 1 6b 4 6,861' 3.850" HES PHL Retrievable Packer TOC j' 5 6,922' 3.813" X-Profile Nipple 2-1/2"x 1/16"slots,48/ft @ 5a 6,973' 3.70" Meth Tb Release(BOT Gun DropSub) .r'.1Kg TOC @ r-,F11C 6 7,750' 3.958 Tubing Tail 8,53TELM "',17a 6a 8,001' Neo Plug+27'cement on top m '7b 6b 8,038' 560'Section of Cut Pipe t F13B 77a 8,690' N/A Neo Plug 53'of cmt+12'sand+35'cmt F14A 7b 8,720' N/A Neo Plug TOG @ 7c 8,890' N/A Plug w/40'of cement 8,830'ELM 7d 9,064' N/A Plug w/81'cement(TOC 8983') TOC 7c F15B 8 9,284' N/A TTS umbrella plug w/cement on top 8,983'ELM • I,, 9 9,572' N/A EZSV Cement Retainer TOC @ F15C 9,015'ELM Pressure Test Details as of 12/2/08 t.'7d ' Set ® . ., 0 F16 Depth Results MR roc @ Good Test 2000 psi to surface.55'above top of liner. 9,172•ELM ., 9,245' 9-%"csg tested good.Could not get pkr to set in csg TOC @ G01 between 9245'&TOL. 9,252'SLM x, - "" •�;8 9,350' Bad.No test above or below. Collapse Csg 9,400' Bad.No test between pkr&BP. 9,299'(+/-) @9392' 9,480' Bad.No test between pkr&BP. Csg WinWindowC4 9,515' Good Test to 2000 psi.Between pkr&BP @ 9560'. integrity Bream 005 9,545' Good Test to 2000 psi.Between pkr&BP @ 9560'. 9245'to 9515 .'Top of fill @ 9522' 11-16-09 Brief Details&Info. ''#Top offCmtCmt 9547 9 Spudded M-32RD on 11/15/99.Completed on 01/25/00. M-32RD was a drill out of M-32(window in the 9-5/8" Milled BP _ =G-1,2 ^'9392'). 5 fish Were left in sidetrack holes while drilling the well: #1 @ 9682'"1226'fish. #2 @ 9564''"1088' fish. #3 @ 12418' S' • fish.#4 @ 11650'^300'fish. #5 @ 9943'(in the M-32RD section) 780'fish. G-4,5 •Hole Section MWT: •Approximate Rotating hrs: 0 17-1/2"to 1347'9.0 to 9.5 ppg o 16"120 hrs B-1 o 12-1/4"to 10588'9.3 to 10.1 ppg o 13-38"560 hrs B_2 o 8-1/2"to 10731'9.0 to 10.5 ppg o 9-5/8"694 hrs Q � o 6"to 13835'9.5 to 10.5 ppg o 7"272 hrs 1 1 Collapse In4-112"Slotted Perforation Details Part 1 E J Liner @ 10825' 241 Y 1-♦ Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Perf.Date Status Notes I" E7 7,372' 7,392' 6,969' 6,985' 20' 6 9/24/2012 Open 3-1/8"HC io r:3..."1,1,4...ma . TD=13,835'MD/9667'TVD Updated On/By:04/30/14 JLL 1 ng Bay Unit/Steehead Platform SCHEMATIC Well#: M-32RD Hiky�ra Alaska.LLC Completed: 10/17/10 Perforation Details Part 2 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Perf.Date Status Notes F5A 8,042' 8,056' 7,491' 7,502' 14' 6 4/26/2012 Isolated F11C 8,625' 8,645' 7,940' 7,955' 20' 6 3/19/2012 Isolated 3-1/8"SDP F13B 8,732' 8,756' 8,022' 8,040' 24' 6 2/4/2012 Isolated 3-1/8"SDP F14A 8,778' 8,793' 8,057' 8,068' 15' 6 7/17/2011 Isolated 2-7/8PJ Omega F15B 8,944' 8,974' 8,183' 8,206' 30' 6 5/24/2011 Isolated 3-1/8"SDP Expro F15C 9,008' 9,014' 8,232' 8,237' 6' 6 5/7/2011 Isolated 3-1/8"SDP Expro 2-7/8" PowerJet F16 9,072' 9,092' 8,281' 8,296' 20' 6 3/16/2011 Isolated Omega 1/29/11& 3/16/11 2-7/8" F16 9,092' 9,112' 8,296' 8,312' 20 6 3/17/2011 Isolated PowerJet Omega 3/17/11 2-1/2" 001 9,212' 9,248' 8,387' 8,413' 36' 5 10/19/2010 Isolated PowerSpiral guns 10/19/10 2-1/2" G05 9,500' 9,521' 8,593' 8,607' 21' 5 11/17/2009 Isolated PowerSpiral guns 11/17/09 4-5/8"TCP 01/2000& G-1 9,625' 9,665' 8,676' 8,700' 40' 18 12/14/2006 Isolated 12/2006 (perf'd 9645'- 9665') 4-5/8"TCP 01/2000& 0-2 9,697' 9,737' 8,700' 8,743' 40' 18 12/14/2006 Isolated 12/2006 (perfd 9714'- 9734') 4-5/8"TCP 01/2000& 0-4 9,915' 9,990' 8,847' 8,890' 75' 18 12/14/2006 Isolated 12/2006(perrd 9933'-9953'& 9970'-99901 4-5/8"TCP 01/2000& 0-5 10,060' 10,210' 8,931' 9,015' 150' 18 12/14/2006 Isolated 12/2006(perrd 10700'-10090', 10120'-10135'& 10180'-10195') 4-5/8"TCP 01/2000& 8-1 10,430' 10,480' 9,131' 9,156' 50' 18 12/14/2006 Isolated 12/2006 (pert'd 10430'- 10445') 4-5/8"TCP B-2 10,510' 10,530' 9,170' 9,180' 20' 18 12/14/2006 Isolated 01/2000& 12/2006 8-2 10,560' 10,570 9,193' 9,198' 10' 6 12/14/2006 Isolated 4-5/8"TCP 12/2006 B3-B7 10,694' 13,835' 9,227' 9,668' 3141' 1/1/2000 Isolated Slotted Liner Updated On/By:04/30/14 JLL I PROPOSED Trading Bay Unit/Steehead Platform Well #: M-32RD HBnorn Alaska.LLC Completed: 10/17/10 RKB=75.15'Rig Floor to TBG Head Casing&Tubing Detail Size Type Wt Grade Thrd ID Top Btm Hole 1 26" Conductor Surf 981' Driven 111 16" Surf Csg 75 K-55 BTC 15.1 Surf 1,347' 22" 1 3a 13-3/8" Csg 61 K-55 BTC 12.5 Surf 3,767' 17.5" az 2 9-5/8" Prod Csg 54 L-80 BTC 8.535 Surf 10,588' 12.25" jt 3b T A .°. MIMI 7" Liner 29 L-80 Butt&KC 6.184 9,301' 10,731' 8-1/2" °E tiltI 3c " 9 F. 1iis, •t 4-1/2" Slotted Liner 12.6 L-80 IBCodAB 3.958 10,694' 13,835' 6" ,.,� 13d ; i y IIPTUBING DETAIL/75.15'RKB to Tbg Hngr a3e ,INF `` s. 4-1/2" 12.6 L-80 TCII 3.96 Surf 5,450' 0 sji 3f - ti st_ 13g E x a ,} I '� I JEWELRY DETAIL ti a}.4 CEMENT DETAIL n" = NO. Depth ID Item<16)§ cmt Cmt Top 1 456' 3.813" SCSSV(TRSV) Cmt to Surf Calc TOC@ surf- 3a 1,563' 3.833" GLM(S1O-2) 1,933 sx assmd 20%loss - E7 2 2,010' 3.833" Chemical Injection Sub Returns to Surf Bumped Plug. 3b 2,643' 3.833" GLM(SFO-2) 2,244 sx Calc TOC @"671'assmd 20% TOC 't 6 t 3c 3,633' 3.833" GLM(SFO-2) loss 8,001' w, ,;,:A 3d 4,553' - 3.833" GLM(SFO-2) Returns to Surf.Calc TOC fl 6a 3e 5,355' 3.833" GLM(SFO-2) 2,607 sx @^2611'assmd 20%loss '' FSA 3f 6,062' 3.833" GLM(SFO-2) 72 bbls Calc TOC to liner top,w/assmd T' 3g 6,797' 3.833" GLM(SFO-2) 20%loss 4 6,861' 3.850" HES PHL Retrievable Packer i 2-1/2"x 1/16"slots,48/ft r I 1* 5 6,922' 3.813" X-Profile Nipple TOC lm a 5a 6,973' 3.70" Mech TbgRelease BOT Gun DropSub) 8,596'ELM S; Cas ( TOC °fr :S». F11C 6 7,750' 3.958 Tubing Tail 8,637'ELM • " `" 1 � 7a 6a 8,001' Neo Plug+2Tcement on top + all '"7b 6b 8,038' 560'Section of Cut Pipe 1+ F13B 7a 8,690' N/A Neo Plug 53'of cmt+12'sand+35'cmt r' , F14A 7b 8,720' N/A Neo Plug Toc @ 7c 8,890' N/A Plug w/40'of cement 8,830 ELM �� 5'� 7d 9,064' N/A Plug w/81'cement(TOC 8983') Toc @ . 7q F15B 8 9,284' N/A TTS umbrella plug w/cement on top 8,983 ELM ° ' 9 9,572' N/A EZSV Cement Retainer ' Fl5C TOC @ 9,015'ELM ^ Pressure Test Details as of 12/2/08 7d Set F16 Depth Results TOC @ - - r« Good Test 2000 psi to surface.55'above top of liner. 9,172'ELM �`` ) 9,245' 9-%"csg tested good.Could not get pkr to set in csg Toc igt',' w w x -.. G01 between 9245'&TOL. 9,252'SLM '°� ';ter „' 8 9,350' Bad.No test above or below. Collapse Csg 9,400' Bad.No test between pkr&BP. 9,299'(+/-) Cv3�z° t 9,480' Bad.No test between pkr&BP. Csg window - 'V 9,515' Good Test to 2000 psi.Between pkr&BP @ 9560'. Integrity Breach` G05 9,545' Good Test to 2000 psi.Between pkr&BP @ 9560'. 9245'to 9515' t` §•1Top of fill @ 9522' 11-16-09 Top of Cmt @9547' Brief Details& Info. «r-- g'.w 9 Spudded M-32RD on 11/15/99.Completed on 01/25/00. M-32RD was a drill out of M-32(window in the 9-5/8" Milled BP'"4 °•'VG-1,2 -9392'). 5 fish Were left in sidetrack holes while drilling the well: #1 @ 9682'"1226'fish. #2 @ 9564'-1088' �- -• 5, G 4fish. #3 @ 12418'"5'fish.#4 @ 11650'_300'fish. #5 @ 9943'(in the M-32RD section)"780'fish. ft pµ •Hole Section MWT: •Approximate Rotating hrs: g - 0 17-1/2"to 1347'9.0 to 9.5 ppg o 16"120 hrs -• a. B-1 0 12-1/4"to 10588'9.3 to 10.1 ppg o 13-38"560 hrs je,, B-2 o 8-1/2"to 10731'9.0 to 10.5 ppg o 9-5/8"694 hrs *4G'r • 0 6"to 13835'9.5 to 10.5 ppg o 7"272 hrs r#i' •� Collapse In 4-1/2"Slotted Perforation Details Part 1 E Liner@ 10825' g 1 • Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Perf.Date Status Notes E7 7,372' 7,392' 6,969' 6,985' 20' 6 9/24/2012 Open 3-1/8"HC $I : m� TD=13,835'MD/9667'TVD Updated On/By:04/30/14 JLL PRO POSED i rading Bay Unit/Steehead Platform . 11Well #: M-32RD Hilcorn Alaska.LLC Completed: 10/17/10 Perforation Details Part 2 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Perf.Date Status Notes F5A 8,042' 8,056' 7,491' 7,502' 14' 6 4/26/2012 Isolated F11C 8,625' 8,645' 7,940' 7,955' 20' 6 3/19/2012 Isolated 3-1/8"SDP F138 8,732' 8,756' 8,022' 8,040' 24' 6 2/4/2012 Isolated 3-1/8"SDP F14A 8,778' 8,793' 8,057' 8,068' 15' 6 7/17/2011 Isolated 2-7/r PJ Omega F15B 8,944' 8,974' 8,183' 8,206' 30' 6 5/24/2011 Isolated 3-1/8"SDP Expro F15C 9,008' 9,014' 8,232' 8,237' 6' 6 5/7/2011 Isolated 3-1/8"SDP Expro 2-7/8" PowerJet F16 9,072' 9,092' 8,281' 8,296' 20' 6 3/16/2011 Isolated Omega 1/29/11& 3/16/11 2-7/8" F16 9,092' 9,112' 8,296' 8,312' 20 6 3/17/2011 Isolated PowerJet Omega 3/17/11 2-1/2" 001 9,212' 9,248' 8,387' 8,413' 36' 5 10/19/2010 Isolated PowerSpiral guns 10/19/10 2-1/2" G05 9,500' 9,521' 8,593' 8,607' 21' 5 11/17/2009 Isolated PowerSpiral guns 11/17/09 4-5/8"TCP 01/2000& 0-1 9,625' 9,665' 8,676' 8,700' 40' 18 12/14/2006 Isolated 12/2006 (perf'd 9645'- 9665') 4-5/8"TCP 01/2000& 0-2 9,697' 9,737' 8,700' 8,743' 40' 18 12/14/2006 Isolated 12/2006 (perf'd 9714'- 9734') 4-5/8"TCP 01/2000& 0-4 9,915' 9,990' 8,847' 8,890' 75' 18 12/14/2006 Isolated 12/2006(pert'd 9933'-9953'& 9970'-9990') 4-5/8"TCP 01/2000& 0-5 10,060' 10,210' 8,931' 9,015' 150' 18 12/14/2006 Isolated 12/2006(perYd 10700'-10090', 10120'-10135'& 10180'-10195') 4-5/8"TCP 01/2000& B-1 10,430' 10,480' 9,131' 9,156' 50' 18 12/14/2006 Isolated 12/2006 (perf'd 10430'- 10445') 4-5/8"TCP B-2 10,510' 10,530' 9,170' 9,180' 20' 18 12/14/2006 Isolated 01/2000& 12/2006 B-2 10,560' 10,570 9,193' 9,198' 10' 6 12/14/2006 Isolated 4-5/8"TCP 12/2006 B3-B7 10,694' 13,835' 9,227' 9,668' 3141' 1/1/2000 Isolated Slotted Liner Updated On/By:04/30/14 JLL Steephead Platform . ll- M-32 Current Hilrnrp Alaeka,11.11A: 04/26/2014 Steelhead Platform Tbg hanger,FMC-TC-1A-EN- M-32 CCL,16%5M X 4 St Hydril 26%16X133/8%95/8% 563 lift and susp,w/4"Type 41/2 H BPV profile,2-3/8 continuous control line, 41055 material BHTA,Bowen, 4 1/16 5M FE X 7-55A Bowen top ra ,,g,' ''«0irra IIIIM Valve,Swab,WKM-M, p.411,7, 41/16 5M FE,HWO,DD Valve,wing,WKM-M, rtvr 41/165M FE,HW0,DD lir• lel:'rtal I Illi"N / Valve,upper master,SSV, 41/165M FE,w/15"Safeco O operator,EE 0 b ' Valve,Master,WKM-M, � i•r saivoive wing, 41/15M FE,HWO,DD :. •" 71 41/165M FE, /15"Safeco > V. operator,EE •r 11 r Tubing head,FMC-TC-60,spec for coil=r I , I i1 • • undbo,16X5Mt616 X5M - ,II - `` = std stdbottom,w/2- 21/16 5M 55O '' `' 301110148.2 i to i n's�xTw o- Valve,FMC-120, Unihead,FMC Type 2,16%5M 21/16 5M FE,HWO,M '3 FE top X 21%2M FMC speedlock bottom,w/4-2 1/16 5M SSO III III fi,IL; �� �. ii J �.I; .i.. Adapter spool,FMC-A-S-S 30"MSS •SI T.,.,,stddbottomX21%2M FMC I I- I�;,, speedlock top,w/2-2"LPO 4� }, — 'H"�= ai 4. I Starting head,FMC,30"MSS �� �I in Anon FE%26'butt weld sa 0, ■'26" 16" 13 3/8" 9 5/8" 41/2 • Schwartz, Guy L (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Thursday, May 01, 2014 1:17 PM To: Schwartz,Guy L(DOA) Subject: RE: M-32 Sundry Application 7-7) I Yes, M-34 is where they moved to. I was told I would have plenty of time to get this job (M-32) away but then the drilling change happened from A-31 to M-34. We are now looking at doing it before drilling gets going on M-34. Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, May 01, 2014 1:03 PM To: Ted Kramer Subject: RE: M-32 Sundry Application Ted, Is this is due to the rig crews moving from the Monopod on short notice (A-31 issues)? Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From:Ted Kramer [mailto:tkramer@hilcorp.com] Sent:Thursday, May 01, 2014 12:58 PM To: Schwartz, Guy L(DOA) Subject: M-32 Sundry Application Guy, a Theabove Sundry was sent over to the AOGCC yesterday via courier. This is a zu gal abandonment for a well we believe is cross flowing sub-surface and affecting other gas prospects which show to be productive on the logs, but are wet when we perf them. Therefore,stopping this cross flow is a high priority. To further complicate things,drilling moving to M-34 has created a short window to get this pump job completed. Any help expediting the approval of the Sundry would be appreciated. If you would like to discuss it in more depth, please give me a call. Respectfully, Ted Kramer Sr. Operations Engineer P g Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 2 Fisher, Samantha J (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday,June 25, 2013 4:35 PM To: Fisher, Samantha J (DOA) Subject: FW: Sundry Cancellation -#312-488 for Steelhead M-32RD (PTD 199-097) Guy Schwartz SCANNED FEB 2 0 2014 Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Juanita Lovett [mailto:jlovettfthilcorp.com] Sent: Tuesday, June 25, 2013 4:21 PM To: Schwartz, Guy L(DOA) Subject: Sundry Cancellation - #312-488 for Steelhead M-32RD (PTD 199-097) Guy, Please cancel sundry#312-488 for Steelhead M-32RD. This project will not be completed and we wanted to close the sundry with the commission. Thank you, Juanita Lovett Sr.Operations/Regulatory Tech Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 100 Anchorage,AK 99503 Office: (907)777-8332 Email: ilovett@hilcorp.com 1 ..OF T� • • \ �� 9 THE STATE �� Alaska Oil and Gas F = f�LA0 -,K.� Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue O. Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 � �� Ted Kramer L g �i +�� Fax: 907.276.7542 C�� �E G Q © n / J Sr. Operations Engineer Hilcorp Alaska, LLC `/ 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil, Middle Kenai G Oil & Middle Kenai G Gas Pools, Trading Bay Unit M -32RD Sundry Number: 312 -488 Dear Mr. Kramer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As P Y rovided 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. , - - ely John . • an m' .'.ner DATED this g day of January, 2013. Encl. 1 • . • • RECEIVED STATE OF ALASKA DEC 2 12 7 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ° A 8G 20 MC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate O Pull Tubing El Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing Cl Other. ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development p= 199 -097 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number. Anchorage, AK 99503 50- 733 - 20462 -01 ■ 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 228 Trading Bay Unit M-32RD " Will planned perforations require a spacing exception? Yes ❑ No El 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0018730 McArthur River Field / Hemlock Oil, Middle Kenai G Oil & Middle Kenai G Gas Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 13,835 • 9,667 I ' 8,001 7,460 ' 8,001 N/A Casing Length Size MD TVD Burst Collapse Conductor 981' 28" 981' 981' Surface 1,347' 16" 1,347' 1,347' 2,630 psi 1,020 psi Intermediate 3,767' 13 -3/8" 3,767' 3,766' 3,090 psi 1,540 psi Production 10,588' 9 -5/8" 10,588' 9,206' 7,930 psi 6,620 psi Liner 1,430' 7" 10,731' 9,266' 8,160 psi 7,020 psi Liner 3,141' 4 -1/2" (slotted) 13,835' 9,668' slotted slotted Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 4 -1/2" 12.6# L -80 5,450' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): HES PHL Retrievable Packer & TRSV SCSSV Packer 6,861' (MD) 6,571' (ND) and SCSSV 456' (MD) 456' (ND) 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic ❑ Development 12 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 2/1/2013 Commencing Operations: Oil ❑ Gas El WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramerthilcorp.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature 4 ! � Phone 907 - 777 -8420 Date 12/26/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 1 2_ U 8 Plug Integrity ❑ BOP Test L Mechanical Integrity Test ❑ Location Clearance ❑ Other: 0O /" 1- C 5 J-U Z C7U0 5 < RBDMS JAN 0 4 2013 Spacing Exception Required? Yes L✓I No • -' . uent Form Required: a • APPROVED BY Approved by: COMMISSIONER /gA5 THE COMMISSION Date: r ir )Z/ `',f' , i Submit Form and , O L Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • \� • Well Work Plan Well: M -32RD Hilcora Alaska, LL1 Date: 12/26/2012 Well Name: M -32RD API Number: 50- 733 - 20462 -01 Current Status: SI Gas Producer Leg: Leg B1, NW Corner Slot #10 Estimated Start Date: February 1, 2013 Rig: Steelhead Rig 51 Reg. Approval Req'd: January 10, 2013 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 199 -097 First Call Engineer: Ted Kramer (907) 777 -8420 (0) (985) 867 -0665 (M) Second Call Engineer: Mike Dunn (907) 777 -8382 (0) (907) 351 -4191 (M) AFE Number: Current Bottom Hole Pressure: 1,874 psi @ 6,985' TVD (From 09 -27 -12 survey) Maximum Expected BHP: 1,837 psi @ 4,200' TVD Max. Anticipated Surface Pressure: 1,417 psi (Using 0.1 psi /ft to surface) Well Summary M -32RD was completed in its current configuration as a gas producer in October of 2010. The completion plan for this well was to perforate the well in the E7 zone (See Current Perforations) to determine if it was productive for gas. This completion was executed as planned but the well tested wet. Closer inspection of the results suggested that there may be a casing leak somewhere between the E -7 perforations and the packer. Forward Plan: The workover plan for this well is to pull the completion packer and set a plug above the E -7 perforations. Next is to run a casing inspection log to look for a casing leak. Once repaired, run a completion packer and perforate in the D sand. Procedure: 1. MIRU Steelhead Rig # 51. 2. ND wellhead and NU BOP stack. Pressure test BOP to 250 psi. low / 2,000 psi high. Note: notify AOGCC 48 hours in advance of test for the opportunity to witness bop test. 3. Kill well with 6% KCL. 4. Pull Tubing and Retrievable packer out of well. 5. RU E -line. RIH with CIBP and set at 7,365'. 6. POOH with Eline and pick up Casing inspection log. RIH to CIBP. Log well from 7,365 to surface. 7. If casing leak is found go to step 8. If not, go to step 12. 8. PU test packer and RIH to just above casing leak. Set packer and establish pump in rate (PIR). 9. If PIR is sufficient, PU EZdrill cement retainer and RIH to 10' above casing leak. Set CMT retainer and establish pump in rate. Well Work Plan Well: M -32RD Hilrnra Alaska, 1,1,1 Date: 12/26/2012 10. Pump Cement squeeze as directed in cement squeeze procedure. Sting out of cement retainer and place 50' of cement on top of the retainer. POOH and WOC. 11. Pressure test casing to 1,900 psi. E-- 12. RIH with bit and drill cement and retainer out to 7,360'. POOH. 13. PU and RIH with Production Packer on 4 -1/2" tubing and set at 4,180'. 14. ND BOP, NU wellhead and test. 15. RD MO drilling Rig. 16. RU E -line and RIH with perf guns and perforate as noted below.These perforations may vary slightly pending completion of log analysis. Top Base Zone Perf Perf D12 ±5,702' ±5,719' D14 ±5,960' ±5,975' D17 ±6,230' ±6,245' 17. Turn well over to production. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematics III - filling Bay Unit/ Steehead Platform SCHEMATIC Well #:M -32RD uatnte a►,.k;t. I.I.Q Completed: 10/17/10 RKB = 75.15' Rig Floor to TBG Head Casing & Tubing Detail Size Type Wt Grade Thrd ID Top Btm Hole 1 26" Conductor Surf 981' Driven 16" Surf Csg 75 K -55 BTC 15.1 Surf 1,347' 22" 13 -3/8" Csg 61 K -55 BTC 12.5 Surf 3,767' 17.5" ji 3a 1 1 9 -5/8" Prod Csg 54 L -80 BTC 8.535 Surf 10,588' 12.25" ' 2 4 1 1 3b , 7 " Liner 29 L -80 Butt & KC 6.184 9,301' 10,731' 8 -1/2" io L' , ... 4 -1/2" Slotted Liner 12.6 L -80 IBCodA6 3.958 10,694' 13,835' 6" oM 3c TUBING DETAIL / 75.15' RKB to Tbg Hngr 3d 4 -1/2" 12.6 L -80 TCII 3.96 Surf 5,450' _e 3e $0 3't 1E JEWELRY DETAIL CEMENT DETAIL a 2 : E___ M_ NO. Depth ID Item Cmt Cmt Top 1 456' 3.813" SCSSV (TRSV) Cmt to Surf Calc TOC@ surf - Sa 3a 1,563' 3.833" GLM (5F0-2) 1,933 sx assmd 20% loss " E 2 2,010' 3.833" Chemical Injection Sub Returns to Surf Bumped Plug. 6 3b 2,643' 3.833" GLM (SFO -2) 2,244 sx Calc TOC @"'671' assmd 20% TOC @ 3c 3,633' 3.833" GLM (SFO -2) loss 8,001' 3d 4,553' 3.833" GLM (SFO -2) Returns to Surf. Calc TOC 6a 3e 5,355' 3.833" GLM (SFO -2) 2,607 sx @'"2611' assmd 20% loss 4 6,861' 3.850" HES PHL Retrievable Packer Calc TOC to liner top, w /assmd F5A 5 6,922' 3.813" X- Profile Nipple 72 bbls 20 %loss 6b 5a 6,973' 3.70" Mech Tbg Release (BOT Gun Drop Sub) 2.1/2" x 1/16" slats, 48/ft 6 7,750' 3.958 Tubing Tail TOC @ 6a 8,001' Neo Plug+ 27'cement on top 8,596'ELM TOC @ F11C 6b 8,038' 560' Section of Cut Pipe 8,637'ELM 7 7a 8,690' N/A Neo Plug 53' of cmt +12'sand +35' cmt Oa 7b 7b 8,720' N/A Neo Plug F13B 7c 8,890' N/A Plug w/ 40' of cement 7d 9,064' N/A Plug w/ 81' cement (TOC 8983') TOC @ F14A 8 9,284' N/A TTS umbrella plug w/ cement on top 8,830'ELM 9 9,572' N/A EZSV Cement Retainer TOC @ F15B 8,983' ELM TOC @ F15C Pressure Test Details as of 12/2/08 9,015'ELM Set 7d Depth Results ®B F16 Good Test 2000 psi to surface. 55' above top of liner. TOC @ 9,245' 9 - %" csg tested good. Could not get pkr to set in csg 9,172' ELM between 9245' & TOL. G01 9,350' Bad. No test above or below. 9,252'SLM ` tl :8 9,400' Bad. No test between pkr & BP. 9,480' Bad. No test between pkr & BP. Collapse Csg 9,515' Good Test to 2000 psi. Between pkr & BP @ 9560'. Csg Window -- 9,299' ( +1 -) 9,545' Good Test to 2000 psi. Between pkr & BP @ 9560'. (0,9392' 005 Integrity Breach 9245' to 9515' Top of fill @ 9522' 11 -16 -09 Brief Details & Info. Top of Cmt @9547' ' o=.48 - 9 Spudded M -32RD on 11/15/99. Completed on 01/25/00. M -32RD was a drill out of M -32 (window in the 9 -5/8" Milled BP G-1,2 "'9392'). 5 fish Were left in sidetrack holes while drilling the well: #1 @ 9682' ` 1226' fish. #2 @ 9564' "' 1088' fish. #3 @ 12418' 5' fish. #4 @ 11650' 300'fish. #5 @ 9943' (in the M -32RD section) — 780' fish. G-4,5 • Hole Section MWT: • Approximate Rotating hrs: 0 17 -1/2" to 1347' 9.0 to 9.5 ppg o 16" 120 hrs B -1 0 12 -1/4" to 10588' 9.3 to 10.1 ppg o 13 -38" 560 hrs B 2 0 8 -1/2" to 10731' 9.0 to 10.5 ppg o 9 -5/8" 694 hrs ■ - Q � nili 0 6" to 13835' 9.5 to 10.5 ppg o 7" 272 hrs _ Collapse in4 -112 " Slotted Perforation Details Part 1 is 1 °'" . Liner @ 10825' Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Perf. Date Status Notes E 7,372' 7,392' 6,969' 6,985' 20' 6 9/24/2012 Open 3 -1/8" HC *b , y p TD = 13,a36'MDf9667'TVD Updated On/ By: 10/08/2012 JLL • ping Bay Unit/ Steehead Platform ., H SCHEMATIC Well #: M -32RD Completed: 10/17/10 Hilcoro Alaska. LLC Perforation Details Part 2 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Perf. Date Status Notes FSA 8,042' 8,056' 7,491' 7,502' 14' 6 4/26/2012 Isolated F11C 8,625' 8,645' 7,940' 7,955' 20' 6 3/19/2012 Isolated 3 - 1/8" SDP F138 8,732' 8,756' 8,022' 8,040' 24' 6 2/4/2012 Isolated 3 - 1/8" SDP F14A 8,778' 8,793' 8,057' 8,068' 15' 6 7/17/2011 Isolated 2 PJ Omega F15B 8,944' 8,974' 8,183' 8,206' 30' 6 5/24/2011 Isolated 3 - 1/8" SDP Expro F15C 9,008' 9,014' 8,232' 8,237' 6' 6 5/7/2011 Isolated 3 - 1/8" SDP Expro 2 -7/8" PowerJet F16 9,072' 9,092' 8,281' 8,296' 20' 6 3/16/2011 Isolated Omega 1/29/11 & 3/16/11 2 -7/8" F16 9,092' 9,112' 8,296' 8,312' 20 6 3/17/2011 Isolated PowerJet Omega 3/17/11 2 -1/2" 601 9,212' 9,248' 8,387' 8,413' 36' 5 10/19/2010 Isolated PowerSpiral guns 10/19/10 2 -1/2" GO5 9,500' 9,521' 8,593' 8,607' 21' 5 11/17/2009 Isolated PowerSpiral guns 11/17/09 4 -5/8" TCP 01/2000 & 0-1 9,625' 9,665' 8,676' 8,700' 40' 18 12/14/2006 Isolated 12/2006 (pert d 9645'- 9665') 4 -5/8" TCP 01/2000 & G -2 9,697' 9,737' 8,700' 8,743' 40' 18 12/14/2006 Isolated 12/2006 (perf'd 9714'- 9734') 4-5/8" TCP 01/2000 & G 9,915' 9,990' 8,847' 8,890' 75' 18 12/14/2006 Isolated 12/2006 (perfd 9933' -9953' & 9970'- 99901 4-5/8 " TCP 01/2000 & 6 10,060' 10,210' 8,931' 9,015' 150' 18 12/14/2006 Isolated 12/2006 (perPd 10700' - 10090', 10120' - 10135' & 10180' - 101951 4 -5/8" TCP 01/2000 & B -1 10,430' 10,480' 9,131' 9,156' 50' 18 12/14/2006 Isolated 12/2006 (per('d 10430'- 10445') 4 -5/8" TCP 8-2 10,510' 10,530' 9,170' 9,180' 20' 18 12/14/2006 Isolated 01/2000 & 12/2006 B -2 10,560' 10,570 9,193' 9,198' 10' 6 12/14/2006 Isolated 4-5/8" TCP 12/2006 B3 -B7 10,694' 13,835' 9,227' 9,668' 3141' 1/1/2000 Isolated Slotted Liner Updated On/ By: 10/08/2012 AL • -..ling Bay Unit/ Steehead Platform • II PROPOSED Well #: M -32RD Completed: 10/17/10 Hileoru Alaska. LLC RKB = 75.15'Rig Floor to TBG Head Casing & Tubing Detail i iii '-,. Type- Wt Grade Thrd ID Top Btm Hole 1 26" Conductor Surf 981' Driven 16" Surf Csg 75 K -55 BTC 15.1 Surf 1,347' 22" 17.5" 13 - 3/8" Csg 61 K -55 BTC 12.5 Surf 3,767' 3a 9 - 5/8" Prod Csg 54 L -80 BTC 8.535 Surf 10,588' 12.25" .4-3g 2 7" Liner 29 L -80 Butt & KC 6.184 9,301' 10,731' 8 -1/2" t ` til 3b IBTC AB 8 L 4 -1/2" Slotted Liner 12.6 L -80 mod 3.958 10,694' 13,835' 6" 4ILE CFA - * 4 TUBING DETAIL/75.15' RKB to Tbg Hngr 4 -1/2" 12.6 L -80 TCII 3.96 Surf 4,180' _ . 3 = , E. JEWELRY DETAIL g 5 - D12 is o . D14 NO. Depth ID Item a ° - 8 e$8 , D17 1 456' 3.813" SCSSV (TRSV) , t - , • , 3a 1,563' 3.833" GLM (SFO -2) • - 2 2,010' 3.833" Chemical Injection Sub E7 3b 2,643' 3.833" GLM (SFO -2) 4 4,180' 3.850" HES PHL Retrievable Packer TOC @ 5 4,211' 3.958" Wireline entry guide 8,001' ' 6a 5a 7,365' CIBP + 25'cement on top 6a 8,001' Neo Plug + 27'cement on top F5A 6b 8,038' 560' Section of Cut Pipe D6b 7a 8,690' N/A Neo Plug 53' of cmt +12'sand +35' cmt TOC @ 7b 8,720' N/A Neo Plug 6,596'ELM 7c 8,890' N/A Plug w/ 40' of cement TOC LS ° F11C 7d 9,064' N/A Plug w/ 81' cement (TOC 8983') 8,637'ELM = • ' - - ` 7a 8 9,284' N/A TTS umbrella plug w/ cement on top 8/16 - 71) 9 9,572' N/A EZSV Cement Retainer F13B ' F14A Pressure Test Details as of 12/2/08 CEMENT DETAIL 8,830 ELM Cmt Cmt Top . Set Results TOC i F15B Depth 1,933 sx Cmt to Surf Calc TOC@ surf - 8,983'ELM ( Good Test 2000 psi to surface. 55' above top of liner. assmd 20% loss F15C 9,245' 9 - %" csg tested good. Could not get pkr to set in csg Returns to Surf Bumped Plug. TOC 9,015'ELM between 9245' & TOL. 2,244 sx Calc TOC @ "671' assmd 20% 7d 9,350' Bad. No test above or below. loss 9,400' Bad. No test between pkr & BP. 2,607 sx Returns to Surf. Calc TOC F16 9,480' Bad. No test between pkr & BP. @"2611' assmd 20% loss TOC i 9,515' Good Test to 2000 psi. Between pkr & BP @ 9560'. 72 bbls Calc TOC to liner top, w /assmd 9,172' ELM 9,545' Good Test to 2000 psi. Between pkr & BP @ 9560'. 20 %loss TOC @ Ca01 2 - 1/2" x 1/16" slots, 48/ft 9,252'SLM Latt, 8 Colla Cs Brief Details & Info. C sg Window 9,299' ( + /-) @9392' Spudded M -32RD on 11/15/99. Completed on 01/25/00. M -32RD was a drill out of M -32 (window in the 9 -5/8" Integrity Breach G05 - 9392 5 fish Were left in sidetrack holes while drilling the well: #1 @ 9682' " 1226' fish. #2 @ 9564' " 1088' 9245' to 9515' .. Top of fill @ 9522' I 11 - 16 - 09 fish. #3 @ 12418' " 5' fish. #4 @ 11650'' 300'fish. #5 @ 9943' (in the M -32RD section) - 780' fish. 1 Top of Cmt 9547' • Hole Section MWT: • Approximate Rotating hrs: 1 . �--} 9 0 17 -1/2" to 1347' 9.0 to 9.5 ppg o 16" 120 hrs Milled BP i G -1,2 o 12 -1/4" to 10588' 9.3 to 10.1 ppg o 13 -38" 560 hrs o 8 -1/2" to 10731' 9.0 to 10.5 ppg o 9 -5/8" 694 hrs G 0 6" to 13835' 9.5 to 10.5 ppg o 7" 272 hrs i B Perforation Details Part 1 4= t 8 - Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) amt 5PF Perf. Date Status Notes D12 +/- 5,702' +/- 5,719' ±5,629' ±5,644' +/- 17 6 Future 1 Collapse in D14 +/- 5,960' +/- 5,975' ±5,854" ±5,867' +/- 15 6 Future e 1 4-1 D17 +/- 6,230' +/- 6,245' ±6,080" ±6,092' +/- 15 6 Future 1 10,825' Slotted ier E7 7,372' 7,392' 6,969' 6,985' 20' 6 9/24/2012 Open 3 -1/8" HC _° r 1 1 TD = 13,835'MD/9667'TVD Updated On/ By: 12/27/2012 JLL • ding Bay Unit/ Steehead Platform PROPOSED Well #: M -32RD H Completed: 10/17/10 ilcoru Alaska. LLC Perforation Details Part 2 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Perf. Date Status Notes F5A 8,042' 8,056' 7,491' 7,502' 14' 6 4/26/2012 Isolated F11C 8,625' 8,645' 7,940' 7,955' 20' 6 3/19/2012 Isolated 3 -1/8" SDP F138 8,732' 8,756' 8,022' 8,040' 24' 6 2/4/2012 Isolated 3 -1/8" SDP F14A 8,778' 8,793' 8,057' 8,068' 15' 6 7/17/2011 Isolated 2 -7/8" PJ Omega F158 8,944' 8,974' 8,183' 8,206' 30' 6 5/24/2011 Isolated 3 - 1/8" SDP Expro F15C 9,008' 9,014' 8,232' 8,237' 6' 6 5/7/2011 Isolated 3 - 1/8" SDP Expro 2 -7/8" PowerJet F16 9,072' 9,092' 8,281' 8,296' 20' 6 3/16/2011 Isolated Omega 1/29/11 & 3/16/11 2 -7/8" F16 9,092' 9,112' 8,296' 8,312' 20 6 3/17/2011 Isolated Powerlet Omega 3/17/11 2 -1/2 001 9,212' 9,248' 8,387' 8,413' 36' 5 10/19/2010 Isolated PowerSpiral guns 10 /19/10 2 -1/2" G0S 9,500' 9,521' 8,593' 8,607' 21' 5 11/17/2009 Isolated PowerSpiral guns 11/17/09 4-5/8" TCP 01/2000 & 6-1 9,625' 9,665' 8,676' 8,700' 40' 18 12/14/2006 Isolated 12/2006 (perPd 9645'- 9665') 4-5/8" TCP 01/2000 & 0-2 9,697' 9,737' 8,700' 8,743' 40' 18 12/14/2006 Isolated 12/2006 (perPd 9714'- 9734') 4-5/8" TCP 01/2000 & G-4 9,915' 9,990' 8,847' 8,890' 75' 18 12/14/2006 Isolated 12/2006 (perrd 9933'.9953'& 9970'- 99900 4-5/8" TCP 01/2000 & 6-5 10,060' 10,210' 8,931' 9,015' 150' 18 12/14/2006 Isolated 12/2006 (pert' d 10700'-10090', 10120'-10135' & 10180'- 10195'I 4-5/8" TCP 01/2000 & 8-1 10,430' 10,480' 9,131' 9,156' 50' 18 12/14/2006 Isolated 12/2006 (perPd 10430'- 10445') 4-5/8" TCP 8 -2 10,510' 10,530' 9,170' 9,180' 20' 18 12/14/2006 Isolated 01/2000 & 12/2006 B -2 10,560' 10,570 9,193' 9,198' 10' 6 12/14/2006 Isolated 45/8" TCP 12/2006 83 -87 10,694' 13,835' 9,227' 9,668' 3141' 1/1/2000 Isolated Slotted Liner i Updated On/ By: 12/27/2012 JLL • • • ' • a Steelhead Platform 16 3 /4 5M BOP (Oil Leg) M -32RD nilr4rr . 1.Ia.Ae. 1.11. Began of pan Ipl Ill e.]3 2Z' pipe for air boot flanges 9.43 2623 Mom pool dear to ra ma Ill 41 Iii Ill Ili 5.10' Hydril n o s ,u 5.48' Moonpool desktop to wellhead roan mare 5393 11 11 111 ! I 1 Top M'Zerd sea 9 W' . I II iur 4111,1111 : in 1 �• 10 300' F SF�FJJ[ I.i1■ 3.58' DSA16%10MX16 %5M .66' •,l ,1,1t 1 e5Ienoe more ra.pemp Re sub protro Riser, 16 % 5M API hub X 16 3/4 10M FE upuerwenrmd Room m Ra sub Gretna 2383 538 damp ebwemm Upper wemem room mar Riser, 16 %5M FEX 16 % SM API hub Ito Fo wemeee Poor wellhead I I -- !!'t A 106 . .1. 41 i T 1T "ICI �I 7 17 • • Bettis, Patricia K (DOA) From: Judy Stanek Ustanek @hilcorp.com] Sent: Friday, December 28, 2012 3:14 PM To: Bettis, Patricia K (DOA) Cc: Ted Kramer; Davies, Stephen F (DOA) Subject: Application for Sundry Approval: TBU M -32RD Attachments: M -32RD Mid Kenai Gas Pool.pdf Patricia, Attached, please find a map showing wells producing or capable of producing from the McArthur River Field, Middle Kenai Gas Pool. Since 2009, the M -32RD well has produced from the Middle Kenai Gas Pool. Our understanding is that additional perforations into this same pool would not require a spacing exception. Thanks for your review, Judy Judy Stanek, CPL Landman Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Ph: 907.777.8341 jstanekPhilcorp.com 1 Middle Kenai Gas Pool Wells M -1E 0 11-06 M 3=12° K-05 I J 6,2, F ■ T9N R13W ■ ADL 17594 �,� section 28 • 10 Ac re s ADL 18730 i G-12 X 21-02 T9N R13W Section 29 M ♦ Mnd • M -,5120 6 WO , o+ 0-192121 12-12 M -10 0d3 • OP Bi Section 32 Steelhead Platform '' T9N R13W Section 33 0 j M -13 7t I • au II•S s 11 Mat M0.CORP ALASKA, LLC ER FIELD Mnl GRAYLING OAS BANOS WELLS one .un,ro ®wo.r4 v x r.. ° I�Y�O FEET M40 wit 1 ro .w.. 3 * w.n cnwA ■ . • Bettis, B Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Friday, December 28, 2012 11:20 AM To: 'tkramer @hilcorp.com' Subject: Application for Sundry Approval: TBU M -32RD Good morning Ted, I started to review Hilcorp's sundry application for the TBU M -32RD well this morning. From the application, Hilcorp plans to run a completion packer and perforate in the D sand, zones D12, 014 and D17. Rule 1 of Conservation Order 228 established a ten acre well spacing requirement for the Middle Kenai Gas Pool. I would appreciate receiving a map of the Middle Kenai Gas Pool for Section 28, Township 9 N, Range 13 W, S.M. that shows the wellbore trace and perforation intervals of wells completed or capable of producing in the same pool as TBU M -32RD within 10 -acre blocks of the TBU M -32RD well bore. If you have any questions, please do not hesitate to call me. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793 -1238 1 T STATE OF ALASKA OCT 1 9 2012 AAA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations Wi Perforate El Other ❑ Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WeII❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development El Exploratory ❑ 199 -097 3. Address: 3800 Centerpoint Drive, Suite 100 StratigraphiC ❑ Service ❑ 6. API Number: Anchorage, AK 99503 50- 733 - 20462 -01 ✓ 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL018730 — Trading Bay Unit M -32RD `- 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): ,. N/A McArthur River Field / Hemlock Oil, Middle Kenai G Oil & Middle Kenai Gas Pools 11. Present Well Condition Summary: Total Depth measured 13,835 feet Plugs measured 8,001 feet true vertical 9,667 feet Junk measured N/A feet Effective Depth measured 8,001 feet Packer measured 6,861 feet true vertical 7,460 feet true vertical 6,571 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 981' 26" 981' 981' Surface 1,347' 16" 1,347' 1,347' 2,630 psi 1,020 psi Intermediate 3,767' 13 -3/8" 3,767' 3,767' 3,090 psi 1,540 psi Production 10,588' 9 -5/8" 10,588' 9,206' 7,930 psi 6,620 psi Liner 1,430' 7" 10,731' 9,266' 8,160 psi 7,020 psi Liner 3,141' 4 -1/2" (slotted) 13,835' 9,668' D �( 9+� slotted slotted Perforation depth Measured depth See Schematic feet SCAN NE ,AN 1 � 1 "�' True Vertical depth See Schematic feet r� / Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 8,302' 7,690' 6,861' (MD) 456' (MD) Packers and SSSV (type, measured and true vertical depth) HES PHL Retrievable Packer 6,571' (TVD) SCSSV / TRSV 456' (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 730 532 Subsequent to operation: 0 0 505 920 475 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas J WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUGO 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Ted Kramer Email tkramerl�hilcorp.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature l C Phone 907 - 777 -8420 Date 10/19/2012 OCT 2 2012 Form 10-404 Revised 10 2 e �°/ y) \;‘,.\--- \ - - 7.-- ; #0 2._ Submit Original Only •ng Bay Unit/ Steehead Platform SCHEMATIC Well #: M -32RD tsu .n Alaska. IAA Completed: 10/17/10 RKB = 75.15'Rig Floor to TBG Head , Casing & Tubing Detail Size Type Wt Grade Thrd ID Top Btm Hole 1 26" Conductor Surf 981' Driven , i . 16" Surf Csg 75 K -55 BTC 15.1 Surf 1,347' 22" 13 -3/8" Csg 61 K -55 BTC 12.5 Surf 3,767' 17.5" il 3a 9 -5/8" Prod Csg 54 L -80 BTC 8.535 Surf 10,588' 12.25" 2 � 9 3b 7„ Liner 29 L -80 Butt & KC 6.184 9,301' 10,731' 8 -1/2" P ^ L 3 C 4 -1/2" Slotted Liner 12.6 L -80 IB�CodAB 3.958 10,694' 13,835' 6" TUBING DETAIL / 75.15' RKB to Tbg Hngr id 3d 4 -1/2" 12.6 L -80 TCII 3.96 Surf 5,450' 4 3e a rir I P / ✓ JEWELRY DETAIL CEMENT DETAIL If B 2 _ , yNK NO. Depth ID Item 8@ Cmt Cmt Top 5 1 456' 3.813" SCSSV (TRSV) Sa 3a 1,563' 3.833" GLM 1,933 sx Cmt to Surf Calc TOC@ surf - ( ) assmd 20% loss P SF0 -2 E7 2 2,010' 3.833" Chemical Injection Sub Returns to Surf Bumped Plug. 6 3b 2,643' 3.833" GLM (SFO -2) 2,244 sx Calc TOC @"671' assmd 20% TOC @@@��� 3c 3,633' 3.833" GLM (SF0 -2) loss 8,00 3d 4,553' 3.833" GLM (SF0 -2) Returns to Surf. Calc TOC 6a 3e 5,355' 3.833" GLM (5E0 -2) 2,607 sx @ - 2611' assmd 20% loss 4 6,861' 3.850" HES PHL Retrievable Packer Calc TOC to liner top, w /assmd _ F5A 72 bbls 5 6,922' 3.813" X- Profile Nipple 20 %loss ((----• 6b 5a 6,973' 3.70" Mech Tbg Release (BOT Gun Drop Sub) 2 -1/2" x 1/16" slots, 48/ft 6 7,750' 3.958 Tubing Tail TOC @ 6a 8,001' Neo Plug + 27'cement on top 8,596'ELM TOC @ ' F11C 6b 8,038' 560' Section of Cut Pipe 8,637'ELM 7 7a 8,690' N/A Neo Plug 53' of cmt +12'sand +35' cmt - - 7b 7b 8,720' N/A Neo Plug : F13B 7c 8,890' N/A Plug w/ 40' of cement 7d 9,064' N/A Plug w/ 81' cement (TOC 8983') TOC @ : F14A 8 9,284' N/A TTS umbrella plug w/ cement on top 8,830'ELM 9 9,572' N/A EZSV Cement Retainer IS TOC @ F15B 8,983'ELM ?; - F15C Pressure Test Details as of 12/2/08 9,015' ELM Set Results Q 7d Depth in = F16 Good Test 2000 psi to surface. 55' above top of liner. TOC @ 9,245' 9 - %" csg tested good. Could not get pkr to set in csg 9,172' ELM l between 9245' & TOL. TOC @ = GO1 9,350' Bad. No test above or below. 9,252'SLM 8 9,400' Bad. No test between pkr & BP. Collapse Csg 9,480' Bad. No test between pkr & BP. 9 299 (+1 (M9392' 9,545' 9,515' Good Test to 2000 psi. Between pkr & BP @ 9560'. Csg window i� 9,545' Good Test to 2000 psi. Between pkr & BP @ 9560'. G05 Integrity Breach 9245' to 9515' Top of fill @ 9522' 11 -16 -09 Brief Details & Info. Top of Cmt @ 9547' 9 Spudded M -32RD on 11/15/99. Completed on 01/25/00. M -32RD was a drill out of M -32 (window in the 9 -5/8" Mined BP _ G -1,2 '"9392'). 5 fish Were left in sidetrack holes while drilling the well: #1 @ 9682' - 1226' fish. #2 @ 9564' - 1088' I fish. #3 @ 12418''" 5' fish. #4 @ 11650''" 300'fish. #5 @ 9943' (in the M -32RD section) - 780' fish. G -4,5 • Hole Section MWT: • Approximate Rotating hrs: o 17 -1/2" to 1347' 9.0 to 9.5 ppg o 16" 120 hrs B -1 0 12 -1/4" to 10588' 9.3 to 10.1 ppg o 13 -38" 560 hrs B 2 o 8 -1/2" to 10731' 9.0 to 10.5 ppg o 9 -5/8" 694 hrs QA o 6" to 13835' 9.5 to 10.5 ppg o 7" 272 hrs I l z .' Collapse in 4-1/2" Slotted Perforation Details Part 1 Liner @ 10825' 9 g Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Perf. Date Status Notes i E6 +/- 7,340' +/- 7,346' ±7,087' ±7,092' +/- 6' 6 Future ig E7 7,372' 7,392' 20' 6 9/24/2012 Open 3 -1/8" HC TD = 13,835'MD/9667'TVD Updated On/ By: 10/08/2012 JLL H . Tilling Bay Unit/ Steehead Platform . H SCHEMATIC well #: M -32RD Completed: 10/17/10 Hilcorn Alaska. LLC Perforation Details Part 2 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Perf. Date Status Notes F5A 8,042' 8,056' 7,491' 7,502' 14' 6 4/26/2012 Isolated F11C 8,625' 8,645' 7,940' 7,955' 20' 6 3/19/2012 Isolated 3 - 1/8" SDP F13B 8,732' 8,756' 8,022' 8,040' 24' 6 2/4/2012 Isolated 3 - 1/8" SDP F14A 8,778' 8,793' 8,057' 8,068' 15' 6 7/17/2011 Isolated 2 PJ Omega F15B 8,944' 8,974' 8,183' 8,206' 30' 6 5/24/2011 Isolated 3 - 1/8" SDP Expro F15C 9,008' 9,014' 8,232' 8,237' 6' 6 5/7/2011 Isolated 3 - 1/8" SDP Expro 2-7/8" PowerJet F16 9,072' 9,092' 8,281' 8,296' 20' 6 3/16/2011 Isolated Omega 1/29/11 & 3/16/11 2 -7/8" F16 9,092' 9,112' 8,296' 8,312' 20 6 3/17/2011 Isolated PowerJet Omega 3/17/11 2 -1/2" 001 9,212' 9,248' 8,387' 8,413' 36' 5 10/19/2010 Isolated Powerspiral guns 10/19/10 2 -1/2" G05 9,500' 9,521' 8,593' 8,607' 21' 5 11/17/2009 Isolated PowerSpiral guns 11/17/09 4 -5/8" TCP 01/2000 & 0 -1 9,625' 9,665' 8,676' 8,700' 40' 18 12/14/2006 Isolated 12/2006 (perfd 9645'- 9665') 4 -5/8" TCP 01/2000 & G -2 9,697' 9,737' 8,700' 8,743' 40' 18 12/14/2006 Isolated 12/2006 (pert d 9714'- 9734') 4-5/8" TCP 01/2000 & G 9,915' 9,990' 8,847' 8,890' 75' 18 12/14/2006 Isolated 12/2006 (perrd 9933' -9953' & 9970'- 9990') 4-5/8" TCP 01/2000 & 0 - 5 10,060' 10,210' 8,931' 9,015' 150' 18 12/14/2006 Isolated 12/2006(perrd 1070d- 10090', 10120- 10135'& 10180 - 10195') 4 -5/8" TCP 01/2000 & B -1 10,430' 10,480' 9,131' 9,156' 50' 18 12/14/2006 Isolated 12/2006 (perf'd 10430'- 10445') 4 -5/8" TCP B -2 10,510' 10,530' 9,170' 9,180' 20' 18 12/14/2006 Isolated 01/2000 & 12/2006 B -2 10,560' 10,570 9,193' 9,198' 10' 6 12/14/2006 Isolated 4-5/8" TCP 12/2006 B3 -B7 10,694' 13,835' 9,227' 9,668' 3141' 1/1/2000 Isolated Slotted Liner Updated On/ By: 10/08/2012 JLL • • Hilcorp Alaska, LLC Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M -32RD 50- 733 - 20462 -01 199 -097 9/19/2012 9/24/2012 D"aij Operations: 09/19/12 - Wednesday Rig up over well. Run line thru grease tubes and re -head line. Pressure test 250 psi low and 3,500 psi high. RIH with 3 -1/8" CCL and wt bars and tag at 8,362'. Tied into the 2 radial torch cuts and the F5A perfs. WLEG is at 8,310'. RIH with 2" drive down bailer with muleshoe flapper bottom and get a fill sample at 8,362'. Hit fill 3 times and had 400 lb overpull. POOH. Bailer was empty except for a few pieces of metal that look like cutter or perf debris. Had some sand coated on flapper but bailer was empty. Rig down for standby and put night cap on well. 09/20/12 - Thursday Rig back up. Make up bridge plug for 4 -1/2" tubing (3.5" OD plug). RIH to 7,790' and got on depth with previous log run. Got on depth and set bridge plug in 4 -1/2" tubing at 7,760'. Logged up and went back down and set down on plug. POOH. Filling tubing with FIW while coming out of hole with E -Line. RIH with 3 -1/2" OD Spectrue Jet Cutter and get tied into plug setting log. Put 1500 psi on tubing and fired jet cutter at 7,750'. Picked up and went back down and tubing had dropped and found top of tubing fish at 8,038'. The plan is to set the basket plug at 8,030' and dump bail the first stage of beads and cement. After we made the cut lost all pressure and the well went on a vacumn. Control room will moniter well. Make up Neo TT basket plug. Rig back up. Pressure test lubricator to 250 psi low and 3,500 psi high. 09/21/12 - Friday RIH with Neo TTBP and set plug at 8,030'. POOH. RIH with 3" bailer filled with ceramic beads and attempted to dump beads in basket plug. POOH and beads did not dump. RIH with 3" bailer filled with ceramic beads and dump beads in basket plug at 8,030' to 8,028'. POOH. RIH with 3 "x30' bailer full of Neo 17# cement slurry and dump cement from 8,028' to 8.022'. POOH. Cement in place at 15:00. Rig down lubricator and WOC. 09/22/12 - Saturday Rig up lubricator. Pressure test to 250 psi low and 3,500 psi high. RIH with 3.45" centralized LIB and close vent on plug at 8,019'. POOH. Showed a good impression of closing the vent. RIH w /1st run of 3 "x40' bailer filled with Neo 17# cement and dump bail cement from 8,020' to 8,016' POOH. RIH w/ 3 "x30' bailer filled with Neo 17# cement and dump bail cement from 8,016' to 8,004'. POOH. RIH w/ 3 "x30' bailer filled with BJ 15.8# cement and dump bail cement from 8,004' to 8,001'. POOH. Cement in place at 2:35. Total of 27' of cement on top of plug. Rig down lubricator and wait on cement. 09/23/12 - Sunday Cement samples were cured at 1630 hrs. Rig up lubricator. Pressure test to 250 psi low and 3,500 psi high. RIH with CCL and wts and tagged top of cement at 8,002'. POOH. Production had trouble getting SSSV to test. Made up a slickline brush and brushed SSSV at 456'. Production testing SSSV. SSSV test passed after cleaning. Rig up lubricator. RIH with GPT tool to determine fluid level. 09/24/12 - Monday POOH with GPT tool. Determined fluid level at 850' coming out of hole. Make up 3 -1/8 "x20' HC, 6 spf, 60 deg phase perf gun. Run in hole and tie in with Schlumberger RST log dated 11 -26 -2008. Spot perf gun from 7,372' to 7,392' and fired perf gun. POOH, Rig down lubricator, secure well and turn well over to Platform. Production going to bring well on. 09/25/12 - Tuesday r STATE OF ALASKA AIWA OIL AND GAS CONSERVATION COMMON . -- REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well Li Plug Perforations © Perforate U Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development © Exploratory p 199 -097 " 3. Address: 3800 Centerpoint Drive, STE 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99503 50 -733- 20462 -01 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL018730 [Steelhead Platform] Trading Bay Unit M -32RD 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): _ K ., McArthur River Field / Hemlock Oil, Middle Kenai G Oil & Middle Kenai Gas Pool 11. Present Well Condition Summary: Total Depth measured 13,835 feet Plugs measured 8,647 feet true vertical , 9,667 feet Junk measured N/A feet Effective Depth measured 8,647 feet Packer measured 6,861' feet true vertical 7,956 feet true vertical 6,570' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 981' 26" 981' 980' Surface 1,347' 16' 1,347' 1,346' 2,630 psi 1,020 psi Intermediate 3,767' 13 -3/8" 3,767' 3,766' 3,090 psi 1,540 psi Production 10,588' 9 -5/8" 10,588' 9,205' 7,930 psi 6,620 psi Liner 1,430' 7" 10,731' 9,266' 8,160 psi 7,020 psi Liner 3,141' 4 -1/2" (slotted) 13,835' 9,667' slotted slotted Perforation depth Measured depth 8,042 - 8,056 feet MAY 2012 True Vertical depth 7,491 -7,502 feet f Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# / L -80 8,302' 7,690' 6,861' MD 456' MD Packers and SSSV (type, measured and true vertical depth) HES PHL Relievable Packer 6,570' TVD SCSSV / TRSV 455' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressur N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development Q r Service ❑ Stratigraphic ❑ Daily Report of Well Operations Y 16. Well Status after work: Oil ❑ Gas ©- WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Ted E. Kramer Printed Name Ted E. Kramer Title Operations Engineer Signature .‹ Phone 907 - 777 -8420 Date 5/1/2012 RBDMS MAY 01 2012 S. Form 10-404 Revised 11/2011 , j ,,`) ,47 � Submit Original Only , ,z--(2., ../., . / /,‘____ ..` II II •teelhead Platform Well # M -32RD Asbuilt Schematic 4/30/12 RKB = 75.15'Rig Floor to TBG Head Casing & Tubing Size Type Wt Grade Thrd ID Top Btm Hole Cmt Cmt To, 26" Conductor Surf 981' Driven Cmt to Surf , • 1 16" Surf Csg 75 K -55 BTC 15.12 Surf 1,347' 22" 1,933 sx Calc TOC@ surf -assmd 20% / loss it Returns to Surf 13 -3/8" Csg 61 K -55 BTC 12.52 Surf 3,767' 17.5" 2,244 sx Bumped Plug 4 14 1111 0 3a Calc TOC @ -671' . I assmd 20% loss Window from 9 392'- 9,408' Returns to Surf 2 Prod Csg 53.5 L -80 BTC 12.25" 2,607 sx Calc TOC @ -2611' �E : �;/ ` a1 3b . 8.535 Surf 10,588' assmd 20% loss o y Calc TOC to ? ` 7" Liner 29 L -80 Butt & KC 6.184 9301' 10,731' 8 -1/2" 72 bbls liner top ,II:', 11111111 11 3c w /assmd 20 %loss 7 3d is Slotted IBTC AB 4 - 1 /2" Liner 12.6 L -80 mod 3.958 10694' 13,835' 6" 2 -1/2" x 1/16" slots 48/ft x ?I! e an T 3e . ; Tubing 75.15' RKB to Tbg Hngr '6 E ;; n ti 4 -1/2" 1 12.6 1 L -80 1 TCII 1 3.958 1 Surf 1 8,302' €% ! IMF 11 JEWELRY DETAIL III �e it , A NO. Depth ID Item Pressure Test Details as of 12/2/08 11111 1 456' 3.813" SCSSV (TRSV) Set Results ' 3a 1,563' 3.833" GLM (SFO -2) Depth b / 1 _ ` 1 ' 2 2,010' 3.833" Chemical Injection Sub Good Test 2000 psi to surface. 55' • _ ' ' * 3b 2,643' 3.833" GLM (SFO -2) above top of liner. 9 -' /a" csg tested MB + SFO -2 3c 3,633' 3.833" GLM 9,245' ( ) good. Could not get pkr to set in t ' �„ 6 * 3d 4,553' 3.833" GLM (SFO -2) csg between 9245' & TOL. 6 .t _. 3 e 5,355' 3.833" GLM (SFO -2) 9,350' Bad. No test above or below. '' 3f 6,062' 3.833" GLM (SFO -2) 9,400' Bad. No test between pkr & BP. ;' • F5A 3g 6,797' 3.833" GLM (SFO -2) 9,480' Bad. No test between pkr & BP. ' " Good Test to 2000 psi. Between t ." 4 6,861' 3.850 HES PHL Retrievable Packer 9,515' p '. TOC G * 5a 6,973' 3.70" Mech Tbg Release (BOT Gun Drop Sub) 9,545' Good Test to 2000 psi. Between 8,686 ELM s • ,. �' " '' # , 6-, 6 8,310' 3.950" WLEG _ pkr & BP @ 9560'. TOC B ' # ae »_.3" r- F C 7a 8,690' N/A Neo Plug 53' of cmt +12'sand +35' cmt 8,637'81.81 Y - - � - ' 7a 7b 8,720' N/A Neo Plug 7, 7c 8,890' N/A Plug w/ 40' of cement t ., FI3B 7d 9,064' N/A Plug w/ 81' cement (TOC 8983') 1 * 8 9,284' N/A TTS umbrella plug w/ cement on top Toc e i f ,9 * , . r s F14A 9 9,572' N/A EZSV Cement Retainer B,N6'ELM _ _� w -• w .., . Yai7 TOC g i' - F16B 6,663ELM, a ' ). 7 `,r": ,.:.. 1 Brief Details & Info: TOC S 1 x _ F15C Spudded M -32RD on 11/15/99. Completed on 01/25/00. M -32RD was a drill out of M -32 (window in the 9 -5/8" - 9392'). 5 fish 6,016 ELM - , `a 0 k .. ,, w „'," , Were left in sidetrack holes while drilling the well: #1 @ 9682' - 1226' fish. #2 @ 9564' -- 1088' fish. #3 @ 12418' - 5' fish. 1� 7d #4 @ 11650' - 300'fish. #5 @ 9943' (in the M -32RD section) - 780' fish. *Hole Section MWT: •Approximate Rotating hrs: y.. , F16 o 17 -1/2" to 1347' 9.0 to 9.5 ppg o 16" 120 hrs roc @ 'i ` +. • , o 12 -1/4" to 10588' 9.3 to 10.1 ppg o 13 -38" 560 hrs _ , 1 , .. 0,172' ELM , , 0 0 8 -1/2" to 10731' 9.0 to 10.5 ppg o 9 -5/8" 694 hrs TOC et os 1,4 'i `3 0 6" to 13835' 9.5 to 10.5 ppg o 7" 272 hrs 11,282 ; " x,18 *NOOK Collapse Csg Cee window 9,299' (; /-) @9392 r__ G06 024 Breach,:. PERFORATION DATA "70 of f18 5522' n4s'asu' a p 1110 -06 Accum Last Present t Top ofCmtgf67' Zone To Btm Amt SPF Perf. Date Condition Notes x � 9 F5A 8,042' 8,056' 14' 6 4/26/12 Open wed e► . d ', ,r _ G -I,2 F11C 8,625' 8,645' 20' 6 3/19/12 Isolated 3 - 1/8" SDP '*" w F13B 8,732' 8,756' 24' 6 2/4/12 Isolated 3 - 1/8" SDP > t' ' 2 • G -4 F14A 8,778' 8,793' 15' 6 7/17/11 Isolated 2 - 7/8" PJ Omega s i -. + n F15B 8,944' 8,974' 30' 6 5/24/11 Isolated 3 -1/8" SDP ExprO Y '"'94( r k 4r4 B - F15C 9,008' 9,014' 6' 6 5/7/11 Isolated 3 - 1/8" SDP Expro * .. *t_ F16 9,072' 9,092' 20' 6 3/16/2011 Isolated 2 -7/8" PowerJet Omega 1/29/11 & 3/16/11 ' - B - F16 9,092' 9,112' 20 6 3/17/2011 Isolated 2 -7/8" PowerJet Omega 3/17/11 001 9,212' 9,248' 36' 5 10/19/2010 Isolated 2 -1/2" PowerSpiral guns 10/19/10 • * e G05 9,500' 9,521' 21' 5 11/17/2009 Isolated 2 -1/2" PowerSpiral guns 11/17/09 10 couapa• in 4412" Slotted G - 9,625' 9,665' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9645-9665') 8 4 ` Liner 10626' G -2 9,697' 9,737' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9714'- 9734') e! `3t t �`2`. ',+( G-4 9,915' 9,990' 75' 18 12/14/2006 Isolated 4 -5/8° TCP 01/2000 & 12/2008 (perrd 9933' -9953' & 9970'- 9990') 4•$ $ '' : ' G -5 10 10 150' 18 12/14/2006 Isolated 4 -5/8° TCP 01/2000 & 12/2006 (perrd 10700'- 10090', 10120'- y C t wa 10135' & 10180' - 10195') B - 10,430' 10,480' 50' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 10430'- 10445') �: 4 ` --''‘f 'Al * ".7 ' B -2 10,510' 10,530' 20' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 ;'l 43 , , '' ' B -2 10,560' 10,570 10' 6 12/14/2006 Isolated 4 -5/8" TCP 12/2006 TO = 13,83b'MD19667'TVD B3 -B7 10,694' 13,835' 3141' 01/01/2000 Isolated Slotted Liner M -32RD Asbuilt Schematic 4 -30 -12 TDF • • 1 Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date M -32RD 50- 733 - 20462 -01 199 -097 4/13/12 4/27/12 D eRyOperetl❑q$: • .,. ,.._ , >w,,.. - ua; !r.. ,, w,�;'; F .. .. ...,e.Z ..r �.iv..:i«:. '„• it 7 - t e'.. .. 4/13/2012 - Friday Rig up lubricator and pressure essu a test to 250 psi low n O s o and ihi h.P together 3"x30' dump bailer with 17# psi Put to et e 3 30 du ba a filled w t Neo 1 g p p p p g g p cement and tagged top of sand at 8,624' RKB. Dumped cement. Made 8 runs with bailer and dumped 28.8' of cement. TOC should be around 8,596'. Rig down and secure well. 04/16/2012 - Monday Rig up lubricator and pressure test to 250 psi and 3,500 psi. Ran 3.25" gauge ring and tagged top of cement at 8,596'. POOH. Ran 2-1/2" RTC -2 -4 / ,500 00 series radial torch and fired torch at 7,800'. Collar at 7,798'. Ran in hole with 3.50" LIB and found that the tubing did not cut all the way. Decided to wait on the larger size cutter. Rig down lubricator and secure well. 04/23/2012 -M n Monday Rig up lubricator, pressure test 250 psi low and 3500 psi high. RIH with 2-15/16" radial torch down to 7796' with CCL at 7784.5'. Fired cutter. Pull up to make sure tools were free. Could not check to see if tubing had fell down hole. POOH. Secured well. 04/24/2012 - Tuesday RIH with 3.50" gauge ring and CCL to last cut at 7796', tool joint at 7798' and first cut at 7800'. POOH. RIH with 10' jar shot. Spot jar shot over both cuts from 7794' to 7804'. Fired shot. Tubing did not drop. POOH. All shots fired. Tried to gas lift fluid off well but it was just looking like it was u tubing from the orifice valve. Got very little fluid back. Rig lubricator off well and secure well. Obtain fluid level machine to determine fluid level before tomorrow's perf job. 4/25/2012 - Wednesday Pressure test to 250 psi low and 3500 psi high. MU and arm 3 -1/8 "x14' HC, 6 spf, 60 deg phase perf gun. RIH and tie into RST log dated 26- Nov -2008. Spotted gun from 8,042' to 8,056' with 948 psi on tubing and fluid level at 4,150'. Fired gun and pressure started to build slowly. POOH. Rig down lubricator and a -line. Secure well and turn well over to production. Tubing pressure 1100 psi. REGEIVCU STATE OF ALASKA APR 1 2 2012 AL KA OIL AND GAS CONSERVATION COMMI ION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations 0 Perforate IS Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ 199 -097 - 3. Address: 3800 Centerpoint Drive, STE 100 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99503 50- 733 - 20462 -01 -0 0 7. Property Designation (Lease Number): 8. Well Name and Number: ADL018730 [Steelhead Platform] Trading Bay Unit M -32RD — 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): McArthur River Field / Hemlock Oil, Middle Kenai G Oil & Middle Kenai Gas Pool 11. Present Well Condition Summary: Total Depth measured 13,835 feet Plugs measured 8,647 feet true vertical 9,667 feet Junk measured N/A feet Effective Depth measured 8,647 feet Packer measured 6,861' feet true vertical 7,956 feet true vertical 6,570' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 981' 26" 981' 980' Surface 1,347' 16' 1,347' 1,346' 2,630 psi 1,020 psi Intermediate 3,767' 13 -3/8" 3,767' 3,766' 3,090 psi 1,540 psi Production 10,588' 9 -5/8" 10,588' 9,205' 7,930 psi 6,620 psi Liner 1,430' 7" 10,731' 9,266' 8,160 psi 7,020 psi Liner 3,141' 4 -1/2" (slotted) 13,835' 9,667' slotted slotted Perforation depth Measured depth 8,625 - 8,645 feet streloofx APR 1 6 2012 True Vertical depth 7,940 -7,956 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# / L -80 8,302' 7,690' 6,861' MD 456' MD Packers and SSSV (type, measured and true vertical depth) HES PHL Retrievable Packer 6,570' TVD SCSSV / TRSV 455' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressun N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development El Service ❑ Stratigraphic ❑ Daily Report of Well Operations 16. Well Status after work: Oil ❑ Gas p -• WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ 3USP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Ted E. Kramer Printed Name ��1 / "'a. •y Title Operations Engineer Signature "4 "7-- Phone 907- 777 -8420 Date 4/11/2012 RBDMS APR 12 1Q !1 J4 "/2.--- Form 10 -404 Revised 11/2011 Submit Original Only -_~~~~~~. �� �� �� ���P � Hilcorp Alaska LLC �^ n o U U �~����� ��U��^�K��� o~�v= ^ ~~~^ n ~ �� � ��°���� �����UU Operations «�KU��k������� ��� ���U � � ~. U o �� K ~ .~ . .. un ~~ . . ~ Summary . . . . . .~ . x Well Name API Number Well Permit Number Start Date End Date M-32RD 50'733'20462'01 199'097 2/3/13 3/19/12 2/3/2012 to 2/4/2012 - Friday Received waiver from AOGCC (Guy Schwartz) to omit the F14 isolation plug from summary procedure. 2/4/2012 to 2/5/2012 - Saturday Pressure test Iubricator 250 psi Iow and 3000 psi high. RIH with 3'1/0"x24',6spf,6Odeg phase perf gun. Perforate from O73J'to8756'. Rig down lubricator and turn well over toproduction. 2/11/2012 to 2/12/2012 - Saturday RU wireline bridge and lubricator. Pressure test lubricator to 250 psi low/2500 psi high. R|H with 3.SO"GRand press/temp tool and tagged fill at 8830'. Begin to POOH. 2/12/2012 to 2/13/2012 - Sunday Completed POOH and RD. Turned well over to production. 2/22/2012 to 2/23/2012 - Wednesday Tubing and casing pressure is stablized at 1934 psi. Rig up E-line lubricator. Pressure test lubricator to 250 psi low and 3000 psi high. RIH with Neo basket plug, set plug at at 8720'. Begin to POOH. Tool hung up at +/ 1,5G3' and pulled out of rope socket. Left tools in well. POOH. Replace cable head. Lubricator full of Hydrate (ice). Put heat trunk around Iubricator to thaw out. 2/23/2012 to 2/24/2012 - Thursday Rig up lubricator. Pressure test to 250 psi low and 3000 psi high. RIH with 3.50" LIB. Tools set down at down at 6953'. POOH. LIB did not show top of cable head on wireline fish. RIH with 3" LIB and set down at 154'. Worked tools to 174'. POOH. Assume ice plug is obstructing E-line. Pour 6 gallons of methonal down lubricator and continued to try to work through ice plug. POOH. 2/24/2012 to 2/25/2012 - Friday Pressure test Iubricator to 250 psi Iow and 3000 psi high. RIH with 1-3/4" drive down bailer with muleshoe flapper hit plug at129'RK@.POOH. Bailer contained appprox 9" of ice. Tubing and casing pressure is stablized at 1930 psi. RetUrr / ' o r /� ^~ 3/1/2012 to 3/2/2012 - Thursday Rig up Iubricator, pressure test to 250 psi low and 2,800 psi high. RIH w/ 2" star bit and drive down bailer numerous times from 1S4'RK8to16O'NK0. Tubing Pressure 2,O9Opsi/[asing Pressure 2,O4Opsi. • • 3/2/2012 to 3/3/2012 - Friday Rig up lubricator, pressure test to 250 psi low and 2,500 psi high. RIH w/ 2" star bit and drive down bailer numerous times from 160' RKB to 168' RKB. Dump bail 3 gallons of methanol on plug and secure well. 3/3/2012 to3/4/2012 - Saturday Rig up lubricator, pressure test to 250 psi low and 2,500 psi high. RIH w/ 1.75" star bit to 1,600 RKB without any obstructions, POOH. RIH w/ 3" LIB and set down at 8,708' RKB, POOH. Have impression of vent plug on LIB. RIH w/ KO tools and verify every GLM had a valve installed, POOH. RD and turn well over to production. 3/5/2012 to 3/6/2012 - Monday Rig up lubricator, pressure test to 250 psi low and 3,000 psi high. RIH w/ 2.65" GR and set down at 8,710. POOH. MU 9- 5/8" Neo plug and RIH to 8,690' and set plug. POOH. MU and RIH w/ 3 "x30' dump bailer to 8,690' and release 3.14' of beads. POOH. RIH w/ 3.14' of 17Ib cement and place at 8,690. POOH. RIH w/ another 3.14' of 17Ibg cement and place at 8,686'. POOH and RD. 3/6/2012 to 3/7/2012 - Tuesday RIH w/ 3" LIB and tag at 8,683' RKB, POOH. Remove spangs and add centralizer, RIH w/ 3" LIB and tag at 8,680' RKB, POOH. RIH w/ 3 "x30' bailer of 17Ib cement and place at 8,680, POOH. 3/7/2012 to 3/8/2012 - Wednesday RIH three times w/ 3 "x30' bailer containg Neo 17Ib cement and placed cement from 8,673'to 8,665'. POOH. RD lubricator and wait on cement. 3/14/2012 - Wednesday RU and pressure test lubricator to 250psi low/ 3,500 high. Complete three runs w/ 3 "x30' bailer and 17Ib Neo cement. Cement placed from 8.663'(tag existing cement) to 8.653' + / -. POOH. Rig down lubricator and secure well. Operations will conduct a positive and negative pressure test once the cement cures. 3/19/2012 - Monday RU and pressure test lubricator to 250psi low/ 3,500 igh. RIH with 3 -1/8 "x20' HC, 6spf, 60 degree phase perf gun and tie into RST log dated 1/31/2012, tag cement ,647: ire guns from 8,645' to 8,625'. POOH. RD and turn well over to production. � it . .. • •eelhead Platform Well # M -32RD Asbuilt Schematic 3/26/12 RKB = 75.15'Rig Floor to TBG Head C a s i f1 e & T u b i n e =EI!==a'rl!=M!•lIlrffE==MEIIIIIIMEMI=VMIIIWEMIIIW!M111111:ETIIIIIIIMRMI Conductor - - -- ®MIIIIIMEMEME M . Cmt to Surf 1 16" Surf Csg 75 K -55 BTC 15.12 Surf 1,347' 22" 1,933 sx Calc TOC@ surf assmd 20% S loss Returns to Surf 13 -3/8" Csg 61 K -55 BTC 12.52 Surf 3,767' 17.5" 2,244 sx Bumped Plug ,G 11111 ;;. 3a Calc TOC @-671' assmd 20% loss W ndow from 9 392'- 9 408' Returns to Surf o !. 2 9 -5/8" Prod Csg 53.5 L -80 BTC 12.25" 2,607 sx Cale TOC @ -2611' 8.535 Surf 10,588' assmd 20% loss e, at il 3b ; Calc TOC to L 1 7" Liner 29 L -80 Butt & KC 6.184 9301' 10,731' 8 -1/2" 72 bbls liner top 3 l' 3c w /assmd 20 %loss all 11 3d 4 -1/2" Slotted 12 6 L -80 IBTC AB 3.958 10694' 13,835' 6" 2 -1/2" x 1/16" slots, 48 /ft c >� Liner mod E '1 3e Tobin' 75.15' RKB to Tbl Hn_r � � . E ' 4 -1/2" 12.6 L -80 TCI1 3.958 Surf 8 <., 113f , 7, ° E iMi. JEWELRY DETAIL � - ° NO. Depth ID Item Pressure Test Details as of 12/2/08 ° 0. 1 456' 3.813" SCSSV (TRSV) Set 1I ° 3a 1,563' 3.833" GLM (SFO-2) Depth Results 2 2,010' 3.833" Chemical Injection Sub Good Test 2000 psi to surface. 55' i_: - 3b 2,643' 3.833" GLM (SFO -2) above top of liner. 9 -' /" csg tested 3c 3,633' 3.833" GLM (SFO -2) 9,245' good. Could not get pkr to set in 5 3d 4,553' 3.833" GLM (SFO -2) csg between 9245' & TOL. 5a 0 3e 5,355' 3.833" GLM (SFO -2) 9,350' Bad. No test above or below. 3f 6,062' 3.833" GLM (SFO -2) 9,400' Bad. No test between pkr & BP. 3g 6,797' 3.833" GLM (SFO -2) 9,480' Bad. No test between pkr & BP. V, 4 6,861' 3.850" HES PHL Retrievable Packer Good Test to 2000 psi. Between 9,515' 6 5 6,922' 3.8] 3" X- Profile Nipple pkr & BP @ 9560'. y ?. 5a 6,973' 3.70" Mech Tbg Release (BOT Gun Drop Sub) 9,545' Good Test to 2000 psi. Between . , 3i° 6 8,302' 3.950" WLEG pkr & BP @ 9560'. TOC @ F11C 7a 8,690' N/A Neo Plug w/ 43' of cement ✓"- 8,647'ELM 7a 7b 8,720' N/A Neo Plug 7b 7c 8,890' N/A Plug w/ 40' of cement F13B 7d 9,064' N/A Plug w/ 81' cement (TOC 8983') 8 9,284' N/A TTS umbrella plug w/ cement on top TOC @ F14A 9 9,572' N/A EZSV Cement Retainer 8,830'ELM 7c TOC @ F15B 8,983'ELM Brief Details & Info: TOC @ • F15C Spudded M -32RD on 11/15/99. Completed on 01/25/00. M -32RD was a drill out of M -32 (window in the 9 -5/8" - 9392'). 5 fish 9,015'ELM Were left in sidetrack holes while drilling the well: #1 @ 9682' - 1226' fish. #2 @ 9564' - 1088' fish. #3 @ 12418' - 5' fish. 7d #4 @ 11650' - 300'fish. #5 @ 9943' (in the M -32RD section) - 780' fish. •Hole Section MWT: •Approximate Rotating hrs: IN F16 o 17 -1/2" to 1347' 9.0 to 9.5 ppg o 16" 120 hrs TOC @ o 12 -1/4" to 10588' 9.3 to 10.1 ppg o 13 -38" 560 hrs 9,172' ELM o 8 -1 to 10731' 9.0 to 10.5 ppg o 9 -5/8" 694 hrs TOC @ , , , GO1 o 6" to 13835' 9.5 to 10.5 ppg o 7" 272 hrs 9,262'SLM 8 4 Collapse Csg c window /� 9,299' ( +/-) 0 ') ` 0392' Integrity Breach, z= G06 PERFORATION DATA 9245' to 9616' ', -. Top of fill at 9622' 11-19409 Zone Top Btm Amt Accum Last Present Notes Top of Cmt at 9647' SPF Perf. Date Condition 1Sr , 9 F11C 8,625' 8,645' 20 6 3/19/12 Open 3 -1/8" SDP Milled BP -----C*- -G-I,2 F13B 8,732' 8,756' 24 6 2/4/12 Isolated 3 -1/8" SDP F14A 8,778' 8,793' 15 6 7/17/11 Isolated 2 -7/8" PJ Omega -~= G-4,6 F15B 8,944' 8,974' 30' 6 5/24/11 Isolated 3 -1/8" SDP Expro F15C 9,008' 9,014' 6' 6 5/7/11 Isolated 3-1/8" SDP Expro F16 9,072' 9,092' 20' 6 3/16/2011 Isolated 2 -7/8" PowerJet Omega 1/29/11 & 3/16/11 B-1 F16 9,092' 9,112' 20 6 3/17/2011 Isolated 2 -7/8" PowerJet Omega 3/17/11 B -2 001 9,212' 9,248' 36' 5 10/19/2010 Isolated 2 -1/2" PowerSpiral guns 10/19/10 Q � , �� . 005 9,500' 9,521' 21' 5 11/17/2009 Isolated 2 -1/2" PowerSpiral guns 11/17/09 t G -1 9,625' 9,665' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9645'- 9665') ' • . Collapse in 4.1@" Slotted G -2 9,697' 9,737' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9714'- 9734') E - Liners 10926' G - 4 9,915' 9,990' 75' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2008 (perfd 9933' -9953' & 9970'- 9990') 0 - 5 10,060' 10,210' 150' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 8 12/2006 (perfd 10700' - 10090', 10120'- 10135' & 10180' - 10195') I B -1 10,430' 10,480' 50' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 10430'- 10445') t o g tr. B -2 10,510' 10,530' 20' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 `Wt! B -2 10,560' 10,570 10' 6 12/14/2006 Isolated 4 -5/8" TCP 12/2006 B3 -B7 10,694' 13,835' 3141' 01/01/2000 Isolated Slotted Liner TD = 13,835'MD/9667'TVD M -32RD Asbuilt Schematic 3 -26 -12 TDF Page 1 of 1 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, February 03, 2012 2:26 PM To: 'Tom Fouts - (C)' Subject: RE: M -32RD/ PTD 199 -097/ Sundry 311 -368 Subject: ry Tom, You have approval to change the procedure as detailed below ( eliminating the cement and plug at The zones F -13B and F -14A are in the same pool so there are no regulatory 8775'). p 9 ry requirements to have them isolated from each other. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Tom Fouts - (C) [mailto:tfouts @hilcorp.com] Sent: Friday, February 03, 2012 1:37 PM To: Schwartz, Guy L (DOA) �) Subject: M -32RD/ PTD 199 -097/ Sundry 311 -368 ED FEB Qt 3 Guy, We are currently performing operations on M -32RD, PTD 199 -097, Sundry 311 -368. At this time Hilcorp is requesting to perforate the F -13B zone without setting the proposed plug at +1- 8,775' at this time. Pending the results of flow test, we would reserve the right to go back and set the plug in the future. Please let me know if you have any questions concerning our plan forward. Thanks, Toni Fouts !Construction Manager Hi lrarp Alaska. l.JA. tfouts @hilcorp.com Direct: (907) 777 -8398 Mobile: (907) 351 -5749 2/3/2012 Chevron 1110 Stead Platform ., Proposed Well # M -3281) - Final Schematic 10/19/11 RKB = 75.15'Rig Floor to TBG Head Casing & Tubing Si. e T}Pe Wt Grade Thrd In Top Btm ride Cnn 1 Cmt Top - 26' Conductor Surf 981 Driven 1 Cmt to Surf ■ 1 16' Surf Csg 75 K -55 8TC 15 12 Surf 1,347' 22' 1,933 sx Cale TOCC surf assmd 20% loss Returns to Surf 13 -3/8' Csg 61 K-55 BTC 12.52 Surf 3,767' 17.5' 2,244 sx Bumped Plug Cale TOC @-671' , 1 3a i ' _ assmd 20% loss J Window from 9 392'- 9,408' Returns to Surf n r 4 2 9 -518' Prod Csg 53 5 1-80 BTC 6.535 Surf 10,588 12 25" 2607 sx Cale TOC @ -2611' i9v 3b , assmd 20% loss Cate TOC to o a l .3:-'i . L; , 7 " Liner 29 1-80 Butt & KC 61s4 9301' 10,731' 8-1/2" liner top w /assmd ' 72 tots � 3c 20 %loss I 1 Slotted IBTC AB I ill 3d • 4 -112" Liner 126 L80 mod 3.958 10694' 13835' 6" 2 12" x 1/16' slots, 48/ft z `tubing 75.15' RKB to Tbg Hngr ZI 2 3e 4-1/2" 1 12.6 1 L 1 TCII 1 3.958 1 Surf 1 8,302' --ii •_ JEWELRY DETAIL Pressure Test Details as of 12/2/08 es r r11331 9 NO. Depth ill Item Set Results • L 1 456' 3.813" SCSSV (TRSV) Depth 1 1 1 ` 3a 1,563' 3.833" GLM (SFO -2) Grand Test 2000 psi to surface. 55' 2 2,010' 3.833" Chemical Injection Sub above top of liner. 9-%" cag tested 9,245' good. Could not col 3b 2,643' 3.833" GLM (SFO -2) g pkr to set in g' P • ' . 3c 3,633' 3.833" GLM (SFO -2) csg between 9245' & TOL_ 5 i 9,350' Bad. No test above or below. Sa . 3d 4,553' 3.833" GLM (SFO -2) 3e 5,355' _ 3.833" GLM (SFO-2) 9,400' Bad. No test between pkr & BP. 3f 6,062' 3.833" GLM (SFO -2) 9,480' Ilad No test between plv & BP. 31 6,797' 3.833" GLM (SFO 2) 9,515' Good 'test tr, 2004) psi. Between 4 6,861' 3.850" HES PHI. Retrievable Packer pkr & BP # 9560'. 6 5 6,922' 3.813" X- Profile Nipple 9,545' Good 't est to 21111)) psi. Between Ss 6,973' 3.70" Meth 'Mg Release (BOT Gun Drop Sub) pkr, & 13P @ 9560', 6 8,302' 3.950" WLEG 6a 8,765' N/A Plug wr10' of cement n 7a 8,890' N/A Plug w.' 40' of cement F138 7b 9,064' N/A Plug w; 81' cement (TOC 8983') •4 '- - • , .6a 8 9,284' WA TTS umbrella plug w/ cement on top —T- P14A 9 9,572' N/A EZSV Cement Retainer 7a TOG - - .. Brief Details & Info: 7tx . : :,..=._ FI5C Spudded M -32RD on 11/15/99. Completed on 01/25/00. M -32RD was a drill out of M -32 (window in the 9 -5/8" .- 9392'). 5 fish Were left in sidetrack holes while drilling the well. 41 {a) 9682' - 1226' fish. 42 @ 9564' - 1088' tish. a3 (d, 12418' -- 5' fish. 9,015'ELM 44 Cad 11650' -- 3(N)' fish ::5 in? 9943' (in the M -32RD section) - 780' fish_ 7b *Hole Section "1%% 1: *Approximate Rotating hrs: . o 17 -1/2' to 1317' 9.0 to 9.5 ppg o 16" 120 his _ . - — F16 0 12 -1/4" to 10 88' 9.3 to 10.1 ppg o 13 -38" 560 hrs TOG O - o 8 -1/2" to 10731' 9.0 to 10.5 ppg o 9 -5/8" 694 hrs 9,172 ELM - 0 6" to 13835' 9.5 to 10.5 ppg o 7" 272 hrs ToC / G01 ' 9.252'SL`A 8 Collapse Csg c.1. Wtnde.,,'� 9,299' ( +1 - d ,3yx PERFORATION DATA cos Accum Last Present 9245' ry Breach - op o fib 9522' Zone Top Btm Amt Notes 9245' to 9515' T f $PF Pert- Date 1:ondldon 11 -16-09 Top of Cr,t@D9547 F11C .4- 8.638' *1 -8 663' 25 6 , Contingency P 9 F 13B +1- 8.749' +1- 8.764' 15 6 Proposed ` - _ F14A 8.778' 8,793' _ 15 6 7/1 7/1 1 open 2 - 718' PJ Omega Mille.] BP _ G - 1,2 F158 8,944' 8,974' 30' 6 5/24/11 Isolated 3 SDP Expro • - - _ F15C 9,008' 9,014' 6' 6 5/7/11 Isolated 3 - 1/8' SOP Expro G-4,5 F16 9,072' 9,092' 20' 6 3/16/2011 Isolated 2 -7/8" PowerJet Omega 129/11 & 3/16/11 F16 9,092' 9,112' 20 6 3/17/2011 Isolated 2- 7/6'PowerJetOmega 3/17/11 GOt 9,212' 9248' 36' 5 ' 0/19/2010 Isolated 2 -12" Powe Spiral puns 10/19/10 005 9,500' 9,521' 21' 5 . "1/17/2009 Isolated 2 -1/2' PawerSpeal Runs 11 /17/09 4 s B -2 G-1 9,625' 9,665' 40' 18 12/14/2006 Isolated 4-5/8" TCP 01/2000 &12/2006 (peed 9645'- 9665') ' _ s. G-2 9,697' 9,737' 40' _ 15 . 12/14/2006 Isolated 4-5/8" TCP 01/20008r 12/2006 (perfd 9714'•9734') t° 1 G - 4 9,915' 9.990' 75' 18 12/14/2006 Isolated 4.58' TCP 01/2000 & 12/0006 (peed 9933.9953' & 9970'9990) e Collapse in 4 -112' Slonee G-5 10,060'. 10 150' 18 12/142006 Isolated 4518' TCP 0112000 & 1212006 (peed 10700' - 10090', 10120'- - t - Liner (410625' 10115' & 1016(1' •10195) 1 t 8-1 10,430' 10,480' 50' 18 12/142006 Isolated 45/8" TCP 011 2000 & 12/2006 (perrd 10430'- 104451 'N - 1 1 8-2 10,510' 10,530' 20' 18 12/14/2006 Isolated 4-5/8" TCP O1 /2000 & 12/2006 8 - 2 10,560' 10,570 10' 6 12/14/2006 Isolated 4 -5/8' TCP 12/2006 8 •}'• - _ -, - 83-87 10,694' 13,835' 3141' 01/01/2000 Isolated Slotted Liner 1 1 I A. 1 TD • 13,835'MD/9667'TVD M -32RD Proposed (F13B) Schematic 10 -19 -201 I.docx TDF: 8115/11 ' • • O SEAN PARNELL, GOVERNOR 0 6 O ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy C. Brandenburg Drilling Manager �ct Union Oil Company an of California P.O. Box 196247 t Anchorage, AK 99519 Re: McArthur River Field, Hemlock Oil Pool, Trading Bay Unit M -32RD Sundry Number: 311 -368 Dear Mr. Brandenburg: 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, Daniel T. Seamount, Jr. Chair DATED this ,3 dd day of November, 2011. Encl. • • i Davies, Stephen F (DOA) From: Winslow, Paul [PRA] [PWinslow @chevron.com] Sent: Tuesday, November 29, 2011 9:12 AM To: Davies, Stephen F (DOA) Cc: Voorhees, Brent J.; Applewhite, Billy -APRS [APRS]; Whitacre, Dave S Subject: Well spacing for M -32RD plugback , � Steve, The proposed recompletion (plugback) of Grayling Gas Sand (GGS) well M -32RD, will be to abandoned the F14A sand and recomplete into the F13B sand. The F13B sand has never been perforated in any GGS well at McArthur River Field, so the recompletion will not violate any spacing order. Depending upon the success and /or producing longevity of the F13B completion, Union Oil Company of California ( "Union ") plans to subsequently move up hole to the F11 sand (in M- 32RD). The F11 sand has been previously perforated (& produced) in wells M -06, M -11, and M -14. The F11 perforations in all three wells (M -06, M -11, & M -14) have been abandoned. Note that the nearest F11 completion (now abandoned), to the M -32RD well, is in the M -11 wellbore. The distance between these two F11 sand penetrations is far greater than the 10 acre spacing order. If you have any further questions, please give me a call. Paul Paul Winslow Petroleum Engineer Petrotechnical Resources Alaska (PRA) PWinslow@chevron.com Chevron North America Exploration and Production Midcontinent /Alaska SBU 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel : 907 - 263 -7941 Cell: 907 - 717 -6824 1 cia,& , k +<LUEIVED • III ‘k,sk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIo iaska Oil & Gas Cone, Commission APPLICATION FOR SUNDRY APPROVALS Anchorage 20 AAC 25.280 , 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations E Perforate El • Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 12 . Exploratory ❑ 199 -097 , 3. Address: ❑ 6. API Number: Stratigraphic ❑ Service PO Box 196247, Anchorage, AK 99519 50 -733- 20462 -01 . 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 0 Trading Bay Unit M -32RD . 9. Property Designation (Lease Number): 10. Field / Pool(s): • ADL018730 [Steelhead Platform] McArthur River Field / Hemlock Oil, Middle Kenai G Oil & Middle Kenai Gas 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): 13,835 ' 9,667 8,983 8,212 8,983 (cement) N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 981' 26" 981' 980' Surface 1,347' 16" 1,347' 1,346' 2,630 psi 1,020 psi Intermediate 3,767' 13 -3/8" 3,767' 3,766 3,090 psi 1,540 psi Production 10,588' 9 -5/8" 10,588' 9,205' 7,930 psi 6,620 psi Liner 1,430' 7" 10,731' 9,266' 8,160 psi 7,020 psi Liner 3,141' 4 -1/2" (slotted) 13,835' 9,667' slotted slotted Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8,778 -8,793 8,057 -8,068 4 -1/2" 12.6# L -80 8,302 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): HES PHL Retrievable Packer / SCSSV 6,861'MD (6,570'TVD) / 456'MD (455'TVD) 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: • Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Operations: 12/20/2011 Commencing Oil 9 p ❑ Gas 1E1 • WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG p 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Billy Applewhite Phone:263 -7671 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature % c < <'' Phone 276 -7600 Date 11/22/2011 COMMISSION USE ONLY r -� Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 I 1 g Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: LAO APPROVED BY Approved by: C• MISSIONER THE COMMISSION Date: / 1 7 2)eJ/ i 1 Form 10-403 Revised 1/2010 NOV 3 #' I SAL S ubm' ' 4yp1' te, ` ft ! f /, ,( . Chevron • Steelhead 410form 1%0 Proposed Well # M -32RD %. Final Schematic 10/19/11 RKB = 75.15'Rig Floor to TBG Head Casing & Tubing Size Type Wt Grade Thrd ID Top Btm Hole Cmt Cmt To , 1 III [ 26" Conductor Surf 981' Driven ' Cmt to Surf 1 16" Surf Csg 75 K -55 BTC 15.12 Surf 1,347' 22" 1,933 sx Calc TOC@ surf -assmd 20% II loss Returns to Surf 13 -3/8" Csg 61 K -55 BTC 12.52 Surf 3,767' 17.5" 2,244 sx Bumped Plug 1� 3a Calc TOC @-671' assmd 20% loss 0 w 1 Window from 9,392'- 9,408' Returns to Surf a 2 9 -5/8" Prod Csg 53.5 L -80 BTC 12.25" 2,607 sx Calc TOC @ -2611' m8 8.535 Surf 10,588' �E S '/' c 3b assmd TO C loss o n Calc OC to ti 1 Zit .1` - r liner top 7" Liner 29 L -80 Butt & KC 6.184 9301' 10,731' 8 -1/2" 72 bbls w/assmd �^ 0 3c " 20 %loss , 1MIM -. Slotted IBTC AB 3d , 4-1/2" Liner 12.6 L -80 mod 3.958 10694' 13,835' 6" 2-1/T x 1/16" slots „o,, R +.:„ Tubing 75.15' RKB to Tbg Hngr E V , � ,'. 3e { 4 -1/2" 12.6 1 L -80 1 TCII 1 3.958 1 Surf 1 8,302' AE 113f t JEWELRY DETAIL Pressure Test Details as of 12/2/08 .V4 43 : J °9 �" NO Depth ID Item Set 1 456' 3.813" SCSSV (TRSV) Depth Results 1 1 ir 1 3a 1,563' 3.833" GLM (SFO -2) Good Test 2000 psi to surface. 55' I" i 2 2,010' 3.833" Chemical Injection Sub above top of liner. 9 -' /e" csg tested 1•' - 3b 2,643' 3.833" GLM (SFO -2) 9,245' good. Could not get pkr to set in " " 3c 3,633' 3.833" GLM (SFO -2) csg between 9245' & TOL. '1 •• 5 it; 3d 4,553' 3.833" GLM (SFO -2) 9,350' Bad. No test above or below. � Sa 3e 6, 5,355' 8 GLM (SFO -2) 9,400' Bad. No test between pkr BP. 3f 062 GLM (SFO -2) 9,480' Bad. No test between pkr & & BP. 3g 6,797' 3.833" GLM (SFO -2) Good Test to 2000 psi. Between 9,515' I x 4 6,861' 3.850" HES PHL Retrievable Packer pkr & BP @ 9560'. 71 6 5 6,922' 3.813" X- Profile Nipple 9,545' Good Test to 2000 psi. Between • ' 5a 6,973' 3.70" Mech Tbg Release (BOT Gun Drop Sub) pkr & BP @ 9560'. I [ 6 8,302' 3.950" WLEG 6a 8,765' N/A Plug w /10' of cement 1 7a 8,890' N/A Plug w/ 40' of cement n r F138 7b 9,064' N/A Plug w/ 81' cement (TOC 8983') ,6a 8 9,284' N/A TTS umbrella plug w/ cement on top ,• 7, FI4A 9 9,572' N/A EZSV Cement Retainer ,Ni, 'A :Ape ; la roc B s! M ' F1513 Brief Details & Info: 8883 'ELM 9 , t 2'° j , � ) Spudded M - 32RD on 11/15/99. Completed on 01/25/00. M -32RD was a drill out of M -32 (window in the 9 -5/8" - 9392'). 5 fish roc a �; .0; j -t " ''' MC Were left in sidetrack holes while drilling the well #1 @ 9682' - 1226' fish. #2 @ 9564' - 1088' fish. #3 @ 12418' - 5' fish. 9,015'ELM i Et #4 @ 11650' - 300'fish. #5 nu, 9943' (in the M -32RD section) - 780' fish. 7b *Hole Section MWT: •Approximate Rotating hrs: t o 17 -1/2" to 1347' 9.0 to 9.5 ppg o 16" 120 hrs `' F16 o 12 -1/4" to 10588' 9.3 to 10.1 ppg o 13 -38" 560 hrs T0C a i• ' r o 8 -1/2" to 10731' 9.0 to 10.5 ppg o 9 -5/8" 694 hrs 9,172' ELM , 6w +„ 4 , o 6" to 13835' 9.5 to 10.5 ppg o 7" 272 hrs roc B 2' P r ' t, < ;6 f ' , - � G01 9,252'SLM ^ { ' F` — 3 6 Collapse Csg Csg Window ; 9,299' ( + / -) @9392' 1. PERFORATION DATA Integrity Bre of fl 9922' Zone Top Bt A Accum Last Present Notes 9246' to sal5 t,.,: B SPF Perf. Date Condition 1115 F1 1C +/ 8,638' +/ 8 25 6 Contingency T of Cm1�964T g Y g F13B +/- 8,749' +/- 8,764' 15 6 Proposed _ F14A 8,778' 8,793' 15 6 7/17/11 open 2 -7/8" PJ Omega Milled O P' 1 G-1,2 F15B 8,944' 8,974' 30' 6 5/24/11 Isolated 3- 1 /8 "SDPExpro F15C 9,008' 9,014' 6' 6 5/7/11 Isolated 3 -1 /8" SDP Expro G4,5 F16 9,072' 9,092' 20' 6 3/16/2011 Isolated 2 -7/8° PowerJet Omega 1/29/11 & 3/16/11 F16 9,092' 9,112' 20 6 3/17/2011 Isolated 2 -7/8" PowerJet Omega 3/17/11 B - G01 9,212' 9,248' 36' 5 10/19/2010 Isolated 2 -1/2" PowerSpiral guns 10/19/10 G05 9,500' 9,521' 21' 5 11/17/2009 Isolated 2-1/2" PowerSpiral guns 11/17/09 a B - G -1 9,625' 9,665' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9645'- 9665') G -2 9,697' 9,737' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9714'- 9734') I G - 4 9,915' 9,990' 75' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9933' -9953' & 9970' - 9990) . 3 Collapse in 4.112" SIotteC G - 5 10,060' 10,210' 150' 18 12/14/2006 Isolated 4 -5/8° TCP 01/2000 & 12/2006 (perfd 10700'- 10090', 10120'- , i Liner e 10825' 10135'8 10180' - 10195) B -1 10,430' 10,480' 50' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 10430'- 10445') B -2 10,510' 10,530' 20' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 1 B -2 10,560' 10,570 10' 6 12/14/2006 Isolated 4 -5/8° TCP 12/2006 t B3 -B7 10,694' 13,835' 3141' 01/01/2000 Isolated Slotted Liner I TD = 13,835'MD/9667'TVD M -32RD Proposed (F13B) FINAL Schematic 10- 22- 2011.docx TDF: 8/15/11 • Chevron ! Steelhead *form %. Well # M -32RD %. Actual Schematic 7/16/11 RKB = 75.15'Rig Floor to TBG Head Casing & Tubing Size Type Wt Grade Thrd ID Top Btm Hole Cmt 1 Cmt Top • 26" Conductor Surf 981' Driven . a :; ; -I.-. ". Cmt to Surf 1 16" Surf Csg 75 K -55 BTC 15.12 Surf 1,347' 22" 1,933 sx Calc TOC@ surf -assmd 20 loss F., Retums to Surf 13 -3/8" Csg 61 K -55 BTC 12.52 Surf 3,767' 17.5" 2,244 sx Bumped Plug Calc TOC @ -671' Ai 3a assmd 20% loss fi I Window from 9,392'- 9,408' Retums to Surf a , 2 9 -5/8" Prod Csg 53.5 L -80 BTC 12.25" 2,607 sx Calc TOC @-2611' - to g i 8.535 Surf 10,588' assmd 20% loss o E 1 3b " Calc TOC to s 1 t " ■ 7" Liner 29 L -80 Butt & KC 6.184 9301' 10,731' 8 -1/2" 72 bbls W /assmd 3c{ 20 %loss r IIIMB, '" Slotted IBTC AB 4 -1 /2" Liner 12.6 L -80 mod 3.958 10694' 13,835' 6" 2 1 /2" x 1 /16° slots, 48/01 ii 3d , 4 ER xy Tubing 75.15' RKB to Tbg Hngr '' SI 11 3 e 4 -1/2" 1 12.6 1 L -80 1 TCII 1 3.958 1 Surf 1 8,302' E 1 .. � 3f )0 - 2 , --. ° - Oa . r JEWELRY DETAIL Pressure Test Details as of 12/2/08 8 f1 1cg a NO. Depth ID Item Set Ili 1 4 56' 3.813" SCSSV (TRSV) D epth Results w 1 I ' I 3a 1,563' 3.833" GLM (SFO -2) Good Test 2000 psi to surface. 55' - ' 2 2,010' 3.833" Chemical Injection Sub 9,245' above top of liner. 9-%" csg tested 3b 2,643' 3.833" GLM (SFO -2) good. Could not get pkr to set in +' 3c 3,633' 3.833" GLM (SFO -2) csg between 9245' & TOL. •! 5 3d 4,553' 3.833" GLM (SFO -2) 9,350' Bad. No test above or below. 6 pkr & BP. 9,400' Bad. No test between 3e 5,355' 3.833" GLM (SFO -2) P 3f 6,062' 3.833" GLM (SFO -2) 9,480' Bad. No test between pkr & BP. ti 3g 6,797' 3.833" GLM (SFO -2) 9,515' Good Test to 2000 psi. Between , • 7 q 4 6,861' 3.850" HES PHL Retrievable Packer pkr & BP @ 9560'. I. 5 6,922' 3.813" X- Profile Nipple 9,545' Good Test to 2000 psi. Between L 6 6,973' 3.70" Mech Tbg Release (BOT Gun Drop Sub) pkr & BP A 9560'. 7 8,302' 3.950" WLEG :% 7a 8,890' N/A Plug w/ 40' of cement 7b 9,064' N/A Plug w/ 81' cement (TOC 8983') 4 8 9,284' N/A TTS umbrella plug w/ cement on top '...e 9 9,572' N/A EZSV Cement Retainer 1r1 rr. F14A TOC g 4.•: ,i • F15B Brief Details & Info: 8,983'ELM 13 Spudded M -32RD on 11/15/99. Completed on 01/25/00. M -32RD was a drill out of M -32 (window in the 9 -5/8" - 9392'). 5 fish TOC g «' , " '' ''A T '' F15C Were left in sidetrack holes while drilling the well: #1 @ 9682' - 1226' fish. #2 @ 9564' - 1088' fish. #3 @ 12418' - 5' fish. 9,016'ELM 1 " "'r*i .. #4 @ 11650' - 300'fish. #5 A 9943' (in the M -32RD section) - 780' fish. . 'oa 7b •Hole Section MWT: •Approximate Rotating hrs: t'- 0 17 -1/2" to 1347' 9.0 to 9.5 ppg o 16" 120 hrs ` F` F16 0 12 -1/4" to 10588' 9.3 to 10.1 ppg o 13 -38" 560 hrs roc g 0 8 -1/2" to 10731' 9.0 to 10.5 ppg 0 9 -5/8" 694 hrs 9,172' ELM „ v3 0 6" to 13835' 9.5 to 10.5 ppg o 7" 272 hrs TOC B A . " G01 9,252'SLM ,, '.i :.rr e :, f g Collapse Csg Csg Window = - • 9,299' ( + / -) @9392' Yr. , NV PERFORATION DATA Integrity Breach " cos Accum Last Present 9246'to9616' . i" , 'Top offill fp 9522' Zone Top Btm Amt SPF Perf. Date Condition Notes .+ 11 .16-09 .' ' Top ofCmt @9547' F14A 8,778' 8,793' 15 6 7/17/11 open 2 -7/8" PJ Omega . 9 F15B 8,944' 8,974' 30' 6 5/24/11 Isolated 3 -1/8" SDP Expro /b ' � ' "" {' F15C 9,008' 9,014' 6' 6 5/7/11 Isolated 3 -1/8" SDP Expro Milled BP ' , , r - », - . G F16 9,072' 9,092' 20' 6 3/16/2011 Isolated 2 -7/8" PowerJet Omega 1/29/11 & 3/16/11 V 14 « ,- F16 9,092' 9,112' 20 6 3/17/2011 Isolated 2 -7/8" PowerJet Omega 3/17/11 X , / . A G G01 9,212' 9,248' 36' 5 10/19/2010 Isolated 2 -1/2" PowerSpiral guns 10/19/10 ,i ' ,' G05 9,500' 9,521' 21' 5 11/17/2009 Isolated 2 -1/2" PowerSpiral guns 11/17/09 - " - 14 G -1 9,625' 9,665' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9645'- 9665') 4. + , * B - G -2 9,697' 9,737' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9714'- 9734') a r"t'` r a B - 2 G - 4 9,915' 9,990' 75' 18 12/14/2006 Isolated 4-5/8 TCP 01/2000 & 12/2006 (perfd 9933' -9953' 8 9970' - 9990) L e, a0t a. G -5 1 0,060' 10,210' 150' 18 12/14/2006 Isolated 4-5/8 TCP 01/ 2000 & 12/2006 (perrd 10700' - 10090', 10120'- � 10135' Z. 10180' - 10195) �X'x ` B -1 10,430' 10,480' 50' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 10430'- 10445') ' Collapse in4.1/2" Slottet B -2 10,510' 10,530' 20' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 '. Liner fp 10825' B -2 10,560' 10,570 10' 6 12/14/2006 Isolated 4 -5/8" TCP 12/2006 IN B3 -B7 10,694' 13,835' 3141' 01/01/2000 Isolated Slotted Liner ea y _ TD = 13,835'MD /9667'TVD M - 32RD Final Schematic 7- 16- 2011.docx TDF: 8/15/11 ' Chevron • *ding Bay Unit %O. Well # M -32RD %10 11/22/11 OBJECTIVES: • Isolate F -14A zone and perforate F -13B zone with contingency to perforate the F-11C zone. . Current BHP: -1,200 psi @ 8,057' TVD � Max Downhole Pressure: 3,615 psi @ 8,034' TVD (Based on virgin pressure gradient of 0.45psi /ft of TVD) MASP: 3,033 psi (Based on a pressure gradient of 0.0725 psi/ foot of TVD) PROCEDURE SUMMARY: 1. Rig up E -line. Pressure test lubricator 250psi low /3500psi high. 2. Set plug at +/- 8,775'. 3. Dump bail +/ -10' of cement. WOC. 4. Perform positive test and chart for 12 hours. 5. Perform negative test and chart for 12 hours. RI tag TOC. 6. Perforate F -13B zone from +/- 8,749' to +/- 8,764'. 7. Rig down E -line. 8. Turn well over to production. Flow test well. Contingency #1 -Add the F -11C sand pending results of production testing of the F -13B sand. 1. Rig up E -line. Pressure test lubricator 250psi low /3500psi high. 2. Perforate F -11 C zone from +/- 8,638' to +/- 8,663'. 3. Rig down E -line. 4. Turn well over to production. Flow test well. 5. Contingency #2 - Isolate the F -13B sand and add the F -11C sand pending results of production testing of the F -13B sand. 1. Rig up E -line. Pressure test lubricator 250psi low /3500psi high. 2. Set plug at +/- 8,720'. 3. Dump bail +/ -25' of cement. WOC. 4. Perform positive test and chart for 12 hours. 5. Perform negative test and chart for 12 hours. RI tag TOC. 6. Perforate F -11 C zone from +/- 8,638' to +/- 8,663'. 7. Rig down E -line. Turn well over to Production. W GA- STATE OF ALASKA S/17i zou ALASKA OIL AND GAS CONSERVATION COMMISSIW REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon 11 Repair Well 11 Plug Perforations U Stimulate 11 Other 11 Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate El Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ 199 -097 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic ❑ Service ❑ 6. API Number: 50- 733 - 20462 -01 © 7. Property resignation (Lease Number): 8. Well Name and Number: ADL018730 [Steelhead Platform] Trading Bay Unit M -32RD " 9. Field /Pool(s): McArthur River Field / Hemlock Oil, Middle Kenai G Oil & Middle Kenai Gas Pool 10. Present Well Condition Summary: Total Depth measured 13,835 feet Plugs measured 8,890 (Cement) feet true vertical 9,667 feet Junk measured N/A feet Effective Depth measured 8,890 feet Packer measured 6,861 feet true vertical 8,142 feet true vertical 6,570 feet Casing Length Size MD 7 TVD Burst Collapse Structural Conductor 981' 26" 981' 980' Surface 1,347' 16" 1,347' 1,346' 2,630 psi 1,020 psi Intermediate 3,767' 13 -3/8" 3,767' 3,766' 3,090 psi 1,540 psi Production 10,588' 9 -5/8" 10,588' 9,205' 7,930 psi 6,620 psi Liner 1,430' 7" 10,731' 9,266' 8,160 psi 7,020 psi Liner 3,141' 4 -1/2" (Slotted) 13,835' . 9,667' Slotted Slotted Perforation depth Measured depth 8,778- 8,793' feet / 'ij. « AI00) All (ri 1 7 ` LU11 True Vertical depth 8,057 -8,068 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2 "(Slotted) 12.6#/ L -80 8,302' 7,690' 6,861' MD 456' MD Packers and SSSV (type, measured and true vertical depth) HES PHL Retrievable 6,570' TVD TRSV 455' TVD 11. Stimulation or cement squeeze summary: RECEIVED Intervals treated (measured): N/A 2011 AUG 16 Treatment descriptions including volumes used and final pressure: N/A ifiekt & Gas Corte. Gommission 12. Representative Daily Average Production or Inittirpltir, Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 92 psi 105 psi Subsequent to operation: 0 8,400 42 781 psi 1550 psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development 0 " Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil ❑ Gas El , WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -198 Contact Billy Applewhite Phone 263 -7671 Printed Name Timothy CC. Brandenburgg Title Drilling Manager Signature ''C +e!� Phone 276 -7600 Date Mow. -r=■ AUG T, Form 10 -404 Revised 10/2010 ' P MS U 1 . r` y 1011 Submit Original Only Chevron • Stec Iliad Platform % . Well'M -32RD %. Final Schematic 7/16/11 RKB = 75.15'Rig Floor to TBG Head Casing & Tubing Size Type Wt Grade Thrd ID Top Btm Hole Cmt Cmt Top 26" Conductor Surf 981' Driven &. ,. .- , ;i.*' Cmt to Surf 1 16" Surf Csg 75 K -55 BTC 15.12 Surf 1,347' 22" 1,933 sx Calc TOC@ surf -assmd 20% II loss Returns to Surf "V 13 -3/8" Csg 61 K -55 BTC 12.52 Surf 3,767' 17.5" 2,244 sx Bumped Plug 4 ; - 3a Cale @-671' assmd d 20 20% % loss 1 Window from 9,392'- 9,408' Returns to Surf ` 2 9 -5/8" Prod Csg 53.5 L -80 BTC 8.535 Surf 10,588' 1225" 2,607 sx Calc TOC @ -2611' assmd 20% loss E ` " Mt ii 3b Calc TOC to o ' qi liner top s„ Lr 7" Liner 29 L -80 Butt & KC 6.184 9301' 10,731' 8 -1/2" 72 bbls 111111 w/assmd j' 3C 20 %loss «" `I Liner Slotted IBTC AB f 3d 4-1/2" 12.6 L -80 mod 3.958 10694' 13,835' 6" 2-1/2" x 1/16" slots, 48/ft E ge i '' Tubing 75.15' RKB to Tbg Hngr i "r"' o E. :, 3e 4 -1/2" 1 12.6 L -80 1 TCII 1 3.958 1 Surf 1 8,302' , 0,, , . , ,, " . n E S 7' 3 111111 11 3f 0' B q, 1 JEWELRY DETAIL Pressure Test Details as of 12/2/08 III 34oI i ' ' �`g NO. Depth ID Item Set W 1 456' 3.813" SCSSV (TRSV) Depth Results MAIL I 3a 1,563' 3.833" GLM (SFO -2) Good Test 2000 psi to surface. 55' , _ 2 2,010' 3.833" Chemical Injection Sub above top of liner. 9 -%" csg tested ' -•� 3b 2,643' 3.833" GLM (SFO -2) 9,245' good. Could not get pkr to set in ., .0. 3c 3,633' 3.833" GLM (SFO -2) csg between 9245' & TOL. 6 Y 3d 4,553' 3.833" GLM (SFO -2) 9,350' Bad. No test above or below. 3e 5,355' 3.833" GLM (SFO -2) 9,400' Bad. No test between pkr & BP. i; 3f 6,062' 3.833" GLM (SFO -2) 9,480' Bad. No test between pkr & BP. v 3g 6,797' 3.833" GLM (SFO -2) 9,515' Good Test to 2000 psi. Between I 4 6, _- 7, 861' 3.850" HES PHL Retrievable Packer pkr & BP @ 9560'. Good Test to 2000 psi. Between `., {� 5 6,922' 3.813" Mech X-Profile Nipple 9,545' t 6 6,973' 3.70" Mech Tbg Release (BOT Gun Drop Sub) pkr & BP @ 9560'. y 7 8,302' 3.950" WLEG 4! 7a 8,890' N/A Plug w/ 40' of cement ■ '.' 7b 9,064' N/A Plug w/ 81' cement (TOC 8983') r F14A 8 9,284' N/A TTS umbrella plug w/ cement on top I 9 9,572' N/A EZSV Cement Retainer " e s r . , tat 4 7a V =y F15B TOC@ 9■ Brief Details & Info: 8,983'ELM,I +' 1 * >? Spudded M -32RD on 11/15/99. Completed on 01/25/00. M -32RD was a drill out of M -32 (window in the 9 -5/8" - 9392'). 5 fish 4 `` F15C Were left in sidetrack holes while drilling the well: #1 @ 9682' -- 1226' fish. #2 @ 9564' - 1088' fish. #3 @ 12418' -- 5' fish. #4 @ 11 650' - 300'fish. #5 @ 9943' (i the M -32RD section) - 780' fish. s,o1s'ELM ' + •A roximate Rotating hrs: '` 7b •Hole Section MWT: PP g y 0 17 -1/2" to 1347' 9.0 to 9.5 ppg o 16" 120 hrs F16 0 12 -1/4" to 10588' 9.3 to 10.1 ppg o 13 -38" 560 hrs T0C @ e' r 0 8 -1/2" to 10731' 9.0 to 10.5 ppg o 9 -5/8" 694 hrs 9,172' ELM , •,.p o 6" to 13835' 9.5 to 10.5 ppg o 7" 272 hrs . ^A& , f g ' G01 r 70CB , 1i1!:91 9,252 SLM ,t8 j_; rC Collaps ' sg ‘1 41111110 r- Cog Window = - 9, 299' ( +1 -) *9392' I V PERFORATION DATA Integrity Breath. cos Zone To p Btm Amt Accum Last Present Notes 9245'to9516' Top offll @9522' SPF Perf. Date Condition t 11-16-09 '9 Top of Cmt re 9547' F14A 8,778' 8,793' 15 6 7/17/11 open 2 -7/8" PJ Omega I - g F15B 8,944' 8,974' 30' 6 5/24/11 Isolated 3 -1/8" SDP Expro F15C 9,008' 9,014' 6' 6 5/7/11 Isolated 3 -1/8" SDP Expro Milled BP � t ` ' ', r t _ G F16 9,072' 9,092' 20' 6 3/16/2011 Isolated 2 -7/8" PowerJet Omega 1/29/11 & 3/16/11 8 " `4y. 4 `` • t;r " F16 9,092' 9,112' 20 6 3/17/2011 Isolated 2 -7/8" PowerJet Omega 3/17/11 't '.1F ..##44rr.1. — G 001 9,212' 9,248' 36' 5 10/19/2010 Isolated 2 -1/2" PowerSpiral guns 10/19/10 i '44.4, - 005 9,500' 9,521' 21' 5 11/17/2009 Isolated 2 -1/2" PowerSpiral guns 11/17/09 '""' 7 { G -1 9,625' 9,665' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9645-9665') ' rs a s . B -1 G-2 9,697' 9,737' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9714'- 9734') T , S" 1 B - G - 4 9,915' 9,990' 75' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 8 12/2006 (perfd 993T-9953'8. 9970' - 9990) 4 -5/8" TCP 01/2000 8 12/2006 (perfd 10700'- 10090', 10120' - G - 10,060' 10,210' 150' 18 12/14/2006 Isolated 10135' & 10180' 10195) 8-1 10,430' 10,480' 50' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 10430'- 10445') ' Collapse in 4 Slottec B -2 10,510' 10,530' 20' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 E '1.: " Liner @10825' B -2 10,560' 10,570 10' 6 12/14/2006 Isolated 4-5/8" TCP 12/2006 2. w a,.' r 1f B3 -B7 10,694' 13,835' 3141' 01/01/2000 Isolated Slotted Liner rtls °3" '. xtr ▪ . ,a T'4 "mow TD = 13,835'MD19667'TVD M -32RD Final Schematic 7- 16- 2011.docx TDF: 8/15/11 • Chevron • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -32RD TRADING BAY UNIT M -32RD ADL0018730 5073320462 QZ8714 160.00 Daily Operations 7/1112011 00:00 - 7/12/2011 00:00 Operations Summary RU lubricator, pressure test to 250 psi low/ 2,500 psi high. RIH and tag fill at 8,978' RKB. RIH with 7" posiset plug and set plug from 8,942' to 8,930'. POOH. RIH with 2 -1/8 "x40' positive dump bailer and dump 1 bailer full of cement on top of plug. 7/12/2011 00:00 - 7/13/2011 00:00 Operations Summary RIH with 2 -1/8 "x40' dump bailer and dump bail 16.2ppg cement from 8,929' to 8,914'. 7/13/2011 00:00 - 7/14/2011 00:00 Operations Summary RIH Dump bail 16.2ppg cement from 8,914' to 8,904'. Runs 8 thru 14. 7/14/2011 00:00 - 7/15/2011 00:00 Operations Summary RIH Dump bail 16.2ppg cement from 8,904' to 8,893'. Runs 15 thru 20. 7/15/2011 00:00 - 7/16/2011 00:00 Operations Summary Pressure tubing up to 950 psi and perform positive pressure test of cement plug. Gaslift fluid from well to perform negative test. 7/16/2011 00:00 - 7/17/2011 00:00 Operations Summary Continue gaslift fluid from well and bleed tubing down to 250psi for 12 hr negative pressure test. 7/17/2011 00:00 - 7/18/2011 00:00 Operations Summary RU Eline PT lubricator 250psi low/ 2,500psi high ,ran press /temp tool and found fluid level at 7,680' and tag top of cement at 8,890'. Pressure tubing up to 914 psi. Perforate with 2 -7/8" powerjet omega, 6 spf, 60 deg phase from 8,778' to 8,793'. Pressure built to 1,890 psi when tools were pulled from well. Rig down Eline.Turn well over to production. ID • Iftg E CIF En S SEAN PARNELL, GOVERNOR ALASKA 0114 AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM'H SSION ANCHORAGE, ALASKA 99501 -3539 �4 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy C. Brandenburg Drilling Manager Union Oil Company of Ca lifornia 1 P.O. Box 196247 Anchorage, AK 99519 Re: McArthur River Field, Hemlock Oil Pool, TBU M -32RD Sundry Number: 311 -198 Dear Mr. Brandenburg: k . �;� 6 0t .may 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, Daniel T. Seamount, Jr. Chair DATED this tS day of June, 2011. Encl. • (e,1 ,` ' E I STATE OF ALASKA 1 c ? i i �f ?(111 ALASKA OIL AND GAS CONSERVATION COMMISSION(D' APPLICATION FOR SUNDRY APPROVALliasha oil & ?pia, Grits. Giiitmission 20 AAC 25.280 1. Type of Request: Abandon El Plug for Redrill El Perforate New Pool El Repair Well ❑ Ch rl pipp Program ❑ Suspend ❑ Plug Perforations 0 ' Perforate 0 • Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: f '10 w ft t t- R/ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: IFIC4N Union Oil Company of California Development El • Exploratory ❑ 199 -097 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196247, Anchorage, AK 99519 50- 733 - 20462 -01 • 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 0 Trading Bay Unit M -32RD • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL018730 Platform] McArthur River Field / Hemlock Oil, Middle Kenai G Oil & Middle Kenai Gas 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): 13,835 9,667 8,983 8,212 8,983 (cement) N/A Casing Length Size / MD / TVD Burst Collapse Structural Conductor 981' 26" 981' 980' Surface 1,347' 16" 1,347' 1,346' 2,630 psi 1,020 psi Intermediate 3,767' 13 -3/8" 3,767' 3,766 3,090 psi 1,540 psi Production 10,588' 9 -5/8" 10,588' 9,205' 7,930 psi 6,620 psi Liner 1,430' 7" 10,731' 9,266' 8,160 psi 7,020 psi Liner 3,141' 4 -1/2" (slotted) 13,835' 9,667' slotted slotted Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8,944 -8,974 / 8,183 -8,205 4 -1/2" 12.6# L -80 8,302 Packers and SSSV Type: Packers and SSSV My (ft) and TVD (ft): HES PHL Retrievable Packer / SCSSV 6,861'MD (6,570'TVD) / 456'MD (455'TVD) 12. Attachments: Description Summary of Proposal 1511 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development El ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/15/2011 Oil ❑ Gas E WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GsTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Billy pplewhit063 -7671 Printed Name Timothy C. Brandenburg Title Drilling Manager --- Signature �� --,�j' - hone 276 -7600 Date 5/31/2011 rallP �010.1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: . 6 \ \-. 1 C;1 Plug Integrity ❑ 1 BOP Test ❑ Mechanical Integrity Test El Location Clearance ❑ Other: Rey St14ii± C'o 20 A.At K. Ill (i' te ev'i't* te. watt y lf1 f1nex , t4. f I's a f pkV VCc( - Subsequent Form Required: t — 4 D i ', APPROVED BY / —i Approved b . COMMISSIONER THE COMMISSION Date: ( / Q /// iii ... Form 10-403 Revised 1/2010 ()RIG! NA BDMS JUN 16 2014 Submit in Dupii ate /71 f Chevron • • Trading Bay Unit 410 Well # M -32RD kl. 5/31/11 OBJECTIVES: • Isolate F -15B zone and perforate F -14A zone with contingency to perforate the F -13B and F -11 C zones. Current BHP: 2956 psi @ 8,279' TVD Max Dow Pressure: 3,557 psi @ 7,895' TVD (Based. virgin pressure gradient of 0.45psi /ft of TVD) MASP: ,05 psi (Based on a pressure gradient of .06 Isi/ foot of TVD) PROCEDURE SUMMARY: 1. R Elie Pressure test lubricator 250psi low /3500psi high. 2. Set Plug at +/ 8,93 '. 3. Dump bail +/- 35' of cement on top of plug in 9 -5/8" casing from +/- 8,930' to +/- 8,895'. WOC. 4. Perform positive test for 12 hrs. Chart test. 5. Perform negative test for 12 hrs. Chart test. RI tag TOC. 6. Perforate the F -14A sand from +rr- 8,778' o +/- 8,793'. 7. Rig down E -line. 8. Turn well over to production. Flow test well. Contingency #1 — Add the F -13B sand pending results of production testing of the F -14A sand. 1. Rig up E -line. Pressure test lubricator 250psi low /3500psi high. 2. Perforate F -13B zone from +/- -8;74' to +/- 8,764'. 3. Rig down E -line. 4. Turn well over to production. Flow test well. Contingency #la — Isolate the F -14A sand and add the F -13B sand pending results of production testing of the F -14A sand. 1. Rig up E -line. Pressure test lubricator 250psi low /3500psi high. 2. Set plug at +/- 8 775'. 3. Dump bail + -10fi cement. WOC. 4. Perform positive test and chart for 12 hours. 5. Perform negative test and chart for 12 hours. RI tag TOC. 6. Perforate F -13B zone from +/- 8,749' to +/- 8,764'. 7. Rig down E -line. Chevron • Trading Bay Unit Well # M -32RD 5/31/11 8. Turn well over to production. Flow test well. Contingency #2 — Add the F -11C sand pending results of production testing of the F -13B sand. 5. Rig up E -line. Pressure test lubricator 250psi low /3500psi high. 6. Perforate F -11 C zone from +/- 8,638' to +/- 8,663'. 7. Rig down E -line. 8. Turn well over to production. Flow test well. Contingency #2a — Isolate the F -13B sand and add the F -11 C sand pending results of production testing of the F -13B sand. 9. Rig up E -line. Pressure test lubricator 250psi low /3500psi high. 10. Set plug at +/- 8,720'. 11. Dump bail +(- 40' of cement from +/- 8,720' to +/- 8,680'. WOC. 12. Perform positive test and chart for 12 hours. 13. Perform negative test and chart for 12 hours. RI tag TOC. 14. Perforate F -11 C zone from +/- 8,638' to +/- 8,663'. 15. Rig down E -line. Chevron • Sti.ead Platform 1%0 Well # M -32RD %. Schematic 6/1/11 RKB = 75.15'Rig Floor to TBG Head Casing & Tubing ` Size Type Wt Grade Thrd ID Top Btm Hole Cmt Cmt To 26" Conductor Surf 981' Driven ' ;''* i ` --+t, Cmt to Surf 1 16" Surf Csg 75 K -55 BTC 15 Surf 1 22" 1,933 sx Calc TOC @ surf -assmd 20% loss Returns to Surf 13 -3/8" Csg 61 K -55 BTC 12.52 Surf 3,767' 17.5" 2,244 sx Bumped Plug in 3a C assmd 20% loss : MMit 1 Window from 9,392'- 9,408' Returns to Surf 12.25" 2,607 sx Calc TOC @ -2611' C* "4 k i , 2 9 -5/8° Prod Csg 53.5 L-80 BTC 8.535 Surf 10,588' - - assmd 20% loss e S. , 3b Cale TOC to ° a y ' liner top Si } 7" Liner 29 L -80 Butt & KC 6.184 9301' 10,731' 8 -1/2" 72 bbls w /assmd ° , . - . ; il 3c 1 20 %loss u Slotted IBTC AB , 4 -1/2" Liner mod 12.6 L -80 3.958 10694' 13,835' 6" 2 -1/2" x 1/16" slots, 48/ft ; il 3d 'e' � p '� Tub 75.15' RKB to Tbg Hngr °'" x n 3 a •„` 3e a 4 -I/2" 12.6 L -80 TCII 3.958 Surf 8302' �x 5 ' ,. `° �: 8 . 11 3f 1 3 > ' l Q g JEWELRY DETAIL Pressure Test Details as of 12/2/08 `P i k ' kos NO. Death ID Item Set Results 1 456' 3.813" SCSSV (TRSV) Depth I 1 3a 1,563' 3.833" GLM (SFO -2) Good Test 2000 psi to surface. 55' v = .? 9 %" csg tested ' 3b 2,643' 3.833" GLM (SFO -2) good. Could not get pkr to set in a " 3c 3,633' 3.833" GLM (SFO -2) csg between 9245' & TOL. 5 ty ; 3d 4,553' 3.833" GLM (SFO -2) 9,350' Bad. No test above or below. y 3e 5,355' 3.833" GLM (SFO -2) 9,400' Bad. No test between pkr & BP. !' :` Or 6,062' 3.833" GLM (SFO -2) 9,480' Bad. No test between r & BP. 3g 6,797' 3.833" GLM (SFO -2) Cood Test to 2000 psi. Between it )., 4 6,861' 3.850" HES PHL Retrievable Packer 9 pkr & BP @ 9560'. 1 7 Good Test to 2000 sr Between 1 1 5 6,922' 3.813" X- Profile Nipple 9 P' ?,' 6 6,973' 3.70" Mech Tbg Release (BOT Gun Drop Sub) Or & BP @ 9560'. 7 8,302' 3.950" WLEG 7a 9,064' N/A Plug w/ 81' cement (TOC 8983') ., .,I 8 9,284' N/A TTS umbrella plug w/ cement on top 9 9,572' N/A EZSV Cement Retainer t z. 1i+ F15B TOO @ V Brief Details & Info: 8,983'ELM i i s,t !) Spudded M -32RD on 11/15/99. Completed on 01/25/00. M -32RD was a drill out of M -32 (window in the 9 -5/8" — 9392'). 5 fish . ' , f. ,,, .14, F15C Were left in sidetrack holes while drilling the well: #1 @ 9682' — 1226' fish. #2 @ 9564' — 1088' fish. #3 @ 12418' — 5' fish. 9, Toc 016 @ ELM c ,44 ....,.0. 4 #4 @ 11650 — 30 0'fish. #5 @ 9943' (in t he M -32RD section) — 780' fish. ' `" ° 7a ..Hole Section MWT: ...Approximate Rotating hrs: ice, o 17 -1/2" to 1347' 9.0 to 9.5 ppg o 16" 120 hrs F16 o 12 -1/4" to 10588' 9.3 to 10.1 ppg o 13 -38" 560 hrs T; :_ IMO o 8 -1/2" to 10731' 9.0 to 10.5 ppg o 9 -5/8" 694 hrs 9,172 M , C1 o 6" to 13835' 9.5 to 10.5 ppg o 7" 272 hrs ik roc@ , A r G01 9,262 SLM; " ham f- 8 Collaps -" Csg Csg Window - 9,299' ( + / -) @9392' 1 ,, PERFORATION DATA Integrityareaell''t v cos Accum Last Present 9246'to9616' L° Top of fill @ 9622' Zone Top Btm Amt SPF Pert. Date Condition Notes 1 ,' ^ Top ofC nit @ 9647' F158 8,944' 8,974' 30' 6 5/24/11 open 3 -1/8" SDP Expro " - '7 9 F15C 9,008' 9,014' 6' 6 5/7/11 isolated 3 -1/8" SDP Expro 0. ` 'A " tt a f ' F16 9,072' 9,092' 20' 6 3/16/2011 Isolated 2 -7/8" PowerJet Omega 1/29/11 & 3/16/11 ' 4, Milled BP ^' , 3 - G-1, F16 9,092' 9,112' 20 6 3/17/2011 Isolated 2 -7/8" PowerJet Omega 3/17/11 *tie G01 9,212' 9,248' 36' 5 10/19/2010 Isolated 2 -1/2" PowerSpiral guns 10/19/10 k* �' +fA" _ G� 5 G05 9,500' 9,521' 21' 5 11/17/2009 Isolated 2 -1/2" PowerSpiral guns 11/17/09 r n . G -1 9,625' 9,665' 40' 18 12/14/20 Isolated 4-5/8" TCP 01/2000 & 12/2006 (perfds645'- 9665') ' a,1 _ G -2 9,697' 9,737' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (pert'd 9714'- 9734') # . B -1 G - 4 9,915' 9,990' 75' 18 12/14/2006 Isolated 4 -5/8° TCP 01/2000 & 12/2008 (ped'd 9933' -9953' & 9970' - 9990) .I y ' g_2 G - 10,060' 10,210' 150' 18 12/14/2006 Isolated 4-5/8° TCP 01/2000 & 12/2006 (ped'd 10700'- 10090', 10120' - 10135' & 10180'- 10195) =Nl 7 B -1 10,430' 10,480' 50' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 10430'- 10445') B -2 10,510' 10,530' 20' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 Collapse in 4-1/2" Slottec B -2 10,560' 10,570 10' 6 12/14/2006 Isolated 4 -5/8 "TCP 12/2006 e s 4 /" i " Liner 4210826' B3 -B7 10,694' 13,835' 3141' 01/01/2000 Isolated Slotted Liner I f F a1 G I .xt w sit" * ! / x m 5 ,1 y t T =" TD = 13,835'MD/9667'TVD M -32RD Schematic 6- 1- 2011.docx CVK: 6/1/11 Chevron +# Ste#ead Platform %. Proposed Well # M -32RD %. Schematic 6/1/11 RKB = 75.15'Rig Floor to TBG Head Casing & Tubing Size Type Wt Grade Thrd ID Top Btm Hole Cmt Cmt To 26° Conductor Surf 981' Driven , : ` ±, , 111 [ Cmt to Surf 1 16" Surf Csg 75 K -55 BTC 15.12 Surf 1,347' 22" 1,933 sx Calc TOC@ surf -assmd 20% loss ( Returns to Surf 13 -3/8" Csg 61 K -55 BTC 12.52 Surf 3,767' 17.5" 2,244 sx Bumped Plug Calc TOC @ -671' 3a assmd 20% loss A 1 Window from 9,392'- 9,408' Returns to Surf s 2 9 -5/8" Prod Cs g 53.5 L -80 BTC 12.25" 2,607 sx Calc TOC -2611' 60 a 4 8.535 Surf 10,588' assmd 20% loss um �E 1 3b Calc TOC to s • �) - ■ 7" Liner 29 L -80 Butt & KC 6.184 9301' 10,731' 8 -1/2" 72 bbls liner top dM • iv 11 3c ,1 w /assmd S , 20%loss 11/111 ss Slotted IBTC AB 4 -1/2" 12.6 L -80 3.958 10694' 13,835' 6" 2 -1/2" x 1/16" slots, 48/ft 3d Liner mod E R � { 1 Tubing 75.15' RKB to Tbg Hngr Mr 11 S ▪ e x 3e �y 4 -1/2" 1 12.6 1 L -80 1 TCH 1 3.958 1 Surf 1 8,302' 4'1F, i ;► lin 11 3f 1 I `tt JEWELRY DETAIL Pressure Test Details as of 12/2/08 t� Al °9 t NO Depth ID Item Set Results t 1 456' 3.813" SCSSV (TRSV) Depth I „ 1 3a 1,563' 3.833" GLM (SFO -2) Good Test 2000 psi to surface. 55' "` - _ ,. - - 2 2,010' 3.833" Chemical Injection Sub above top of liner. 9 - %" csg tested 9,245' v3 3b 2,643' 3.833" GLM (SFO -2) good. Could not get pkr to set in 0 3c 3,633' 3.833" GLM (SFO -2) csg between 9245' & TOL. 3d 4,553' 3.833" GLM (SFO -2) 9,350' Bad. No test above or below. 3e 5,355' 3.833" GLM (SFO -2) 9,400' Bad. No test between pkr & BP. 3f 6,062' 3.833" GLM (SFO -2) 9,480' Bad. No test between pkr & BP. 3g 6,797' 3.833" GLM (SFO -2) 9,515' Good Test to 2000 psi. Between 4 6,861' 3.850" HES PHL Retrievable Packer pkr & BP @ 9560'. } rF' 5 6,922' 3.813" X- Profile Nipple 9,545' Good Test to 2000 psi. Between 6 6,973' 3.70" Mech Tbg Release (BOT Gun Drop Sub) pkr & BP @ 9560'. t ',�; 7 8,302' 3.950" WLEG �� 7a +/- 8,895' N/A Proposed: Plug w/ /- 35''of cement 7b 9,064' N/A Plug w/ 81' cement (110C 8983') A 8 9,284' N/A TTS umbrella plug w/ cement on top F14A 9 9,572' N/A EZSV Cement Retainer a : }k' t '' 7 a $81r j - mg g a s' t * F75 Brief Details & Info: 8,983'ELM ' .. „. Spudded M -32RD on 11/15/99. Completed on 01/25/00. M -32RD was a drill out of M -32 (window in the 9 -5/8” - 9392'). 5 fish roc g 1 ' ' ' , F15C Were left in sidetrack holes while drilling the well: #1 @ 9682' - 1226' fish. #2 @ 9564' - 1088' fish. #3 @ 12418' - 5' fish. 9,016 ELM fi .r t " r #4 @ 11650' -- 300'fish. #5 @ 9943' (in the M -32RD section) - 780' fish. 4 " . {,fir : .Hole Section MWT: •Approximate Rotating hrs: ' o 17 -1/2" to 1347' 9.0 to 9.5 ppg o 16" 120 hrs • I IIIMIIIIP F16 o 12 -1/4" to 10588' 9.3 to 10.1 ppg o 13 -38" 560 hrs Too e o 8 -1/2" to 10731' 9.0 to 10.5 ppg o 9 -5/8" 694 hrs 9,172' ELM 4 � 4 s " t rr , ,r* '' �t ,g, . ,Y , • o 6" to 13835' 9.5 to 10.5 ppg o 7" 272 hrs G01 TOC 42 9262'SLM yl �r' 'X t'' s' i/.2t y.: Collapse Csg csg 392' ; b 9,299' ( + /•) PERFORATION DATA Goa Accum Last Present Integrity Breaehr, 0. ' ' o of Z one T op Bt m A m t Notes 9245' to 9616' •. P B 9 622 SPF Perf. Date Condition 1ofCm tgp9547' F11C +/- 8,638' / Top +1- 8,663' 25 6 Contingency 9 F13B +/- 8,730' +/- 8,740' 10 6 Contingency S ( F13B +/- 8,749' +/- 8,764' 15 6 Contingency Milled BP' ? = G1,2 F14A +1- 8,778' +/- 8,793' 15 6 Proposed t t, F15B 8,944' 8,974' 30' 6 5/24/11 Isolated 3 -1/8" SDP Expro G F15C 9,008' 9,014' 6' 6 5/7/11 Isolated 3 -1/8" SDP Expro Fi 6 9,072' 9,092' 20' 6 3/16/2011 Isolated 2 -7/8° PowerJet Omega 1/29/11 & 3/16/11 B -1 F16 9,092' 9,112' 20 6 3/17/2011 Isolated 2 -7/8" PowerJet Omega 3/17/11 GO1 9,212' 9,248' 36' 5 10/19/2010 Isolated 2 -1/2" PowerSpiral guns 10/19/10 ' a A � ' B - 2 G05 9,500' 9,521' 21' 5 11/17/2009 Isolated 2 -1/2" PowerSpiral guns 11/17/09 -, G -1 9,625' 9,665' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9645- 9665') 1 I G -2 9,697' 9,737' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9714'- 9734') 1 r Collapse in 4.1/2" 8lottet G - 4 9,915' 9,990' 75' 18 12/14/2006 Isolated 4-5/8• TCP 01/2000 & 12/2006 (perfd 9933' -9953' & 9970' - 9990) e I Liner @ 10825' G - 10,060' 10,210' 150' 18 12/14/2006 Isolated 4-5/8• TCP 01/2000 & 12/2008 (perfd 10700'- 10090', 10120'- 10135' & 10180' - 10195) B -1 10,430' 10,480' 50' 18 12/14/2006 Isolated 4 -5/8° TCP 01/2000 & 12/2006 (perfd 10430'- 10445') 13+ 1 i B -2 10,510' 10,530' 20' 18 12/14/2006 Isolated 4 -5/8° TCP 01/2000 & 12/2006 Eg r 13-2 10,560' 10,570 10' 6 12/14/2006 Isolated 4 -5/8° TCP 12/2006 ,0_ 1 - B3 -B7 10,694' 13,835' 3141' 01/01/2000 Isolated Slotted Liner 1 ' TD = 13,835'MD/9667'TVD M - 32RD Proposed Schematic 6- 1- 2011.docx CVK: 6/1/11 STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMISS IUN 0 3 2011 REPORT OF SUNDRY WELL OPERATIONS All� UiR , l E� CON. C9n�nniSSiut 1. Operations Abandon 11 Repair Well 11 Plug Perforations U Stimulate U Other LA Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ 71°-' "; ilus Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ 2. Operator Union Oil Company of Califomia 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ 199 -097 — 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic❑ Service ❑ 6. API Number: 50- 733 - 20462 -01 -- 0 7. Property Designation (Lease Number): 8. Well Name and Number: ADL018730 [Steelhead Platform] Trading Bay Unit M -32RD ' 9. Field /Pool(s): McArthur River Field / Hemlock Oil, Middle Kenai G Oil & Middle Kenai Gas Pool 10. Present Well Condition Summary: Total Depth measured 13,835 feet Plugs measured 8,983 (cement) feet true vertical 9,667 feet Junk measured N/A feet Effective Depth measured 8,983 feet Packer measured 6,861 feet true vertical 8,212 feet true vertical 6,570 feet Casing Length Size MD / TVD Burst Collapse Structural Conductor 981' 26" 981' 980' Surface 1,347' 16" 1,347' 1,346' 2,630psi 1,020psi Intermediate 3,767' 13 -3/8" 3,767' 3,766' 3,090psi 1,540psi Production 10,588' 9 -5/8" 10,588' 9,205' 7,930psi 6,620psi Liner 1,430' 7" 10,731' 9,266' 8,160psi 7,020psi Liner 3,141' 4 -1/2" (slotted) 13,835' 9,667' - - Perforation depth Measured depth 8,944 -8,974 feet / ry True Vertical depth 8,183 -8,205 feet JUN 0 6 L °11 Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 8,302' MD 7,690' TVD Packers and SSSV (type, measured and true vertical depth) HES PHL Retrievable Packer / SCSSV 6,861' / 456' MD " 6,570' / 455' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: (shut in) - - - - Subsequent to operation: (shut in) - - - - 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory Development 0 ` Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil ❑ .-Gas 0 WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -093 Contact Chis Kanyer 263 -7831 Printed Name Timothy C. Brandenburg Title Drilling Manager OP Signature O� _ — Phone 276 -7600 Date 5/31/2011 gift. = DIMS JUN 0 3 2011-• Subm Original Form 10-404 Revised 10/2010 g Only 1 • Chevron • • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -32RD TRADING BAY UNIT M -32RD ADL0018730 5073320462 QZ8714 160.00 • Jobs Primary Job Type Job Category Objective Actual Start Date Actual End Date Plug - Permanent Well 1/20/2011 3/18/2011 Services Primary Wellbore Affected Wellbore UWI Well Permit Number M -32RD 507332046201 1990970 Daily Operations 4/28/2011 00:00 - 4/29/2011 00:00 Operations Summary RU Eline. PT lubricator to 250psi low and 2500psi high. RIH w/ 3.125" GR and tagged fill at 9,093'. 4/29/2011 00:00 - 4/30/2011 00:00 Operations Summary Con't RIH w/ 3.25" GR, tag fill @ 9093'. Correlate to RST log. POOH. RIH w/ 9 -5/8" plug, set plug at 9069'. Log to 8700' as POOH. RIH w/ 3 "x40' dump bailer. Could not get past 6960'. RIH w/ 2.74" LIB, tag obstruction at 6963'. POOH. RD Eline. 4/30/2011 00:00 - 5/1/2011 00:00 Operations Summary Waiting on fishing tools. 5/1/2011 00:00 - 5/2/2011 00:00 Operations Summary RU slickline. Pressure test lubricator 250psi low /2500psi high. RIH w/ fishing tools, tag fish at 6,974', work over fish, push fish out of tubing tail and down to fill at 9,087'. Left top of fish at 9,075', POOH. RD slickline. 5/2/2011 00:00 - 5/3/2011 00:00 Operations Summary RU Eline RIH and set 9 -5/8" vented thru- tubing plug at 9,064'. RIH w/ 3 "x30' dump bailer and dump bail ceramic beads (1 run) and 8ft of 17.0ppg cement (2 runs) on top of plug. WOC for 18hrs. 5/3/2011 00:00 - 5/4/2011 00:00 Operations Summary Continue WOC. RIH w/ 3 "x30' dump bailer and tag TOC at 9,050'. RIH w/ 3.25" LIB and tagged TOC at 9,050'. RIH w/ 3 "x40' dump bailer and dump bail 17.0ppg cement (6 runs) on top of cement plug to 9,025'. Begin WOC. 5/4/2011 00:00 - 5/5/2011 00:00 Operations Summary Continue to dump bail 17.0ppg cement w/ 3 "x40' dump bailer to 9,025'. WOC and contact AOGCC to witness pressure test & tag of cement plug. Witness waived, requested copies of charted pressure tests. 5/5/2011 00:00 - 5/6/2011 00:00 Operations Summary WOC. Pressure test plug to 920 psi. and monitor 5/6/2011 00:00 - 5/7/2011 00:00 Operations Summary Unload well, bleed tubing to 100 psi and annulus to 320 psi. RU slickline, pressure test lubricator 250psilow /2500psi high. Begin RIH w. Press /temp log and perform negative test. 5/7/2011 00:00 - 5/8/2011 00:00 Operations Summary Run Press/Temp tool. Tag top of cement at 015' D slickline. RU wireline, pressure test lubricator 250psilow /2500psi high. RIH w/ 3 -1/8" 6spf 60deg phased perf guns and perforate from 9,008' 014'. RD wireline. Turn well over to production. 5/8/2011 00:00 - 5/9/2011 00:00 Operations Summary Contnue RD of equipment. Production testing well. 5/9/2011 00:00 - 5/10/2011 00:00 Operations Summary Begin RU of slickline lubricator and tools for next day operations. 5/10/2011 00:00 - 5/11/2011 00:00 Operations Summary RU slickline, pressure test lubricator 250psi low /2500psi high. RIH w/ press /temp tool and found fluid level at 1902'RKB SLM. Rig down slickline. Discuss forward plan. 5/11/2011 00:00 - 5/12/2011 00:00 Operations Summary RU E -line, RIH w/ 3 "x40' dump bailer tag top of cement @ 9015'RKB ELM. PU 1' dump 17 PPG cement w/ bottom of bailer @ 9014'RKB ELM, POOH 5/12/2011 00:00 - 5/13/2011 00:00 Operations Summary RIH w/ 3" x 40' dump bailer, tag top of cement @ 9004.5' RKB ELM, place bottom of bailer 1' off top of cement, dump sand, POH. RIH w/ 3 "x40' dump bailer tag top of cement @ 9001'RKB ELM and dump 17.0ppg cement, POH. RIH w/ dump bailer to 8997' RKB ELM, dump sand, POH. Only half of sand dumped from bailer. RIH w/ 3 "x40' dump bailer to @ 8998'RKB ELM and dump 17.0ppg cement, POH, cement did not dump from bailer. RIH w/ 3 "x40' dump bailer to @ 8998'RKB ELM and dump 17.0ppg cement, POH. 5/13/2011 00:00 - 5/14/2011 00:00 Operations Summary Standby. WOC • Chevron • • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -32RD TRADING BAY UNIT M -32RD ADL0018730 5073320462 QZ8714 160.00 Daily Operations 5/14/2011 00:00 - 5/15/2011 00:00 Operations Summary Standby. 5/15/2011 00:00 - 5/16/2011 00:00 Operations Summary Perfom positive test on cement plug, start 994 psi Ending 988 psi, Lift fluids from well using platform gas lift. 5/16/2011 00:00 - 5/17/2011 00:00 Operations Summary Unload fluid from well bore, Bleed tubing and annulus to 126 psi, Perfom negative test: starting pressure 126 psi to final pressure 119 psi in 12 hours. 5/17/2011 00:00 - 5/18/2011 00:00 Operations Summary Con't negative test on cement plug. RU E -line. RIH w/ 1 -3/8" Press/Temp tool. RIH to fluid level @ 3758' RKB. POOH. RIH w/ 3.25" GR, tag top of cement @ 8983' RKB. POOH. RD E -line. 5/24/2011 00:00 - 5/25/2011 00:00 Operations Summary / " Rig up lubricator and pressure test to 250 psi low and 2500 psi high. Perforated the F15B zone with 3 -1/8" SDP, 60 degree phase, 6 spf fom 8944' to 8974'. Tie in log was Schlumberger Sigma log dated 11- 26 -11. Pressure started increasing 1 psi per min. Had 109 psi on tubing before perforating and 149 psi after rigging down. All shots fired, turn well over to production. t Chevron • Stead Platform %. Well # M -32RD %. Schematic 6/1/11 RKB = 75.15'Rig Floor to TBG Head Casing & Tubing Size Type Wt Grade Thrd ID Top Btm Hole Cmt Cmt Top 26" Conductor Surf 981' Driven .'»''yi' Cmt to Surf 1 16" Surf Csg 75 K -55 BTC 15.12 Surf 1,347' 22" 1,933 sx Calc TOC@ surf - assmd 20% "r, loss 4 Returns to Surf 13-3/8" Csg 61 K -55 BTC 12.52 Surf 3,767' 17.5" 2,244 sx Bumped Plug Calc TOC © -671' •x � 3a assmd 20% loss µ r d 6 I Window from 9,392'- 9,408' Returns to Surf , ;, ' 2 9 -5/8" Prod Csg 53.5 L-80 BTC 8.535 Surf 10,588' 1225" 2,607 sx Calc TOC © -2611' e 7 1 3b ` t assmd20kloss o 1 Cale TOC to s in 7" Liner 29 L-80 Butt & KC 6.184 9301' 10,731' 8 -1/2" 72 bbls liner top , Um 4 w /assmd e . 3c m ' 20 %loss r t Slotted r mod IBTC AB -f all iii 3d Line 4 -1/2" 12.6 L -80 3.958 10694' 13,835' 6" 2-1/2" x 1/1s, 48 /0 e R "4 4 1 .' Tubing 75.15' RKB to Tbg Hngr h s 5' slot o e S. " % ' 3e l 4 -1/2" 12.6 1 L -80 1 TCH 1 3.958 1 Surf 1 8,302' , n. a„t.s.a, - : is i 13f a g E JEWELRY DETAIL Pressure Test Details as of 12/2/08 dt ..s a NO. Depth, ID Item Set Results y 1 1 456' 3.813" SCSSV (TRSV) Depth 1 alit 1 "# 3a 1,563' 3.833" GLM (SFO -2) Good Test 2000 psi to surface. 55' "` - -' 2 2,010' 3.833" Chemical Injection Sub above top of liner. 9 g ood. Could not g P %" csg tested L - ...,1 3b 2,643' 3.833" GLM (SFO -2) 9 et plc to set in ' 3c 3,633' 3.833" GLM (SFO -2) csg between 9245' & TOL. I 6 r , 3d 4,553' 3.833" GLM (SFO -2) 9,350' Bad. No test above or below. 4,;,.' 3e 5,355' 3.833" GLM (SFO -2) 9,400' Bad. No test between pkr & BP. 3f 6,062' 3g 6,797' 3.833" GLM (SFO -2) 9,480' Bad. No test between pkr & BP. 3.833" GLM (SFO -2) 9515' Good Test to 2000 psi. Between 'i 7 ).4f: , 4 6,861' 3.850" HES PHL Retrievable Packer pkr & BP @ 9560'. 1 5 6,922' 3.813" X- Profile Nipple Good Test to 2000 psi. Between 9 i 6 6,973' 3.70" Mech Tbg Release (BOT Gun Drop Sub) pkr & BP @ 9560'. 7 8,302' 3.950" WLEG ?' 7a 9,064' N/A Plug w/ 81' cement (TOC 8983') 8 9,284' N/A TTS umbrella plug w/ cement on top , 9 9,572' N/A EZSV Cement Retainer "i'° 1 fil S:; F15B rocs .5,1" *;. Brief Details & Info: 8,983'ELM y f Srx t ,,, :1'1 tp Spudded M -32RD on 11/15/99. Completed on 01/25/00. M -32RD was a drill out of M -32 (window in the 9 -5/8" -9392'). 5 fish TOC ''‘YE .. FI5C Were left in sidetrack holes while drilling the well: #1 @ 9682' - 1226' fish. #2 @ 9564' - 1088' fish. #3 @ 12418' - 5' fish. 9,016'ELM :75 , 40 .3.1,‘.4. 4. :0 44 11650' - 300'fish. #5 @ 9943' (in the M -32RD section) - 780' fish. ....... *Hole Section MWT: •Approximate Rotating hrs: 3, 0 17 - 1/2" to 1347' 9.0 to 9.5 ppg o 16" 120 hrs ` � _ ` F16 o 12 -1/4" to 10588' 9.3 to 10.1 ppg o 13 -38" 560 hrs s, roc n2' ELM 0 8-1/2" to 10731' 0 6" to 13835' 95 to to o 10.5 10.5 10.5 ppg ppg 9.5 o 9 -5/8" 694 hrs : �� �� o 7" 272 hrs :� a G01 9,282'SLLM , 1`fi = i �" i'a':7M,,,;1 . 6 Collaps " Csg Csg Window _ 9,299'( + / -) @9392• I.,..'' 0 PERFORATION DATA - Integrity Breach 006 Zo ne T O Btm Amt Accum Last Present Notes 9245'to9516' .t` lopoffll 962 Top SPF Perf. Date Condition ".. + 6 open p 11.16-09 8,944' 8,974' 30' 6 5/24/11 o 3 -1/8" SDP Expro e ':.. Top of Cmt @9647' F1 5 P .- ` .,r " ° 9 F15 9,008' 9,014' 6' 6 5/7/11 isolated 3 -1/8" SDP Expro / ( '",`I(' ^ ' f* F16 9,072' 9,092' 20' 6 3/16/2011 Isolated 2 -7/8" PowerJet Omega 1/29/11 & 3/16/11 Milled BP + . r G-1,2 F16 9,092' 9,112' 20 6 3/17/2011 Isolated 2 -7/8" PowerJet Omega 3/17/11 ; GO1 9,212' 9,248' 36' 5 10/19/2010 Isolated 2 -1/2" PowerSpiral guns 10/19/10 ?' ,,�t? '"t « G-4,5 005 9,500' 9,521' 21' 5 11/17/2009 Isolated 2 -1/2" PowerSpiral guns 11/17/09 ! G -1 9,625' 9,665' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9645'- 9665') * 1 (� G -2 9,697' 9,737' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9714' 9734') '1 '...1 - B -1 G-4 9,915' 9,990' 75' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 8 12/2006 (pe 993 7 " d' 3' - 9953' 8, 0' - 9990 5 10,060' 10,210' 150' 18 12/14/2006 Isolated 4 TCP 01/2000 8 12/2008 (perfd 10700' - 10090', 10120' - � , - g -2 G - 10135' 8 10180' - 10195) r f -_ � , ' a B -1 10,430' 10,480' 50' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perf'd 10430'- 10445') .µ B -2 10,510' 10,530' 20' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 Collapse in 4 -1 /2" Slotkt B -2 10,560' 10,570 10' 6 12/14/2006 Isolated 4 -5/8" TCP 12/2006 E t ,' uner�1o826' B3 -B7 10,694' 13,835' 3141' 01/01/2000 Isolated Slotted Liner F. : TD = 13,835'MD/9667'TVD M -32RD Schematic 6- 1- 2011.docx CVK: 6/1/11 . • Page l of l Regg, James B (DOA) r` 4)9 7 From: Dalebout, Joseph [APRS] [Daleboutl @chevron.com] ,1 Sent: Wednesday, May 11, 2011 6:31 PM k? To: Regg, James B (DOA); Applewhite, Billy -APRS [APRS] Subject: M -32rd Pressure Test Attachments: [Untitled].pdf; 001NIKSTL Scanned Image Jim, We tagged at 9015' RKB on the 5/7/2011, also see attached pressure test charts both positive and negative tests were good. Perforated the F15C sand on the 5/8/2011. Would not flow and turned out to be wet. We are in the process of Isolating the F15C sand now and should have Cement in place around noon tomorrow. Will wait on cement 24 hrs before testing. I will give you a call Thursday A.M. and discuss further. Thanks Joe Dalebout 776 -6833 398 -5234 A 4 0114, MAY 8 Z O 1 5/16/2011 � �� q -- # - y _ -- 120-f - -- " e /-�„ /5p s - _._._ w a �. , B � " �'' ,/" ,. ,-- p '` - — �...__,__ ----- - -105 °- -�. `.,�� -�� � �'S� \ �� i c�0 7 ,.- sp y 7< 1 ' i ----"" ?- °O -`,. 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I - ^+ -..a.. • t \'''' N ' -, '''•''----, 1 , O ! . f \N i b y/`J -r 6 . 0 , 11 1116, ''''''''''',,,,,.- '''' - '' :tCk'C ... . a-- '''''' = ...,-.'''''' ' • • S WEE [IF ALASKA SEAN PARNELL, GOVERNOR ALASKA 0114 AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVAl`ION COMIIIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Timothy C. Brandenburg Drilling Manager (I - 0 q Union Oil Company of California t 1 i P.O. Box 196247 Anchorage, AK 99519 Re: McArthur River Field, Hemlock Oil 85 Middle Kenai Pool, TBU M -32RD Sundry Number: 311 -093 ANNUED MAR Dear Mr. Brandenburg: 2011 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, J Daniel T. Seamount, Jr. Chair DATED this -3d day of March, 2011. Encl. CSI • 7 .Z (3,1, `, Gh STATE OF ALASKA 7 �f41 AR 4 ?.on o31:40u ALASKA OIL AND GAS CONSERVATION COMMISSION 4. APPLICATION FOR SUNDRY APPROVALSAtsske Oil & G c ans. 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ ChanNWIEWProgram ❑ Suspend ❑ Plug Perforations El - Perforate 0 - Pull Tubing ❑ ]Rl4k Time Extension 0 Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Te St I2 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development Q - Exploratory ❑ 199 -097 - 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196247, Anchorage, AK 99519 50- 733 - 20462 -01 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 0 Trading Bay Unit M -32RD- 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL018730 [Steelhead Platform] -, McArthur River Field / Hemlock Oil, Middle Kenai G Oil & Middle Kenai Gas 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): 13,835 9,667 9,172 8,356 9,172 (cement) N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 981' 26" 981' 980' Surface 1,347' 16" 1,347' 1,346' 2,630 psi 1,020 psi Intermediate 3,767' 13 -3/8" 3,767' 3,766 3,090 psi 1,540 psi Production 10,588' 9 -5/8" 10,588' 9,205' 7,930 psi 6,620 psi Liner 1,430' 7" 10,731' 9,266' 8,160 psi 7,020 psi Liner 3,141' 4 -1/2" (slotted) 13,835' 9,660' slotted slotted Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,072 -9,112 8,281 -8,311 4 -1/2" 12.6# L -80 8,302 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): HES PHL Retrievable Packer / SCSSV 6,861'MD (6,570'TVD) / 456'MD (455'TVD) 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Development 0 Service El 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/6/2011 Oil ❑ Gas El - WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ ❑ GINJ El WAG El Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer 263 -7831 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature _ .,- .'t G e 276 -7600 Date 3/23/2011 -- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ( ( ` Plug Integrity 2 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance El Other: R ECEIVE MAP ; .4 Subsequent Form Required: , 0 — q 0 44. Alaska 011 8 q>wtr Gi n a C�nirr aay .U/! aE .vr :> / APPROVED BY Approved by: -- COMMI SIONER THE COMMISSION Date: 3 . 3 d 11 Form 10-403 Revised 1/201 - N MAR 31101 k I G1NAL Submit in Duplicate Chevron • • Trading Bay Unit W Well # M -32RD 1%01 3/23/11 OBJECTIVES: • Isolate F -16 zone and perforate F -15C zone with contingency to perforate the F -15B zone. Current BHP: 2,956 psi @ 8,279' TVD Max Do o e Pressure: 3,635 psi @ 8,231' TVD (Based on virgin pressure gradient of 0.45psi /ft of TVD) MASP 2,81 si (Based on a pressure gradient of 0.1psi/ foot of TVD) PROCEDURE SUMMARY: 1. RU Eline. Pressure test lubricator 250psi low /3000psi high. 2. Set Plug at +/- 9,065'. 3. Dump bail +/- 35' of cement on top of plug in 9 -5/8" casing from +/- 9,065' to +/- 9,030'. WOC. 4. Perform negative test for 12 hrs. Chart test. RI tag TOC. 5. Perforate the F -15C sand from +/- 9,006' to +/- 9,016'. 6. Rig down E -line. 7. Turn well over to production. Flow test well. Contingency #1 – Add the F -15B sand pending results of production testing of the F -15C sand. 1. Rig up E -line. Pressure test lubricator 250psi low /3000psi high. 2. Perforate F15B zone from +/- 8,944' to +/- 8,974'. 3. Rig down E -line. 4. Turn well over to production. Flow test well. Contingency #2 – Isolate the F -15C sand and add the F -15B sand pending results of production testing of the F -15C — sand. 1. Rig up E -line. Pressure test lubricator 250psi low /3000psi high. 2. Dump bail 47' of cement from +/- 9,030' to +/- 8,983'. WOC. 3. Perform negative test and chart for 12 hours. RI tag TOC. 4. Perforate F15B zone from +/- 8,944' to +/- 8,974'. 5. Rig down E -line. 6. Turn well over to production. Flow test well. " Chevron • Stetad Platform iiiV Wel M -32RD Schematic Revised 3/23/11 RKB = 75.15'Rig Floor to TBG Head Casing & Tubing Size Type Wt Grade Thrd ID Top Btm Hole Cmt Cmt Top 26" Conductor Surf 981' Driven , ` +,,� ti , Cmt to Surf 1 16" Surf Csg 75 K -55 BTC 15.12 Surf 1,347' 22" 1,933sx CaIcTOC@surf -assmd 20 % loss t Returns to Surf 13 -3/8" Csg 61 K -55 BTC 12.52 Surf 3,767' 17.5" 2,244 sx Bumped Plug 4 a 3 Calc TOC @ -671' assmd 20% loss F '''. Window from 9,392'- 9,408' Returns to Surf I 2 9 -5/8" Prod Csg 53.5 L -80 BTC 12.25" 2,607 sx Calc TOC @ -2611' m 8.535 Surf 10,588' assmd 20% loss :A - , "« 3b " Calc TOC to s * "* 7" Liner 29 L 80 Butt & KC 6.184 9301' 10,731' 8-1/2' /2" 72 bbls liner top w /assmd "I ^ 3c 'J 20 %loss Slottener mod AB 4 Li 4 -1/2" 12.6 L -80 3.958 10694' 13,835' 6" 2-1/2" x 1/16 slots, 48/0 '' 3d Tubing 75.15' RKB to Tbg Hngr ' o f *, I -- 4 -1/2" 1 12.6 1 L -80 1 TCH 1 3.958 I Surf 1 8,302' I E4 , E g J j1 3e sa y! JEWELRY DETAIL Pressure Test Details as of 12/2/08 oe's 3f NO. Depth ID Item S e t Results ;I 1 456' 3.813" SCSSV (TRSV) Depth l e! al 3a 1,563' 3.833" GLM (SFO -2) Good Test 2000 psi to surface. 55' � 2 2,010' 3.833" Chemical Injection Sub 9,245' above top of liner. 9-%" csg tested 3b 2,643' 3.833" GLM (SFO -2) good. Could not get pkr to set in e h 1 1 1 ,. 3c 3,633' 3.833" GLM (SFO -2) csg between 9245' & TOL. - 3d 4,553' 3.833" GLM (SFO -2) 9,350' Bad. No test above or below. +. a 3e 5,355' 3.833" GLM (SFO -2) 9,400' Bad. No test between pkr & BP. V, 5 3f 6,062' 3.833" GLM (SFO -2) 9,480' Bad. No test between Or & BP. ti" 6 3g 6,797' 3 GLM (SFO -2) 9,515' Good Test to 2000 psi. Between N MB t 4 6,861 3.850 HES PHL Retrievable Packer pkr & BP @ 9560'. ` ? 5 6,922' 3.813" X- Profile Nipple 9,545' Good Test to 2000 psi. Between iii '"" 7 tit 6 6,973' 3.70" Mech Tbg Release (BOT Gun Drop Sub) Or & BP (u, 9560'. Tag TOC (j 7 8,302' 3.950" WLEG • r 9,172 RKB ELM 1 n o 1/29/11 8 9,284' N/A TTS umbrella plug w/ cement on top ' 9 9,572' N/A EZSV Cement Retainer r � r' � TOC Ig 9,263' ., ..' RKBSLM � 1 Collapse Csg 9,299' ( +I -) t'' Csg Wiadow Brief Details & Info: X9392' Spudded M -32RD on 11/15/99. Completed on 01/25/00. M -32RD was a drill out of M -32 (window in the 9 -5/8" - 9392'). 5 fish mtegriry Breacn " ; Were left in sidetrack holes while drilling the well: #1 @ 9682' - 1226' fish. #2 @ 9564' -- 1088' fish. #3 @ 12418' - 5' fish. 9245' to 9515' G06 #4 @ 11650' - 300' fish. #5 @ 9943' (in the M -32RD section) - 780' fish. ,. Top ofRHH@9522' •Hole Section MWT: •Approximate Rotating hrs: 11 o 17 -1/2" to 1347' 9.0 to 9.5 ppg o 16" 120 hrs Top of Cm41.1 9647' o 12 -1/4" to 10588' 9.3 to 10.1 ppg o 13 -38" 560 hrs ID 9 o 8 -1/2" to 10731' 9.0 to 10.5 ppg o 9 -5/8" 694 hrs 0 6" to 13835' 9.5 to 10.5 ppg o 7" 272 hrs - G-1,2 i ,. G-4,5 I PERFORATION DATA B -1 Zone Top Btm Amt Accum Last Present Notes SPF Perf. Date Condition F16 9,072' 9,092' 20' 6 3/16/2011 Open 2 -7/8" PowerJet Omega 1/29/11 & 3/16/11 B-2 F16 9,092' 9,112' 20 6 3/17/2011 Open 2 -7/8" PowerJet Omega 3/17/11 G01 9,212' 9,248' 36' 5 10/19/2010 Isolated 2 -1/2° PowerSpiral guns 10/19/10 Milled BP d. G05 9,500' 9,521' , 21' 5 11/17/2009 Isolated 2 -1/2" PowerSpiral guns 11/17/09 G -1 9,625' 9,665' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perf'd 9645- 9665') G -2 9,697' 9,737' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9714'- 9734') G - 4 9,915' 9,990' 75' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9933' -9953' & 9970' - 9990') G - 10,060' 10,210' 150' 18 12/14/2006 Isolated 4-5/8" TCP 01/2000 & 12/2006 (perfd 10700'- 10090', 10120' - Couapse In /2" slotted 10135 & 1 - 10195') Liner e 10926' 4.1 B -1 10,430' 10,480' 50' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 10430- 10445') B -2 10,510' 10,530' 20' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 B -2 10,560' 10,570 10' 6 12/14/2006 Isolated 4 -5/8" TCP 12/2006 B3 -B7 10,694' 13,835' 3141' 01/01/2000 Isolated Slotted Liner E d ' so i'4 fir 4' 4"x• TD = 13,835'MD19667'TVD M -32RD Schematic 3- 23- 2011.docx SBJ: 3/23/2011 ' 'chevron %. "PROPOSED Stead Platform Well # M -32RD %.1 Schematic 3/23/11 RKB = 75.15'Rig Floor to TBG Head Casing & Tubing Size Type Wt Grade Thrd ID Top Btm Hole Cmt Cmt Top 26" Conductor Surf 981' Driven ., ;,,, ,,, , „ _ Cmt to Surf 1 16" Surf Csg 75 K -55 BTC 15.12 Surf 1,347' 22" 1,933 sx Calc TOC@ surf -assmd 20% 1111 loss Returns to Surf 13 -3/8" Csg 61 K -55 BTC 12.52 Surf 3,767' 17.5" 2,244 sx Bumped Plug Calc TOC @ -671' e , 1 il 3a assmd 20% loss v I Wndow from 9,392' - 9,408' Returns to Surf 6 1 ' 2 9 -5/8 P rod Csg 53.5 L-80 BTC 8.535 Surf 10,588' 12.25" 2,607 sx Calc TOC @ -2611' .. assmd 20% loss 3b :' _. o 2 Calc TOC to IF ;' 7" Liner 29 L -80 Butt & KC 6.184 9301' 10,731' 8 -1/2" 72 bbls liner top w /assmd 3 c ' 20 %loss }" 4-1/2" S � °� 12.6 L -80 mood AB 3.958 10694' 13,835' 6" 2 -1/2" x 1/16" slots, 48/ft E 4 .' 3d ,� Tubing 75.15' RKB to Tbg Hngr � ' : 1' o 4 - 1/2" 12.6 L -80 TCII 3.958 Surf 8,302 ° .� ,.,�,,1; h ., � x ,., E 4 , i $ 8 E �) j1 3eIX, 5 0 '' JEWELRY DETAIL Pressure Test Details as of 12/2/08 1 ;1 s' g - 4. 1111 j1 NO. Depth ID Item Set Results 1 456' 3.813" SCSSV (TRSV) Depth " 3a 1,563' 3.833" GLM (SFO -2) Good Test 2000 psi to surface. 55' i * � 3g4 2 2,010' 3.833" Chemical Injection Sub 9,245' above top of liner. 9-%" csg tested good. Could not get kr to set in 3b 2,643' 3.833" GLM (SFO -2) g t P 4 .% 1 I 1 " 3c 3,633' 3 833" GLM (SFO -2) csg between 9245' & TOL. = 1 3d 4,553' 3.833" GLM (SFO -2) 9,350' Bad. No test above or below. : t 3e 5,355' 3.833" GLM (SFO -2) 9,400' Bad. No test between pkr & BP. 5 3f 6,062' 3.833" GLM (SFO -2) 9,480' Bad. No test between pkr & BP. a' g s' 3g 6,797' 3.833" GLM (SFO -2) 9,515' ,r. Good Test to 2000 psi. Between t * 7 1 4 6,861' 3.850" HES PHL Retrievable Packer pkr & BP @ 9560'. t t '> 5 6,922' 3.813" X- Profile Nipple 9,545' Good Test to 2000 psi. Between '` `'t 6 6,973' 3.70" Mech Tbg Release (BOT Gun Drop Sub) Or & BP @ 9560'. 7 a �,:eir S'a +a* .t f - ^ Tag TOC 7 8,302' 3.950" WLEG r y r 9,172 RKB ELM 7a 9,065 N/A Plug w /( + / -) 35' cement (Proposed) ' k 1129/11 8 9,284' N/A TTS umbrella plug w/ cement on top , ,,,. ,p RKB roc X9,263' 9 9,572' N/A EZSV Cement Retainer 6 1 Collapse Csg 9,299' ( +l -) Csg Window Brief Details & Info: @9392' Spudded M -32RD on 11/15/99. Completed on 01/25/00. M -32RD was a drill out of M -32 (window in the 9 -5/8" - 9392'). 5 fish Integrity Breach Were left in sidetrack holes while drilling the well: #1 @ 9682' - 1226' fish. #2 @ 9564' -- 1088' fish. #3 @ 12418' - 5' fish. 9245' to 9515' • — 005 #4 @ 11650' - 300' fish. #5 @ 9943' (in the M -32RD section) - 780' fish. Top of fill�9622' •Hole Section MWT: •Approximate Rotating hrs: 11.16 - 0s o 17 -1/2" to 1347' 9.0 to 9.5 ppg o 16" 120 hrs lop of cmt 9647 o 12 -1/4" to 10588' 9.3 to 10.1 ppg o 13 -38" 560 hrs s 9 o 8 -1/2" to 10731' 9.0 to 10.5 ppg o 9 -5/8" 694 hrs o 6" to 13835' 9.5 to 10.5 ppg o 7" 272 hrs G -1.2 G-4,5 • PERFORATION DATA ' 8-1 Zone Top Btm Amt Accum Last Present Notes SPF Perf" Date Condition F15B +/- 8,944' +/- 8,974' 30' 6 Contingency ■ B - F15C +/- 9,006' +/- 9,016' 10' 6 Proposed F16 9,072' 9,092' 20' 6 3/16/2011 Isolated 2 -7/8" PowerJet Omega 1/29/11 & 3/16/11 Milled BP �? F16 9,092' 9,112' 20 6 3/17/2011 Isolated 2 -7/8" PowerJet Omega 3/17/11 GOt 9,212' 9,248' 36' 5 10/19/2010 Isolated 2 -1/2" PowerSpiral guns 10/19/10 i- G05 9,500' 9,521' 21' 5 11/17/2009 Isolated 2 -1/2" PowerSpiral guns 11/17/09 I < G -1 9,625' 9,665' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9645- 9665') Collapse in a112" 8bt0ed G -2 9,697' 9,737' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 ( perfd 9714'- 9734') Liner 10825' G - 4 9,915' 9,990' 75' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9933' -9953' & 9970'- 9990') G -5 10,060' 10,210' 150' 18 12/14/2006 Isolated 4-5/8" TCP 01/2000 & 12/2006 (perfd 10700' - 10090', 10120' - 10135' & 10180' - 10195') B -1 10,430' 10,480' 50' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 ( perfd 10430'- 10445') B -2 10,510' 10,530' 20' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 E N B -2 10,560' 10,570 10' 6 12/14/2006 Isolated 4 -5/8" TCP 12/2006 B3 -B7 10,694' 13,835' 3141' 01/01/2000 Isolated Slotted Liner TD = 13,835'MD/9667'TVD M -32RD (F15C) Proposed Schematic 3- 23- 2011.docx SBJ: 3/23/2011 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well LJ Plug Perforations U Stimulate U Other U Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate El Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ 199 -097 1 " 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic❑ Service ❑ 6. API Number: 50- 733 - 20462 -01 =00 7. Property Designation (Lease Number): 8. Well Name and Number: I. ADL018730 [Steelhead Platform] ' Trading Bay Unit M -32RD 9. Field /Pool(s): McArthur River Field / Hemlock Oil, Middle Kenai G Oil & Middle Kenai Gas Pool 10. Present Well Condition Summary: Total Depth measured 13,835 feet Plugs measured 9172 (cement) feet true vertical 9,667 feet Junk measured N/A feet Effective Depth measured 9,172 feet Packer measured 6,861 feet true vertical 8,356 feet true vertical 6,570 feet Casing Length Size MD / ND Burst Collapse Structural Conductor 981' 26" 981' 980' Surface 1,347' 16" 1,347' 1,346' 2,630psi 1,020psi Intermediate 3,767' 13 -3/8" 3,767' 3,766' 3,090psi 1,540psi Production 10,588' 9 -5/8" 10,588' 9,205' 7,930psi 6,620psi Liner 1,430' 7" 10,731' 9,266' 8,160psi 7,020psi Liner 3,141' 4 -1/2" (slotted) 13,835' 9,667' Perforation depth Measured depth 9,072 -9,112 feet ECEl �y `ZU1 MAR 2 4 True Vertical depth 8,281 -8,311 feet DIED APR . / Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 MP Q & $38S ' ^,rssior es Packers and SSSV (type, measured and true vertical depth) HES PHL Retrievable Packer / SCSSV 6,861' / 456' MD 6,570' 455' ND 11. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 94psi 98psi Subsequent to operation: 0 0 0 105psi 395psi 13. Attachments: 14. Well Class after work: ,. Copies of Logs and Surveys Run N/A Exploratory I=1 Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil ❑ t Gas El WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Chis Kanyer 263 -7831 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature / C. �R -- Phone 276 -7600 Date 3/23/2011 HBDINlS MAR 2 9 1011 Form 10-404 Revised 10/2010 Submit Original Only Chevron • Stead Platform IN Well # M -32RD Schematic Revised 3/23/11 RKB = 75.15'Rig Floor to "fBG Head Casing & Tubing Size Type Wt Grade Thrd ID Top Btm Hole C mt Cmt To 1 26" Conductor Surf 981' Driven Cmt to Surf 1 16" Surf Csg 75 K -55 BTC 15.12 Surf 1,347' 22" 1,933 sx Caassmd @ % surf f loss ' R to Surf 13 -3/8" Cs 61 K -55 BTC 12.52 Surf 3,767' 17.5" 2,244 sx Bumped Plug g Calc TOC @ -671' at ,i I ) 3a assmd 20% loss CS Window from 9,392'- 9,408' Returns to Surf s - t� ! .25" 2,607 sx Calc TOC @ -2611' • ' °� 8.535 Surf 10,588' assmd 20% loss e '. I r a 3b '! Calc TOC to o t finer top 5� 7" Liner 29 L -80 Butt & KC 6.184 9301' 10,731' 8 -1/2" 72 bbls w /assmd � 3c 20 %loss e Slotted mod AB R i 4-1/2" Liner 12.6 L-80 mod 3.958 10694' 13,835' 6" 2-1/2" x 1/16" slots, 48/ft r il 3d Tubing 75.15' RKB to Tbg Hngr m R ,. o �-" 4 -1/2" I 12.6 1 L -80 1 TCH 1 3.958 I Surf 1 8,302' Ili y' felt' , 11 3e �: JEWELRY DETAIL Pressure Test Details as of 12/2/08 i'Ls ', 3f _ NO. Depth ID Item S e t Results ME il 1 456' 3.813" SCSSV (TRSV) Depth ±`4t 9 '.4 3a 1,563' 3.833" GLM (SFO -2) Good Test 2000 psi to surface. 55' 3 2 2,010' 3.833" Chemical Injection Sub above top of liner. 9 csg tested } 4 3b 2,643 3.833" G LM ( SFO -2) 9,245 g ood. Could not g et pkr to set in k„ I IIIWE I 3c 3,633' 3.833" GLM (SFO -2) csg between 9245' & TOL. r _ .1 3d 4,553' 3.833" GLM (SFO - 9,350' Bad. No test above or below. _ ♦ 3e 5,355' 3.833" GLM (SFO -2) 9,400' Bad. No test between pkr & BP. '± 3.833" GLM (S - 9,480' Bad. No test between pkr & BP. 2 5 3f 6,062 r* s� 3g 6,797' 3.833" GLM (SFO -2) 9,515' Good Test to 2000 psi. Between tt JIM 6 4 6,861' 3.850" HES PHI Retrievable Packer pkr & BP @ 9560'. !",:,,t. Good Test to 2000 psi. Between �" 7 5 6 3.813" X- Profile Nipple 9 6 _ 6,973' 3.70" Mech Tbg Release (POT Gun Drop Sub) pkr & BP @ 9560'. 4:f* , TOc (j 7 8,302' 3.950" WLEG . - ` 917 RKB ELM 8 9,284' N/A TTS umbrella plug w1 cement on top to . -?' < `'l t r =" ° 9 9,572' N/A EZSV Cement Retainer s*} _ TOC IS 9,263' 1 RKB SLM I Collapse sg 9,299' ( + -• • Csg Window Brief Details & Info: a" °:9392' Spudded M -32RD on 11/15/99. Completed on 01/25/00. M -32RD was a drill out of M -32 (window in the 9-5/8" - 9392'). 5 fish Integrity Breach ; � Were left in sidetrack holes while drilling the well: #1 @ 9682' - 1226' fish. #2 @ 9564' - 1088' fish. #3 @ 12418' - 5' fish. 9246' to 9616' 1; 006 44 @ 11650' - 300'fish. #5 @ 9943' (in the M -32RD section) - 780' fish. ' y 'Topot69 I§ 5922' •Hole Section MWT: •Approximate Rotating hrs: 11 -16-09 o 17 -1/2" to 1347' 9.0 to 9.5 ppg o 16" 120 hrs *: 1 r ; Top ofcmtg9w7' o 12- 1 /4 "to 10588' 9.3 to 10.1 ppg o 13 - 38" 560 hrs Ali 1 ,. o 8 -1/2" to 10731' 9.0 to 10.5 ppg o 9 - 5/8" 694 hrs ► . , • o 7" 272 hrs , r .+� o 6" to 13 9.5 to 10.5 ppg t fib e : G12 l �, G4,5 y1 4' 1 .1 PERFORATION DATA . M , x Accum Last Present 1 jt .4, r ; = B -1 Zone Top Btm Amt SPF Perf. Date Condition Notes . ' ,, r y — F16 9,072' 9,092 20' 6 3/16/2011 Open 2 -7/8" PowerJet Omega 1/29/11 & 3/16/11 � '' 53 F16 9,092' 9,112' 20 6 3/17/2011 Open 2 -7/8" PowerJet Omega 3/17/11 y GO1 9,212' 9,248' 36' 5 10/19/2010 Isolated 2 -1/2" PowerSpiral guns 10/19/10 MIIIId BP V r` 4. ' : G05 9,500' 9,521' 21' 5 11/17/2009 Isolated 2 -1/2" PowerSpiral guns 11/17/09 G -1 9,625' 9,665' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9645- 9665') i" G -2 9,697' 9,737' 40' _ 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perf d 9714- 9734') G - 4 9,915' 9,990' 75' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9933' -9953' & 9970' - 9990) 4 -5/8" TCP 01/2000 & 12/2008 (perf'd 10700' - 10090', 10120- G - 10,060' 10,210' 150' 18 12/14/2006 Isolated Collapse in 4 Slotted 10135' & 10180' - 10195) e; Liner @10825' B -1 10,430' 10,480' 50' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12)2006 (perfd 10430'- 10445') > • -'+ *' -'' B -2 10,510' 10,530' 20' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 r B -2 10,560' 10,570 10' 6 12/14/2006 Isolated 4 -5/8" TCP 12/2006 r 1 63 -67 10,694' 13,835' 3141' , 01/01/2000 Isolated Slotted Liner o ae tit 1 , , a ,i m y 1 't ifY t t L fp. a -', 7 TD = 13,835'MD19667'TVD M -32RD Schematic 3- 23- 2011.docx SBJ: 3/23/2011 Chevron • °110 Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -32RD TRADING BAY UNIT M -32RD ADL0018730 5073320462 QZ8714 160.00 n Primary Job Type Job Category Objective Actual Start Date Actual End Date Plug - Permanent Well 1/20/2011 Services Primary Wellbore Affected Wellbore UWI Well Permit Number M -32RD 507332046201 1990970 Ai1' � Q11 003t0,,-..3/16/2011 00 � : .., :r = ,s .. Operations Summary Perform maintenance on Schlumberger equipment. 3116122011 00:00 - 3/17/2011 0 00 Operations Summary RU Eline. Pressure test lubricator to 250psi low and 3000psi high. MU, RIH and Perforate with 2 -7/8" HC PowerJet Omega pert gun from 9072' - 9092'. POOH. LD spent guns. RD Eline.Flow test well. ;3/k201 OOx00.- 3/1812011 00 :00 Operations Summary RU Eline. PT lubricator to 250psi low and 3000psi high. RIH and Perforate with 2 -7/8" HC PowerJet Omega pert gun from 9092' - 9112'. POOH. LDspe gun. RD Eline. Turn well over to production. torah STATE OF ALASKA �fiii,o/l ALASKA. AND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U • Stimulate U Other U Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 • Exploratory ❑ 199 -097 \ 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic Service ❑ 6. API Number: 50- 733 - 20462 -01 7. Property Designation (Lease Number): 8. Well Name and Number: ADL018730 [Steelhead Platform] Trading Bay Unit M -32RD • 9. Field /Pool(s): . McArthur River Field / Hemlock Oil, Middle Kenai G Oil & Middle Kenai Gas Pool 10. Present Well Condition Summary: Total Depth measured 13,835 • feet Plugs measured 9,172' feet true vertical 9,667 feet Junk measured N/A feet Effective Depth measured 9,172' feet Packer measured 6,861 feet true vertical 8,356' feet true vertical 6,570 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 981' 26" 981' 980' Surface 1,347' 16" 1,347' 1,346' 2,630psi 1,020psi Intermediate 3,767' 13 -3/8" 3,767' 3,766' 3,090psi 1,540psi Production 10,588' 9 -5/8" 10,588' 9,205' 7,930psi 6,620psi Liner 1,430' 7" 10,731' 9,266' 8,160psi 7,020psi Liner 3,141' 4 -1/2" (slotted) 13,835' 9,667' Perforation depth Measured depth 9,072 -9,092 feet True Vertical depth 8,281 -8,296 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" / 12.6# L -80 8,302' MD 7,690' TVD Packers and SSSV (type, measured and true vertical depth) HES PHL Retrievable Packer / SCSSV 6,861' / 456' MD 6,570' / 455' TVD 11. Stimulation or cement squeeze summary: RECEIVE3 Intervals treated (measured): M ` MAR 0 1 20 1 t FEB 2 4 201 N/A Treatment descriptions including volumes used and final pressure: Gas C p N/A ea & Gas CQes. 12. Representative Daily Average Production or Injection Dom• Oil-Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 840psi 417psi Subsequent to operation: 0 11,250 3 940psi 1,529psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory Development 0 • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil ❑ Gas U • WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -446 Contact Chis Kanyer 263 -7831 Printed Name j , Timothy C. Brandenburg Title Drilling Manager /,, r Signature _ ., . /.._ A. Phone 276 -7600 Date 2/22/2011 BDMS MAR GI ZM11 e* /> x.2-9. r/ Form 10 -404 Revised 10/2010 Submit Original Only • Chevron • • Chevron - Alaska %.0 Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M 32RD TRADING BAY UNIT M -32RD ADL0018730 5073320462 QZ8714 160.00 �, s, ' Primary Job Type Job Category Objective Actual Start Date Actual End Date Plug - Permanent Well 1/20/2011 Services Primary Wellbore Affected Wellbore UWI Well Permit Number M -32RD 507332046201 1990970 e m 1/20/2011 00:00'- 1/211201100:0Q Operations Summary RU slickline. Pressure test lubricator to 250psi low /2500psi high. RIH and tag at 9,252'. Begin dump bailing sand from 9,252' to 9,241'. 1/21/2011 00:04- 1/22/2011 00:00 Operations Summary Continue dump bailing sand from 9,241' to 9,224'. 1/22/2011 00:00 - 1/23/2011 O0, 1. °4,. Operations Summary Continue dump bailing sand from 9,224' to 9,210'. RD Slickline. RU Eline. Pressure test lubricator to 250psi low /2500psi high. RIH and tag sand at 9,202'ELM. Begin dump bailing 16.2ppg cement from 9,202' to 9,199'. 1/23/2011 00 :00 1/24/2011 00: # °j : s' Operations Summary Continue dump bailing 16.2ppg cement from 9,199' to 9,180'. '1 24/2011 i 0 :00' -1/2 4 Operations Summary Continue dump bailing 16.2ppg cement from 9,180' to 9,177'. RD Eline. WOC. ".00 2011 00:00 Operations Summary Performed negative test on plug, failed. RU slickline, Pressure test lubricator 250psi low /2500psi high. RIH w/2.5" bailer tagged cement at 9,172'SLMr" RIH w/ static pressure temperature survey to 9,172'. POOH. 1128/2011 00:00 >N 11271201 0040 e � °. �.:�. Operations Summary Continue POOH with pressure temperature survey, download data, RD slickline. Production performed negative pressure test, good test 112812011 00 :00 1/29/201100: +'# Operations Summary RU slickline, pressure tested lubricator 250psi low /2500psi high. RIH w/ 3.68" GR and located fluid at 4,009' RKB SLM. Gas lifted fluid from well, Bleed off pressure to 150psi, RIH w/ 3.68" GR and located fluid at 7,247' RKB SLM. 1729/2011 00:00 1130/2011 00:00 u ° 1 Operations Summary Waited 3 hours and re- located fluid level at 7,246' RKB SLM. RD slickline. RU Eline, pressure tested lubricator 250psi low /2500psi high. RIH w/ 2 -7/8" PJ Omega 6spf, 60deg guns and perforate F -16 zone from 9,072'- 9,092'. RD Eline. Turned well over to production. • Chevron • Stad Platform � Well# M -32RD — Schematic RKB = 75.15'Rig Floor to TBG Head Casing & Tubing ' Size Type Wt Grade Thrd ID Top Btm Hole Cmt Cmt Top i 26" Conductor Surf 981' Driven ,-V' ' " l <a PA +' l • Cmt to Surf 1 16" Surf Csg 75 K -55 BTC 15.12 Surf 1,347' 22" 1,933 sx Calc TOC@ surf -assmd 20% loss 9 Returns to Surf 13 -3/8" Csg 61 K -55 BTC 12.52 Surf 3,767' 17.5" 2,244 sx Bumped Plug `" 1 3a C assmd 20% loss .' S I Window from 9,392'- 9,408' Returns to Surf 2 9 -5/8" Prod Csg 53.5 L-80 BTC 12.25" 2,607 sx Cale TOC @ ^2611' R � " 1 8.535 Surf 10,588' assmd 20% loss el s a j1 3b ;" CaIc TOC to o II 7" Liner 29 L-80 Butt & KC 6.184 9301' 10,731' 8 -1/2" 72 bbls liner top v 3c « � 20 %loss a" Slotted IBTC AB 4 -1/2 Liner 12.6 L -80 mod 3.958 10694' 13,835' 6" 2 -1/2" x 1/16" slots, 48/ft E R i r 3d a .: Tubing 75.15' RKB to Tbg Hngr '5 1,:; n,� 4 -1/2" 1 12.6 1 L -80 1 TCH 1 3.958 Surf 1 8,302' E a t y . B$1 1 � 3e tl y�E ri; 1 JEWELRY DETAIL Pressure Test Details as of 12/2/08 ali .0:02 3f N O. Depth ID Item Set Results 1 456' 3.813" SCSSV (TRSV) Depth 3 3a 1,563' 3.833" GLM (SFO -2) Good Test 2000 psi to surface. 55' 3g 1,7 lilt il 2 2,010' 3.833" Chemical Injection Sub 9 above top of liner. 9-%" csg tested 3b 2,643' 3.833" GLM (SFO -2) good. Could not get pkr to set in k _ 1 "1 . 1 3c 3,633' 3.833" GLM (SFO -2) csg between 9245' & TOL. 3d 4,553' 3.833" GLM (SFO -2) 9,350' Bad. No test above or below. r m ' 3e 5,355' 3.833" GLM (SFO -2) 9,400' Bad. No test between pkr & BP. 5 3f 6,062' 3.833" GLM (SFO -2) 9,480' Bad. No test between pkr & BP. ' ' � 3g 6,797' 3.833" GLM (SFO -2) Good Test to 2000 psi. Between 9,515' t4^ 6 ? 4 6,861' 3.850" HES PHL Retrievable Packer pkr & BP @ 9560'. 14,, 7 5 6,922' 3.813" X- Profile Nipple 9,545' Good Test to 2000 psi. Between ;' 6 6,973' 3.70" Mech Tbg Release (BOT Gun Drop Sub) pkr & BP @ 9560'. ,; Tag roc Q 7 8,302' 3.950" WLEG T tr O. , - 9,1728K8 /111ELM 8 9,284' N/A TTS umbrella plug w/ cement on top - ,r,, ° i F ' 9 9,572' N/A EZSV Cement Retainer '}1'"1 TOC Q 9,263' - t . 1 RKB SLM - 1 Collaps sg 9,299' ( +l -) A Csg Window Brief Details & Info: @9392' Spudded M -32RD on 11/15/99. Completed on 01/25/00. M -32RD was a drill out of M -32 (window in the 9 - 5/8" - 9392'). 5 fish 4. Integrity Breach ; ► Were left in sidetrack holes while drilling the well: #1 @ 9682' — 1226' fish. #2 @ 9564' — 1088' fish. #3 @ 12418' — 5' fish. 9245' to 9515 G05 04 @ 11650' — 300'fish. #5 @ 9943' (in the M -32RD section) — 780' fish. Top 01811 Q9622' *Hole Section MWT: •Approximate Rotating hrs: 11 0 17 -1/2" to 1347' 9.0 to 9.5 ppg o 16" 120 hrs _ Top of Cmt Q 9547' 0 12-1/4" to 10588' 9.3 to 10.1 ppg o 13 -38" 560 hrs ��� • � . 9 o 8 -1/2" to 10731' 9.0 to 10.5 ppg o 9 -5/8" 694 hrs o 6" to 13835' 9.5 to 10.5 ppg o 7" 272 hrs I G-1,2 I G-4,5 I _ PERFORATION DATA ' B -1 Zone Top Btm Amt Accum Last Present Notes SPF Perf. Date Condition I F16 9,072' 9,092' 20' 6 1/29/2011 • Open 2 -7/8" PowerJet Omega 1/29/11 • B 2 G01 9,212' 9,248' 36' 5 10/19/2010 Isolated 2 -1/2" PowerSpiral guns 10/19/10 G05 9,500' 9,521' 21' 5 11/17/2009 Isolated 2 -1/2" PowerSpiral guns 11/17/09 M;ii BP <> G -1 9,625' 9,665' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9645'- 9665') •;G G -2 9,697' 9,737' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9714'- 9734') — G - 4 9,915' 9,990' 75' 18 12/14/2006 Isolated 4-5/8" TCP 01/2000 & 12/2006 (perfd 9933' -9953' & 9970' - 9990) G -5 10,060 10,210' 150' 18 12/14/2006 Isolated 4 TCP 01/2000 & 12/2008 (perfd 10700' - 10090', 10120'- 10135' & 10180' - 10195) collapas in d-1/2 "S lotted B -1 10,430' 10,480' 50' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 10430'- 10445') LinerQ10826' B -2 10,510' 10,530' 20' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 B -2 10,560' 10,570 10' 6 12/14/2006 Isolated 4 -5/8" TCP 12/2006 B3 -B7 10,694' 13,835' 3141' 01/01/2000 Isolated Slotted Liner E iii • B TD = 13,835'MD/9660'TVD M -32RD Schematic 2- 3- 2011.docx CVK: 2/3/2011 • • SEAN PARNELL, GOVERNOR SligifIE ALA SKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy C. Brandenburg Drilling Manager Union Oil Company of California r vl .- 09/ P.O. Box 196247 I vl _ ` Anchorage, AK 99519 Re: McArthur River Field, Middle Kenai Gas Pool, TBU M -32RD Sundry Number: 310 -446 5 JAN I ZOli Dear Mr. Brandenburg: 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, Daniel T. Seamount, Jr. Chair r DATED this 3 day of January, 2011. Encl. ta6o • • 'i ` ir. / tq / Zoto STATE OF ALASKA ��t ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool El Repair Well ❑ Change Approved Program ❑ Suspend p Plug Perforations 0 * Perforate IS ' Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development Ei • Exploratory ❑ 199-097 ` 3. Address: 6. API Number: Stratigraphic ❑ Service ❑ PO Box 196247, Anchorage, AK 99519 50- 733 - 20462 -01 . 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: } 'y " Spacing Exception Required? Yes ❑ No i)^' � " Trading Bay Unit M -32RD 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL018730 [Steelhead Platform] McArthur River Field / Middle Kenai Gas Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): 4 Total Depth TVD (ft): , Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13,835 9,660 9,263 8,423 9,263 (cement) N/A Casing Length Size MD / TVD Burst Collapse Structural Conductor 981' 26" 981' 980' Surface 1,347' 16" 1,347' 1,346' 2,630 psi 1,020 psi Intermediate 3,767' 13 -3/8" 3,767' 3,766 3,090 psi 1,540 psi Production 10,588' 9 -5/8" 10,588' 9,205' 7,930 psi 6,620 psi Liner 1,430' 7" 10,731' 9,266' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,212'- 9,248' 8,386'- 8,412' 4 -1/2" 12.6# L -80 8,302' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): HES PHL Retrievable Packer / SCSSV 6,861'MD (6,570'TVD) / 456'MD (455'TVD) 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Development El Service ❑ 14. Estimated Date for 1/3/2011 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas 0 • WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer 263 -7831 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature _ G�,_/' Phone 276 -7600 Date 12/28/2010 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3I 0 " L P-10 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ T EEVED Other: _:s LC 2 8 2010 ,. , ., . , Cans, CommiSS$Of :;._;;rage Subsequent Form Required: 1 O — 4_ O 1 APPROVED BY r / /1 Approved by: / / COMMISSIONER THE COMMISSION Date: / r iZ 30 r Form 10 -403 Revise. 1 A IAN 04 2Qi - 1 R I G t N n Submit in Duplicate Chevron . Trading Bay Unit 4.1 Well # M -32RD 10/28/10 OBJECTIVE: • Isolate G - 01 zone and perforate F16 zone, with contingency to perforate the F15C, F15B, & F14A zones. PROCEDURE SUMMARY: 1 RU slickline. Pressure test lubricator 250psi low /2500psi high. 2 Dump bail +/- 51' of cement on top of cement plug from +/- 9,263' to +/- 9, 212'. 3 RD slickline. 4 RU Eline. Pressure test lubricator 250psi low /2500psi high. 5 Dump bail +/- 25' of cement on top of sand in 9 -5/8" casing from +/- 9,212' to +/- 9,187'. 6 WOC. 7 Tag top of cement at +/- 9,187' RKB. 8 Perforate F16 zone from +/- 9,070' to +/- 9,112'. 9 RD Eline. 10 Turn well over to production. Flow test well. Contingency - Perforate the F15C, F15B, & F14A zones, pending results of production testing of each zone. 11 RU Eline. Pressure test lubricator 250psi low /2500psi high. 12 Perforate F15C zone from +/- 9,008' to +/- 9,018'. 13 RD Eline. 14 Turn well over to production. Flow test well. 15 RU Eline. Pressure test lubricator 250psi low /2500psi high. 16 Perforate F15B zone from +/- 8,943' to +/- 8,975'. 17 RD Eline. 18 Turn well over to production. Flow test well. 19 RU Eline. Pressure test lubricator 250psi tow /2500psi high. 20 Perforate F -14A zone from +/- 8,778' to +/- 8,798'. 21 RD Eline. 22 Turn well over to production. Flow test well. M -32RD REVISED BY: CVK 10 -28 -10 Chevron • Stad Platform Well # M -32RD 111111 PROPOSED Schematic — RKB = 75.15'Rig Floor to TBG Head Casing & Tubing Size Type Wt Grade Thrd ID Top Btm Hole Cmt Cmt To. f 26" Conductor Surf 981' Driven '* sir ■ x,1 m. 4 s ' Cmt to Surf 1 16" Surf Csg 75 K -55 BTC 15.12 Surf 1,347' 22" 1,933 sx Calc TOC@ surf -assmd 20 % loss 42 RBumped eturns to Surf 13 -3/8" Csg 61 K -55 BTC 12.52 Surf 3,767' 17.5" 2,244 sx 't1 Calc TOC @67 1' 1 iiiii I) 3a assmd 20% loss s 1 Window from 9 9,408' Returns to Surf 9 -5/8" Prod Csg 53.5 L -80 BTC 12.25" 2,607 sx Calc TOC @--2611' JEW . 2 8.535 Surf 10,588' assmd 20% loss MEV li. 3 t Calc TOC to o s liner top s 7" Liner 29 L -80 Butt & KC 6.184 9301' 10,731' 8 -1/2" 72 bbls w /assmd u� 3c s 20 %loss € [ f1 Slotted IBTC AB mr. C 4 -1/2" 12.6 L -80 3.958 10694' 13,835' 6" 2-1/2" x 1/16" slots, 48/ft Liner mod e� 11 3 d X ' 1 .g Tubing 75.15' RKB to Tbg Hn -r : o a 4-1/2" 12.6 L -80 TCH 3.958 Surf 8,302' , ' - e ,V 9, FOs 3 ,;� 3e 'y ° E t 9� E r JEWELRY DETAIL Pressure Test Details as of 12/2/08 °, zio. NO. Depth ID Item Set . 3f 1 456' 3.813" SCSSV (TRSV) Depth Results 3a 1,563' 3.833" GLM (SFO -2) Good Test 2000 psi to surface. 55' � 2 2,010' 3.833" Chemical Injection Sub above top of liner. 9 -' /a" csg tested 4 3b 2,643' 3.833" GLM (SFO -2) 9,245' good. Could not get pkr to set in I ..,1.t`° 1 1a 3c 3,633' 3.833" GLM (SFO -2) csg between 9245' & TOL. ' 3d 4,553' 3.833" GLM (SFO -2) 9,350' Bad. No test above or below. r1= 3e 5,355' 3.833" GLM (SFO -2) 9,400' Bad. No test between pkr & BP. "54 AIM A 3f 6,062' 3.833" GLM (SFO -2) 9,480' Bad. No test between pkr & BP. '%a 5 A 1 3g 6,797' 3.833" GLM (SFO -2) 9,515' Good Test to 2000 psi. Between 1 = 6 1 4 6,861' 3.850" HES PHL Retrievable Packer pkr & BP @ 9560'. I 5 6,922' 3.813" X- Profile Nipple 9,545' Good Test to 2000 psi. Between _.. 7 6 6,973' 3.70" Mech Tbg Release (BOT Gun Drop Sub) pkr & BP @ 9560'. 4J4 7 8,302' 3.950" WLEG k + , ,C,,,;.++< ' 4 8 9,284' N/A TTS umbrella plug w/ cement on top Tag TOC 9 9,572' N/A EZSV Cement Retainer ^ � { L" «y� '.� ° 8 9,263' RKB SLM V 3, 10/26110 1 Collapse Csg 9,299' ( + / -) r'+ Csg Window Brief Details & Info: 09392' Spudded M -32RD on 11/15/99. Completed on 01/25/00. M -32RD was a drill out of M -32 (window in the 9 - 5/8" — 9392'). 5 fish Integrity Breach 4 Were left in sidetrack holes while drilling the well: #1 @ 9682' — 1226' fish. #2 @ 9564' — 1088' fish. #3 @ 12418' — 5' fish. 9245' to 9515' 006 #4 @ 11650' — 300' fish. #5 @ 9943' (in the M -32RD section) — 780' fish. r Top of fill ft 9622' •Hole Section MWT: •Approximate Rotating hrs: 11.16 -09 o 17 -1/2" to 1347' 9.0 to 9.5 ppg o 16" 120 hrs _ Top of Cmt a 9647' o 12 -1/4" to 10588' 9.3 to 10.1 ppg o 13 -38" 560 hrs ��� 4. ��� 9 o 8 -1/2" to 10731' 9.0 to 10.5 ppg o 9 -5/8" 694 hrs o 6" to 13835' 9.5 to 10.5 ppg o 7" 272 hrs G-1,2 I G-4,5 I PERFORATION DATA B -1 Zone Top Btm Amt Accum Last Present Notes SPF Pelf. Date Condition J F14A +/- 8,778' +/- 8,798' +/ -20' 6 Contingency 2 -7/8" PowerJet Omega B -2 F15B +/- 8,943' +/- 8,975' +/ -32' 6 Contingency 2 -7/8" PowerJet Omega S _ F15C +/- 9,008' +/- 9,018' + / -10' 6 Contingency 2 -7/8" PowerJet Omega Milled BP F16 +/- 9,070' +1- 9,112' +/ -42' 6 Proposed 2 -7/8" PowerJet Omega — G05 9,500' 9,521' 21' 5 11/17/2009 Isolated 2 -1/2" PowerSpiral guns 11/17/09 0 -1 9,625' 9,665' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9645- 9665') G -2 9,697' 9,737' 40' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9714'- 9734') ailOkr Collapse In 4.1/2" Slotted G - 4 9,915' 9,990' 75' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 9933' -9953' & 9970' - 9990') Liner ft 10826' 4 -5/8" TCP 01/2000 & 12/2006 (perfd 10700'- 10090', 10120'- G - 10,060' 10,210' 150' 18 12/14/2006 Isolated 10135' & 10180' 10195) B -1 10,430' 10,480' 50' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 (perfd 10430'- 10445') B -2 10,510' 10,530' 20' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 E . B -2 10,560' 10,570 10' 6 12/14/2006 Isolated 4 -5/8" TCP 12 /2006 i 3 1' • B3 -B7 10,694' 13,835' 3141' 01/01/2000 Isolated Slotted Liner il TD = 13,835'MD/9660'TVD M -32RD Proposed Schematic 12- 28- 10.docx CVK: 12/28/2010 • Chevron • Steead Platform I N Well # M -32RD Schematic — RKB = 75.15'Rig Floor to TBG Head Casing & Tubing Size Type Wt Grade Thrd ID Top Btm Hole Cmt Cmt To i 26" Conductor Surf 981' Driven 1!„5' 44"-tiitrf, ;;: � ,-'.. Cmt to Surf 1 16" Surf Csg 75 K -55 BTC 15.12 Surf 1,347' 22° 1,933 sx Calc TOC@ surf -assmd 20% loss 1 Returns to Surf 13 -3/8" Csg 61 K -55 BTC 12.52 Surf 3,767' 17.5" 2,244 sx Bumped Plug Calc TOC @ -671' "+ '- 11 3a i assmd 20% loss ', 8 I Window from 9,392'- 9,408' Returns to Surf ' 2 9 -5/8° Prod Csg 53.5 L-80 BTC 12.25" 2,607 sx Calc TOC @ -2611' 8.535 Surf 10,588' assmd 20% loss ® . 3b , — Calc TOC to 3 ,° F ' liner top 7 Lin er 29 L -80 Butt & KC 6.184 9301' 10,731' 8 -1/2" 72 bbls v /assmd � ; w il 3c t /asloss Slotted IBTC AB 71 4 -1 /2 Liner 12.6 L -80 mod 3.958 10694' 13,835' 6" 2 -1/2" x 1/16" slots, 48/ft E R cap 3d Tubing 75.15' RKB to Tbg Hngr v 2. },,. 4 -1/2" 1 12.6 1 L -80 1 TCII 1 3.958 1 Surf 1 8,302' � 8 : s 9 j 1 3e E,t♦ I k JEWELRY DETAIL Pressure Test Details as of 12/2/08 'Rd 'A Il 3f ! NO. Depth ID Item Set Results ., tI 1 456' 3.813" SCSSV (TRSV) Depth_ ;,,,,4% ', 3a 1,563' 3.833" GLM (SFO -2) Good Test 2000 psi to surface. 55' St U 4 ,P 2 2,010' 3.833" Chemical Injection Sub 9,245' above top of liner. 9-%" csg tested 3b 2,643' 3.833" GLM (SFO -2) good. Could not get pkr to set in l'T, 1 1 1 r 1 es: 3c 3,633' 3.833" GLM (SFO -2) csg between 9245' & TOL. 3d 4,553' 3.833" GLM (SFO -2) 9,350' Bad. No test above or below. r 3e 5,355' 3.833" GLM (SFO -2) 9,400' Bad. No test between pkr & BP. +at' '"' 3f 6,062' 3.833" GLM (SFO -2) 9,480' Bad. No test between pkr & BP. I' 5 3g 6,797' 3.833" GLM (SFO -2) Good Test to 2000 psi. Between 9,515' ; t 6 ► e, 4 6,861' 3.850" HES PHL Retrievable Packer pkr & BP @ 9560'. 7 a 5 6,922' 3.813" X- Profile Nipple 9,545' Good Test to 2000 psi. Between 1 6 6,973' 3.70" Mech Tbg Release (BOT Gun Drop Sub) pkr & BP @ 9560'. 4 7 8,302' 3.950" WLEG Tag TOC B 8 9,284' N/A TTS umbrella plug w/ cement on top 9,263' RKB SLM _. ,, 10/26/10 9 9,572' N/A EZSV Cement Retainer d I Collaps Csg 9,299' ( + / -) 1 Csg Window Brief Details & Info: @9392' Spudded M -32RD on 11/15/99. Completed on 01/25/00. M -32RD was a drill out of M -32 (window in the 9 -5/8" - 9392'). 5 fish Integrity Breach J Were left in sidetrack holes while drilling the well: #1 @ 9682' - 1226' fish. #2 @ 9564' - 1088' fish. #3 @ 12418' - 5' fish. 9245' to 9615' G06 #4 @ 11650' - 300'fish. #5 @ 9943' (in the M -32RD section) -- 780' fish. Top of fill @m *Hole Section MWT: •Approximate Rotating hrs: 11.16 -09 o 17 -1/2" to 1347' 9.0 to 9.5 ppg Top 11 Cmt@ 64 o 16" 120 hrs ��, • =� T 0 12 -1/4" to 10588' 9.3 to 10.1 ppg o 13 -38" 560 hrs o 8 -1/2" to 10731' 9.0 to 10.5 ppg o 9 -5/8" 694 hrs o 6" to 13835' 9.5 to 10.5 ppg o 7" 272 hrs G -1,2 G -4,5 PERFORATION DATA - B.1 Accum Last Present Zone Top Btm Amt gpP Perf. Date Condition Notes . 001 9,212' 9,248' 36' 5 10/19/2010 Open f /Prod 2 - 1/2" Powerspiral guns 10/19/10 B - G05 9,500' 9,521' 21' 5 11/17/2009 Isolated 2 - 1 /2"PowerSpiral guns ll /17/09 I G -1 9,625' 9,665' 40' 18 12/14/2006 Isolated 4 -5/8° TCP 01/2000 & 12/2006 ( perfd 9845' - 9665) Milled BP _ '`_ G - 9,697' 9,737' 40' 18 12/14/2006 Isolated 4 -5/8° TCP 01/2000 & 12/2006 (perfd 9714'- 9734') G -4 9,915' 9,990' 75' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2006 ( perfd 9933' -9953' & 9970' - 9990) G -5 10,060 10,210' 150' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 6 12/2006 ( perfd 10700'- 10090', 10120'- 10135'8 10180' - 10195') atiNk Collapse in 4-112" Slotted B - 10,430' 10,480' 50' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2008 ( perfd 10430' - 10445') Liner @10825' B - 10,510' 10,530' 20' 18 12/14/2006 Isolated 4 - 5/8 "TCP 01/2000 B - 10,560' 10,570 10' 6 12/14/2006 Isolated 4 - 5/8° TCP 12/2006 B3 - 10,694' 13,835' 3141' 01/01/2000 Isolated Slotted Liner E 1 • 1' es •";,,,,,.• TD = 13,835'MD/9660'TVD M -32RD Schematic 11 - 16 - 10.docx CVK: 11/16/2010 • ` � 7 Davies, Stephen F (DOA) From: Kanyer, Christopher V [Chris.Kanyer @chevron.com] Sent: Thursday, December 30, 2010 11:37 AM To: Davies, Stephen F (DOA) Cc: Aubert, Winton G (DOA) Subject: RE: M -06 & M -32RD spacing exemption Attachments: D16C Base Map 20000.jpg Steve, See attached mapping of the D -16C sand. The our estimation made below about the spacing of the M -6 & M -12 wells was incorrect, your figure of +1 -1850' seems accurate. In answer to the phone message you left regarding the definition of "proximity" regarding the F sands proposed for the M- 32RD well, the M -14 well produced from the F sands but has been P &A'd and redrilled. I do not have a mapping of the F sands like above. From my understanding there are currently no Steelhead wells producing from these proposed F sands in the lease block (ADL018730) and therefore does not require a spacing exemption. It does appear that the proposed perforation of M -06 does not conform to Rule 2 of CO 228, which governs spacing of production intervals within the well to be less than 1 000' TVD between top & bottom perfs. We are current) reviewing p p p Y g this and will get back to you shortly. Let me know if you have any additional questions. Chris Kanyer e• Technical Assistant Wellbore Maintenance Team Office: (907) 263 -7831 Cell: (907) 250 -0374 Chevron North America Exploration and Production Midcontinent/Alaska SBU 3800 Centerpoint Dr, Suite 100 Anchorage, AK 99503 From: Davies, Stephen F (DOA) [mailto:steve.davies @alaska.gov] Sent: Thursday, December 30, 2010 10:20 AM To: Kanyer, Christopher V Cc: Aubert, Winton G (DOA) Subject: RE: M -06 & M -32RD spacing exemption Chris, Regarding the proposed perforations in the D16 sands in TBU M -06: On my workstation, I measure about 1850' between the tops of the D16 sand in M -12 and M -06. Am I wrong? But 1850' of separation still exceeds the 10 -acre well spacing required by Conservation Order 228, Rule 1. Does the proposed perforation of M -06 conform to Rule 2 of CO 228 (attached), which governs spacing of production intervals within the well? Thanks, Steve Davies AOGCC From: Kanyer, Christopher V [mailto:Chris.Kanyer @chevron.com] Sent: Wednesday, December 29, 2010 11:47 AM • / ?2 To: Davies, Stephen F (DOA) Subject: M -06 & M -32RD spacing exemption Steve, According to my understanding of spacing exemptions, it is not required for either M -06 and M -32RD. M -06 will attempt to perforate D -16B and or D -16C. The only well in proximity that is producing from this horizon is M -12 which is over 3000' away from the planned perforated intervals. M -32RD will attempt to perforate the F -15C, F -15B and F -14A zones. M -14 had produced from these intervals but has been P &d across these intervals. No other wells in proximity are producing from this interval. M -06 will not abandon the lowered F -6 and F -7 intervals due to possibility for future production. The D -16 sands are expected to be much lower pressure (500 psi) than the F sands cross flow is not an issue based on recent reservoir tests. Please let me know if you have any other questions. Thanks, Chris Kanyer •• Technical Assistant Wellbore Maintenance Team Office: (907) 263 -7831 Cell: (907) 250 -0374 Chevron North America Exploration and Production Midcontinent /Alaska SBU 3800 Centerpoint Dr, Suite 100 Anchorage, AK 99503 2 ALASKA9 STATE OF ALASKA �''•�3lD �� jl�tl ZG�� AND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Li Repair Well Li Plug Perforations Stimulate Lj Other Li Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑✓ Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development R] Exploratory ❑ 199 -097 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic❑ Service ❑ 6. API Number: s 50- 733 - 20462 -01 7. PropertLIDesignation (Lease Number): 8. Well Name and Number: ADL0018730 [Steelhead Platform] Trading Bay Unit M -32RD 9. Field /Pool(s): W McArthur River Field / Middle Kenai Gas Pool 10. Present Well Condition Summary: Total Depth measured 13,835 feet Plugs measured 9,263 feet true vertical 9,660 feet Junk measured N/A feet Effective Depth measured 9,263 feet Packer measured 6,861 feet true vertical 8,423 feet true vertical 6,570 feet Casing Length Size MD TVD Burst Collapse Structural J Conductor 981' 26" 981' 980' Surface 1,347' 16" 1,347' 1,346' 2,630 psi 1,020 psi Intermediate 3,767' 13 -3/8" 3,767' 3,766' 3,090 psi 1,540 psi Production 10,588' 9 -5/8" 10,588' 9,205' 7,930 psi 6,620 psi Liner 1,430' 7" 10,731' 9,266' 8,160 psi 7,020 psi Perforation depth Measured depth 9,212'- 9,248' feet f True Vertical depth 8,386' - 8,412' feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 8,302' MD 7,690' TVD HES PHL Retrievable 6,861' MD / Packers and SSSV (type, measured and true vertical depth) Packer (6,5 70' TVD) SCSSV 456'MD (455 . 4 il 11. Stimulation or cement squeeze summary: Intervals treated (measured): NOV v 1 9 2010 N/A t V Treatment descriptions including volumes used and final pressure: + �' � �4R . CMl o N/A 12. Representative Daily Average Production or Injection Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 660 psi 660 psi Subsequent to operation: 0 1600 100 335 psi 170 psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development 2 " Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil Gas Ej WDSPL I GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 1 310-226 Contact Chris Kanyer 263 -7831 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 276 -7600 Date 11/17/2010 RBDMS Nov 19 Form 10404 Revised 10/2010 Submit Original Only r Chevron Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -32RD TRADING BAY UNIT M -32RD ADL0018730 5073320462 QZ8714 160.00 dx Primary Job Type Job Category Objective Actual Start Date Actual End Date Perforation - Post Production Well Abandon G -5, Perforate G01, f16, 15c, 15b 10/9/2010 Services Primary Wellbore Affected Wellbore UWI Well Permit Number M -32RD 507332046201 1990970 .. - ., r Operations Summary RU wireline. Pressure test lubricator 250psi low /2500psi high. RIH, tie in to schematic, and set 9 -5/8" umbrella plug from 9,284'- 9,293' RKB WLM. RIH and � dump bail ceramic beads on top of plug. fQ/ ! p Operations Summary Made multiple dump bailer runs of 16.6ppg cement on top of umbrella plug to 9,283'RKB WLM. Otlllaol0.0 10M212Q1 :oo:oo" w, l_ .. n e Operations Summary Made two additional dump bailer runs of 16.6ppg cement on top of umbrella plug to 9,286'RKB WLM (below top of umbrella plug vent). WOC. 101'" X10115/2010 :f .. Operations Summary RU wireline. Pressure test lubricator to 250psi low /2500psi high. RIH w/ 3.5" LIB and tag top of umbrella plug vent at 9,283' RKB WLM and close same. Begin RIH w/ 2 -1/8 "x30' dump bailer. 0115! '0 ' Ot7 /x �y Zc-s, Yk !� — Operations Summary Made multiple dump bailer runs of 16.4ppg cement on top of umbrella plug to 9,281'RKBWLM. 00:00 : I 01imal Operations Summary Made multiple dump bailer runs of 16.4ppg cement on top of umbrella plug to 9,265'RKB WLM. RD wireline. 101 1 0 01*2610 00:00 Operations Summary Mobe Eline equipment for pert operations. 10/20/2010 001` :'.; ;; �s, Operations Summary RU Eline. Pressure test lubricator 250psi low /250psi high. RIH w/ 2.85" LIB and tag TOC at 9,264.5'RKB WLM. RIH and pert G -01 sand w/ 2.5" deg phased 5spf Power Spiral guns from 9,248-9,238.5'& 9,238.5'- 9,229'. (1 10111'12010'00:00 Operations Summary RIH and continue to pert G -01 sand w/ 2.5" eg phased 5spf Power Spiral guns from 9,219.5'- 9,229' and 9,212'- 9,219.5'. RD Eline, Turn well over to production. '060 . h' Operations Summary RU slickline. Pressure test lubricator 250psi low /2500psi high. Tagged fill at 9,263' RKB SLM. Run pressure /temperature log to 9,264'RKB SLM. Work slickline brush from 395'- 458'RKB SLM. RD slickline, turn well over to production. Chevron • Ste4ad Platform Wel M -32RD Schematic i B= 75.15'Rig Floor to TBG Head C as in g & T u b i n Size Type Wt Grade Third ID Top Him Hole Cmt Cmt Top 26" Conductor Surf 981' Driven Cmt to Surf 1 16" Surf Csg 75 K -55 BTC 15.12 Surf 1,347' 22" 1,933 sx Calc TOC@ surf -assmd 20% loss Returns to Surf 13 -3/8" Csg 61 K -55 BTC 12.52 Surf 3,767' 17.5" 2,244 sx Bumped Plug Calc TOC @ -671' 3a assmd 20% loss 0 a Window from 9,392'- 9,408' Returns to Surf 2 95/8" Prod Csg 53.5 L-80 BTC 8.535 Surf 10,588' 12.25" 2,607 sx Calc TOC @- •261 1' 3b , assmd 20% loss E r Calc TOC to s q 7" Liner 29 L-80 Butt 8 KC 6.184 9301' 10,731' 8 -1/2" 72 bbls liner top w /assmd " 3 c 20 %loss Slotted IBTC AB 4 -1/2 Liner 12'6 L-80 mod 3.958 10694' 13,835' 6" 2-1/2" x 1/16" slots, 48/ft E R 3d Tubing 75.15' RKB to Tbg Hn r g . 4 -1/2" 12.6 L -80 TCII 3.958 Surf 8,302 y BaR 6 3e - 1 JEWELRY DETAIL Pressure Test Details as of 12/2/08 was ' 3f r3d De th ID Item Set Results S 456' 3.813" SCSSV TRSV De th " 1 3.833" GLM SFO -2 Good Test 2000 psi to surface. 55' 3g 2,010' 3.833" Chemical Injection Sub above top of liner. 9-%" csg tested 2 643' 3.833" GLM SFO -2 9,245' good. Could not get pkr to set in 3 3.833" GLM SFO -2 cs between 9245' & TOL. 4 3.833" GLM SFO-2) 9 Bad. No test above or below. 3e 5,355' 3.833" GLM SFO-2) 9,400' Bad. No test between pkr & BP. 5 3f 6,062' 3.833" GLM SFO-2) 9,480' Bad. No test between pkr & BP. 3 6,797' 3.833" GLM SFO -2 Good 'rest to 2000 psi. Between g g 9,515' l � 4 6 F 3.850" HES PHL Retrievable Packet p k r & BP 9560'. 5 6,922' 3.813" X- Profile Nipple Good Test to 2000 psi. Between 9,545' & BP 9560'. / 7 6 6 3.70" Mech Tb Release BOT Gun Drop Sub 7 8,302' 3.950" WLEG 3* Tae roc g 9 284' N/A TTS umbrella plug w/ cement on to 9,263'RKB SLM 9 9,572' N/A EZSV Cement Retainer 10125110 1 . �8 Collapse Csg 9,299' r Csg Window Brief Details &Info: @9392' Spudded M -32RD on 11/15/99. Completed on 01/25/00. M -32RD was a drill out of M -32 (window in the 9 -5/8" - 9392'). 5 fish Integrity Breach ; Were left in sidetrack holes while drilling the well: #1 @ 9682' - 1226' fish. #2 @ 9564' - 1088' fish. #3 @ 12418' - 5' fish. 9245'to 9615' i r,* cos #4 P 11650' - 300'fish. #5 @ 9943' in the M -32RD section - 780' fish. ' r Top of fill @9522' .Hole Section MWT: -Approximate Rotating hrs: 11 -16 -09 o 17 -1/2" to 1347' 9.0 to 9.5 ppg 0 16" 120 hrs Top of Cna @ 9647 o 12 -1/4" to 10588' 9.3 to 10.1 ppg o 13 -38" 560 hrs 9 o 8 -1/2" to 10731' 9.0 to 10.5 ppg o 9 -5/8" 694 hrs 0 6" to 13835' 9.5 to 105 ppg 0 7" 272 hrs G -1,2 G -4,5 I - PERFORATION DATA 8 - 1 Zone Top Btm Amt Accum Last Present Notes SPF Perf. Date Condition — G01 9 9 36' 5 10/19/2010 Open f /Prod 2 -1/2" PowerSpiral guns 10119/10 B -2 G05 9,500' 9,521' 21' 5 11/17/2009 Isolated 2 - 112" Powerspiralguns 11117/09 Milled BP <� • G -1 9,625' 9,665' 40' 18 12/1412006 Isolated 4 -5/8" TCP 01/2000 812/2006 ( perfd 9845' -9885) G - 9,697' 9,737' 40' 18 12114/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2000 (perfd 9714' -9734) -I G -4 9,915' 9,990' 75' 18 12114/2006 Isolated 4 -5/8" TCP 01/2000 & 1212008 (perfd 9933'-9953'& 9970' -9990) I I I I G -5 10,060' 10,210' 150' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 12/2008 (perfd 10700'- 10090', 10120'- 1 I 10135' & 10180' -10195 Collapse In 4.1/2" Slotted B -1 10,430' 10,480' 50' 18 12/14/2006 Isolated 4 -5/8" TCP 01/2000 & 1212006 (perfd 10430' - 10445) 4 - 0 0 W , 1 Liner @ 10826' B - 2 10,510' 10,530' 20' 18 12/14/2006 Isolated 4 - 5/8" TCP 01/2000 & 12/2008 l I I t B - 10,560' 10,570 10' 6 12/14/2006 Isolated a -5 /6 TCP 1212006 I 1 B3 -B7 10,694' 13,835' 3141' 0110112000 Isolated Slotted Liner t t E I 1 1 1 • H� 1 1 1 1 t I I 1 I' 1 TD = 13,835'MD/9660'TVD M -32RD Schematic 11- 16- 10.docx CVK: 11/16/2010 ~~Q~~ OCR Q~Q~~{Q /.~.~~.«~o~.~ Timothy C. Brandenburg H Drilling Manager ,~, ~ ~'/ Union Oil Company of California P.Q. Box 196247 Anchorage, AK 99519 Re: McArthur River Field, Middle Kenai Gas Pool, TBU M-32RD Sundry Number: 310-226 Dear Mr. Brandenburg: <.~~ ~ e; ; X~i ~,~,~/ t.~ LJ U.. 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, Daniel T. Seamount, Jr. Chair DATED thi day of July, 2010. Encl. ~~', ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION /,~' ~ APPLICATION FOR SUNDRY APPROVALS ~( 20 AAC 25.280 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Perforations ^Q Perforate ^~ Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-enter Susp. Well ^ Stimulate ^ Alter Casing ^ ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ~ Exploratory ^ 199-097 . 3. Address: ^ Stratigraphic ^ Service 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20462-01 7. If pertorating, 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 ^~ Trading Bay Unit M-32RD ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL018730 [Steelhead Platform] McArthur River Field /Middle Kenai Gas Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 13,835 9,660 9,299 8,450 9,547 (cement) 9,299 (Collapsed casing) Casing Length Size MD ND Burst Collapse Structural Conductor gg1' 26" 981' 980' Surface 1,347' 16" 1,347' 1,346' 2,630 psi 1,020 psi Intermediate 3,767' 13-3/8" 3,767' 3,766 3,090 psi 1,540 psi Production 10,588' 9-5/8" 10,588' 9,205' 7,930 psi 6,620 psi Liner 1,430' 7" 1 ,731' 9,266' 8,160 psi 7,020 psi Liner 3,141' 4-1/2" 13,835 9,660' Perforation Depth MD (ft~ Pertoration Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): ,,% / 9,500'-9,521' 8,592'-8,607' 4-1/2" 12.6# L-80 8,302' Packers and SSSV Type: Packers d SSSV MD (ft) and ND (ft): HES PHL Retrievable Packer / SCSSV 6,861'MD (6,570'ND) / 456'MD (455'ND) 12. Attachments: Description Summary of Proposal ^~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 14. Estimated Date for 8/1/2010 15. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^~ WDSPL ^ Plugged ^ 16. Verbal Approval: Date: N/A WINJ ^ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer 263-7831 Printed Name Timothy C. Brandenbur Title Drilling Manager Signature Phone 276-7600 Date 7/22/2010 COMMISSION USE ONLY Number: ~ / O ~~ Conditions of a roval: Notif Commission so that a re resentative ma witness Sund pp y ry p y Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ ~~~~~~~ Other: ~ `~ L~,4 s~: . ~ . tai ~`t ~~ C~1~. Cis ~:a l t/ Subsequent Form Required: ~ d - T D t~, f~nctflrage APPROVED BY / Approved by: COMMISSIONER THE COMMISSION I Date: ZO .~/ / v RB~MS ~u~ ~ a ~o~a I G I N A L ~~ ' ~` 3F`° Form 10-403 Revised 12/2009 ~ a R Submit in Duplicate vfGA- a=/z8~Lota Chevron • • Trading Bay Unit Well # M-32RD 7/22/10 OBJECTIVE: • Set plug in 9-5/8" casing and perforate G-01 zone, with contingency to perforate the F-16, F-15C, & F-156 zones. PROCEDURE SUMMARY: 1 RU Eline. Pressure test lubricator 250psi low/2500psi high. 2 RIH and set 9-5/8" plug on to top of collapsed casing at +/- 9,298' RKB. 3 Dump bail at least 25' of cement on top of 9-5/8" plug. 4 RD Eline. 5 WOC. 6 RU Eline. Pressure test lubricator 250psi low/2500psi high. 7 Tag top of cement at +/- 9,273' RKB. i 8 Perforate G-01 zone from +/- 9,212' to +/- 9,248'. 9 RD Eline. 10 Turn well over to production. Flow test well. Contingency -Perforate the F-16, F-15C, & F-15B zones, pending results of production testing of each zone. 11 RU Eline. Pressure test lubricator 250psi low/2500psi high. 12 Perforate F-16 zone from +/- 9,070' to +/- 9,112'. " 13 RD Eline. 14 Turn well over to production. Flow test well. 15 RU Eline. Pressure test lubricator 250psi low/2500psi high. 16 Perforate F-15C zone from +/- 9,008' to +/- 9,018'. , 17 RD Eline. 18 Turn well over to production. Flow test well. 19 RU Eline. Pressure test lubricator 250psi low/2500psi high. 20 Perforate F-15B zone from +/- 8,943' to +/- 8,975'. , 21 RD Eline. 22 Turn well over to production. Flow test well. M-32RD REVISED BY: CVK 7-22-10 Chevron • Stead Platform We # M-32RD -~ Completed 10/10/09 RKB = 75.15'Rig Floor to TBG Head C a s i n & T u b i n fia 's e~ ~a E og Size T e Wt Grade Thrd ID To Btm Hole Cmt Cmt To 26° Conductor Surf 981' Driven Cmt to Surf 16" Surf Csg 75 K-55 BTC 15.12 Surf 1,347 22" 1,933sx CaIcTOC@surf -assmd 20 loss Returns to Surf ' " Bumped Plug 13-3/8" Csg 61 K-55 BTC 12.52 Surf 3,767 17.5 2,244 sx Calc TOC @-671' assmd 20% loss Window from 9,392'- 9,408' Returns to Surf 9-5/8" Prod Csg 53.5 L-80 BTC ' 12.25" 2,607 sx Calc TOC @-2611' 8.535 Surf 10,588 assmd 20% loss Calc TOC to 7" Liner 29 L-80 Butt & KC 6.184 9301' 10,731' 8-1 /2" 72 bbls liner top w/assmd 20%loss 4-1/2" Slotted 12 6 L-80 IBTC AB 3.958 10694' 13,835' 6" 2-1 /2" x 1/16" slots, 48/ft Liner . mod Tubin 75.15' RKB to Tbg Hngr 4-1/2" 12.6 L-80 TCII 3.958 Surf 8302' IFWRI.RV IIFTAII. Preccure Test netails as of 12/02/2008 NO. De th ID Item 1 456' 3.813" SCSSV TRSV 3a 1,563' 3.833" GLM SFO-2 2 2,010' 3.833" Chemical In'ection Sub 3b 2,643' 3.833" GLM SFO-2 3c 3,633' 3.833" GLM SFO-2 3d 4,553' 3.833" GLM SFO-2 3e 5,355' 3.833" GLM SFO-2 3f 6,062' 3.833" GLM SFO-2 3 6,797' 3.833" GLM SFO-2 4 6,861' 3.850" HES PHL Retrievable Packer 5 6,922' 3.813" X-Profile Ni le 6 6,973' 3.70" Mech Tbg Release (BOT Gun Drop Sub 7 8302' 3.950" WLEG 8 9.i73' N/[1 EZ.SV Cement Retainer Set Results De th Good lest 2000 psi hl surface. 55' above top of liner. 9-'/"csg 9,245' tested good. Could not get pkr to set in csg between 9245' & TOL. 9,350' Bad. No test above or below. 9,400' Bad. No test between kr & BP. 9,480' Bad. No test between kr & BP. 9 515' ('°od I est to 2000 psi. Between ' , kr & BP 9560 . 9 545' t'O°d "test to 2000 psi. Between ' , kr & BP 9560 . n.-:oo nor~a~ .e, t.,e Integrity Brear 9246' to 9616' Spudded M-32RD on 11/15!99. Completed on 01/25/00. M-32RD was a drill out of M-32 (window in the 9-5/8" -9392'). 5 fish Were left in sidetrack holes while drilling the well: #1 @ 9682' - 1226' fish. #2 @ 9564' -- 1088' fish. #3 @ 12418' _ 5' 6sh. #4 11650' - 300'fish. #5 9943' in the M-32RD section - 780' fish. .Hole Section MWT: •A roximate Rotatin hrs: 0 17-1/2" to 1347' 9.0 to 9.5 0 l6" 120 hrs 0 12-1/4" to 10588' 9.3 to 10.1 0 13-38" 560 hrs 0 8-I/2" to 10731' 9.0 to 10.5 0 9-5/8" 694 hrs 0 6" to 13835' 9.5 to 10.5 0 7" 272 hrs vGR~neeTtnty neTs i Collapse in 4.112" Slotted I .Liner @ 10826' i, . I ~t ~ I- '~.1 ' t . ^l., 1 E ~d . t' .~'~ ..^y (.. ei~ .4+1. 1 w° NI 1 Zone Top Btm Amt Accum SPF Last Perf. Date Present Condition Notes GOS 9,500' 9,521' 21' S 11117/2009 0 en f/Prod 2-1 /2" Powers iral uns it/t7/o9 G-1 9,625' 9,665' 40' 18 12/14/2006 ISOlated 4-5/8" TCP 01/2000 8 12/2006 erfd 9845'-9665' G-2 9,697' 9 737' 40' 18 12/14/2006 Isolated a-518" TCP Ot/2000 8 1212008 eRd 9714'-9734' G-4 9 915' 9 990' 75' 18 12/14/2006 Isolated 4-5/8" TCP 0112000 8 12/2006 eRd 9933'-9953' 8 9970'-9990' G-5 10 060' 10,210' 150' 18 12/14/2006 Isolated 4-5/8" 7CP 01/2000 & 12/2006 (peRd 10700'-[0090', 10120'-10135' & 10180'-10195' B-1 10,430' 10,480' S0' 18 12/14/2006 Isolated a-sla" 7cP ot/2o00 a 12/2006 d'd 10430'-10445' B-2 10,510' 10,530' 20' 16 12/14/2006 Isolated 4-5/8" TCP 01/2000812/2006 B-2 10 560' 10 570 10' 6 12/14/2006 Isolated 4-5/e" TcP tv2oo6 63-B7 10,694' 13,835' 3141' 01/01/2000 Isolated SlonedLiner CVK: 2/4/2010 TD = 13,835'MDI9860'ND M-32RD Well Schematic Revised 3-11-10.docx Chevron -~ RKB = 75.15'Rig Floor to TBG Head 1 's ~~ ~o E Off. A~ Um vR U w oE~ m E ~~£ A~~ U~3 3a 2 3b 3c 3d 3e 3f -.' 7 fri Integrity Brear 9246' to 9615' Milled 8P ~ ~ Collapse Csg 9,299' (+l-) ~. Csg W indow !,' @9392' _ GO6 ~- Top of fill ~ 9622' 11-06-09 Top o1 Cmt ~ 964T 9 G 1,2 , ~ B-1 /!~ i27 . ~ ~. 1 1 Collapse in 4.1/2" Sbtted 1 1 Liner ~ 10826' i 1 1 I I, I E 1 `m ~ 1 , i 1 '. !' a I 1 so I I.. t' I 1- .: 4 r ,t". 1,- .~J;~ ,r`. -1'. TD = 13,835'MDI9660'TVD M-32RD Well Schematic Revised 3-I1-10.docx St ead Platform We # M-32RD Proposed Schematic C a s i n & T u b i n Size T e Wt Grade Thrd ID To Btm Hole Cmt Cmt To 1 26" Conductor Surf 981' Driven Cmt to Surf 16" Surf Csg 75 K-55 BTC 15.12 Surf 1,347' 22" 1,933 sx Calc TOC@ surf -assmd 20 loss Returns to Surf 13-3/8" Csg 61 K-55 BTC 12.52 Surf 3,767' 17.5" 2,244 sx Bumped Plug Cale TOC @-671' assmd 20% loss Window from 9 ,392'- 9,408' Returns to Surf 9-5/8" Prod Csg 53.5 L-80 BTC 8 535 Surf 10 588' 12.25" 2,607 sx Calc TOC @-2611' , , assmd 20 % loss Cale TOC to 7" Liner 29 L-80 Butt & KC 6.184 9301' 10,731' 8-112" 72 bbls liner top w/assmd 20%loss 4 1/2" Slotted 126 L-80 IBTC AB 3.958 10694' 13 835' 6" 2-1 /2" x 1/16" slots, 48/ft Liner mod , Tubin 75.15' RKB to Tbg Hn r 4-1/2" 12.6 l; 80 TCII 3.958 Surf 8,302' JFWFI.RV IIIiTAII. Preccure Test netailc ac of 12/2/OR IYO. De th ID Item Set R lt l 456' 3.813" SCSSV TRSV De tti esu s 3a 1 563' 3.833" GLM SFO-2 Good 'Pest 2(100 psi to surface. 55' 2 2,010' 3.833" Chemical In'ection Sub 9 245' above top of liner. 9-%a" csg tested 3b 2 643' 3.833" GLM SFO-2 , good. Could not get pkr to set in 3c 3,633' 3.833" GLM SFO-2 cs between 9245' & TOL. 3d 4 553' 3.833" GLM SFO-2 9,350' Bad. No test above or below. 3e 5 355' 3.833" GLM SFO-2 9,400' Bad. No test between kr & BP. 3f , 6 062' 3.833" GLM SFO-2 9,480' Bad. No test between kr & BP. 3 , 6,797' 3.833" GLM SFO-2 515' 9 (:ood'fest to 2000 psi. Between 4 6 861' 3 850" HES PHL Retrievable Packer , kr & BP 9560'. 5 , 6,922' . 3.813" X-Profile Ni le 9 545' Good 'l'est [0 2000 psi. Between 6 973' 6 3 70" Mech Tb Release BOT Gun Dro Sub , ~ & BP 9560'. 7 , 8,302' . 3.950" WLEG 8 +/_9,298' N/A ll S umbrella plu>; w/+/-25' cement orl to 1 9 9,572' N/A EZSV Cement Retainer RriPf Iletailc .C Infrc Spudded M-32RD on 11/15/99. Completed on 01/25/00. M-32RD was a drill out of M-32 (window in the 9-5/8" 9392'). 5 6sh Were left in sidetrack holes while drilling the well: #l @ 9682' _ 1226' fish. #2 @ 9564' _ 1088' fish. #3 @ 12418' - 5' fish. #4 11650' - 300'fish. #5 9943' in [he M-32RD section - 780' fish. .Hale Section MWT: •A roximate Rotatin hrs: 0 17-1/2" to 1347' 9.0 to 9.5 0 16" 120 hrs 0 12-1/4"to 10588' 9.3 to 10.1 0 13-38" 560 hrs 0 8-1/2" to 10731' 9.0 to 10.5 0 9-5/S" 694 hrs 0 6" to 13835' 9.5 to 10.5 0 7" 272 hrs PFRFORATI(1N IIATA Zone Top Btm Amt Accum SPF Last Perf. Date Present Condition Notes F15B +/-8,943' +/-8,975' 32' Proposed F15C +l-9,008' +/-9,018' 10' Proposed F16 +/-9,070' +/_9,112' 42' Proposed G01 +/-9.212' +/-9,248' 36' Proposed G05 9,500' 9,521' 21' S 11/17/2009 Open f/Prod 2-i/2" PowerSpiral guns 11/17/09 G-1 9,625' 9,665' 40' 18 12/1412006 Isolated 4-5/8" TCP 01/2000 8 12/2006 (perftl 9845'-9666 G-2 9,697' 9,737' 40' 18 12/14/2006 Isolated 4-6/8" TCP 01/2000 8 12/2006 (perfd 9714'-9734') G-4 9,915' 9,990' 75' 18 12/14/2006 I601ated 4-5/8" TCP 01/2000 8 12/2006 (perfd 9933'-9953' 8 9970'-9990') G-5 10,060' 10,210' 150' 1 B 12/14/2006 Isolated 4-6IB" TCP 01/2000 8 12/2006 (perfd 10700'-10090', 10120'- 10135' 8 10180'-10195' B-1 10,430' 10,480' S0' 18 12/14/2006 Isolated 4-5/8" TCP 01/2000 812/2008 (perfd 10430'-10445') B-2 10,510' 10,530' 20' 18 12/14/2006 Isolated 4-s/e° TCP 01/2000 812/2006 B-2 10,560' 10,570 10' 6 12/14/2006 Isolated 4-6/8" TCP 12/2006 83-87 10,694' 13,835' 3141' 01/0112000 Isolated Slotted Liner CVK: 7/22/2010 :~- - ~ kGCr~- ' STATE OF ALASKA ~~~ ~ ~ ZQ~9~~~L lrooq ALAS~IL AND GAS CONSERVATION COMMI~ON WELL COMPLETION OR RECOMPLETION REP OR~jo,I~tans.Commis 1a. Well Status: Oil ^ Gas ^~ SPLUG ^ Plugged ^ Abandoned ^ Suspended^ 20nnC 25.105 ZoAAC zs.~ ~o GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other ^ No. of Completions: 1b. Well Class: Af!t'.]?f1i9QS Development ^Q Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: Union Oil Company of California 5. Date Comp., Susp., or Aband.: 11/17/2009 12. Permit to Dri 199-097 ll Number: d ~ 3. Address: PO Box 196247, Anchorage, AK 99519 6. Date Spudded: 11/15/1999 13. API Number: 50-733-20462-01 4a. Location of Well (Governmental Section): Surface: 969' FNL, 527'FWL, Sec 33, T9N, R13W, S.M. 7. Date TD Reached: 1/16/2000 14. Well Name and Number: Trading Bay Unit M-32RD Top of Productive Horizon: 1749' FSL, 1411'FWL, Sec 28, T9N, R13W, S.M. 8. KB (ft above MSL): 75.15 GL (ft above MSL): 15. Field/Pool(s): McArthur River Field Total Depth: 110' FSL, 2382'FEL, Sec 21, T9N, R13W, S.M. 9. Plug Back Depth(MD+TVD): 9,547' MD (8,624' ND) Middle Kenai Gas 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 214,146 y- 2,499,533 Zone- 4 10. Total Depth (MD + ND): 13,835' MD (9,660' ND) 16. Property Designation: ADL018730 [Steelhead Platform] TPI: x- y- Zone- 4 Total Depth: x- 216,648 y- 2,505,955 Zone- 4 11. SSSV Depth (MD + ND): 456' MD (455' ND) 17. Land Use Permit: N/A 18. Directional Survey: Yes No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: 185 (tt MSL) 20. Thickness of Permafrost MD/TVD: N/A 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): N/A 22.Re-drill/Lateral Top Window MD/TVD: N/A 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD TOP BOTTOM SETTING D TOP EPTH TVD BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 26" K-55 Surface 981' Surface 980' Driven N/A 16" 75# K-55 Surface 1,347' Surface 1,346' 22" 1933 sx 13-3/8" 61# L-80 Surface 3,767' Surface 3,766' 17-1/2" 2244 sx 9-5/8" 53.5# L-80 Surface 10,588' Surface 9,205' 12-1/4" 2607 sx 7" 29# L-80 9,301' 10,731' 8,451' 9,266' 8-1/2" 72 bbl 4-1/2" 12.6# L-80 10,694' 13,835' 9,251' 9,660' 6" Slotted liner 24. Open to production or injection? YesO No^ If Yes, list each 25. TUBING RECORD interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD(fVD) 2-1/2" guns 5spf 45deg G-05 9,500'-9,521'MD (TVD) 4-1/2" 8,302' 6,861'MD (6,570'TVD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~ ~ ~fl~~ DE9 5 ~IN ERV A825 D) RlAL USED AMOUNT s~'cd'~~~Dti~ r~~~ O ( 45bbl 15.8ppg cemen 27. PRODUCTIO N TEST Date First Production: 11/17/2009 Method of Operation (Flowing, gas lift, etc.): Flowing Date of Test: 12/13/2009 Hours Tested: 24 Production for Test Period Oil-Bbl: 0 Gas-MCF: 6,040 Water-Bbl: 0 Choke Size: N/A Gas-Oil Ratio: N/A Flow Tubing Press. 1,062 psi Casing Press: 550 psi Calculated 24-Hour Rate ~- Oil-Bbl: 0 Gas-MCF: 6,040 Water-Bbl: 0 Oil Gravity -API (corr): N/A 28. CORE DATA Conventional Core(s) Acquired? Yes ^ No ^~ Sidewall Cores Acquired? Yes ^ No ^~ If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. IAA ~ ~ rg(~ Form 10-407 Revised 7/2009 CONTINUED ON REVERSE ~ ~ ~ Submit original only 28. GEOLOGIC MARKERS (List all formations a arkers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Top needed, and submit detailed test information per 20 AAC 25.071. Permafrost -Base N/A Formation at total depth: 30. List of Attachments: Operations Summary, Wellbore Schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ronnie Santos 263-7978 Printed Name: Timothy C. Brandenburg Title: Drilling Manager , ~ Signature: C, - Phone: 907-276-7600 Date: 12/16/2009 ~ ~~ 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. 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. Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level 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 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: 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 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: 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. Fomt 10-407 Revised 7/2009 Chevron Chevron -Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M-32RD TRADING BAY UNIT M-32RD ADL0018730 5073320462 QZ8714 160.00 Jobs ~ Primary Job Type Job Category Objective Actual Start Date Actual End Dale Well Conversion Major Rig Convert well from Oil to Gas 9/25/2009 10/11/2009 Work Over (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number M-32RD 507332046201 1941360 - Dal O eratfons 8l25I2009 00:00 - 9126!2008 00:00 _ _ Operations Summary Skid rig on M-32RD. RU equipment. _ - 9/26/2008' 00:00 - 8/27/2009 00:00 _-- - _ _ _ _ _ _ Operations Summary D and remove tree from WH. NU riser and BOPE. Continue RU. PU handling equipment. Check tbg and csg pressure -vacuum. Install BPV. N _ s/27/2oos oo:oo - snsnoos oa:oo Operations Summary Continue NU riser and BOPE. Hook up choke and kill lines. RU pipe handling equipment. Slip and cut drilling line. Service TDS and other equipment. PU 5" DP and rack back in derrick. Notice given to AOGCC for upcoming BOP test. 912$/200800:00 - 9/29/2009 00:00 __ _ __ _ - - -_ _ -- - Operations Summary Finished PU 5" DP. Test TDS. RU for BOPE test. Begin testing BOPE. Test annular preventer to 200 psi low with 3-112" DP. BOP test waived by AOGCC Jim Regg. 9/29/2009 00:00 -8/30/2009 00:00 Operations Summary ,~ Test Annular to 250/2000 with 3-1/2" and 4-1/2" pipe. Test rams, all safety valves, choke, kill line and valves to 25 3~psi. Troubleshoot and service. /BOP. Circulate hole with FIW. Flowcheck well =static. Pull and laydown 81 jts of 4-1 /2" kill string. 8/30/2009 OOpO - 10/1/2008 00:00 _ _ _ f -- -- - Operations Summary Finish POH/LD 4-1/2" kill string. Change UPR from 4-1/2" to 5". Test UPR with 5" DP to 250 psi low and 3000 psi high. Test annular with 5" DP to 250 psi low and 2000 psi high. PU and MU 6" bit and cleanout BHA. TIH with 3-1/2" and 5" DP to 8038'. 10/1/2008 00:00 - 10/2/2009 00:00 _ Operations Summary Continue TIH and tag Bjat 9566'. Drillout BP. Circulate hole and flowchek well -static. Chase and wash down remainder of BP to 9650'. Shut in well ' " TOL at 10,697 . Circulate due to LEL gas alarm. Circulate and monitor well -static. Continue wash and ream the remainder of BP down to the 4-1/2 hole clean. Establish injection rates and pressures. POOH. - - - - - - 10/2/2008 D0:00 - 10/3/2009 00:00 Operations Summary Finish POOH. R/U APRS E-Line and RIH with CCL and EZSV. Correlate CCL with 7" TOL. CCL unable to properly identify casing collars. Stuck with EZSV at 9546'. Set EZSV at 9546' and POH. MU RIH with stinger for EZSV and tag/sting into EZSV at 9520' (26' higher than CCL depth). EZSV failed to test. POOH. - -- - -__ ___ - __ 1013/2009 00:00 -10/412009 00:00 _ _ Operations Summary RIH with 6" bit and BHA. Tag EZSV at 9519'. Drillout EZSV and chase to the top of 4-1/2" slotted liner at 10,697'. Circulate hole. POOH. MU new EZSV and running tool on DP. Install RA sub in string for correlation. 10/4/200 900:00 - 10/5/2009 00:00 __ _ _ _ ____ . __ _ __ Operations Summary RIH with 7" EZSV cement retainer to 9580' on drillpipe. RU SLB wireline and RIH with CCL and GR. Correlate EZSV on depth. POH and RD SLB wireline and tools. PU and set EZSV with top at 9572'. Release from EZSV. Spaceout DP for cement sque ze. Test casing and EZSV to 1500 psi with 500 psi lost in 15 minutes. Establish reverse circulating rates. Sting into EZSV and establish injection rat hile holding 1500 psi backside pressure. Bleed and open annulus to check for flow while injecting below EZ with 1900 psi -- no flow. Squeezed bls 15.8ppg of cement below EZSV at 2bpm 2600psi, w/ final squeeze pressure of 2100psi, and dumped bbls on top. Reverse circulate ex s cement. RD cementing equipment. POOH. 10/5/2009 00:00 -1016/2008 00:00 _ _ Operations Summary POOH and UD EZSV running tool. RIH with 6" bit and cleanout BHA. Tag TOC at 9514'. AOGCC Jeff Jones waived to witness tag TOC. Polish cement to 9547' (25' above EZSV). Circulate hole clean. POOH 4 stands. Pit management in preparation for displacement with completion fluids. 10/6/2009 00:00 -10/7/200800:00 - - - -- - -- Operations Summary RIH to TOC. Circulate hole a with casing wash trai . "Displace well with 6% KCL completion fluid. POOH and UD BHA. Change UPR 4-1/2" fixed rams. Test annular to 250 000 si. Test UPR to 25 300b psi with 4-1/2" pipe, 5 minutes each test. AOGCC Jeff Jones waived to witness BOPE test. 1017/2009 00:00 -1 018/20 0:00 _ _ Operations Summary Finish BOPE test. Run 4-1/2" 12.6#, L-80 TC-II tubing and Completion jewelry. Land tubing hanger in wellhead with end of completion string at 8302' Chevron Chevron -Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M-32RD TRADING BAY UNIT M-32RD ADL0018730 5073320462 QZ8714 160.00 Dal. CY rations 10/8/2009-00:00 -10/9/2009 OO:QO __ _.__ _ __ Operations Summary Circulate and spot 50 bbls of corrosion inhibitor treated 6% KCL above the production packer. Land tubing hanger and engage hold down pins. Rupture burst disk in chemical injection line with 4600 psi. Set production packer with top at 6861' and test to 2000 psi for 30 minutes. N/D BOPE. N/U tree and test to 250/5000 psi for 30 minutes each test. -- - - -- -- 10/9/2009 00:00 - 10/10/2009 00:00 Operations Summary Clean pits and perform general rig maintenance. _ _ 10/10/200900:00 -10/11/2009 00:00 _ _-_ Operations Summary Perform general rig maintenance and housekeeping while waiting on boat and weather. Prepare to skid rig to well M-31 L1. Rig operations released from M-32RD at 2400 hrs, 10/10/2009. -- -- - 11/16/2009 00:00 - 11/17/2009 00:00 Operations Summary Rig up E-line and pressure test lubricator to 350 psi lowl2900 psi high. Run Spinner, Pressure, ~ Temperature survey to determine source of gas flow below production packer at 6,861'. Tag fill at 9522' RKB. RD Eline. Secure well. Survey indicates gas influx determined at 9,498'-9,502'. 11/17/2009 00:00 -.11118/2009 00:00 Operations Summary RU Eline lubricator and pressure test to 2900 psi. Perforate G-05 zone (9500' - 9521.5') with 2.5" Powerspiral, 5spf, 45 degree pendulum guns (3 runs - 9,511.5'-9,521', 9,504.5'-9,514', 9,500'-9,509.5'). Secure well and RD Eline. Turnover well to production for flow test. Chevron • S~Ihead Platform Well # M-32RD -~ Completed 10/10/09 RKB = 75.15'Rig Floor to 7BG Head C a s i n & T u b i n Size T e Wt Grade Thrd ID To Btm Hole Cmt Cmt To 26" Conductor Surf 981' Driven Cmt to Surf 16" Surf Csg 75 K-55 BTC 15.12 Surf 1,347' 22° 1,933 sx Calc TOC@ surf -assmd 20 % loss Returns to Surf ' " Bumped Plug 13-3/8" Csg 61 K-55 BTC 12.52 Surf 3,767 17.5 2,244 sx Calc TOC @-671' assmd 20 % loss Window from 9 ,392'- 9,408' Returns to Surf 9-5/8" Prod Csg 53.5 L-80 BTC ' 1225° 2,607 sx Calc TOC @-2611' 8.535 Surf 10,588 assmd 20% loss Calc TOC to 7" Liner 29 L-80 Butt & KC 6.184 9301' 10,731' 8-1 /2" 72 bbls liner top w/assmd 20 % loss 4-1/2" Slotted 12 6 L-80 IBTC AB 3.958 10694' 13,835' 6" 2-1 /2" x 1/16" slots, 48/ft Liner mod Tubin 75.15' RKB to Tbg Hngr 4-1/2" 12.6 L-80 TCII 3.958 Surf 8,302' iFWFI.RV T1F.TAiI. Pressure Test Details as of 12/02/200R Integrity Breai 9246' ro 9676' Csg Window ~n~9392' GO6 of Cmt ~ 964T NO. De th ID Item 1 456' 3.813" SCSSV TRSV 3a 1 563' 3.833" GLM SFO-2 2 2,010' 3.833" Chemical In'ection Sub 3b 2,643' 3.833" GLM SFO-2 3c 3,633' 3.833" GLM SFO-2 3d 4,553' 3.833" GLM SFO-2 3e 5,355' 3.833" GLM SFO-2 3t 6 062' 3.833" GLM SFO-2 3 6,797' 3.833" GLM SFO-2 4 6 861' 3.850" HES PHL Retrievable Packer 5 6,922' 3.813" X-Profile Ni le 6 6,973' 3.70" Mech Tbg Release (BOT Gun Drop Sub 7 8,302' 3.950" WLEG 8 9,572' N/A EZSV Cement Retainer Set Results De th Good West 2000 psi to surface. 55' above top of liner. 9-'/" csg 9,245' tested good. Could not get pkr to set in csg between 9245' & TOL. 9,350' Bad. No test above or below. 9,400' Bad. No test between kr & BP. 9,480' Bad No test between kr & BP. 9 515' Good 'l'est to 2000 psi. Between ' , kr & BP 9560 . 9 545' ~:ood'Test to 2000 psi. Between ' , kr & BP 9560 . Rriwf Pneailc R. Infn• Spudded M-32RD on 11/15/99. Completed on 01/25/00. M-32RD was a drill out of M-32 (window in the 9-5/8" -9392'). 5 fish Were left in sidetrack holes while drilling the well: #1 @ 9682' - 1226' fish. #2 @ 9564' ' 1088' fish. #3 @ 12418' - 5' fish. #4 11650' _ 300'fish. #5 9943' in the M-32RD section - 780' fish. •Hole Section MWT: •A roximate Rotatin hrs: 0 17-I/2" to 1347' 9.0 to 9.5 0 16" 120 hrs 0 12-]/4" to 10588' 9.3 to 10.1 0 13-38" 560 hrs 0 8-1/2" to 10731' 9.0 to 10.5 0 9-5/8" 694 hrs 0 6" to 13835' 9.5 to 10.5 0 7" 272 hrs PGRGl1R ATrl1N IIATA in 4.1@" Sbtkd 70826' t ,... I~. 1 1 I. E I ~ I I .' I - ~ I so I I N- I I, 1 ' r ~r TD = 13,835'MD19860'TVD M-32RD Current Well Schematic 12-16-09.docx Zone Top Btm amt Accum SPF Last Perf. Date Present Condition Notes G05 9,500' 9,521' 21' S 11/17/2009 O en f/Prod 2.1/2' Powers iral uns 11/17/09 G-1 9,625' 9,665' 40' 18 12/14/2006 Isolated 4-5/8" TCP 01/2000 8 12/2006 eRtl 9645'-9685' G-2 9 697' 9 737' 40' 18 12/14/2006 ISOlated 4-5/8" TCP 01/2000 8 12/2006 rfd 9714'-9734' G-4 9 915' 9 990' 75' 18 12/14/2006 Isolated 4-5/8" TCP 01/2000 8 12/2006 rftl 9933'-9953' 8 9970'-9990 G-5 10,060' 10210' 150' 18 12/14/2006 Isolated 4-5/8" TCP 01/2000 8 72/2006 (perftl 10700'-10090', 10120'-[0135' 81o1e0'-1o19s B-1 10,430' 10,480' S0' 18 12/14/2006 Isolated a-5/e" rcP olnooo 8 tvzoos emtl toa3o'-7oaas B-2 10,510' 10,530' 20' 18 12/1412006 Isolated a-5/s" TCP 01/2000 8 12/2008 B-2 10,560' 10,570 10' 6 12/14/2D06 Isolated a-5/6"TCPtv2o06 B3-67 10 694' 13 835' 3141' 01/01/2000 Isolated stoned Liner CVK: 12/16/2009 Chevron 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 October 20, 2009 To: AOGCC Mahnken, Christine R 333 W. 7t" Ave. Ste#100 Anchorage, AK 99501 ~ ~ ~ WELL LOG TYPE SCALE LJv' DHTE B-LINE CD NOTES LAS, PDS, DLIS. LRU 1A COMPLETION RECORD 5" 16-Sep-09 1 1 PDS SLU 41-33RD PERFORATION RECORD 5" 23-Jul-09 1 1 PDS TBU M-32RD RST SIGMA 5" 26-Nov-09 1 1 PDS, LAS, DLIS ~~~ D E ~ ~ 200 ~~~'~os ! ~ ~ ~ ~~~ ~~"~~~ ~~ Please acknowledge receipt by signing and returning one copy of this .transmittal or FAX to 907 263 7828. Received ey: Page 1 of 1 ~ ~qa- o~-t ~ Aubert, Winton G {DOA) From: Santos, Ronilo [ronniesantos~chevron.com] Sent: Wednesday, September 30, 2~09 1:09 PM To: Aubert,lAlir~ton G (DOA} Cc: Bannett, Nigel (Nigel.Bonnett}; Nienhaus, Doug R; Tyler, Steve L; Kanyer, Christopher V Subject: M-32RD Gas Conversion Workover {Sundry No. 309-278) Mr. Aubert, Please refer to Sundry No. 309-278. Our current procedure for the subject workover is planned far squeezing with cement the cafc~lated wellbore volume below the cement retainer. This will involve 137 bbls of slurry to theoretically cover the 7" and 4-1/2" liner capacity below the cement retainer and 5" open hole annulus of the 4-1J2" slotted liner interval. In a workover of this well last December 2006, an attempt to cleanout the 4-1/2" slotted liner interval failed at a shallower depth of 10,825' MD with some abstruction in the wellbore. The zones across the 4-1/2" slotted liner interval are all of the Hemlock-B sands. For operational efficiency, we would like to propose that the down squeeze method to be calculated with cement volume from the last cleanout depth of 10,825' MD instead of the total depth of 13, 835' MD. This will reduce the volume of cement to 46 bbls. We would like to reconfirm with you that there is a likely possibility that the 137 bbls calculated volume may not all be squeezed in place during the actual job. ff this will happen we will circuiate out and handle the excess cement on surface. I will try to get in touch with you on the phone to further this discussion. Regards, Ronnie Santos 907-306-5$57 907-263-7978 ,._~ ~~~~~ ~ ~tu~ t' ~' `~ 2~C1~ ~~ ,~ ~~. 9l30/2009 ~ ~J ~ ~ ~~ ~ ~ ~ ~~~~ ~~ i~ .~ ~ ~ ~~ ~ ~~'~ ~a~ k~., ~ ~ ~ ~ ~ ~ ~ ~ SEAN PARNELL, GOVERNOR ~ ~~ ~ ~~ * ~~~~ ~ ~ ~ ~ ~ ~ .. s ~~ ~ ~ ~ ~~ ~ ~,~ ~ _ ~~ ~ ~~ ,~~ ~ ~..~ ~ t~i~-7~1~ OI~ t'~1sL Vr~-7 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA7'IO1~T COMl-IISSIOI~T ,~ ANCHORAGE, ALASKA 99501-3539 r PHONE (907) 279-1433 ~ FAX (907) 276-7542 Mr. Timothy C. Brandenburg Drilling Manager Union Oil Company of California ~ b q P.O. Box 19647 1 ~ ~ ~ Anchorage, AK 99516 ~ Re: McArthur River, Middle Kenai Gas Pool, Trading Bay Unit M-32rd Sundry Number: 309-278 ~+. _`'~+ ° i-14 ) ~" . ~? ?'~J y 7~:~~ f ~y. 4 x. ' aMe~ , . Deax Mr. Brandenburg: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of August, 2009 Encl. Q (~ ,0°I O_` "' ~ STATE OF ALASKA ~ ALAS4~K"OIL AND GAS CONSERVATION COMMIS~ON ~~ Cl~ ~' APPLICATION FOR SUNDRY APPROVALS ~n nnr ~F ~Rn ~~~ ~,~~,""~ o g ~U~1J ~ ~,Y }~ ri' 1. Type of Request: Abandon^ Suspend ^ Operational shutdown ^ Perforate ^ WaiVerO' ""~ y'~ ther ~ Alter casing^ Repairwell ^ Plug Perforations ^~ ' Stimulate ^ Time Extension [~ " ' Run 4-1/2" Change approved program^ Pull Tubing ^~ Perforate New Pool ^~ ~ Re-enter Suspended Well ^ Completion 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ~. Exploratory ~ 199-097 • 3. Address: Stratigraphic ~ Service ~ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20462-01 ~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Weli Name and Number: property line where ownership or landownership changes: ~ ~ ~ ~ Spacing Exception Required? Yes ^ No / 0 ``b' (~ Trading Bay Unit M-32RD 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ~~~~~~1 ~~ ~(~~ ~F~ ~`~, ~ ~ ADL0018730 Trading Bay Unit [Steelhead Platform] 75.15' 1 McArthur River /Hemlock Oil & Middle Kenai G Oil •-~~l ~ 12• PRESENT WELL CONDITION SUMMARY Sz va ~, g°a ~~~~~ Total Depth MD (ft): . Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 13,835 9,660 9,560 8,633 ~ 9,560' 10,825' Casing Length Size MD ND Burst Collapse Structural 981' 26" 981' 980' Conductor 1,347' 16" 1,347' 1,346' 2,630 psi 1,020 psi Surface 3,767' 13-3/8" 3,767' 3,766' 3,090 psi 1,540 psi Intermediate 10,588' 9-5/8" 10,588' 9,205' 7,930 psi 6,620 psi Production 1,430' 7" 10,731' 9,266' 8,160 psi 7,020 psi Liner 3,141' 4-1/2" 13,835' 9,660' N/A N/A PerForation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6# L-80 8,909' ~ Packers and SSSV Type: Packers and SSSV MD (ft): N/A N/A 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP S t h ^~ Exploratory ^ Development ^~ ' Service ^ 15. Estimated Date for 1 009 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^~ • Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ronnie Santos 263-7978 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature P ne 276-7600 Date 8/6/2009 r - COMMISSION USE ONLY C diti f l N tif i i th d N b ~~'~~/ (~ C t t ti it S on ons o approva : o y omm on so a represen un ry um er: ss a a ve may w ness ~ ~ Plug Integrity Mechanical Integrity Test ^ Location Clearance ^ BOP Test [ other: T~~ -rQ.~- ~~~ C ~ 3 00 0 ~,0 ~, . Tthf ~-~'~-~-lav $o !~ E~'o Zoon ~o Li~ . Subsequent Form Required: ~ p ~ e~p'~'. ~ APPROVED BY g ~~i A roved b : ~ ~ COMMISSIONER THE COMMISSION Date: d~ ~ pp y ., ~, Form 10-403 Revised 06/2006 .Q~ ~ ~'~~~'~ ~0~~ 8ubmit in Duplicate ~ ' ~ . . ., s .... . "f i t.' d ~ . Chevron , ~ ~ OBJECTIVE: . Steelhead Platform Well # M-32RD 8/3/09 • Abandon G-Zone and Hemlock oil sands. Recomplete as a Grayling Gas Sands (GGS) gas producer. PROCEDURE SUMMARY: 1. Install BPV. ND tree. NU and pressure test BOPE. Pull BPV. ~f 2. POOH w/ 4-1/2" L-80 tubing killstring. 3. RIH & drill out BP @ 9560'. Push same to 4-'/2' TOL at 10,694' (+/-) RKB. 4. Set cement retainer @ 9570' (+/-). Mix/Pump 100 (+/-) bbls of cement. Place 95 (+/-) bbls of cement below retainer. PU above retainer spot 3(+/-) bbls of cement on top of retainer. POOH. 5. PUMU Cleanout assembly. RIH & tag TOC. Polish/clean out cement 25' above cement retainer. 6. PUMU completion packer and jewelry. RIH w/ 4-1/2" 12.6# L-80 tubing to 8,300' (+/-) with packer at 6,880' (+/-). 7. PUMU slickline conveyed plug. Set plug in nipple. Pressure up on tubing. Set packer at 6,880' (+/-). Pressure test packer to 2500 psi. 8. Install BPV. ND BOPE. NU and pressure test tree. Pull BPV. ~ 9. Secure well and release rig to production. Production to gas lift fluid from the wellbore. 10. RU Eline and pressure test lubricator to 250 psi low/2500 psi high. /" 11. PerForate The following GGS zones: ^ F13B (upper) 8,733' (+/-) - 8,740' (+/-) ^ F13B (lower) 8,749' (+/-) - 8,764' (+/-) ^ F 14A 8, 778' (+/-) - 8, 798' (+/-) ^ F 15B 8, 944' (+/-) - 8, 976' (+/-) ^ F 15C 9, 006' (+/-) - 9, 016' (+/-) ^ F16 9,070' (+/-) - 9,112' (+/-) ^ G01 9,212' (+/-) - 9,248' (+/-) ^ G05 9,500' (+/-) - 9,530' (+/-) Note: If perforated zones are undesirable, contingency operations are to run posi-set packer and dump bail cement. 12. Continue perforating the next interval up until acceptable well deliverability is attained. 13. Rig down E-Line and turn well over to production. M-32RD REVISED BY: CVK 8-3-09 • • Chevron Steelhead Platform ~ Well # M-32RD Completion w/ Kill String 12/4/08 RKB = 75.15'Rig Floor to TBG Head C a s i n g 8~ T u b i n g % 5~ ~s u~ o~ ~~ ~_ n 6~ ~~ ~A 3~ egg 3g $ES B~h *~ag ~g~s Size T e Wt Grade Thrd ID To Btm Hole Cmt Cmt "fo 26" Conductor Surf 981' Driven Gnt to Surf 16" Surf Csg 75 K-55 BTC 15.12 Surf 134T 22" 1933 sx Calc TOC'n, surf -azsmd 20 % loss Retums lo Sur( 13-3/S" Csg 61 K-55 BTC 12 52 Surf 3767' 17 5° 2244 sx Bumped Plug ' . . Calc TOC [r,-671 assmd 20 % loss " Window from 9392'- 9408' " Retums to Sud 9-5/8 Prod Csg 53.5 L-80 BTC ' 12.25 2607 sx Caic TOC'd,-2(,I I' 8.535 Surf 10588 assmd2o% loss Calc TOC to 7" Liner 29 L-80 Butt & KC 6.184 9301' 10731' 8-I/2" 72 bbls linertop ~c/asmd 20%loss Sbtted IBTC 4_~~2 Liner ~Z'6 L-SO ABmod 3.958 10694' 13835' 6" 2-I/2"c Vl6'slois.asin Tubin 75.15' RKB to Tb Hn r a-I/2" 12.6 l, SO IBTC AB 3.958 Surf 8 909' ~F~wH ~ uv nF°ren / ~= ~• ~ NO. De th ID Item 1 9,30Y 6.184" Baker 7" ZXP Liner To Packer 2 9,Sfi0' 7" BriJ e Plu 3 10,694' S25" Baker tie back sleeve for 4-1/2° slotted Liner 4 10,705' 4360" Baker HMC liner han er Precsure Tesf Defails as nf 12/02/200R 1 4_ ~rtegily ~each . 4, 92lB to 9616' ~ _ 2 • aR w aa. l ~ .vAr G1~ : G4,5 P B-1 , 3 : ~ - &2 4 •~ - Set Set De th Result 1 9245' Good 7'e.t 2000 psi to surface. 55' above top of linec 9-'/," csg tested good. Could not get pkr to set in csg between 9245' & TOL. 2 9350' I3ad. No test above or below. 3 9400' E3nd No test between kr & BP. 4 9480' I3ad No test between kr & BP. 5 9515 Good fest to 20U0 isi. Between kr & BP « 9560'. 6 9545 Goud "fest to 2000 si. Between kr & BP r 9560'. ur~arnar~~i~.e, ~~r • Spudded M-32RD on I 1/1 S/99. Completed on 01/25/00. M32RD was a drill out of M-32 (window in the 9-5/8° -9392'). 5 fish Were left in sidetrack holes while drilling the well: N1 @ 9682' - 1226' fish. k2 @ 9564' - 1088' fish. #3 ~a? 12418' - S fish. #4 I 1650' - 300'fish. #5 9943' in the M-32RD section - 780' fish. •Hole Section MWT: •A roximate Rotatin hrs: 0 17-I/2" to 1347' 9A to 9.5 0 16' 120 hrs 0 12-t/4" ro 10588' 93 to 10.1 0 13-38" 5G0 hrs 0 8-I/2° to 10731' 9A to 10.5 0 9-5/8" 680 hrs 0 6" to 13835' 9.5 to 10.5 0 7" 258 hrs - i i - 1 I ~ ~ PF:RFORATION DATA i ~ ~ c.~~a ,:a i ~ Cdlap.c R~ ~ ~ 12/116 q',11~&S ~ i i f~ I I I I E= I I $y' a~ 1 I ~ ~ m_ ~ I 1 I I i i I I I I I I I i i i ~ ~ Zone Top Btm Amt. Accum SPF Last Perf Date Present Condition Notes G-1 9,625' 9,665' 40' 18 12/14/2006 Open f/ Prod 4-5/8" TCP 01/00 8 12/O6 (perfed 9645'Fi65') G-2 9,697' 9,737' 40' 18 12/14/2006 Open f/ Prod 4-5/8" TCP 01/00 & 12/O6 (perted 9714'-734') Ci-4 9,9~~J~ 9,99~~ 7rJ~ ~8 ~2~~4~2~06 Open f/ Prod ~-5/e"TCP01/00612lO6(perted9933'-953'89970'-990') G-5 10,060' 10,210' 150' 18 12/14/2006 O en f/ Prod 4-5/8" TCP 01/00 6 12/O6 (10070'-10090', 10120'-135' 8 10180'-195') B-1 10,430' 10,480' 50' 18 12/14/2006 Open f/ Prod 4-5/8" TCP Ot/00 8 12/O6 (Perfed 10430'-10445') B-2 10,510' 10,530' 20' 18 12/14/2006 Open f/ Prod 4-5/8" TCP 01/00 & 12/O6 B-2 10,560' 10,570' 10' 6 12/14/2006 Open f/ Prod 4-5/8" TCP 12/O6 63-67 10,694' 13,835' 3,141' 1/1/2000 Open f/ Prod Slotted Liner ~ i TD =13,835'ND/9660'ND C:\INTERIIvAM-32RD Workover 2009\Schematic\M-32RD Current Well Schematic 12-16-08rev2-20090803.doc RMS: 08/03/2009 i i Steelhead Platform Well # M-32RD Proposed Convert to Gas Casin 8~ Tubin ~~ ~~ ~o ~~ ~~ ua Size T W~ Grade Thrd ID To Btm Hole Cmt Cmt"Po 26" Conductor Surf 981' Driven Cmt to Surt 16" SurfCsg 75 K55 BTC 15 12 Surf 1347' 22" 1933sx CaICTOC~surf . -assmd 20 % loss Retums to Surf 133/8" Csg 61 K-55 BTC 12.52 Surf 376T 17.5" 2244 sx Bumped Plug ' Calc TOC @~71 assmd20% loss Window from 9392'- 9408' Retums to Surf 9-5/8" Prod Csg 53.5 L-80 BTC ' ~ 2.z5" 2607 sx Calc TOC @-2611' g.535 Surf 10588 assmd 20 % lass Calc TOC to 7" Liner 29 L-80 Butt & KC 6 184 9301' 10731' 8-1/2" 72 bbls ~ liner tap . w/assmd 20%loss Slotted IBTC AB 10694 4-~~2 12.6 L-80 3.958 , 13835' 6" 2-1/2" x 1/16" slots, 48/ft Liner mod Tubin 75.15' RKB to Tb Hn r ~l-I/2" 12.6 1,80 "I'CII 3.958 Surf 8300' Pressure'I'est Uetails as of 12/02/2008 InOeqiry Brea 92~T to951S i~wF~~ uv nti°rnn NO. De th ID Item I 450' SSSV 2 2000' Chemical Idection Sub 3 TBD GLM's 4 -6880' Packer -50'above E sand 5 -6910' Profile Ni le 6 -6940' Mech Tbg Release (-50' above E sand 7 -8300' EOT -50 above F-8 sand 8 -9570' Cement Retainer - F178 ~ p~a =Fia P~~~d -fl58 praposed =F15C popasM =fl8 praposetl =ow Rac~ea I ~ c.gw~ao.. ) ~9392' / : (3D5proposed Spudded M-32RD on I I/ I S/99. Completed on O1/25/00. M-32RD was a drill out of M-32 (window in the 9-5/8" -9392'). 5 fish Were lefl in sidetrack holes while drilling the well: #1 ~ 9682' - 1226' fish. #2 @ 9564' - 1088' fish. H3 (n~ 12418' - S fish. N4 11650' - 300'fish. NS 9943' in the M32RD section - 780' fish. •Hole Section MWT: •A roximate Rotatin hrs: o U-1/2° to 134T 9A [0 9.5 0 l6' 120 hrs 0 12-I/4° to 10588' 9.3 ro 10.1 0 13-38" S60 hrs o S-U2" to 10731' 9.0 to 10.5 0 9-5/8" 680 hrs 0 6" to 13835' 9.5 to 10.5 0 7" 258 hrs DRRGORATIl1N IIATA 2one Top Btm ~~ Accum gpp Last peri. Date Present Conditlon Notes F136 8733' 8740' 7' PRqPOSED u erF13B F136 8749' 8764' 15' PROPOSED IowerFl3B F14A 8778' 8798' 20' PROPOSED F156 8944' 8976' 32' PROPOSED F15C 9006' 9016' 10' PROPOSED F16 9070' 9112' 42' PROPOSED G01 9212' g248' 36' PROPOSED G05 9500' 9530' 30' PROPOSED G-~ 9625' 9~~ 40' 18 12/14/2~6 O Cf1 flPfOd 4-5/8" TCP 012000 8 12/2006 erPd 9645'-9665' G-2 9697~ 9737~ 40~ 18 12/14/2~6 O 8f1 f/PfOd 4-5/8" TCP 012000 8 12/2006 erPd 9714'-9734' G-4 9915' 9990' 75' 18 ~2/~4/2~6 O en f/Prod 4-5/8" TCP 012000 8 12/2006 erPd 9933'-9953' 8 9970'-9990' G-$ 1~060' 10210~ 150~ 18 12/14/2006 O en f/Prod ~~01 OCP 01 5000 8 12/2006 (perfd 70700'-10090', 10120'-10135' B-~ 10430~ 10480~ 50~ 18 12/14/2006 O 0f1 f/PfOd 4-5/8" TCP 012000 8 12/2006 erPd 10430'-10445' B-2 10510' 10530' 20' 18 12/14I2006 O en f/Prod 4-5/8" TCP 012000 3 12Y2006 B-2 10560' 10570 10' 6 12/14/2006 O en f/Prod 4-5/8° TCP 122006 B3-B7 10694' 13835' 314T 01/01/2000 O enf/Prod s~oneduner / 7D =13,8357VDV96607W M-32RD Proposed Well Schematic Rev2-20090803.doc RMS: 8/03/2009 RI~ = 75.15'Rig Floor to 7BG Head Rriaf Ilnfailc R Infn• ~ ~ M-32RD Workover 20-314" BOP / Diverter Stack Up • • Page 1 of 1 Aubert, Winton G (DOA) Fr~n: Santos, Ronilo [ronnie_santos~chevron_com] Sent: Thursday, August 13, 2009 5:46 PM Ta: Aubert, Wirrton G (DOA) Cc. Bon~ett, Nigel (NigeLBonnett}; Tyler, Steve L; Kanyer, Christopher V Subject: M-32RD Workover to Convert from Oil to Gas Producer Mr. Aubert, In response to your phone inquiry on S/12/09 regarding the M-32RD workover to convert to a GGS gas producer in tieu of a well repair to regain its oil production, please find the foNowing short summary that led to this strategy: • M-32RD was an ESP well that was shut-in and subsequently killed in August 2008 after the well exhibited an ability to naturally flow gas. Chemical analysis indicates that the gas was from the GGS sands. The well was suspended in December 2008 with a bridge plug set 55' above the existing oil perforations. • A wel l repair to regain its oil production will be complicated and has a low possibility of success against the option to convert to a GGS gas producer. The depth interval from 9245' in the 9- 5/8" casing down to 9515' in the 7" liner failed to pressure test. • The mingling of the gas into the oil zone will cause irreversible reservoir damage in one of the reservoirs and a loss of asset value for either the gas or oi! reserves. • Since the well was suspended, the shut-in tubing pressure remained nil. • Producing the GGS sands will theoretically deplete the gas sands over time and may allow oil production in the future. I hope that this will satisfy your inquiry. Regards, Ronnie Santos 907 306 5857 g~14~2oa9 5 10 104 3 10 102 , 10 ~ i DATE 2000 01 02 03 04 05 06 07 08 09 Page 1 of 7~ I~„ ~ ~ Maunder, Thomas E (DOA) From: Bonnett, Nigel (Nigel.Bonnett) [Nigel.Bonnett@chevron.com] Sent: Monday, February 09, 2009 5:06 PM To: Maunder, Thomas E (DOA) Cc: Tyler, Steve L Subject: RE: TBU M-32RD (199-097) - AGAIN Tom, 1 can assure you that there is na reiuctance t~ provide reports with grsater detail - or detai! far you #o #ulty understand our process of investigating the well anomaly at Steelhead M32. So 1 do apologise for the rniscarnmunication and waste of your time. We wi1! endeavour to ensure that the pert+nent details #hat yo~ value are fully documented in reports submitted to you. With respect to Steelhead weli M-32, the 9-5/8" casing ;rvas tested from surface to 9245 ft MD to 2000 psi with a test packer. The 7" EZ-Drii was set at 9560 ft MD to pravide a base. Then a test packer was run #o investigate the 7" liner. Above 9480 ft, we were unabie to get a test on the 7" to the EZ-Dril. At 9515 ft, we were able to obtain a 200D psi #est down to the EZ-Dril at 9560 ft. So in Summary, on Steeihead weil M-32, we have a section o# 7"' liner above 9b15 ft and into #he 9-5/8" casing #~ 9245 ft that is untested or fails to test. The 7" liner is at 9301 ft MD. `s Apologies, once again for causing frustration. ;~,;;"~;;`~'.'R~;~.~::' f' i~ ~=~ ~'~ `= ~~ Regards, Nigel From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, February 09, 2009 3:35 PM To: Bonnett, Nigel (Nigel.Bonnett) Subject: RE: TBU M-32RD (199-097) -- AGAIIV Nigel, What is happening here is precisely what 1 desire to avoid and that is i#erating to get a report that makes sense. Tfiis is not a valuable use of anyone's time. i sense there is a reluctance #o provide reports with greater de#ail. Is this sa?? I'd like to get this issue satisfactorily resolved. My need is for grea#er and accurate detail. 1 look forward to your reply. Tom Maunder, PE AOGCC : Maunder, Thomas E (DOA) Sent: o February 09, 2009 3:30 PM To: 'Kanyer, Chris V' Cc: Tyler, Steve L; Bonnett, ' Nigel.Bonnett) Subject: RE: TBU M-32RD (199-09 AIN Chris, This version appears to take care of eve to 11/28. Going o is the 7" EZ dri11 what is tested against from 9350'? If the EZ dritl was s 50', how is possible to run below i est as sta#ed in the report of 12/1 ? I look forward to ep{y. Tom Mau . E ~~~~~~~ '~ ~eo 8/14/2009 Page 1 of 2 i • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, February 09, 2009 3:30 PM To: 'Kanyer, Christopher V' Cc: Tyler, Steve L; Bonnett, Nigel (Nigel.Bonnett) Subject: RE: TBU M-32RD (199-097) -- AGAIN Chris, This version appears to take care of events up to 11/28. Going forward, is the 7" EZ drill what is tested against from 9350'? If the EZ drill was set at 9350', how is possible to run below it and test as stated in the report of 12/1 ? I look forward to your repiy. Tom Maunder, PE AOGCC From: Kanyer, Christopher V [maiito:Chris.Kanyer@chevron.com] Sent: Monday, February 09, 2009 2:16 PM To: Maunder, Thomas E (DOA) Cc: Tyler, Steve L; Bonnett, Nigel (Nigel.Bonnett) Subject: RE: TBU M-32RD (199-097) -- AGAIN Tom, I apologize for the confusion. The summaries for 11/26-11/27 on M-32RD were accidently copied from well operations on SRU 211-33. I have fixed the summary & attached a copy for you records. Let me know if you will need any further clarification. Thanks, Chris Kanyer Technical Assistant Welibore Maintenance Team Office: (907) 263-7831 Cell: (907) 250-0374 Chevron North America Exploration and Production Midcontinent/Alaska SBU 3800 Centerpoint Dr, Suite 100 Anchorage, AK 99503 From: Tyler, Steve L Sent: Monday, February 09, 2009 1:53 PM To: Kanyer, Christopher V Subject: FW: TBU M-32RD (199-097) -- AGAIN From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] 2/9/2009 Page 2 of 2 ~ • Sent: Monday, February 09, 2009 1:36 PM To: Tyler, Steve L Cc: Bonnett, Nigel (Nigel.Bonnett) Subject: RE: TBU M-32RD (199-097) -- AGAIN Steve, Further to my earlier note, I am reviewing the operations summary for the work accomplished in November and have some questions. 1. It appears that there are some operational descriptions missing following the comment "MU US{T log" at the end of 11 /25. 2. The summary for 11126 begins with "Finish LD BHA" and then "RU casing running gear". I do not find that any notification was given of the need to run 9-5/8" casing in the weil. iVathing was included in the sundry approved for the vvork on this well. Pfease provide additional information regarding this matter. i, Nothing is noted in the operations summary regarding employing 9-5/8" casing rams. Please provide additional information regarding this. 4. In the summary for 11/28, retrieving a storm packer is mentioned however I find nothing previously in the summary that one was set. 5. The operations summary for succeeding days alsa appears "patchy and broken up". I'd appreciate your providing a clearer summary of the operations. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA} Sent: Monday, February 09, 2009 1:16 PM To: Chantal Walsh -Petrotechnical; Steve Tyler Cc: Nigel Bonnett (Nigel.Bonnett@chevron.com) Subject: TBU K-19 (174-008) and TBU M-32RD (199-097) Chantal, Steve and Nigel, I am belatedly reviewing the operations reports submitted with the 404s for the work accomplished on these wells in November. I think we have spoken regarding the level of operations detail provided in the past. Is there a "next higher" level of detail that can be provided? Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 2/9/2009 ~~~ ~~ STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS /~~ 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Ran Kill String _ Performed: Alter Casing ^ Pull Tubing0 - Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ~ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Ciass Before Work : 5. Permit to Drill Number: Name: Development Q- Exploratory^ 199-097 - 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic^ Service ^ 6. API Number: 50-733-20462-01' 7. KB Elevation (ft): 9. Well Name and Number: 75.15' Trading Bay Unit M-32RD ~ 8. Property Designation: 10. Field/Pool(s): , ADL0018730 Trading Bay Unit [Steelhead Platform] McArthur River / Hemlock Oil & Middle Kenai Oil 11. Present Well Condition Summary: Total Depth measured 13,835 ~ feet Plugs (measured) 9,560' true vertical 9,660 - feet Junk (measured) 10,825' Effective Depth measured 9,560 feet true verticai 8,633 feet Casing Length Size MD 1VD Burst Collapse Struciural 981' 26" 981' 980' Conductor 1,347' 16" 1,347' 1,346' 2,630 psi 1,020 psi Surface 3,767' 13-3/8" 3,767' 3,766' 3,090 psi 1,540 psi intermediate 10,588' 9-5/8" 10,588' 9,205' 7,930 psi 6,620 psi Production 1,430' 7" 10,731' 9,266' 8,160 psi 7,020 psi Liner 3,141' 4-1/2" 13,835' 9,660' N/A N/A PerForation depth: Measured depth: See Attached Schematic True Vertical depth: See Attached Schematic Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 8,675' Packers and SSSV (type and measured depth) N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-BbI Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 620 psi 0 psi Subsequent to operation: 0 0 0 0 psi 0 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development Q- Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil Q~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-373 Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg -- ~ • Title Drilling Manager .. . . - Signature -' `"~~ Phone 276-7600 Date 12/18/2008 Form 10-404 Revised 04/2006 ~. G~ " '~~'O` , ~«p ~ ~y~. ; , ~;; Submit Original Only . _.i~,. Chevron • ~lhead Platform ~ Well # M-32RD Comrletion w/ Kill String 12/4/08 RKB = 75.15'Rig Fl oor to TBG Head C a s i n & T u b i n Size T e Wt Grade Thrd ID To Btm Hole Cmt Cmt'I'o i 26" Conductor Surf 981' Dnven ~ ti' Gntto Surf ~ 16" SurfCsg 75 K-55 E3TC 15.12 Surf 1347' 22" 1933 s~ Calc~roc'%~ surf -assmd 20% loss ~ ~ ~. , Retums to Surf :~' ~ ~ 13-3/S" Csg 61 K-55 BTC 12.52 Surf 3767' 17.Y' 2244 sx Bumped Plug Calc TOC @-671' assmd 20% loss `^ ~ " Window from 939Y- 9408' " Remms to Surf ~p~ ~ 9-5/8 Prod Csg 53.5 L-80 BTC 8 535 Surf 10588' 12.25 2607 sx Calc TOC Q-261 I' . assmd20% loss o . ~ Calc TOC ro ~ ti' 7" Liner 29 L-80 Butt & KC 6.184 9301' 10731' 8-1/2" 72 bbls liner top ~ ~ !~ w/asmd 20 % I oss ~ "~ 4~~~~ Slotted ~~~6 L-80 BTC AB 3.958 10694' 13835 G' 2-v?" r i/ia" s~o~s, ax/ti Liner mod c~ Tubin 75.15' RKB to Tb Hn r ~ a ~-1/2" 12.6 1, 80 _ f3utt 3.958 tiurf 8,76V s~fi ~ B°~ A ~~~ JF.WFJ.RY IIF.TAII. NO. De th ID Item 1 9,301' 6.184" Baker 7" ZXP Liner To Packer 2 9,560' 7" Brid e Plu 3 I Q694' S.25" Baker tie back sleeve for 41/2" slotted Liner 4 10,705 4360" Baker HMC liner han er ~ 10 Gg W iudav ~~. - G-1,2 = G~,S = B-1 - B~2 Rrirf IlPtailc R Infn~ Spudded M-32RD on 1 U15/99. Completed on Ol/25/00. M-32RD was a drill out of M-32 (window in the 9-5/8" -9392'). 5 fish Were lett in sidetrack holes while drilling the well: #I @ 9682' - 1226' fish. #2 @ 9564' - 1088' fish. #3 @ 12418' -- 5' fish. #4 11650' - 300'fish. #5 9943' in the M-32RD section - 780' fish. •Hole Section MWT: •A roximate Ratatin hrs: 0 17-1/2" to 1347' 9A ro 9.5 0 16" 120 hrs 0 12-1/4" to 10588' 93 to ]0.1 o I3-38" 560 hrs o S-1/2" to 10731' 9.0 to 10.5 0 9-5/8" 680 hrs 0 6" to 13835' 9.5 to 10.5 0 7" 258 hrs ~"~ i''L i i PERFORATION DATA ~ i i c~.ad.~r i I Cdl~e Rpe I ~ 12/ab'Pj 14825 1 E ~~ I I ~ ~ I I Z= I I ~~ I I 1 I ~ ~ ~ i ~ ~ i i I I I I I I I i ~ ~ i i ~ Zone Top Btm Amt. Accum SPF Last Perf Date Present Condition Notes G-1 9,625' 9,665' 40' 18 12/14/2006 Open f/ Prod 4-5/S" TCP 01I00 & 12/06 (perfed 9645~-sss~> G-2 9,697' 9,737' 40' 18 12/14/2006 Open f/ Prod 4-5/8" TCP 01/00 & 12/06 (perfed 9714'-734~> G-4 9,915' 9,990' 75' 18 12/14/2006 Open f/ P~Od 4-5/8' TCP 01/00 3 12/OB (perteA 9933'-953' 3 9970'-990') G-5 10,060' 10,210' 150' 18 12/14/2006 Open f/ Prod 4-5/8' TCP 01/00 d 12/OB (10070'-10090', 10120'-135' 6 10180'-195~ B-1 10,430' 10,480' S0' 18 12/14/2006 Open f/ Prod a-sia~~ TCP 01l00 & 12106 (Perfed 10430~-ioaas~~ B-2 10,510' 10,530' 20' 18 12/14/2006 Open f/ Prod 4-5/8" TCP 01/00 & 12/O6 B-2 10,560' 10,570' 10' 6 12/14/2006 Open f/ Prod 4-5/8" TCP 12/06 63-67 10,694' 13,835' 3,141' 1/1/2000 Open f/ Prod Slotted ~iner TD= 13,835'ND/9660'ND O:\NA[J~MCBU~Alaska\Depts\Drilling\Users\TylerS12008 Projects~2008 Steelhead~M-32RD\SchematicUvl-32RD Current Well Schematic 12-16-08.doc CVK: 12/16/2008 • ~ Chevron - Alaska Daily Operations Summary IMobe i Mobe rig onto well. Mix sized salt aill. RU eline. Arm tubing punch. MU/RIH, tag standing valve at 8839' PU and position tubing punch in first full joint i ablove XN nipple. Attempt to pressure up tubing, well on vacuum. Fire tubing punch, top shot at 8814', bottom at 8820'. POOH. RD eline. Bled gas pressure off tbg x csg annulus. Circulated well with 3% KCL taking retums to production. Pump rates 2-4 bpm. Total um ed 585 I~ bbls with water back after 450 bbls um ed. Monitored welt 90 b h loss rate. Pumped 120 bbls sized salt pill, squeezing into formafion. ircu ated out ! f remaining (50bbls) sized salt down tubing and up annulus. ND tree. NU BOPE. 24 hr notice given to AOGCC of upcoming BOP test, transportation for ~; AOGCC inspector lined up to witness tomorrow's test. ; i NU BOPS. Start testing BOPS. AOGCC inspector did not arrive for witness of BOP test. ~ Test BOPs 250 low, 3000 high. Test good. Rig up tongs and shieve. Unseat tubing hanger` Circulate bottoms up hydrocarbons to surface Pull tubing hanger to floor POOH w/tubing f~.f~~~~,P~sSl~"'~'~~~~~~~~+~i~iii/, "' \ .; ~~~ : ~:.,~ - \,'r Q~i.:. . ,/~ F, az.':.,, "i \ w[.e , ~~.: , /„_~.,..,_:~~.• \~~'.~.:~ 6a.,i,/,,z rOperetions Summary -ti~.=_.~_,_ ~r~ ° ~~ _.. ~~-~ ~%,....~. i Continue to POOH with ESP completion. LD ESP Assembly. RIH w/ 4-1/2" 12.6# IBT tubing as killstring due to waiting on boat and logistics of pipe POOH wdh killstrmg, standmg back tbg PUMU tandem clean out assembly i --„~,>~( .#., ) /~ ~~~~ti~~~~~. ~C'~~f ,~..~~k~M /.,i;,. ~ ~ /~: ~ . .::1 ,~" ~;~.~ ~~'',,.,,,/y-~'Z:... -; 1~ , ~,,,'~ ~f . •,a ~~ F l Y~ „ ~~ . ~ "~'~;~/ ~~,--,y,.~ '` Operations Summary ~ ~ i PUMU Tandem Cleanout BHA w/ 7" & 9-5/8" casing scrapers. RIH on 5" DP while intermediately CBU with sweeps. "t'112512QU8 QE! i~t~ -'t11~ ~~,'',4~l~'.: ;'>: :" " ". ; !.. .a !. ,.~-~''~.,. .;:.. .. . y,, . ~~ ~~ ~ . .... . ~ ~ . .'. .n.... . : '; ;; .:-•~ iOperations Summary ~! Continue to RIH with scraper assembly. Pump high vis. sweep, 25 bbls. No cuttings or gas observed. Displace hole w/670 bbls clean fluid. POOH LD ~ BNA (no fluids loss to formatiortl. MU USlT loa. RIH w/ 9-5/8" USIT logging tool. Log 9-5/8" casing from 9,30Q' to surface. RIH w 7" USIT logging tool. Log from 9,655' to 9,100'. POOH. RIH w/ RST loging I tooL Log from 9,600' to 1,400' POOH, RD Eline. PUMU 7" Champ pkr. RIH. I 'Cont RIH w/ 7" Chanmp pkr. istorm akr. RIH set same Ca~ : RIH. Enqaqe and retrieve storm qkr. POOH ~D same. RIH set 7" Champ qkr (a~. 9580'. Attempt to pressure test liner & csq to 2000 Finished POOH & LD 7" Champ Pkr. PUMU 9-5/8" RTTS pkr & BP. Set RTTS (a~ 9245'. Tested 9-5/8" csq to 2000 asi for 30 min. POOH LD 9-5/8" RTTS I& BP assy. PUMU 7" EZ Drill BP. RIH. ~ • Chevron - Alaska Daily Operations Summary ~M 132RD ITRADING BAY UNIT M-32RD IADL001873Q ~5073320462 IQZ8714 ~n9f160.00 ~test DP annulus from 9350' to surface to 2000 psi Failed. ( RI set pkr @ 9400'. Attempt to test liner to 9560' Failed. RI set pkr @ 9545' (15' above BP @ 9560'). Pressure test liner to BP @ 2000 psi for 30 min. PU ito 9515'. Set pkr. Tested liner between pkr & BP to 2000 psi for 30 min. PU to 9480'. Set pkr. Attempt to test liner between pkr & BP Failed. POOH w/ packer. LD 3-1/2" DP. RIH w/ 4-1/2" 12.6# L-80 Butt tubing kill string to 8675'. ~, Continue RIH w/ 4-1/2" Kill String tbg to 8909'. Land tbg hngr. RI LDS. Set BPV. Strip BOPE off well. ' Continue ND BOPE. NU Tree. test same. down, move riq to M-18. ~ ~ ~Chevron ~ Chevron - Alaska ~ Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (fl) Water Depth (ft) M-32RD TRADING BAY UNIT M-32RD ADL0018730 5073320462 QZ8714 160.00 Completion - Reconfigure Major Rig 11/14/2008 12/4/2008 Work Over (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number M-32RD 5073320462-01 1941360 D~ " ~, ~~~ 3~, ~,: "~;s , ,>, ~ ~ ~, t~ ~~, . M. , ~ ~ ~ . . ~ v: ~r,, ,~ ~ ~ _ ~ ~~~~ ~ 11HM200& 00:00 -11/15/200$ 00:00 ~ ry~ . _ • Operatlons Summary ~ Y Rig up slick line. RIH with standing valve, et in XN nipple at 8829'. POOH. Fluid level at 1800'. - - , _: ~;,,,~ r 11/15/2008 00:00'-11/1612008 00:00 ~ , ,,.: , x , - Operations Summary RD slick line. Begin Mob rig from previous we M-13). 91118120Q8 00:00~ =1~1/1'~/2008 00:00 ~ ~ ~ ~ ~~ `~ ~ . ~x ~~~s , ~ . , ~ ~,=::'-~ Ooerations Summarv _ .. _ .,-. . .,.,,'~-:..: _ ,,~; Mobe 91'~~"1200$OOAO,~~~f~"~t2a0800:~ " ~~ Operafions Summary Mobe rig onto well. Mix sized salt pill. RU eline. Arm tu ' g punch. MU/RIH, tag standing valve at 8839' PU and position tubing punch in first full joint ablove XN nipple. Attempt to pressure up tubing, well on cuum. Fire tubinq nunch. too shot at 8814'. bottom at 882Q'. POOH. ~ ~: . r; °~~ a.~,.~'~ ~ t1t1812008~00.00~-..~~a tr'~~ t~~i~ "~ ~ ~ ~ ~~ ~ ~ ~ Operations Summary ~ RD eline. Bled gas pressure off tbg x csg annulus. Circulated v il with 3% KCL taking retums to production. Pump rates 2-4 bpm. Total pumped 585 bbls, with water back after 450 bbls pumped. Monitored well h I r Pumped 120 bbls sized salt pill, squeezing into formation. Circulated out remaining (50bbis) sized salt down tubing and up annulus. ND tre NU BOPE. 24 hr notice given to AOGCC of upcoming BOP test, transportation for AOGCC inspector lined up to witness tomorrow's test. 7'1l19t2008 ~00:0~ =11/20120Q8 00:00 ~~.: . ~ ~ ~ ~ ~ ~~ ~ ~ . ,.., ~. : ~~. . ~°~~~3 ~~., ~ Operations Summary NU BOPS. Start testing BOPS. AOGCC inspector did not arrive for witne of BOP test. ~,, , . ~ . 11/2 ~ ~ 'r*11/21/'~~08`Ob:Oi},. ,. ~n~~,~ ~ ~~ n . ~. Operetions Summary Test BOPs 250 low, 3000 high. Test good. Rig up tongs and shieve. 111~1~2~Q A4:00 -11/2212008 00:00~ ~~ ~ ~ ~~: r- ~ ~ ~~~r~~ ~. ,~ ~ , ~ ~.. ~~,~~.. ~.~~.:. Operations Summary ~ Unseat tubing hanger. Circulate bottoms up, hydrocarbons to surtace. Pull tubing h ger to floor. POOH w/tubing. 11' 2/200$' b~:00 -11l23/2008 00:00 ~ `;x~ ` ` " Operations Summary Continue to POOH with ESP completion. LD ESP Assembl . RIH w/ 4-1/2" 12.6# IBT tub as kilistrin due to waitin on boat and lo istics of i e ~ ~1X2312008~ 00:00--11f24I2008 00:00~ ~~ ~ ~ ~ ~ ~ ~ ;~~ ~ a,~ Operations Summary POOH with killstring, standing back tbg. P ndem clean out asse T172d12008~~00:0~~=1'il7 ~ ~ ~ ~ `'~~ ~ ~~~~ '~., ~~t'~ Opera6ons Summary ~ ~ , PUMU Ta le nout BHA w/ 7" -" casin scr e. RIH on 5" DP wh' e intermediately CB ith sweeps. ~ < , ~ w ~tt 8U ~,~6~ ~ ~'"~~~~^~ ,~ ~~.~ ~~ t ,;~ ~ ti ~ ~ ~ ~~ ~. ~ ~ ~. . ,~ ~ .~ , rations Summary Continue to RIH with scraper assembly. Pump high vis sweep, 25 bbl o cuttings or gas observed. Dis ace hole w/670 bbls clean fluid. POOH LD BHA (no fluids loss to formation). MU USIT loa. 2 ; .w .r ~. 11126~2Q08OQ:QQ-11t271~005 Q:1~. :~,. . ~ ~ ~ ~ ~ ~ ~~~ ~ ~ ' :< : ~ ~ ~~ ; ~~ Operations Summary ~ Finish LD BHA. RU casing running gears. -5/8" 40 ppf L-80 BTC casing. Land casing on WH hanger with C at 2095'. Circulate while preparing to cement casing. 11',~~ ~ ~' ~~ -'11/2 :00 ~ ~s r ~; ~ ~~ ` ~~"~~.:~~: wr. M~, , ,_ ~ ~~.~.. . Operations Summary ' ~ ~ ~ ~-~~ ~~ ~ ~ ' ~ ~ ~ ~~~~ ~~ ~ ~ : ndition hole prior n in`g: -PPess~re tesf'ceme ' s to 5000 psi. Cement casing with lead and tai lurry. RD cementing gears. Installed and test WH pack 5000 psi. Test BOP aria gas detection sy ems. ~ ~2oot ~o:oa - aoo~a Qo o~~° ~~£ ~ ` ; 5~ } Operations Summary Finish tested BO E. RIH. Engage and retrieve storm pkr. POOH LD sam RIH set 7" Champ pkr @ 9580'. Attempt to pressure st liner 8 csg to 2000 psi. No Joy. PU et pkr @ 9400'. Attempt to pressure test to 2000 psi. Joy. POOH. ~,~.. <, : , ~.,. /2912 8 0. `~ ~ ~~k, , nx~ ~ ~ ~ , , ~,~ 7 . ~ . ,w~n ~ , , „~ Operations Summary ~ Finished POOH & LD 7" TTS pkr & BP. Set RTTS @ 9245'. Tested 9-5/8" csg to 2000 psi for 30 min. POO LD 9-5/S" RTTS & BP assy. PUMU 7" EZ Drill BP. RIH. ~ ~ Chevron Debra Oudean Chevron North America Exploration and Production Technical Assistant 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 Tele: 907 263 7889 Fax: 907 263 7828 E-mail: oudeand@chevron.com ice/ MM~ Y~ `J l d v d l ~~ l`~ O `~ Q~+ ~ P \ DATE January 22, 2009 To: AOGCC Mahnken, Christine R ~,~~ ~~~ ~ ~: , 333 W. 7th Ave. Ste# 100 ~ ~ ~ Anchorage, AK 99501 WELL LOG TYPE SCALE LOG DATE L UN S CD LOGGED # INE TBU M-06 CEMENT EVALUATION ULTRASONIC IMAGING TOOL 5" 9/10/2009 300-12392 1 X GR/CCL TBU M-06 CEMENT EVALUATION 5" 9/10/2009 400-12392 1 X ULTRASONIC IMAGING TOOL GRlCCL TBU M-06 VISION SERVICE MEASURED DEPTH RECORDED 7/24/2009 0-12502 X X MODE 1:600 / 1:240 TBU M-06 VISION SERVICE 7/24/2009 0-12502 X X TRUE VERTICAL DEPTH RECORDED MODE 1:600 / 1:240 TBU M-06 PRODUCTION LOG 12/24/2009 11370-12380 2 X W/GHOST/DEFTffEMP/PRESS/DENS/GR/CCL TBU M-O6 FINAL WELL REPORT -NOTEBOOK 9/1/2009 X X FORMATION LOG MD /FORMATION LOG TVD /LWD COMBO LOG MD /LWD COMBO LOG TVD /GAS RATION LOG MD /GAS RATION LOG TVD /DRILLING DYMANICS MD /DRILLING DYNAMICS TVD ' TBU M-20 VISION SERVICE MEASURED DEPTH RECORDED 10/19/2009 380-10474 1-5 X X MODE 1:600 / 1:240 i TBU M-20 VISION SERVICE 10!19/2009 380-10474 1-5 X TRUE VERTICAL DEPTH RECORDED MODE 1:600 / 1:240 TBU M-20 FINAL WELL REPORT -NOTE BOOK 9/1/2009 X X FORMATION LOG MD /FORMATION LOG TVD /LWD COMBO LOG MD /LWD COMBO LOG TVD /GAS RATION LOG MD /GAS RATION LOG TVD /DRILLING DYMANICS MD !DRILLING DYNAMICS TVD TBU M-32 RD PERFORATION RECORD 2.5 POWER SPIRALS 11/17/2009 9100-9520.5 2 X X TBU M-32 RD FLOWMETER LOG 11/16/2009 8700-9522 1 X X WELL DATA REPORT DATE TBU M-20 DCS ANALYSIS REPORT 12/9/2009 Please acknowledge receipt by signing and rgt-erning one copy of this transmittal or FAX to 907 263 7828. Received 6~: \~ ~ I ~ I Date: Cheer®C9 Francisco Castro Chevron North•rica 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 January 13, 2009 To: AOGCC Mahnken, Christine R 333 W. 7th Ave. Ste# 100 Anchorage, AK 99501 __ 1 ~ ~i ~ INTERVAL ~ NOTES -LAS, PDS, WELL ~ LGG TYPE i SCALE LOG DATE RUM ~ L ~ B-LINE j SD ~ i LOGGED DLIS - - --- - _ __ --- -~ - - - i ~ --- -- -,;` CEMENT MAPPING TOOL SRU 312-09 SCMT-GR 5" 1-Nov-08 1 1 1 3650-6000 PDS, DLIS .~,~~ =j v TBU M-32RD RST-SIGMA 5" 26-Nov-08 1 1 1 50-9300 DLIS, PDS `~~. } ,; TBU M-32RD RST -SIGMA TVD 5" 25-Nov-08 1 1 1 50-9300 LAS, DLIS, PDS i~ 4 ~f' `~ HV B-13 RST - GR -CCL 5" 12-Nov-08 1 1 1 3600-7685 LAS, DLIS, PDS _____-- 'i`7~ ''~ ~ HV B-12 RST - GR -CCL 5" 12-Nov-08 1 1 1 3700-10313 LAS, DLIS, PDS `~ HV A-8 PLUG SETTING RECORD 5" 7-Dec-08 1 1 1 6077-6301 DLIS, PDS ~j~ r HV A-8 PSP -WATER ENTRY 5" 10-Dec-08 1 1 1 4836-6160 LAS, DLIS, PDS !~ ~ HV A-8 PSP -DEFT 5" 22-Nov-08 1 1 1 4900-7300 PDS, DLIS -a ~j ~ IRU 13-31 USIT 5" 2-Dec-08 1 1 1 50-6250 LAS, DLIS, PDS /~~ IRU 13-31 PRESSURE TEMPERATURE 5" 10-Dec-08 1 1 1 100-6192 LAS, DLIS, PDS ~ ~ Please acknowledge receipt by signing and returning one copy of thls~trara~n 007 263 7828. '1 ,~, -, Received ~i / _ Date: ~,§r~ ~ ~ ~~.~;°~ I( ,' i _.:: M-32RD -Current 16-3/4" BOP stack Page 1 of 1 Regg, James B (DOA) (~j~ ~~q-~~-~ From: Kanyer, Christopher V [Chris.Kanyer@chevron.com] ~ ~ t~I~~ Sent: Tuesday, November 18, 2008 3:10 PM ~~~ To: Regg, James B (DOA) Cc: Vaussine, Ray J. (rajv) (RayVaussine); Tyler, Steve L; Nienhaus, Doug R Subject: M-32RD -Current 16-3/4" BOP stack Attachments: Steelhead Current BOP Schematic.xls Mr. Regg, Due to setbacks in receiving all components of our new 20-3/4" BOP stack, we will be using our current 16-3/4" BOP stack that is in operation for our work on M-32RD. I have attached a current schematic of this BOP stack. «Steelhead Current BOP Schematic.xls» Through our conversations with Mr. Tom Maunder, we will make sure to give proper notice in the use of our new 20-3/4" BOP stack as discussed. Please let me know if you have any questions. Thanks, 6,~k:~~1~~'C'E1~F_..xG~ IV Ii `:" C. .P. ~illJ~' ~-~~a- ~~ ~~~~~ ~f~ ~(.(a(~SiY~r? ~.Q,~~ ~"~ llJv- 1 ~'1e~(l~ -~ ~~~ ~;~~ `~i~•~,~~zcr,~ -}~ rtes Chris Kanyer es Technical Assistant Wellbore Maintenance Team (907) 263-7831 Chevron North America Exploration and Production Midcontinent/Alaska SBU 3800 Centerpoint Dr, Suite 100 Anchorage, AK 99503 ~ ~l~ n ~~ ~.e.~ 11/18/2008 M-32RD 16 3/4" BOP Stacie To of Rota Table K6= 71.61' 71.61' Drip Pan 36.25' 6.75' This is wrong -y f 5.3' I 16 3/4" 5M Hydril Annular 5.40' 16 314" 10 M Hydril DBL Gate 4 1/2"Pipe Rams 6.03' 18 314" SM Riser 23.47' 19.96' Upper well Bay Floor 16 3/4" 5M Riser Hub Connection on top Flanged Bottom 2.51' 60' ~~ ~ Top of 16" 5 M Tbg Spool 59.76' TBG Spool s Code Definition Cali Cali er to CCL Casin collar locator ChmCt Chemical Cutter CmtEv Cement Evaluation Cnotz See Notes Com I Com letion Com u Com uter Lo Corro Corrosion Dens Densi Di Di DirSv Directional Surve DnHoE Downhole E ui ment Dos Dail O erations DrIRt Drill Rate FMI Formation Micro Ima er FmTst Formation Tester FrmTst Formation Tester FwR t Re ort: Final Well Re ort GasAn Gas Anal sis GR Gamma Ra Gradi Gradiometer GST Gamma Ra S ectromet IndRs Induction/Resistivi In'P In'ection Profile Leak Leak Litho Litholo Ma Rs Ma netic Resonance Mud Mud Lo Neut Neutron Noise Noise Perf Perforation Poro Porosi Press Pressure Prod Production ROP Rate of Penetration RST Reservoir Saturation Sam I Sam le SeisV Seismic/Veloci Sonic Sonic SP SP Sin Sinner Srve Surve - Misc Tem Tem erature ThDc Thermal Deca Trace Tracer Ver LIS Verification WtrFl Water Flow L_..,~ M-13 BOP stack Maunder, Thomas E (DOA) Page 1 of 1 From: Kanyer, Christopher V [Chris.Kanyer@chevron.com] Sent: Thursday, October 23, 2008 2:02 PM To: Maunder, Thomas E (DOA) Subject: M-13 BOP stack know Chantal answered your question about the BOP stack far M-13. I wanted to follow up with some info. The change out of the BOP stack on Steelhead is scheduled to occur before we move onto M-32RD to pull tubing and run our kill string. This should be about 11/5/08. Let me know if you have any more questions or concerns. Chris Kanyer • Technical Assistant Wellbore Maintenance Team (907) 263-7831 Chevron North America Exploration and Production Midcontinent/Alaska SBU 909 W. 9th Avenue Anchorage, AK 99501-3322 ~~ a~ ~`~" ~~~-©~~ 2/9/2009 • ALASSiA Olii A1QD ~5 COI~TSERQATIOIQ COM1rIISSIOI~T Timothy C. Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ,~~~ ~ •n~ ~> ,r,n,., Re: McArthur River Field, Hemlock G Oil Pool, M-32RD ~ ®~ 1 Sundry Number: 308-373 ~~ 1 Dear Mr. Brandenburg: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this~-1 dart' of October, 2008 Encl. ~~ STATE OF ALASKA `D'~,AL~ OIL AND GAS CONSERVATION COMII~ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon^ Suspend ^ Operational shutdown^ Perforate ^ Waiver^ OtherO Alter casing^ Repair well ^ Plug Perforations^ Stimulate ^ Time Extension ^ Run Kill strin Change approved progran^ Pull Tubing^./ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^ Exploratory ^ 199-097 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20462-01 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 ^~ Trading Bay Unit M-32RD 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL0018730 Trading Bay Unit [Steelhead Platform] 75.15' McArthur River/Hemlock Oil & Middle Kenai G Oil 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft); Plugs (measured): Junk (measured): 13,835' 9,660' 10,825' 9,294' N/A 10,825' Casing Length Size MD TVD Burst Collapse Structural 981' 26" 981' 980' Conductor 1,347' 16" 1,347' 1,346' 2,630 psi 1,020 psi Surface 3,767' 13-3/8" 3,767' 3,766' 3,090 psi 1,540 psi Intermediate 10,588' 9-5/8" 10,588' 9,205' 7,930 psi 6,620 psi Production 1,430' 7" 10,731' 9,266' 8,160 psi 7,020 psi Liner 3,141' 4-1 /2" 13,835' 9,660' •" ~ N/A Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 4-1 /2" 12.6# L-80 ~~ ~; y ~ ~~~~ 8,990' Packers and SSSV Type: Packers and SSSV MD ((ft): /~M~SI~~ ~ ~ " ~ ` ~ ' ' N/A ~~ i +. 8: ; ~ Qi. ~ .: ~titT111 iISS~ii N/A 13. Attachments: Description Summary of Proposal ^~ 14. Well Class after proposed wo . •~~ 4 ~ J~ ~ Detailed Operations Program ^ BOP Sketch ^~ Exploratory ^ Development [[~/to ~Service ^ 15. Estimated Date for 11/15/2008 16. Well Status after proposed work: Commencing Operations: Oil 0 Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name ®n Timothy C. Brandenburg Title Drilling Manager (" Signature ~ `~ Phone 276-7600 Date 10/14/200 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number ~ Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ ~~ ~/~~ -- ,~ ~ ~ ,~/ ~ [ Other: ~~~ PS i ~~~ ~ '~' ~~r-. Subsequent Form Required: `v~~1 " ~V APPROVED BY ~ Approved by: COMMISSIONER THE COMMISSION Date: ! ~ f Z ~ - - ~$ CFA., U ~ i ~ ~ n _ ~°' ,~ ~o. so. oS Form 10-403 Revised 06/2006 ~ ~ ~Q~~ ~ ~ ~ L.] L Submit in Duplicate Chevron • OBJECTIVE: Steelhead Platform Well # M-32RD 9/29/08 Retrieve existing ESP completion. Utilize Eline conveyed logging tools for assessing wellbore integrity. Qualify future remediation of well as an oil or gas producer. PROCEDURE SUMMARY: 1. MIRU slickline. RIH shift sldg sleeve open 2. Mix Sized Salt pill. Pump sized salt pill. Displace with FIW. Monitor well to ensure losses are manageable. 3. Install BPV. ND tree. NU BOPE. 4. PUMU Landing joint. Test BOPE 250 psi low / 3000 psi high (Test Annular 250 psi low/1500 psi high). 5. POOH w/ 4-1/2" tubing & ESP Equipment. LD ESP equipment. 6. PUMU 9 5/s" csg scrapper w/ bit. RIH on 5" DP (reciprocating pipe while RIH) to TOL @ 9300'. CBU. POOH. 7. PUMU 7" csg scrapper w/ bit. RIH on 400' of 3-1/2" DP & 5" DP (reciprocate in 7" liner) to 9600'. CBU. POOH. 8. RU Eline. PUMU RST Log tools. RI to 9600'. Log to 3550'. POOH. 9. PUMU USIT Log tools f/ 9-5/8". RI to TOL @ 9300'. Log to 3550'. Make additional passes as necessary (Indentify TOC & cmt/pipe integrity). POOH. 10. PUMU USIT Log tools f/ 7". RI to 9600'. Log to TOL @ 9300'. Make additional passes as necessary (Indentify TOC & cmt/pipe integrity). POOH. 11. RIH w/ 4-%2" tubing kill string to 8900'. Land same. 12. ND BOPE. NU Wellhead. 13. Release rig. M-32RD REVISED BY: SLT 9/29/08 Chevron . • Steelhead Platform Well # M-32RD ESP Repair WO 12/18/06 RKB = 75.15'Rig Floor to TBG Head e ti Uo 3~ ' x V~ aE~ ~~ ai°- U~ Casing & T u b i n Thrd ID Top E 26" Conductor Surf 981' Driven Cmt to Surf 16" Surf Csg 75 K-55 BTC 15.12 Surf 1347' 22" 1933 sx Calc'rOCru surf -assmd 20% loss Retums to Surf 13-3/8" Csg 61 K-55 BTC 12.52 Surf 3767' 17.5" 2244 sx Bumped Plug Calc TOC @-671' assmd 20% loss " Window from 9392'- 9408' " Retums to Surf 9-5/8 Prod Csg L-80 BTC ' 12.25 2607 sx Calc TOC @-2611' 53.5 8.535 Surf 10588 assmd 20% loss Calc TOC to 7" Liner 29 L-80 Butt & KC 6.184 9301' 10731' 8-1/2" 72 bbls liner top w/asmd 20%loss " Slotted IBTC AB ' ~ 4-1/2 Liner 12.6 L-80 mod 3.958 10694' 13835 G ~-i/," r i/ih" sio~s. as/rt Tubin 75.15' RKB to Tb Hn r 4-1/2" 12.6 I: 8(1 Butt 3.958 Surf 8,990` ESP Cablc w/1213/s" I/OSOLl3C 90F'13 I8S GA1. (2.361" ' Chem inj lines 3.7 x 1.611") Surf 8,'190 .IFWF.I,RY DF.TAI1. a. b. c. d. e. f. 9 h 2-9 10 Csg Window a9393' G-1,2 G-4,5 = B-1 B-2 NO. De th ID Item a. 1853' 3.958" 4-1/2" SFO Mandrel w/ dumm valve drift ID = 3.833" b. 2923' 3.958" 4-1/2" SFO Mandrel w/ dumm valve drift ID = 3.833" c. 3736' 3.958" 4-1/2" SFO Mandrel w/ dumm valve drift ID = 3.833" d. 4414' 3.958" 4-1/2" SFO Mandrel w/ dumm valve drift ID = 3.833" e. 5031' 3.958" 4-1/2" SFO Mandrel w/ dumm valve drift ID = 3.833" f. 5509' 3.958" 4-1/2" SFO Mandrel w/ dumm valve lift [D = 3.833" 6023' 3.958" 4-1/2" SFO Mandrel w/ dumm valve drift ID = 3.833" h. 6593' 3.958" 4-1/2" SFO Mandrel w/ dumm valve drift ID = 3.833" l 8839' 3.75" "XN" Ni Ie ( rofile = 3.813" 2 18895' NA Pressure Head 3 8896' NA Dischar e Head 4 8897' NA Pum Model HC7800 HPHVMT AR 1-1, CSE27940PC 5 8910' NA Pum Model HC7800 HPHVMT AR 1-I, CSE27940PB 6 8923' NA Pum Model HC7800 HPHVLT AR 1-1, CSE27940PA 7 8937' NA Seal Assembl 8 8952' NA Motor - 800 HP 0216009878 21 H00489 9 8987' NA Phoenix Sensor XT-1/Anode/Centralizer bottom 8990' 10 9301' 6.184" Baker 7" 7XP Liner To Packer 11 10694' 5.25" Baker tie back sleeve for 4-1 /2" slotted Liner 12 10705' 4.360" Baker HMC liner han>;er Rrief Details & Info: Spudded M-32RD on 11/15/99. Completed on 01/25/00. M-32RD was a drill out ofM-32 (window in the 9-5/8" -9392'). 5 fish Were left in sidetrack holes while drilling the well: #1 @ 9682' - 1226' fish. #2 @ 9564' - 1088' fish. #3 @ 12418' - 5' fish. #4 ~ 11650' - 300'fish. #5 rnr 9943' in the M-32RD section - 780' fish. •Hole Secfion MWT: •A roximate Rotatin hrs: 0 17-1/2" to 1347' 9.0 to 9.5 0 16" 120 hrs 0 12-1/4" to 10588' 9.3 to 10.1 0 13-38" 560 hrs 0 8-]/2" to 10731' 9.0 to 10.5 0 9-5/8" 680 hrs 0 6" to 13835' 9.5 to 10.5 0 7" 258 hrs 1 1 1 1 1 1 PERFORA-PION DATA 1 1 I Co•cermd wi6 1 1 Colapve Rpe 1 1 IL06'a 10,825' 1 1 1 ~;~ 1 1 ~ `~ I 1 5i 1 1 1 1 I I I 1 1 1 1 1 1 I 1 1 1 1 1 1 I 1 1 I Zone Top Btm Amt. Accum SPF Last PerfDate ( Present Condition Notes G-1 9,625' 9,665' 40' 18 12/14/2006 Open f/ Prod 4-5/6" TCP Ot/00 8 12/06 (perfed 9645'-665') G-2 9,697' 9,737' 40' 18 12/14/2006 Open f/ Prod 4-5/6" TCP 01/00 8 12/06 (perfed 9714'-734') G-4 9,915' 9,990' 75' 18 12/14/2006 Open f/ Prod 4-5/B" TCP O1/00 8 12/08 (perfed 9933'-953' 8 9970'-990') G-5 10,060' 10,210' 150' 18 12/14/2006 Open f/ Prod 4-5/8" TCP 01/00 8 12/08 (10070'-10090', 10120'-135' & 10180'-195') B-1 10,430' 10,480' 50' 18 12/14/2006 Open f/ Prod 4-5/8" TCP 01/00 8 12/06 (Perfed 10430'-10445') B-2 10,510' 10,530' 20' 18 12/14/2006 Open f/ Prod 4-5/8"TCP01/00812/O6 B-2 10,560' 10,570' 10' 6 12/14/2006 Open f/ Prod 4-5/8" TCP 12/06 B3-67 10,694' 13,835' 3,141' 1/1/2000 Open f/ Prod Slotted Liner , r TD = 13,835'MD/9550'TVD O:\NAU\MCBU\Alaska\Depts\Drilling\Users\Tyler5\2008 Projects\2008 Steelhead\M-32RD\Schematic\M-32RD ESP Schem Dec06.doc CRW: 01/15/2007 Chevron , elhead Platform ell # M-32RD Proposed Comrletion w/ Kill String RItB = 75.15'Rig Floorto TBG Head Casi ng & T u b i n Size T e Wt Grade Thrd ID To Btm Hole Cmt Cmt To 26" Conductor Surf 981' Driven Cmt to Surf 'g I ti" Surf Csg 75 K-55 BTC 15.12 Surf 1347' 22" 1933 sx Calc TOC a surf ~ „ -assmd 20 % loss a~. i ~ Returns to Surf ~a ' yy 13-3/8" Csg 61 K-55 BTC 12.52 Surf 3767' 17.5" 2244 sx Bumped Plug Calc TOC @-671' ~S ~ assmd 20% loss ~'q ' Window from 9392'- 9408' " Returrs to Sure 9-5/8" Prod Csg L-80 BTC ' 12.25 2607 sx Calc TOC @-261 I' ~~ 53.5 8.535 Surf 10588 assmd 20% loss ~ Calc TOC to A 7" Liner 29 L-80 Butt & KC 6.184 9301' 10731' 8-I/2-' 72 bbls liner rop ~~ w/asmd 20°/loss 4-1/2" Slotted 12 6 L-80 IBTC AB 3.958 10694' 13835' 6" _-la- x I/16~ slots, as/et .~ Liner . mod ,: a Tubin 75.15' RKB to Tb Hn r ~ ~ 4-1/2" 12.6 1,-80 Butt 3.958 Surf (8,900' b~o ~ ~~ b r c~ ~~ ` .IFWF.I ,RV t)RTAII. NO. De th ID Item 1 9301' 6.184" Baker 7" 7XP Liner To Packer ~3` r 2 10694' 5.25" Baker tie back sleeve for 4-1/2" slotted Liner 3 10705' 4.360" Baker HMC liner han er 10 c.R wt oaow !d9A2' = G-1,2 Gd,5 = B-1 = B-2 Rrief nrtailc .C Infne Spudded M-32RD on 11/15/99. Completed on 01/25/00. M-32RD was a drill out of M-32 (window in the 9-5/8" -9392'). 5 fish Were left in sidetrack holes while drilling the well: # 1 @ 9652' - 1226' fish. #2 @ 9564' ~ 1088' fish. #3 @ 12418' ~ 5' fish. #4 11650' - 300'fish. #5 9943' in the M-32RD section - 780' fish. .Hole Section MWT: •A roximate Rotatin hrs: 0 17-1/2" to 1347' 9.0 to 9.5 0 16" 120 hrs 0 12-1/4° to 10588' 9.3 to 10.1 0 13-38" 560 hrs 0 8-1/2" to 10731' 9.0 to 10.5 0 9-5/8" 680 hrs 0 6" to 13835' 9.5 to 10.5 0 7" 258 hrs 1 1 1 I I I PI';RFORA7'ION DATA I I 1 Cmmned wfh 1 I Cd,gaeRpe 1 117A16 'd p41r23 1 1 1 1 1 ~ 1 1 m Eq ~i I 1 8o- 1 1 1 1 ~R I 1 1 I 1 I 1 t I I I 1 1 1 1 1 1 1 Zone Top Btm Amt. Accum SPF Last Perf Date Present Condition Notes G-1 9,625' 9,665' 40' 18 12/14/2006 Open f/ Prod a-s/s" TCP 01100 & 12/OS (perfed 9645'-665') G-2 9,697' 9,737' 40' 18 12/14/2006 Open f/ Prod a-s/a" TCP 01/00 & 12/06 (perfed 9714'-734') G-4 9,915' 9,990' 75' 18 12!14/2006 Open f/ Prod 4-5/9" TCP01/00 & 12/08 (perfed 9933'-953' 8 9970'-990') G-5 10,060' 10,210' 150' 18 12/14/2006 Open f/ Prod 4-5/9" TCP 01/00 & 12/08 (10070'-10090', 10120'-135' d 10180'-195 B-1 10,430' 10,480' 50' 18 12/14/2006 Open f/ Prod 4-5/8" TCP 01/00 & 12/06 (perfed 10430'-1044s') B-2 10,510' 10,530' 20' 18 12/14/2006 Open f/ Prod 4-5/8"TCP O1/00 & 12/06 B-2 10,560' 10,570' 10' 6 12/14/2006 Open f/ Prod 4-5/t3"TCP 12/06 B3-B7 10,694' 13,835' 3,141' 1/1/2000 Open f/ Prod Slotted Liner 1 I TD = 13,835'MD/9680'ND O:\NAUVvICBUWIaska\Depts\Drilling\Users\TylerS\2008 Projects\2008 Steelheadwt-32RD\Schematic\M-32RD Proposed Sept08.doc SLT: 9/29/2008 • M-32RD 20 3/4" BOP Stack up • • . CHOKE MANIFOLD TO GAS BUSTER TO DERRICK VENT TO SHALE SHAKERS 5ECT10N AA ' 1 ~k AlL YALYES iN FLOW PATH ARE 9-!/!6' 5000 PSl CAMERON GATE TYPE Chevron ~ elhead Platform ell # M-32RD Pro osed Com letion w/ Kill Strin ~ r ~ RIB = 75.15'Rlg Floor to TBG Flead Cabin 81 T u b i n 1P tl a g ~y~ it W e~ N 'Sg. ~° N °~~b ~~ Size T e Wt Grade Thrd ID To Btm Hole 26" Conductor Surf 981' Driven 16" Surf Csg 75 K-55 BTC 15.12 Surf 1347' 22" 13-3/8" Csg 61 K-55 BTC 12.52 Surf 3767' 17.5" Window from 9392'- 9408' " 9-5/8" Prod Csg 53.5 L-80 BTC g,535 Surf 10588' 12.25 7" Liner 29 L-80 Butt & KC 6.184 9301' 10731' 8-1/2" 4-I/2" Linad 12.6 L-80 ~oaC ~ 3.958 10694' 13835' 6" Tubin 75.15' RKB to Tb Hn r 4-1/2" 12.6 L-80 Butt 3.958 Surf (8,900' .IF,WF,i.RY DF.TAii, NO. De th ID Item 1 9301' 6.184" Baker 7" ZXP Liner To Packer 2 10694' 5.25" Baker tie back sleeve for 4-1/2" slotted Liner 3 10705' 4.360" Baker HMC liner han er e~ ~ , >t 10 1 ~ - S! ~i ~ ~,7 Csg Wiedow t~ ' ~ ~ @9A2' :rr G-1,2 t w * G-4,5 . } ~~ ?+` . B-1 r: B-2 Rrinf rlvtailc .G Infne Cmt Cmt To Cmt to Surf 1933 sx Calc TOC@ surf -assmd 20% loss Returns to Surf 2244 sx Bumped Plug Calc TOC @-671' assmd 20% loss Returns to Surf 2607 sx Calc TOC @-2611' assmd 20% loss Calc TOC to 72bbls liner top w/asmd 20%loss 2-1/2" x 1/16" slots, 48/ft Spudded M-32RD on 11/15/99. Completed on 01/25/00. M-32RD was a drill out ofM-32 (window in the 9-5/8" -9392'). 5 fish Were left in sidetrack holes while drilling the well: #1 @ 9682' _ 1226' fish. #2 @ 9564' _ 1088' fish. #3 @ 12418' ~ 5' fish. #4 11650' - 300'fish. #5 9943' in the M-32RD section - 780' fish. .Hole Section MWT: •A roximate Rotatio hrs: 0 17-1/2" to 1347' 9.0 to 9.5 0 16" 120 hrs 0 12-1/4" to 10588' 9.3 to 10.1 0 13-38" 560 hrs 0 8-1/2" to 10731' 9.0 to 10.5 0 9-5/8" 680 hrs 0 6" to 13835' 9.5 to 10.5 0 7" 258 hrs 1 I I PERFORATION DATA 1 1 Cmaemed wi6 1 1 Cdy,seMpe 1 I IZ96 @ 19,ffi9 I ~ ~ ~ i 1 ~ I 1 m ~~ I 1 8o- ~ 1 I 1 ~o I 1 1 I I I I I 1 I I i / 1 1 1 1 1 Zone Top Btm Amt. Accum SPF Last Perf Date Present Condition Notes G-1 9,625' 9,665' 40' 18 12/14/2006 Open f/ Prod 4-s/s" TCP 01/00 & 12/06 (perfed 9645'-665') G-2 9,697' 9,737' 40' 18 12/14/2006 Open f/ Prod 4-s/s" TCP 01/00 & 12/06 (perfed 9714'-734') G-4 9,915' 9,990' 75' 18 12/14/2006 Open f/ Prod 4.5/8" TCP 01/00 & 12/08 (perfed 9933'-953' & 9979'-990') G-5 10,060' 10,210' 150' 18 12/14/2006 Open f/ Prod 4-5/8"TCP 01/00812/06(10070'-,0090',,0,20'-135'&10180'-195') B-1 10,430' 10,480' 50' 18 12/14/2006 Open f/ Prod 4-5/8" TCP 01/00 8 12/06 (perfed 10430'-10445') B-2 10,510' 10,530' 20' 18 12/14/2006 Open f/ Prod 4-s/s^ TCP 01/00 & 12/06 B-2 10,560' 10,570' 10' 6 12/14/2006 Open f/ Prod 4-5/8"TCP 12/06 63-B7 10,694' 13,835' 3,141' 1/1/2000 Open f/ Prod Slotted Liner I 1 TD = 13,835'MD/9680'ND O:\NAU\MCBiJ\Alaska\Depts\Drilling\Users\TylerS\2,008 Projects\2008 Steeihead\M-3212D\Schematic\M-32RD Proposed Sept08.doc SLT: 9/29/2008 - ~ M-32RD 20 314" BOP Stack up '1[' D r r- a r m N z o .. . v ~~ m w A N O O O .9 N n D ~. '~ 0 x b ro m n 0 z a r f -~ 0 p N' C N 0 a n x ' Cl ~ o ;~ !m !.A ''2 O ! Q N i"' a '~ N x n m x a 1 /~ rn ~, `-, -~-- M Steelhead Safety Valve test results 8-23-2008 Regg, James B (DOA) From: Myers, Chris S [myersc@chevron.com] Sent: Monday, August 25, 2008 5:27 PM To: Regg, James B (DOA) Cc: Brandenburg, Tim C Subject: Steelhead M-32 ~~26I?mZ~ Page 1 of 1 ~ +~-~-~ Jim. ~1>t 1~'1-32, 3ust giving you a heads up on well M-32 on Steelhead. It looks like the waif has started to flow some gas above and beyond what the current down hole reservoir would normally produce. We are monitoring it's rate closely and the team is working on the best path forward at this time. There are no containment issues; it just appears to not beano flow well anymore. We should have more information in the morning, If you need to contact me you can call my cell @ 398-9955. Thanks, ~n~ ~~ ~~~~~~ ~~f~NN~~ S~F :~ (~ 2008 n~ ~,~~ ~ ~ ~ ~~~~ Chris S. Myers Operations Superintendent MidContinentjAlaska SBU Chevron North America Exploration and Production Co, 909 West 9th Avenue Anchorage, Alaska 99501-3322 Tel 907 263 7654 Fax 907 263 7847 Mobile 907 398 9955 myersc@ehevron.com 8/26/2008 h vron F•cisco Castro C @ Chevron North America Exploration and Production Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 Teie: 907 263 7889 Fax: 907 263 7828 E-mail: fcbn@chevron.com December 3, 2007 To: AOGCC Howard Okland 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 ~ ~ . ~ . , i PERMIT # API NUMBER I WELL LOG TYPE SCAL LE OG INTERVAL. -T RUN B- .FILM CD NOTES - D-.TE I LC~GED TM LF`dE i i LA'~~ I PD I I DL13 _ _ I-~~-------- COMPLETION - 1 -Dec- 19000 - DT P 3 TBU M RECOR C 199-097-0 507332046201 32RD CORRELATION 5" 06 9550 1 1 1 1 PDC COMPLETION RECORD 1,56" TUBING TBU M- PUNCHER, 4 SPF, 18-Nov- 6000 - PDS, 199-097-0 507332046201 32RD 0 DEG 5" 06 8885 1 1 1 1 PDF ~ 1 S ~3"~ ~s~3 ~ ~4~i~ D~.C 11.20D7 Please acknowledge receipt by signing and returning one copy of this transmittal ar, FAX tQ,9.Q7 263 7828. Received By: Date: r9 ~_ . STATE OF ALASKA I AlÞ: Oil AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS ø /...~'d 1. Operations Abandon Repair Well Performed: Alter Casing 0 Pull TUbing 0 Change Approved Program 0 Ope rat. Shutdown 0 2. Operator Union Oil Company of California Name: 3. Address: Plug Perforations Perforate New Pool 0 Perforate 0 4. Well Class Before Work: Development 0 Stratigraphic 0 PO Box 196247, Anchorage, AK 99519 Stimulate Other ./ Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number¡: Exploratory 0 199-97 Service 0 6. API Number: 50-733-20462-01 ( 9. Well Name and Number: M-32RD - 10. Field/Pool(s): McArthur River Field, G/Hemlock ; 7. KB Elevation (ft): 75.15' Rig Floor to TBG Spool 8. Property Designation: Trading Bay Unit! Steel head Platform 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural Conductor Surface Intermediate Production Liner Slotted Liner Perforation depth: :::¡ n :::r pI,. /8710 A> (. Z."/.o "1 measured 13,835' feet true vertical 9,660' feet measured 10,825' feet true vertical 9,294' feet Length Size 981' 26" 1347' 16" 3767' 13-3/8" 1 0588' 9-5/8" 1430' 7" 3141' 4-1/2" .f3 (:1 \\0 :::¡ t'1J> f' '" n § Plugs (measured) nla 3 -.....¡ Junk (measured) 10,825' I Could not clean otipast "" '" S' :::¡ - < m o Measured depth: See attached schematic MD 1VD Burst Collapse 981' 980' 1347' 1347' 2630 psi 1020 psi 3767' 3767' 3090 psi 1540 psi 10588' 9211' 7930 psi 6620 psi 10731 ' 9258' 8160 psi 7020 psi 13835' 9660' NIA NIA SCANNED JAN 3 0 2007 True Vertical depth: Tubing: (size, grade, and measured depth) 4-1/2", L-80, 12.6# @ 8,990' Packers and SSSV (type and measured depth) nla 12. Stimulation or cement squeeze sum" Intervals treated (measured): nla 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure ~ ~~ ~ 30 5497 71 15. Well Class after work: Exploratory 16. Well Status after work: Oil0 Gas 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 265 . 345 Tubing Pressure 83 77 Development ./ Service x WAG 0 GINJ 0 WINJ 0 WDSPL 0 Sundry Number or NIA if C.O. Exempt: 306-188 Contact Chantal Walsh 263-7627 Signature Title Drilling Manager Phone 907-276-7600 Date 1/24/2007 RBDMS 8Ft .IAN;} () 20,% t/~...... ~ /.z9-o7 sU~ini4~7 Form 10-404 Revised 04/2006 ORfGlr~AL Primary Job Type ESP Jobs Primary Job Type ESP Objective Workover and replace the failed ESP in Well M-32RD Daily Operations 11/18/200600:00 -11/19/2006 00:00 Operations Summary RU Eline. RIH with 5.5'. 1.56" 20ES Tubing Punches with 23 shots. Shoot tubing punch holes above ESP equipment. POOH and lay down guns. RD Eline. 11/22/200600:00 -11/23/2006 00:00 Operations Summary Rig prep. SIMOPS with produciton. 11/23/2006 00:00 - 11/24/2006 00:00 Operations Summary SIMOPS with production. Rig prep. 11/24/200600:00 -11/25/2006 00:00 Operations Summary Rig prep. Mixing 3% KCL water. 11/25/200600:00 -11/26/2006 00:00 Operations Summary Rig prep. PJSM. Mix sized salt pill. 11/26/200600:00 -11/27/2006 00:00 Operations Summary Continue mixing pill. Prep to kill well. 11/27/200600:00 -11/28/2006 00:00 Operations Summary Pumped 3% KCL @ 66 bbls got fluid returns (crude), @ 151 bbls away, switched to 10 bbls saturated salt, followed with 71 bbls sized salt pill, displaced with 90.2 bbls bull headed. PJSM. Repeat spotting pill: 3.7 bbls 3% KCL, 10 bbls saturated salt spacer, and displaced with 51 bbls FIW w/3%KCL, leaving 61 bbls of pill in tbg. Open annulus and circ 61 bbls of back. Pump FIW w 3% KCL taking returns. Total of 605 bbls wI clean returns through out. 11/28/200600:00 -11/29/2006 00:00 Operations Summary PTSM with NAD. Set BPV PJSM, Nipple down tree. PRE- spud meeting. NU BOPE. 11/29/200600:00 -11/30/2006 00:00 Operations Summary PJSM, SIMOPS with production. Change out rams. Set 2 way check. Shell test BOP to 3000psi. Pull BPV, install 2 way check valve. and test. Test BOPE with State Witness present. All tested 250/3000 psi. 11/30/200600:00 -12/112006 00:00 Operations Summary PTSM, Finish BOPE testing. Had failure on lower safety valve on TID and got waiver to change valve out when out of the hole with ESP. Pull two way check valve. PJSM. MIU landing jt to tbg hanger. Pull tbg hanger loose. Static well loss rate 1.2 bbls in 8 hours. Mix and pump a dry job. POOH with ESP assembly. Stand back 4-1/2" tbg. LD GLMs. 12/1/200600:00 -12/2/2006 00:00 Operations Summary PTSM. POOH with ESP standing back 4-1/2" tbg. SIMOPS with production. LD ESP Pump and power assembly. Change upper pipe rams form 4-112" to 5". 12/2/200600:00 - 12/3/2006 00:00 Operations Summary PTSM. Test 3-1/2" and 5" pipe rams and test bag on 3-1/2" and 5" DP. Passed low and passed 3000psi test on third attempt. RU wireline to fish ESP junk out of hole. 7 runs retrieving: 14 superbands, 5 partial bands, test plug rubber, small pieces of anode, scale and chunks of salt. 12/3/200600:00 -12/4/2006 00:00 Operations Summary PTSM. RD Eline after 8th run in hole and no fish. Monitoring well... no static loss. SIMOPS with prod. PU BHA for cleanout.fish. Trip in hole. 12/4/200600:00 - 12/5/2006 00:00 Operations Summary PTSM. Continue tripping in hole. Establish pump pressures. Tag up on fill at 10,302'. Wash and ream to 10,320. Pump 15 bbls viscous sweep and got back a moderate amount of sand, scale. Continue to wash and ream and pump viscous sweeps. got back over three 55 gal drums full of pay sand. Tagged 4-1/2"liner at 10,694'. Circ, reciprocate, and pump more viscous sweep. Returns less than previous. Daily Operations 12/5/200600:00 -12/6/2006 00:00 Operations Summary PTSM. Monitor well for static loss, 9 to 10 bbls/hr. LD Cleanout assembly and stand back DCs. Retrieve 8 foot flat guard, and three small pieces of super band. also small metal chunks and some hemlock formation. RU wireline. RIH wlBPT junk bailer with 8.375" GR, @ 2000' PU to check weight and OJ fired and released junk bailer. POOH wI no junk bailer. RIH wI GS tool and tagged top of balier at 9372' (top of liner), latched up. POOH with bailer. MU 5.75" GR to 10472'. POOH, recoved 1 superband along with piece of metal. . RIH with junk bailer and GR to 10,501' and stalled again. POOH recovered only sand. RD Slickline. Pull wear ring and set test plug. Change lower rams from 3-1/2" to 2-7/8". 12/6/200600:00 - 12/7/2006 00:00 Operations Summary Test BOP. RU tongs and prep to run tbg. RIH with 2-7/8" IBT wash string. MU XO and joint of 5" DP with circ valve and ball catcher. RIH w/5" DP to above 7" liner top. Proceed through liner top. 12/7/200600:00 - 12/8/2006 00:00 Operations Summary RIH wI clean out assembly. Tag liner top at 10695'. Establish circulation, CBU, and work down to 10787. No further progress on making hole. Repeated attempts and no progress. Pumped sweep, and CBU. Minimal sand returns. POOH. MU mud motor and drag bit. RIH. 12/8/200600:00 -12/9/2006 00:00 Operations Summary RIH w/ clean out assembly, passed into 7" liner without a bobble, and stopped prior to the 4-112" liner and proceeded in without a problem. Tagged up at 10787'. Worked at passing through with no results, POOH. LD mud motor and bit. Bit had wear. MU wear ring tool and pull wear ring and set test plug. Change lower rams from 2-7/8" to 3-1/2". Test. 12/9/200600:00 -12/10/2006 00:00 Operations Summary Pull test ring and install wear ring. PUMU BHA , Mill, XO, Bit sub, 12/10/200600:00 -12/11/2006 00:00 Operations Summary RIH. Continue to work pipe through bad spot at 10787. Continue to have drag. Establish good circulation and reamed from 10772 - 10740. CBU and had fine sand and metal shavings. Circulated until clean. Pulled out of the 4-112" liner and picked up drag at 10650. Could not move down. Kept working up and lost drag at 10470. POOH with 5" DP and 3-1/2". Boot baskets had sand and several rocks. MU new BHA, RIH with 5" DP. 12/11/200600:00 -12/12/2006 00:00 Operations Summary RIH to 10634. Check weights. Wash down from 10624 to 10834. Pumped sweep, had lots of sand and scale. Worked down to to 10844. Pump 31 bbls sweep. POOH. LD equipment and noted damage to the mule shoe. Suspect tools were outside of casing. PU BHA and RIH 12/12/200600:00 -12/13/2006 00:00 Operations Summary Fill up hole with fluid. RIH and tag top of 4-112" liner. Circ and reciprocate pipe. Pump 10 bbls salt spacer, 50 bbls size salt pill, 5 bbls salt spacer, spot on bottom with 187 bbls. POOH, standing back, LD BHA. Change out lower rams to 4-112", test BOPE to 250/3000 psi. 12/13/200600:00-12/14/200600:00 Operations Summary Pull test plug and fill hole with 59 bbls. Safety meeting on TCP guns. PU and RIH with TCP guns. MU TCP RIH with TCP assembly. RU E-line. RIH with logging tools. 12/14/200600:00 - 12/15/2006 00:00 Operations Summary Log with gamma ray to tie in for perforations. High gamma reading hendered tie in. POOH with logging tools. Installed a 2.84" GR to confirm 5"DP x 3-1/2" DP XO. Spaced out and dropped bar. POOH, monitoring loses on hole. LD DP and TCP guns. All shots fired. 12/15/200600:00 -12/16/2006 00:00 Operations Summary PU ESP completion. Fill motor with oil. Install chemical lines. Fill seal and pump section with oil. Inspected motor lead and found damage. Had to replace. Installed motor lead, flat guard, and bands on ESP. PU discharge head and pressure head. Found Phoenix line was an I wire line - had to pull Phoenix tool to surface and install proper line, reinstall flatguard and banding. MU check valves in Chem line and pump through both check valves. RIH with 4-112" tbg installing cannon clamps on first four connection s and every other after. Cannon clamps on both sides of GLMs Meg test every 1000'. 12/16/200600:00 - 12/17/2006 00:00 Operations Summary Continue to RIH with ESP on 4-1/2" tbg and ESP cable. Check cable every 10 stands and place cannon clamp on every other jt and both sides of mandrels. Check ESP cable every 10 stands. MU hanger with pup on landing joint. BPV installed. Orient hangerlpenetrator to well head. Test ESP cable. Install into hanger w/pigtail. Measure and cut ESP cable. Daily Operations 12/17/200600:00 -12/18/2006 00:00 Operations Summary Complete pig-tail splice and test. Install chemical lines and test void to 5000 psi. Pump through chemical injection lines. Lower tbg hanger to wellhead and retest ESP cable. Remove rams from BOPE and ND BOPE. Prep to conect wellhead. Connect and test to3000 psi. Land tree. NU production on tree. 12/18/200600:00 -12/19/2006 00:00 Operations Summary NU tree to productio flow lines, pull BPV and set 2 way check in tbg hanger. Shell test tree and release well to production for ESP start up. Begin demobing rig. 12/19/200600:00 -12/20/2006 00:00 Operations Summary Demobe rig. 12/20/200600:00 -12/21/2006 00:00 Operations Summary Demob 12/21/200600:00 -12/22/2006 00:00 Operations Summary Demob 12/22/200600:00 -12/23/2006 00:00 Operations Summary Demob 12/27/200600:00 -12/28/2006 00:00 Operations Summary Demob 12/28/200600:00 - 12/29/2006 00:00 Operations Summary Demob 12/29/200600:00 -12/30/2006 00:00 Operations Summary Demob 12/30/200600:00 -12/31/2006 00:00 Operations Summary Demob 1/17/200700:00 -1/18/2007 00:00 Operations Summary RKB 7515'R' FI t TaGH d = 19 oor 0 sa as! n g & I U I rig Size l' Grade Thrd I lD TOD Btm Hole Cmt ~ Conductor Surf 981' Driven ~ Cmt to Surf 8 16" Surf Csg 75 K-55 BTC I 15.12 Stilf 1347' 22" ! 1933 sx Calc TOC@ surf ~j -assmd 20% loss @'" Returns to Surf üO Bumped Plug ON 13-3/8" Csg 61 K-55 BTC 12.52 Surf 3767' 17.5" 2244 sx >-~ CalcTOC@-67I' ð~ assmd 20% loss ~~ - Window from 9392' - 9408' Returns to·Surf 9-5/8" Prod Csg L-8 ~ Stilf 10588' 12.25" 2607 sx Calc TOC@-261!' fi~ a. 53.5 assmd 20% loss 'N @~ ü E Calc TOC to ~ ~ b. 7" Liner 29 L-80 Butt & KC 6.184 9301' 10731' 8-1/2" 72 bbls liner top Q " w/asmd 20%1055 ü c. 4-1/2" Slotted 12.6 L-80 fETC AB 3.958 10694' 13835' 6" 2-112" x 1116" slots, 48/ft Liner mod c;>; d. Tubin!! 75.15' RKB to Tbg Hngr ON 4..112" I I;U I I flldt I 3.958 I Surf I 8.990' ~ ro lAM) ü¡' e. õï:~í? I/OSOLBC 90FB 185 GAL (2.361" ~oo ~, ~!~ ¡¡ 1.611") 1~~ f. .IIfWlf .w,", DETAIL ~@~ NO. Deoth ID~ 9 1853' 3.95 4-1/2" SFO Mandrel wi dummy valve drift ID = 3.833" a. b. 2923' 3.958" 4-1/2" SFO Mandrel wi dummy valve drift lD = 3.833" h. c. 3736' 3.958" 4-1/2" SFO Mandrel wi dummy valve driit ID = 3.833" d. 4414' 3.958" 4-1/2" SFO Mandrel wi dummy valve drift ID = 3.833" e. 5031 ' 3.958" 4-1/2" SFO Mandrel wi dlUlUTIY valve driit lD - 3.833" f. 5509' 3.958" 4-1/2" SFO Mandrel wi dummy valve driit 1D = 3.833" g. 6023' 3.958" 4-1/2" SFO Mandrel wi dummy valve drift 1D = 3.833" h, 6593' 3.958" 4-1/2" SFO Mandrel wi dlUumy valve drift ID = 3.833" 1 8839' 3.75" "XN" Nipple (profile = 3.813") :2 ±8895' NA Pressure Head 3 8896' NA Discharge Head 4 8897' NA Pump Model HC7800 HPHVMT AR 1-1, CSE27940PC 2-9 5 8910' NA Pump Model HC7800 HPHVMT AR 1-1, CSE27940PB 6 8923' NA Pump Model HC7800 HPHVL T AR 1-1, CSE27940P A 7 8937' NA Seal Assembly II 8952' NA Motor- 800 HP C216009878 2 !H00489 9 8987' NA Phoenix Sensor XT-11 Anode/Centralizer (bottom (âj 8990') 10 930 l' 6.184" Baker 7" ZXP Liner Top Packer 10 11 10694' 5.25" Baker tie back sleeve for 4-1/2" slotted Liner 12 10705' 4.360" Baker HMC liner hanger Sf;{ Window G-1,2 Brief Details 8. Info: Spudded M-32RD on 11/15/99. Completed on 01/25/00. M-32RD was a drill out ofM-32 (window in the 9-5/8" -9392'). 5 fish Were left in sidetrack holes while drilling the well: #1 @ 9682' - 1226' fish. #2 @9564' - 1088' fish. #3 @ 12418' - 5' fish. G4,S #4 (à; 11650' - 300'fish. #5 (âj 9943'(in the M-32RD section) - 780' fish. -Hole Section MWT: -Approximate Rotann!! Ilrs: 0 17-1/2" to 1347' 9.0 to 9.5 DOll 0 16" 120 hrs B-1 0 12-1/4" to 10588' 9.3 to 10.1 ppg 0 13-38" 560 hrs 0 8-1/2" to 10731' 9.0 to 10.5 ppg 0 9-5/8" 680 llfs B-2 0 6" to 13835' 9.5 to 10.5 Dug 0 7" 258 hrs . - ~ c b 4-5/8" TCP 01/00 & 12/06 (p"rfed 9645'-665') 4-5/8" TCP 01/00 & 12106 (perfed 9714'-734') Zone Top G-1 9,625' Æ G-2 9,697' . c G-4 9,915' ::¡ ~ G-5 10, " B-1 10,430' B-2 10,510' B-2 10,560' B3-B7 10,694' 4-5/S" TCP 01/00 & 12/06 (perfed 9933'-953' & 9970'-990') 51S" TCP 01100 & 12/06 (10070"10090', 10120'-135' & 10180'-195') Open fl Prod 4-5/8" TCP 01/00 & 12/06 (Perfed 10430'-10445') Open fl Prod 4-5/8" TCP 01/00 & 12/06 Open fl Prod 4-5/8" TCP 12/06 Open fl Prod Slotted Liner TD = 13,835'MD/9660'iVD M-32RD Existing ESP Schm 12-06.doc CRW: 01/15/2007 SARAH PALIN, GOVERNOR AI"AA~Wl OIL AlQ) GAS CONSERVATION COMMISSION 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 January 12,2007 Mr. Chris Myers Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99519 SCANNED JAN 1 6 2007 RE: No-Flow Verification Trading Bay Unit M-32RD, PTD 199-097 Dear Mr. Myers: On January 8, 2007 an AOGCC Petroleum Inspector witnessed a "no flow test" at Unocal's Steelhead platfonn, Trading Bay Unit Well M-32RD. The well was opened to atmosphere through flow measurement equipment with suitable range and accuracy and monitored. The well demonstrated no gas or fluid flow while open to atmosphere, and no pressure build-up during a shut in monitoring period. The subsurface safety valve may be removed from service in Well M-32RD based on this no-flow test result. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if the well demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the King Salmon platfonn. Sincerely, ;jC4~'E3 ,~ James B. Regg t:l Petroleum Inspection Supervisor cc: Bob Fleckenstein . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P I. Supervisor ./ì I~Uít1 . . cl I 1'1 --0 Î -I \..,..I DATE: January 8, 2007 FROM: Jeff Jones Petroleum Inspector SUBJECT: No-Flow Test Chevron! Steelhead PL T Well M-32RD PTD-1990970 MRF / Trading Bay Unit January 8, 2007: I traveled to Chevron's TBU Steelhead Platform in Cook Inlet to witness a No-Flow Test on oil producing well M- 32RD Chevron Operator Mike Chivers performed the test today in a safe and proficient manner. Prior to the test we inspected the well and verified to the extent possible an open flow path from the well bore and discussed the test procedure. Well M-32RD was lined up from the tree top swab valve and the casing inner annulus through an Armor-Flow model # 3461-03TO flow meter (180 SCFH to 1800 SCFH span) and a 3/4" hose terminating in an open top container Flow from the well was monitored for 3 hours with readings recorded every 30 minutes (see below). Unassisted gas flow from the well was below the measurable range of the flow meter and no liquid was produced during the test. Well M-32RD meets the AOGCC requirements for a No-Flow determination. Summary: I traveled to Chevron's TBU Steelhead Platform in Cook Inlet and witnessed a successful No-Flow test on oil well M-32RD. Attachments: none ~ Chris Meyers, Mike Chivers (Chevron) Gas <180 SCFH <180 SCFH <180 SCFH <180 SCFH <180 SCFH <180 SCFH <180 SCFH Start Test End Test Produced to open top container through ;\rmor-Flow meter model #3461-03TO Tota] liquid produced: None &CANNED JAM 2 5 2007 JBJ 02 Page I of I 2007-0 I 08_ No-flow _ TBU _~1-32 ~Jx1s e e -------- Original Message -------- Subject:RE: Chevron Well Work week of Dee 4 - 10 Date:Wed, 13 Dee 2006 08:24:20 -0600 From:Brandenburg, Tim C <brandenburgt@ehevron.eom> To:Thomas Maunder <tom_maunder@admin.state.ak.us> Tom, \,,~ - OS \ As for M-32rd, the problem is approximately 130' into the 4-1/2" slotted liner. We can no longer access 3010' of lateral. We are hopeful that it is at least still in communication from a production standpoint. Tim -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, December 12, 2006 12:37 PM To: Brandenburg, Tim C Subject: Re: Chevron Well Work week of Dec 4 - 10 Tim, Not good on the potential parted liner. How much hole did you lose? Tom Brandenburg, Tim C wrote, On 12/12/2006 12:07 PM: > Tom, > > Please see the attached well work summary and forecast. > > Thanks, > > Tim > > «CVX Wellwork 06 I.xls» > ~f'·A~."t.~~Þ:::.!'.} v~U"U, ~G:i3~(L, C 'í :3 1 of 1 12/13/2006 7:56 AM Re: FW: Well M-32 RD (199-097) sundryN¡r 306188 . Chantal, The change in scope (cleanout, re-perf, new pert) is acknowledged. Due to the changes, it will be necessary to redemonstrate that the well is no-flow. The procedure you included provides for performing the no-flow demonstration 2 weeks after the well is placed back in service. The platform should coordinate with Jim Regg (793-1236) to arrange an Inspector. Delaying the blind ram test is acceptable until the completion is pulled. With regard to not having shear rams, the AOGCC does not have a requirement for shear rams in surface stacks. I believe that having blind rams is a Unocal/Chevron internal requirement in the ESP Workover Guidelines. Call or message with any further questions. Tom Maunder, PE AOGCC Walsh, Chantal-Petrotechnical [contractor] wrote, On 11110/2006 5:45 PM: Tom, In finalizing the details of the ESP workover, we would like to request a variance to postpone pressure testing the complete shut off (blind) rams until we are out of the hole with the completion. Do not hesitate to contact me if you have any questions. Chantal , \,-: i: Þ'i' !\! \).:: f\ O""IN-¡,:,;......·..... f;'¡, "-';' L' JL From: Walsh, Chantal -Petrotechnical [contractor] Sent: Tuesday, November 07, 2006 12:07 PM To: Thomas Maunder Cc: Klemmer, Stephanie J; Harness, Evan; Martin, J. Hal; Cole, David A; Brandenburg, Tim C Subject: Well M-32 RD Sundry Number 306 188 Tom, Attached is an amended procedure for the Steel head well M-32RD. We previously submitted a 10-403 and were approved to work over the well. We are now intending to clean out the wellbore and reperforate 165' of G-zone and Hemlock and Add perfs to 10' of HB-2, in addition to pulling and replacing the failed ESP assembly in the well. The changes in the procedure summary are in bold font. Please let me know if you have any questions and if we can proceed with the work. We intend to move to the Steel head platform in approximately two weeks. Thank you, Chantal Walsh Petroleum Engineer Chevron phone # 263-7627 References: lof2 11/14/2006 11:49 AM Re: FW: Well M-32 RD (199-097) Sundry N.r 306188 Permit to Drill # 199-097 10-403 Sundry Number 306-188 Date signed: 5/30/06 . 20f2 11/14/2006 11 :49 AM Chevron . Steer ad Platform "Veil M-32RD ESP Repair OBJECTIVE: Replace the failed ESP assembly currently in Well M-32RD. PROCEDURE SUMMARY: 1. Shut off gas-lift gas. Bleed down slowly to avoid damaging ESP cable. Turn off cathodic protection system. 2. Circulate residual oil out of annulus and load well wi salt inhibited FIW. 3. Spot sized salt pill (if necessary) to manage losses and keep hole full while POR and while RIH wi tubing and ESP assembly. 4. Set BPV and N/D tree on Well M-32RD. N/U BOPE. Test 16-3/4" BOPE (see attached diagram) to 25013,000 psi. Note: To streamline and optimize the rig up, we would like to 2" 5K flanged rubber hoses for our choke and ki11lines to the stack. We would like to run blind rams not blindlshear rams in the lower double gate (we do not have nor have any blind/shear rams been manufactured for the 16-3/4" stack) 5. Verify well dead. 6. POR wi tubing, cable & failed ESP. Visually inspect tubing & LID singles while POR. Send failed ESP equipment & unusable tubing to shore. 7) Clean out well bore to +1- 13800' 8) Run guns and reperforate G-Zone Benches 1,2,4,5 G-1: 9645-9665 G-2: 9714-9734 G-4: 9933-9953 9970-9990 G-5: 10070-10090 10120-10135 10180-10195 Reperforate Hemlock Benches 1,2 HB-1: 10430-10445 HB-2: 10510-10530 ADD perfs to Hemlock 2 HB-2: 10560-10570 9. RIH wi replacement ESP assembly. 10. Install BPV. NID BOPE. N/U & test tree. 11. Install flow line and surface facilities & turn well over to Production. Turn platform cathodic protection back on. 12. Startup ESP. 13) After two weeks of production with ESP, shut well down and perform a NO-FLOW test. AOGCC M-32RD ESP Ammended Workover Summary.doc 1 of 1 May e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission I TO: Jim Regg rY J. P I. Supervisor i~ 6~q,to¡¡, DATE: June 8, 2006 FROM: Chuck Scheve, Petroleum Inspector Steelhead Platform SUBJECT: No Flow Trading Bay Unit M32RD PTD# 1990970 Thursday. June 8. 2006: I traveled to Unocal's Steelhead Platform and witnessed a no- flow test on well M32RD. I arrived on location and found the well bled off and opened to atmosphere with no flow of gas or fluid evident. The well was shut in and observed for three hours with no pressure build up observed and no flow when reopened. I recommend Well M32RD on the Steelhead Platform be approved no flow status for the purpose of removing the Sub Surface Safety Valve. SUMMARY: Well M32RD meets the AOGCC requirements for no flow status. 'd'Ç""'" "i\iN" q J 13 N "S "3 . .'\!', .,þ. .," ,'.. . Co ~"- e FRANK H. MURKOWSKI, GOVERNOR AI,AS&:A OIL AlWD GAS CONSERVATION COMMISSION June 9, 2006 333 W. 7'H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Chris Myers Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99519 ~(' i,j\¡i\i~(,¡ ¡IJ ';J "" 0' fj{"'cCi.8' ""j fc;Irt,; \: ,; -wc....'-:i\,j: ~ \¡ 1- {j LU U RE: No-Flow Verification Trading Bay Unit M-32, PTD 199-097 Dear Mr. Myers: On May 12,2006 an AOGCC Petroleum Inspector witnessed a "no flow test" at Unocal's Steelhead platform, Trading Bay Unit Well M-32RD, Tþe well was opened to atmosphere through flow measurement equipment with suitable range and accuracy and monitored for several hours. The well demonstrated no gas or fluid flow while open to atmosphere, and no pressure build-up during a 3-hour shut in monitoring period. The subsurface safety valve may be removed from service in Well M-32RD based on this no-flow test result. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if the well demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Steelhead platform. Sincerely, ~. " \ -, .~ <-:--) "YvvLl€J .~ ~eqC:7 James B. Regg { ! Petroleum Inspection Supervisor cc: Bob Fleckenstein e e FRANK H. MURKOWSKI, GOVERNOR AI,ASKA. OIL AlO) GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Brandenberg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99519 Re: McArthur River Field M-32RD Sundry Number: 306-188 ~"\ ~O \0\ ",r·£ j;\.1~¡¡;::r:. ð\..-.d~vrv; \:t.;...,..... Dear Mr. Brandenburg: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may fIle with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thi~dayofMay, 2006 Encl. a STATE OF ALASKA (,fif ~ Jt AlA~ Oil AND GAS CONSERVATION COMM.ON ?(fi;¡" APPLICATION FOR SUNDRY APPROVAL.: . ~ x) 20 MC 25.280 f) V's. s- /3&' l' '. .. 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate U WaiverU Otl1er0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Repìace Failed' Change approved program 0 Pull Tubing [] , Perforate New Pool 0 Re-enter Suspended Well 0 ESP 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development [] Exploratory 0 199-097 . 3. Address: Stratigraphic 0 Service 0 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20462-01 7. KB Elevation (ft): 9. Well Name and Number: 163' KB above MSL M-32RD . 8. Property Designation: 10. Field/Pools(s): Trading Bay UniU Steelhead Platform ~þL /87JO ~!> C:-.#. 06 McArthur River Field, G/Hemlock 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): IJUnk (measured): 13835' , 9660' 13835' 9660' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 1,347' 16" 1,347' 1,347' 2,630 psi 1,020 psi Surface 3,767' 13-3/8" 3,767' 3,767' 3,090 psi 1 ,540 psi Intermediate 10,588' 9-5/8" 10,588' 9,211' 7,930 psi 6,620 psi Production Liner 1 ,430' 7" 10,731' 9,258' 8,160 psi 7,020 psi Slotted Liner 3,141' 4-1/2" 13,835' 9,660' N/A N/A Perforation Depth MD (ft): Perforation Depth TVD (ft): rUbing Size: Tubing Grade: Tubing MD (ft): See attached schematic See attached schematic 4-1/2" L-80, 12.6# 8,911' Packers and SSSV Type: Packers and SSSV MD (ft): None N/A 12. Attachments: Description Summary of Proposal l.:J 13. Well Class after proposed work: Schematic [] BOP Sketch [] Exploratory 0 Development [] Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/30/2006 Oil [] Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 I Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Larry Buster 263-7 Printed Name Tim Brandenburg Title Drilling Manager Signature --z...::: /"'ì ~~ Phone 907-276-7600 Date .s ~ Zt:¡ -DC::,. ~ COMMISSION USE ONLY «- Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 30~-1Er6" Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 i?\ S\L- Ç\C-\~~'>L> ~\tL ú..CŒç:> \-c..h\ ~ 3()OO~~~:, \3.0~ \-cS~ , Other: ' -~ ~ ~ o ~~~O\'-~ -\Ð \D<L c.D~u~ \.-UJ ;.s::." .'-i I \.J~ t \> E~~ \)...Jc,,\~ç \>t-cci . ~ Subsequent Form Required: t~o~ (jj III RBDMS BFL MAY 3 1 2006 APPROVED BY Date: 5- 3o,.()þ Approved by: . V~ÕMMISSI THE COMMISSION T \,/" V [")1 ~j;,. í". z.~.()(;. ¡~>_d . . Form 10-403 Revised 11/2004 o ¡ G\ NAL Sub~ln Duphca~ Æ.. f1Jþ/OÓ RKB = 75.15'Rig Floor to TBG Spool I I I I I I I ¿j I I I I I I I D. M-32RD Schem 2005-04-25 9-5/8" Window 7" 4-1/2" 2 2,022 3,128' 3,942' 4,665' 5,186' 5,604' 6,025' 29 12.6 K-55 K-55 N-BO Buttress Buttress L-BO L-BO Buttress Hydril 511 6.184 3.958 3.958 3.958 3.958 3.958 3.958 3.95B 3.958 3.958 1/19/00 1/19/00 G-2 G-4 G-5 spf 12 spf 12 spf 12 spf TD = 13,835' MD/9660' HK-l 10430' 10510' 10694' Slotted Liner 10480' 10530' 13835' HK3-7 Chevron === e e Steelhead Platform Well M-32RD ESP Repair OBJECTIVE: Replace the failed ESP assembly currently in Well M-32RD. PROCEDURE SUMMARY: 1. Shut off gas-lift gas. Bleed down slowly to avoid damaging ESP cable. Turn off cathodic protection system. 2. Circulate residual oil out of annulus and load well wi salt inhibited FIW. 3. Spot sized salt pill (if necessary) to manage losses and keep hole full while POR and while Rill wi tubing and ESP assembly. 4. Set BPV and NID tree on Well M-32RD. N/U BOPE. Test 16-3/4" BOPE (see attached diagram) to 25013,000 psi. Note: To streamline and optimize the rig up, we would like to 2" 5K flanged rubber hoses for our choke and kill lines to the stack. - We would like to run blind rams not blind/shear rams in the lower double gate (we do not have nor have any blind/shear rams been manufactured for the 16-3/4" stack) 5 . Verify well dead. 6. POR wi tubing, cable & failed ESP. Visually inspect tubing & LID singles while POR. Send failed ESP equipment & unusable tubing to shore. 7. Rill wi replacement ESP assembly. 8. Install BPV. NID BOPE. N/U & test tree. 9. Install flow line and surface facilities & turn well over to Production. Turn platform cathodic protection back on. 10. Startup ESP. AOGCC M-32RD ESP Workover Summary 1 of 1 May 23, 2006 71.81' RÎg Sub- Grating Upper well Bay Floor 36.25' 6.75' 5.85 15.98 23.47' 12.51' Top o,f 11" 5 M Tbg Spool 59.76' J STATE OF ALASKA ) ALA8 .. OIL AND GAS CONSERVATION COMMIt>SION REPORT OF SUNDRY WELL OPERATIONS RE(~E'\fEO MAY 1 9 2005 Stimulate U Other L:J . ~eplac~ Fa\I~.~uf1 WaiverD :Arn~fft8~&.rGIDi LímS. liOI1ti1~!ù>~ Re-enter Suspended WelQtmra~e 5. Permit to Drill Ñ~ber: Exploratory D 199-97 Service D 6. API Number: 50-733-20462-01 9. Well Name and Number: M-32RD 10. Field/Pool(s): McArthur River Field, G/Hemlock 1. Operations Abandon U Repair Well U Performed: Alter Casing D Pull Tubing 0 Change Approved Program D Operat. Shutdown D 2. Operator Union Oil Company of California Name: 3. Address: Plug Perforations U Perforate New Pool D Perforate D 4. Current Well Class: Development 0 Stratigraphic D PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 163' KB above MSL 8. Property Designation: Trading Bay UniU Steelhead Platform 11. Present Well Condition Summary: Total Depth measured 13,835' feet true vertical 9,660' feet Effective Depth measured 13,835' feet true vertical 9,660' feet Casing Length Size MD Structural Conductor 1347' 16" 1347' Surface 3767' 13-3/8" 3767' Intermediate 10588' 9-5/8" 10588' Production Liner 1430' 7" 10731' Slotted Liner 3141' 4-1/2" 13835' Perforation depth: Measured depth: See attached schematic True Vertical depth: Plugs (measured) nla Junk (measured) nla TVD Burst Collapse 1347' 2630 psi 3767' 3090 psi 9211' 7930 psi 9258' 8160 psi 9660' NI A SCANNED MAY 2 G 200~j 1020 psi 1540 psi 6620 psi 7020 psi NIA Packers and SSSV (type and measured depth) nla 4-1/2", L-80, 12.6# @ 8,911' Tubing: (size, grade, and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 40 2362 857 330 6733 71 15. Well Class after proposed work: Exploratory n Development ,ïl 16. Well Status after proposed work: Oil0 Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Oil-Bbl 251 491 x Contact Larry Buster 263-7853 Printed Name Timothy C. Brandenburg Signature r :l L.tf /- Tubing Pressure 102 71 Service n GINJ D WINJ D WDSPL D Sundry Number or NIA if C.O. Exempt: 305-051 Title Drilling Manager Phone 907-276-7600 Date 5/18/2005 RBDMS 8Ft MIlV ? :-1 7n05 OR\G\NAL Form 10-404 Revised 04/2004 Submit Original Only ) ) Primary Job Type ESP Jobs Lease/Serial ADL0018730 I Primary Well bore Affected Main Hole AFE No. I Buster QC Eng 163665 Daily Operations 3/20/200500:00 - 3/21/2005 00:00 Operations Summary Start mobilization of rig. 3/21/200500:00 - 3/22/2005 00:00 Operations Summary Continue with rig mobilization 3/22/200500:00 - 3/23/2005 00:00 Operations Summary Continue with rig mobilization. 3/23/200500:00 - 3/24/200500:00 Operations Summary Continue with rig mobilization. 3/24/200500:00 - 3/25/2005 00:00 Operations Summary Mobilize full crews to Platform. Have facility orientation 3/25/200500:00 - 3/26/2005 00:00 Operations Summary Hold pre-operations meeting. Circulate well with 3% KCL brine. Pump 145 bbl sized salt pill. 3/26/200500:00 - 3/27/2005 00:00 Operations Summary Set BPV. N/D tree. NIU BOPE 3/27/200500:00 - 3/28/2005 00:00 Operations Summary Test BOPE to 3,000 psi high I 250 psi low. Pull tubing hanger. Pull and stand-back 4-1/2" tubing. 3/28/200500:00 - 3/29/200500:00 Operations Summary Continue to pull 4-1/2" tubing. UD failed ESP assembly. 3/29/200500:00 - 3/30/2005 00:00 Operations Summary P/U new ESP assembly. RIH on 4-1/2" tubing. 3/30/200500:00 - 3/31/200500:00 Operations Summary Continue to run new ESP assembly. 3/31/200500:00 - 4/1/200500:00 Operations Summary Land and test tubing hanger. NID BOPE. NIU and test tree to 5,000 psi/250 psi.. Note electrical problem on ESP start-up. Prep to nipple back up with BOPE. 4/1/200500:00 - 4/2/200500:00 Operations Summary NIU and test BOPE to 3,000 psi/250 psi. Pull tubing hanger. POOH to first cable splice at 869'. Splice new cable section. Prep to re-Iand tubing hanger. 4/21200500:00 - 4/3/2005 00:00 Operations Summary Land and test tubing hanger. NID BOPE. NIU and test tree to 5,000 psi. Release rig. 4/14/200500:00 - 4/15/200500:00 Operations Summary Prep to re-enter well . 4/15/200500:00 - 4/16/200500:00 Operations Summary Circulate down tubing with 3% KCL brine taking returns on annulus. NID tree and NIU and test BOPE to 3,000 psi/250 psi. 4/16/200500:00 - 4/17/200500:00 Operations Summary Finish testing BOPE. Pull ESP assembly. 4/17/200500:00 - 4/18/200500:00 Operations Summary R/U slick line and fish junk out of the hole to 9,133'. MIU 8-1/2" mill BHA. PIU 3-1/2" drill pipe. 4/18/200500:00 - 4/19/200500:00 Operations Summary PIU 3-1/2" and 5" drill pipe. RIH washing down to 9,301'. ) Daily Operations 4/19/200500:00 - 4/20/200500:00 Operations Summary MIU 6" bit and 7" casing scraper. RIH to 10,676' and criculate hole clean. 4/20/200500:00 - 4/21/200500:00 Operations Summary POOH. M/U venturi junk basket. RIH and wash to 10,676'. POOH. UD BHA. 4/21/200500:00 - 4/22/200500:00 Operations Summary MIU 6" bit. RIH to 10,693'. Circulate hole clean. POOH. UD BHA. PIU 2-7/8" drill pipe and 3-1/8" claean-out assembly. 4/22/200500:00 - 4/23/200500:00 Operations Summary RIH and wash down to 10,995' inside the 4-1/2" liner. Pump 110 bbl sized salt pill. POOH. 4/23/200500:00 - 4/24/200500:00 Operations Summary POOH. R/U to run ESP. RIH wI new ESP on 4-1/2" tubing. 4/24/200500:00 - 4/25/200500:00 Operations Summary Continue in hole with new ESP. Land and test tubing hanger. 4/25/200500:00 - 4/26/200500:00 Operations Summary N/D BOPE. N/U and test tree to 5,000 psi. Prep to release rig. 4/26/200500:00 - 4/27/200500:00 Operations Summary Prep to release rig. 4/27/200500:00 - 4/28/200500:00 Operations Summary Release rig. • • STEELHEAD PLATFORM WELL #: M-32RD Completion Diagram as of 4/25/05 RKB = 75.15' Rig Floor to TBG Spool SIZE WT CASING AND TUBING DETAIL GRADE CONN ID MD TOP MD BTM. 16 75 K-55 Buttress 15.124 Surf. 1,347' 13-3/8" 61 K-55 Buttress 12.515 Surf. 3,767' 9-5/8" 53.5 N-80 Buttress 8.535 Surf. 10,588' Window 9392' 9408' 7" 29 L-80 Buttress 6.184 9,301' 10,731' 4-1/2" 12.6 L-80 Hydri1511 3.958 10,694' 13,835' 4-1/2" slotted lin er has 2-1/2" x 1/16" slots, 48/ft Tubing: 4-1/2" 12.6 L-80 IBTC AB mod 3.958 Surf 8,911' NO Depth ID JEWELRY Item 1 74.3' 4.930" FMC TC-lA-ENS 16-3/4" TBG Hanger, 4-1/2" Mod Butt connection W/CIW type H BPV profile With #0 ESP cable w/ two 3/8" SS chem. Inj. Lines 2 2,022 3.958 #7 4-1/2" MMA GLM w/ 1-1/2" SFO-2 RK latch 3,128' 3.958 #6 4-1/2" MMA GLM w/ 1-1/2" SFO-2 RK latch 3,942' 3.958 #5 4-1/2" MMA GLM w/ 1-1/2" SFO-2 RK latch 4,665' 3.958 #4 4-1/2" MMA GLM w/ 1-1/2" SFO-2 RK latch 5,186' 3.958 #3 4-1/2" MMA GLM w/ 1-1/2" SFO-2 RK latch 5,604' 3.958 #Z 4-1/2" MMA GLM w/ 1-1/Z" SFO-2 RK latch 6,025' 3.958 #1 4-1/2" MMA GLM w/ orifice valve 3 8.903' ESP pressure discharge sub 8,992' Bottom of HC 10,000 ESP BH:~ Date Zone Top Perforations BTM Comments 1/19/00 G-1 9625' 9665' 12 spf 1/19/00 G-2 9697 9737 12 spf 1/19/00 G-4 9915' 9990' 12 spf 1/19/00 G-5 10060' 10210' 12 spf 1/19/00 HK-1 10430' 10480' 12 spf 1/19/00 HK-2 10510' 10530' 12 spf HK 3-7 10694' 13835' Slotted Liner d ~ TD = 13,835' MD/9660' TVD M-32RD Schem 2005-04-25 REVISED: 4/25/05 BY: DED RE: M-32RD Sundry # 305-051 ) ) Subject: RE: M-32RD Sundry # 305-051 From: "Buster, Larry W" <lbuster@unocal.com> Date: Fri, 15 Apr 2005 14:59:08 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> \ q~-o~ ~ Tom, Thank You for the quick response. Yes, we do have safety valves for all sizes of Drill Pipe. Specifically on the 2-7/8" string; we have rented the stabbing valves and come as part of the rental "kit" from Weatherford. Regards, Larry Larry Buster Drilling Engineer Unocal Corporation 909 West 9th Avenue Anchorage, AK 99501 Tel: (907) 263-7853 Cell: (907) 250-0374 Fax: ( 907 ) 2 63 - 7 8 84 Ibuster@unocal.com -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.st.at.e.a.k.us] Sent: Friday, April 15, 2005 2:52 PM To: Buster, Larry W Subject: Re: M-32RD Sundry # 305-051 Larry, What you propose is acceptable. I presume that you have the appropriate stabbing valve in order to close any of the drill string components in use. Tom Maunder, PE AOGCC Buster, Larry W wrote: Tom, We are on the well now. I can send over hard copies of our proposed procedure ASAP. We are not planning to clean-out all the way to the toe of the slotted liner, but only below Hemlock Bench 5, which 1,400' into the 4-1/2'1 liner will do for us. Shane Hauck tells me we do have 2-7/8" rams for the "monster" I will give you a follow-up phone call this afternoon. Larry -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Friday, April 15, 2005 11:40 AM To: Buster, Larry W Subject: Re: M-32RD Sundry # 305-051 Larry, I take it you are on the well right now, correct?? Will you be sending any hard copies over?? From the lengths given in the drawing, it does not appear that you are planning to totally clean out the 4-1/2" liner, correct?? Do you have 2-7/8" rams for the "monster"?? Tom Maunder "';:L.'~ N ~\!F.r· l-\r~p ¡, 8 2005 Buster, Larry W wrote: Hello Torn, I would like to bring you up to speed on our ongoing workover operations on the Steelhead M-32RD ESP workover (Sundry #305-051). We 1 of 3 4/15/2005 3:03 PM RE: M-32RD Sundry # 305-051 ) ) successfully pulled the failed ESP and re-ran a new replacement ESP assembly. However, after bringing the pump on line, the well wanted to pump-off and it became apparent we have blockage of some sort deeper in the well. We are working to move back onto the well and make a clean-out run into the 4-1/2" slotted liner to remove the blockage. The following is a program summary of our proposed work: 1. Fill well with 3% KCL-FIW and circulate slowly thru the ESP assembly taking returns on the 9-5/8" Casing annulus circulating until any oil is circulated out. Note: _ This step has already been done and the well wants to loose - 12 bbl/hour with a full fluid column of 3% KCL-FIW. We continue to keep fluid going in to keep a visual fluid level at surface. 2. Install BPV. N/D tree and N/U and test 16-3/4" BOPE stack to 3,000/250 psi. Note: We will N/U with 4-1/2" TPR, Blinds and annular (same as proposed/approved in Sunday #305-051) . 3. Pull 4-1/2" tubing and ESP assembly. 4. R/U Slickline. RIH with slickline fishing junk basket and fish any debris off the top of the 7" liner at 9,301' or as deep as possible. 5. InstallS" TPR, Blinds and 3-1/2" LPR and test to BOPE to 3,000/250 psi. 5. p/u 5" and 3-1/2" Drill Pipe and 6" bit clean-out assembly. 6. RIH cleaning out to above the 4-1/2" slotted liner top. Note: Will control losses with sized salt LCM pills as required. 7. M/U 4" ID Venturi Bailer on Drillpipe and RIH cleaning out to the top of the 4-1/2" slotted liner. POOH. 8. P/U 3.7" OD Mill clean-out BHA and RIH cleaning out approximately 100-150' into the liner top. Circulate and POOH. 9. p/u - 1,400' of 2-7/8" Drill Pipe (or 3-1/8" Drill Collars) with 3.7" Mill Clean-out BHA on 3-1/2" and 5" Drill Pipe. *NOTE: Tom, I would like to request a waiver from having to M/U and test 2-7/8" Pipe Rams here if possible. The well is a no-flow well and we will be keeping the hole full. * 10. Clean-out the 4-1/2" slotted liner with 3% KCL-FIW using sweeps as required. POOH. 11. Run ESP Assembly on 4-1/2" tubing. 2 of 3 4/15/2005 3 :03 PM RE: M-32RD Sundry # 305-051 ) 12. N/D BOPE. N/U and ~est Tree. Release Rig. ') I have attached a copy of the M-32RD schematic for your reference. Thanks, Larry «M-32RD Schem 11-8-01.doc» *Larry Buster* Drilling Engineer Unocal Corporation 909 West 9th Avenue Anchorage, AK 99501 Tel: (907) 263-7853 Cell: (907) 250-0374 Fax: (907) 263-7884 Ibuster@unocal.com 30f3 4/15/2005 3 :03 PM Re: 10-403 Steelhead M-32RD ) ) Subject: Re: 10-403 Steelhead M-32RD From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Fri, 25 Mar 2005 07:34:24 -0900 To: "Buster, Larry W" <lbuster@unocal.com> \ C;~ '-0 ~ ì CC: Evan Harness <ehamess@unocal.com> Larry, Sorry I didn't get this to you earlier. This note confirms our conversation. What you propose is acceptable for M-32RD. This should be a "simple" pump change out, with no need to employ the top drive and the well is "no flow". Keep us advised regarding the status of repair/replacement on the IBOP. Tom Maunder, PE AOGCC Buster, Larry W wrote: Dear Torn, We are currently working towards rig mobilization for the planned ESP workovers on Steelhead M-32RD and M-28. We will be starting next week with M-32RD and our Drilling Foreman will give your Inspectors adequate notice. r would like to make a request for a component test requirement waver on the M-32RD ESP Workover (10-403 #305-051). Specifically, I would like to request a waver from testing the IBOP on the Steelhead Rig Top Drive System. The IBOP is not working (it appears to be a linkage problem), and the time to fix it will take us past our projected start date. r feel comfortable in requesting this waver in that the M-32RD well is well and we will not run a work string into the well (we will pull the re-run a replacement without any clean-out or additional perforating) . have floor valves available should be need to stab onto the pipe while running. r appreciate your consideration of this request and am available at your convenience for any further discussions or information. Thank You and Regards, a no-flow pump and We will pulling or *Larry Buster* Drilling Engineer Unocal Corporation 909 West 9th Avenue Anchorage, AK 99501 Tel: ( 907) 263 - 7853 Cell: (907) 250-0374 Fax: ( 9 0 7 ) 2 63 - 7 8 8 4 Ibuster@unocal.com ".~"""'"'''''''''''''''''''''''''''''-'''''''''''''''''''''''''''''-'''................................ '~(;,f4 NÍ\' F ~ ,', :, M.I-\ J~ ~:~ ~~ ~;~ [l 0 ;,j 1 of 1 3/25/2005 7:34 AM ) (rü: ~I r[ 11 ¡ t, . I ¡ , I' \:::¿: ¡f AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION Tim Brandenburg Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99519 Re: McArthur River M-32RD Sundry Number: 305-051 Dear Mr. Brandenburg: ffiJ / / /' ! ) Ite¡ -If! FRANK H. MURKOWSKI, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to superiã, r Co rnless rehearing has been requested. {¡ , Si cer~: ~- 10 . 0 an DATED thiS~ day of February, 2005 Enc!. SCANNED MAJ~ Ü 2 20D5 Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 163' KB above MSL 1. Type of Request: ) STATE OF ALASKA ) ALASKA Oil AND GAS CONSERVATION COMMI\:)\:)ION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: I Î 7fjD~lb¡âÇ :''',;;i'',iìl¡~;\'m:::iI"~ "" "",ôthërliJ' '. l:~~pl~c'~ Failed ESP Suspend U Repair well D Pull Tubing 0 Perforate U ~:'Wå¡vJ~;Û Stimulate D Time Extension D' Re-enter Suspended Well D 5. Permit to D~!Jl.-Number: Exploratory D 199-97 ''',il'' Service D 6. API Number: 50-733-20462-01 ,v'" Development Stratigraphic 0 D 9. Well Name and Number: M-32RD 8. Property Designation: Trading Bay UniU Steel head Platform 11. Total Depth MD (ft): 13835' Casing Structural Conductor Surface I ntermed iate Production Liner Slotted Liner Perforation Depth MD (ft): See attached schematic Packers and SSSV Type: None 10. Field/Pools(s): McArthur River Field, G/Hemlock PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): 9660' Effective Depth MD (ft): Effective Depth TVD (ft): 13835' 9660' Plugs (measured): None Junk (measured): None Length Size MD TVD Burst Collapse 1347' 3767' 10588' 1430' 3141' 16" 13-3/8" 9-5/8" 1347' 3767' 10588' 10731' 1347' 3767' 9211' 9258' 9660' Perforation Depth TVD (ft): See attached schematic Tubing Grade: 4-1/2" L-80, 12.6# Packers and SSSV MD (ft): N/A 2630 psi 3090 psi 7930 psi 8160 psi N/A Tubing MD (ft): 8911' 1020 psi 1540 psi 6620 psi 7020 psi N/A 7" 4-1 /2" 13835' Tubing Size: 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Schematic 0 BOP Sketch 0 Exploratory D Development 0 Service D 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/15/2005 Oil 0 Gas D Plugged D Abandoned D 16. Verbal Approval: Date: WAG D GINJ D WINJ D WDSPL D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Tim Brand~urg ---- Title Drilling Manager Signature 7~ d) /.2-..Phone 907-276-7600 Date ... ~ COMMISSION USE ONLY Contact Larry Buster ~- z.3-c:::>..:3 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: J¿)~ CJS-I BOP Test .~ Mechanical Integrity Test D Location Clearance D Other OÇ>tx:oA'\o"'~ .\0 ~~ Cù~ck'J ì" O-~'-O~ \ù / \..J~\ \:: S V ~o~~\ ~\b~'.)rßCJ\>"k'S-\--'tI'..~'Ùú.\ ~ l.~o¡,>. 7£'()a~\ W?-k<s~. SUbseQ'771(m rm; (~~ \,\\ I\~CC)\( o.~ ú.c..c..t~~\fé'./ APProvl ~~ ~ COMMISSIONER ~::~~~~I=;ION Date: 7;M 6S -.../ \f!BDMS 8Fl MAR 0 1 1005 ! Y, Fonn 10-403 Revised 11/2004 0 R \ G \ N Þ \ L Plug Integrity D Submit in Duplicate ) ) Steelhead Platform Well M-32RD ESP Repair UNOCAL8 OBJECTIVE: Replace the failed ESP assembly currently in Well M-32RD. PROCEDURE SUMMARY: 1. Shut off gas-lift gas. Bleed down slowly to avoid damaging ESP cable. Turn off cathodic protection system. 2. Circulate residual oil out of annulus and load well wi salt inhibited FIW. 3. Spot sized salt pill (if necessary) to manage losses and keep hole full while POR and while RIR wi tubing and ESP assembly. 4. Set BPV and N/D tree on Well M-32RD. N/U BOPE. Test 16-3/4" BOPE (see attached diagram) to 25013,000 psi. 5CC(){>S\ ~.\ ~ì ~()~7<è Note: To streamline and optimize the rig up, we would like to 2" 5K flanged rubber hoses for our choke and kill lines to the stack. We would like to run blind rams not blind/shear rams in the lower double gate (we do not have nor have any blind/shear rams been manufactured for the 16-3/4" stack) 5. Verify well dead. 6. POR wi tubing, cable & failed ESP. Visually inspect tubing & LID singles while PORe Send failed ESP equipment & unusable tubing to shore. 7. RIR wi replacement ESP assembly similar to the current failed completion (see attached diagram). 8. Install BPV. N/D BOPE. N/U & test tree. 9. Install flow line and surface facilities & turn well over to Production. Turn platform cathodic protection back on. 10. Startup ESP. AOGCC M-32RD ESP Workover Summary 1 of 1 February17,2005 ~ ' uNOCa~~b • • STEELHEAD PLATFORM WELL #: M-32RD Completion Diagram AO 11/8/01 RKB = 75.15' Rig Floor to TBG Spool SIZE WT CASING AND TUBING DETAIL GRADE CONN ID MD TOP MD BTM. 16 75 K-55 Buttress 15.124 Surf. 1,347' 13-318" 61 K-55 Buttress ]2.515 Surf. 3,767' 9-5/8" 53.5 N-80 Buttress 8.535 Surf. 10,588' Window 9392' 9408' 7" 29 L-80 Buttress 6.184 9,301' 10,731' 4-1/2" 12.6 L-80 Hydri1511 3.958 10,694' 13,835' 4-1/2" slotted liner has 2-1/2" x 1/16" slots, 48/ft Tubing: 4-1/2" 12.6 L-80 IBTC AB mod 3.958 Surf 8,911' NO Depth ID JEV1-'EERY Item 1 42.9' 4.930" FMC TC-IA-ENS 16-3/4" TBG Hanger, 4-1/2" Mod Butt connection W/CIW type H BPV profile With #0 ESP cable w/ two 3/8" SS chem. Inj. Lines 2 2410' 3.958 #6 4-1/2" MMG GLM w/ 1-1/2" SFO-2 RK latch 3807' 3.958 #5 4-1/2" MMG GLM w/ 1-l/2" SFO-2 RK latch 4682' 3.958 #4 4-1/2" MMG GLM w/ 1-1/2" SFO-2 RK latch 5191' 3.958 #3 4-1/2" MMG GLM w/ 1-1/2" SFO-2 RK latch 5613' 3.958 #2 4-1/2" MMG GLM w/ 1-1/2" SFO-2 RK latch 6060' 3.958 #1 4-1/2" MMG GLM w/ 1-1/2" SFO-2 RK latch 3 11996' Phoenix Sensor l;auge IR223' T~"D-BRT) 8998' Centrilift 600 hp 725 ESP pump bottom Date Zone Top Perforations BTM Comments 1/19/00 G-1 9625' 9665' 12 spf 1/19/00 G-2 9697' 9737' l2 spf 1/19!00 G-4 9915' 9990' 12 spf 1/19/00 G-5 10060' 10210' 12 spf 1/19/00 HK-1 10430' 10480' 12 spf 1/19/00 HK-2 10510' 10530' 12 spf HK 3-7 10694' 13835' Slotted Liner ~ TD = 13,835' MD/9660' TVD M-32RD Schem 11-8-01 REVISED: 1 1 /8/01 DRAWN BY: JFB M-32RD 16 3/4" BOP Stack up DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Permit to Drill No. 1990970 Well Name/No. TRADING BAY UNIT M-32RD Operator UNION OIL CO OF CALIFORNIA APl No. 50-733-20462-01-00 MD 13835 TVD 9660 Completion Date 1/25/2000 Completion Status CO-20 Current Status CO-20 UIC N REQUIRED INFORMATION Mud Log N._9 Samples N___~o Directional Survey No -- DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint) Well'Log Information: Log/ Interval Data Digital Digital Log Log Run OH / Dataset Type Media Format Na/me Scale Media No Start Stop CH Received Number Comments __--~'"'--' Y~IS DEP:fH ~ONT'L ....... --5- ................. ~I~A-L- ........ ~'4~0-0 ....... ~-6-06 ..... /Sh .....§7i5-/5666 t~..-""RES/GR-MD 25 FINAL 10690 13835 OH 5/19/2000 ~'/'' RES/GR-TVD 25 FINAL 8700 9500 OH 5/19/2000 l '--T-'~' O 8/30/2001 10266t-..,-~' 10690-13835 Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/(~ Daily History Received? ~/N Formation Tops Receuived? {~-~/N Comments: Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL F Dan Williamson Drilling Manager 11/08/01 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Report of Sundry Operations (Form 10-404) Steelhead, Well M-32RD McArthur River Field Commissioner Heusser: Enclosed for your review is a Report of Sundry Well Operations (Form 10-404) for the recent workover to replace the failed electric submersible pump (ESP) in Steelhead Well #M-32RD. The workover was successful and no additional work is planned for Well M-32RD at this time. If there are any questions, please contact Jerry Bowen at 263-7640. Drilling Manager RECEIVED AOGCC cover letter404.doc Tim Billingsley STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: O~er: Change out failed ESP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 163' 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. Location of well at surface Leg B1, Slot 10 Steelhead Platform 8. Well number 969' FNL, 527' F'WL, Sec. 33, TgN, R13W, SM M-32RD At top of productive interval 9. I 1749' FSL, 1411' FWL, Sec. 28, T9N, 13W, SM 199-97 At effective depth 10. APl number 110' FSL, 2382' FEL, Sec. 21, T9N, 13W, SM 50- 733-20462-01 At total depth 11. Field/Pool McAdhur River Field 110' FSL, 2382' FEL, Sec. 21, T9N, 13W, SM G Zone and Hemlock 12. Present well condition summary Total depth: measured 13,835' feet Plugs (measured) true vertical 9,660' feet Effective depth: measured 13,835' feet Junk (measured) true vertical 9,660' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1,347' 16" 1,933 sx 1,347' 1,347' Surface 3,767' 13-3/8" 2,244 sx 3,767' 3,767' Intermediate 10,588' 9-5/8" 2,607 sx 10,588' 9,211' Production Liner 1,430' 7" 343 sx 10,731' 9,258' SLotted Liner 3,141' 4-1/2" Slotted 13,835' 9,660' Perforation depB: measured 9,625'-9,665'; 9,697'-9,737'; 9,915'-9,990'; 10,060'-10,210'; 10,430'-10,480'; 10,510'-10,530'; Slotted Lnr = 10,731'-13,835' true vertical 8,671'-8,693'; 8,713'-8736'; 8,839'-8,883'; 8,923'-9,007'; 9,123'-9,148'; 9,162'-9,172'; Slotted Liner = 9,258'-9,660' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, Buttress Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) NO N/A '- Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Oct-13-2001 534 BOPD 2540 MCFD (gas lift) 5836 BWPD 1245 psi (gas lift) 144 psi Subsequent to operation Nov-10-2001 857 BOPD 290 MCFD 9350 BWPD 0 psi 82 psi 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: Signed: .... Williamson Title: Drilling Manager Date: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Date 10/30/01 10/31/01 11/1/01 11/2/01 11/3/01 11/4/01 11/5/01 11/6/01 11/7/01 11/8/01 Daily Report of Well Operations Steelhead Well M-32RD Workover to Replace Failed ESP AFE #152117 Summary Bled off SICP (gas lift pressure) from csg. Started skidding rig from M-12 to M~32RD at 12:00 hrs. Finished skidding rig. Unable to position V-door & catwalk due to high wind. Hooked up lines to wellhead. Continued hooking up & testing lines to wellhead. SICP 80 psi. SITP 15 psi. Bled SICP & SITP to 0 psi. Re-positioned catwalk & set the V-door in place. Unable to receive additional base oil due to weather. Circulated 140 bbls 7.4 ppg base oil down tbg (to displace produced hydrocarbon). Checked tree void areas for pressure. Set BPV. ND X- mas tree & NUB OPE. Finished NU BOPE. Recovered BPV & installed TWC valve. Attempted to test BOPE, located & repaired two problems with Koomey unit. Tested all BOPE to 250/3000 psi. Engaged hanger with landing joint. RU & tested hard lines to annulus. Circulated well with 650 bbls base oil. Recovered unknown amount of crude oil & 210 bbls produced water. Final SICP175 psi, SITP 200 psi. Attempted to bleed pressure to 0 psi. Continued attempts to bleed SICP & SITP to 0 psi. Could not bleed SICP and SITP below 34 & 29 psi, respectively. Obtained 200 bbls 9.0 ppg OBM from storage. Top killed well by bullheading 23 bbls OBM down tubing & 77 bbls OBM down csg. Well on slight vacuum. Backed out hold down pins. RU to POH with tbg. Un-landed completion. POH & LD hanger. POH with 2400' of 4 ½" tbg, inspecting for thread damage, scale & pitting. Cleaned connections & replaced AB Mod. seal rings at break points. Continued POH inspecting tbg & standing same in derrick. Added OBM to account for pipe displacement, well remained dead. LD 3 joints due to thread damage, no NORM/scale/corrosion detected. Inspected & L/D failed ESP & Sentry sensor. Found pitting corrosion on ESP assembly & apparent corrosion hole in lower seal section immediately above motor. RU to run ESP. Started making up new 600 hp ESP assembly & Phoenix sensor. Finished M/U ESP assembly & RIH on original 4 ½" 12.6 ppfL-80 AB Mod IBTC SCC tbg to 7032'. Conducted conductivity tests every 1000'. Continued RIH. Make up tbg hanger & splice cable to penetrator with two 3/8" SS chemical injection lines. Landed hanger with ESP base at 8998' MD. RD 4 ½" running equipment. Started cleaning, preserving & ND BOPE for rig de-activation. Finished ND BOPE. NU & test 4 1/16" 5m X-mas tree. Recovered BPV & installed TWCV. Tested tree to 5000 psi. Connected flowline. Turned well over to Production. Continued rig de-activation. Continued rig de-activation. Skidded rig over waterflood & connected electrical power & hydraulics. FINAL REPORT. UNOCAL RKB = 75.15' Rig Floor to TBG Spool TOL ~ 9,301' TOL ~ 10,694' STEELHL,..D PLATFORM WELL #: M-32RD Completion Diagram AO 11/8/01 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID MD TOP MD BTM. 16 75 K-55 Buttress 15.124 Surf. 1,347' 13-3/8" 61 K-55 Buttress 12.515 Surf. 3,767' 9-5/8" 53.5 N-80 Buttress 8.535 Surf. 10,588' Window 9392' 9408' 7" 29 L-80 Buttress 6.184 9,301' 10,731' 4-1/2" 12.6 L-80 Hydril 511 3.958 10,694' 13,835' 4-1/2" slotted liner has 2-1/2" x 1/16" slots, 48/ft Tubing: 4-1/2" 12.6 L-80 1BTC AB mod 3.958 Surf 8,911' JEWELRY NO Depth ID Item 1 42.9' 4.930" 2 2410' 3.958 3807' 3.958 4682' 3.958 5191' 3.958 5613' 3.958 6060' 3.958 3 8996' 8998' FMC TC-1A-ENS 16-3/4" TBG Hanger, 4-1/2" Mod Butt connection W/CIW type H BPV profile With g0 ESP cable w/two 3/8" SS chem. Inj. Lines #6 4-1/2" MMG GLM w/1-1/2" SFO-2 RK latch #5 4-1/2" MMG GLM w/1-1/2" SFO-2 RK latch #4 4-1/2" MMG GLM w/1-1/2" SFO-2 RK latch #3 4-1/2" MMG GLM w/1-1/2" SFO-2 RK latch #2 4-1/2" MMG GLM w/1-1/2" SFO-2 RK latch #1 4-1/2" MMG GLM w/1-1/2" SFO-2 RK latch Phoenix Sensor gauge (8223' TVD-BRT) Centrilift 600 hp 725 ESP pump bottom Date Zone Top 1/19/00 G-1 9625' 1/19/00 G-2 9697' 1/19/00 G-4 9915' 1/19/00 G-5 10060' Perforations BTM Comments 9665' 12 spf 9737' 12 spf 9990' 12 spf 10210' 12 spf 1/19/00 HK-1 10430' 10480' 12 spf 1/19/00 HK-2 10510' 10530' 12 spf HK 3-7 10694' 13835' Slotted Liner TD = 13,835' MD/9660' TVD M-32RD Schem 11-8-01.doc REVISED: 11/8/01 DRAWN BY: JFB Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7528 E-mail: childersd@ unocal.corn Debra A. Childers Technologist DATA TRANSMITTAL August 30, 2001 To: Lisa Weepie 333 W 7th Ave, #100 Anchorage, AK 99501-3539 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99501 Unocal Alaska Transmitting the following: TBU M-32 RD & FORMATION EVAL LOGS 1/16/00 i' CD M-32 RD PB1 FORMATION EVAL DIGITAL DATA SURVEYS RECECVED Alaska Oil & Gas Cons. Commission ,'~,nchorage Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Date: ..... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: Other: Change out ESP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 163' 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. Location of well at surface Leg B1, Slot 10 Steelhead Platform 8. Well number 969' FNL, 527' FWL, Sec. 33, T9N, R13W, SM M-32rd At top of productive interval 9. Permit number/approval number 1749' FSL, 1411' FWL, Sec. 28, T9N, 13W, SM 199-97 At effective depth 10. APl number 110' FSL, 2382' FEL, Sec. 21, T9N, 13W, SM 50- 733-20462-01 At total depth 11. Field/Pool McArthur River Field 110' FSL, 2382' FEL, Sec. 21, T9N, 13W, SM G Zone and Hemlock 12. Present well condition summary Total depth: measured 13,853' feet Plugs (measured) true vertical 9,660' feet Effective depth: measured 13,853' feet Junk (measured) true vertical 9,660' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1,347' 16" 1,933 sx 1,347' 1,347' Surface 3,767' 13-3/8" 2,244 sx 3,767' 3,767' Intermediate 10,588' 9-5/8" 2,607 sx 10,588' 9,211' Production Liner 1,430' 7" 343 sx 10,731' 9,258' SLotted Liner 3,141' 4-1/2" Slotted 13,835' 9,660' Perforation depth: measured 9,625'-9,665'; 9,697'-9,737'; 9,915'-9,990'; 10,060'-10,210'; 10,430'-10,480'; 10,510'-10,530'; Slotted Liner = 10,731'-13,835' true vertical 8,671'-8,693'; 8,713'-8736'; 8,839'-8,883'; 8,923'-9,007'; 9,123'-9,148'; 9,162'-9,172'; Slotted Liner = 9,258'-9,660' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, Buttress Packers and SSSV (type and measured depth)RECEIVED None 13, Stimulation or cement squeeze summary N/AJAN 2001 Intervals treated (measured) N/A Alaska Oil & Gas Cons. Commission Treatment deScription including volumes used and final pressure Anchorage N/A 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1-7-01 470 220 4,482 1,279 113 Subsequent to operation 1-21-01 967 250 7,901 0 86 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: Signe _D_~n Williamson Title: Drilling Manager Date: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICAT Workover Summary Steelhead M-32rd 1/12/01 - 1/19/01 DAY 1 (1/12/01) CONT. RIG UP. DISPLACE WELL TO BASE OIL KILL FLUID. PUMP A TOTAL OF 940 BBLS, LOST 295 BBLS DURING CIRCULATION. MONITOR WELL, STABLE. SET BPV. NIPPLE DOWN TREE AND SEAL FLANGE. DAY 2 (1/13/01) NIPPLE UP 16-3/4" STACK. ANNULAR, DOUBLE GATE, MUD CROSS, SINGLE GATE. DAY 3 (1/14/01) CONT. NU BOPE. TEST BOPE 250/3,000 PSI. TEST WHITNESSED BY AOGCC P.I. JEFF JONES. DAY 4 (1/15/01) CONT. BOPE TEST. CHECK WELL, STABLE. PULLHANGER FREE AT 205K. PULL TO FLOOR. LD ESP PENETRATOR AND HANGER. RU TO SPOOL ESP CABLE. POOH WITH ESP COMPLETION. WELL TAKING 5-7 BPH. DAY 5 (1/16/01) CONT. POOH WITH ESP COMPLETION. WELL TAKING 4 BPH. DAY 6 (1/17/01) CONT. POOH WITH ESP COMPLETION. PUMP TO SURFACE. FOUND MOTOR LEAD SHORTED OUT AT MOTOR (POTHEAD CONNECTION). PU NEW MOTOR, SEAL SECTION AND PUMP. RIH. DAY 7 (1/18/01) CONT. RIH WITH NEW ESP COMPLETION. DAY 8 (1/19/01) CONT. RIH WITH ESP COMPLETION. PU TUBING HANGER AND LAND SAME. RIG DOWN LANDING JOINT. INSTALL BPV. NIPPLE DOWN BOPE. INSTALL TREE. PULL BPV, SET TWC AND TEST TREE, SEAL FLANGE AND TUBING HANGER TO 5,000 PSI, OK. RIG DOWN. RIG RELEASED AT 24:00 HOURS. RECEIVED JAN g A Z001 Alaska 0il & Gas Cons. Comrnission Anchorage UNOCAL RKB = 74.30' Rig Floor to TBG Spool STEELHI~. ~O PLATFORM WELL #: M-32RD As of 1-20-01 SIZE WT CASING AND TUBING DETAIL GRADE CONN ID MD TOP MD BTM. 16 75 13-3/8" 61 9-5/8' 53.5 K-55 Buttress 15.124 Surf. 1,347' K-55 Buttress 12.515 Surf. 3,767' N-80 Buttress 8.535 Surf. 9,408' 7" 29 L-80 4-1/2' 12.6 L-80 421/2" slotted liner has 2-1/2" x Tubing: 4-1/2" 12.6 L-80 Buttress 6.184 9,301' 10,731' Hydril 511 3.958 10,694' 13,835' 1/16" slots, 48/ft BTC AB mod 3.958 Surf 9,108' JEWELRY No Depth ID OD Item 1 74.3' 4.930 2 2379' 3.958 7.032 3,780' 3.958 7.032 4,688' 3.958 7.032 5,202' 3.958 7.032 5,611' 3.958 7.032 6,060' 3.958 7.032 3 9,093' 9,221' 6.812 FMC TC-1A-ENS 16-3/4" TBG Hanger, 4-1/2" Mod Butt Top & Btm, CIW type H BPV profile, w/ESP cable, ¼" I wire for downhole pressure and 3/8" chem inj line. #6 4-1/2" MMG GLM, RK Latch, 1-1/2" R-2 valve #5 4-1/2" MMG GLM, RK Latch, 1-1/2" R-2 valve #4 4-1/2" MMG GLM, RK Latch, 1-1/2" R-2 valve #3 4-1/2" MMG GLM, RK Latch, 1-1/2" R-2 valve #2 4-1/2" MMG GLM, RK Latch, 1-1/2" R-2 valve gl 4-1/2" MMG GLM, RK Latch, 1-1/2" R-2 valve Baker Sentry pressure gauge (8,296' TVI)) Centrilift ESP pump bottom TOL ~ 9,301' G-1 G-2 G-4 G-5 H-1 2 TOL ~ 10,694' I I I I I I I I I I I Date Zone Top 1/19/00 G-1 9625' 1/19/00 G-2 9697' 1/19/00 G-4 9915' 1/19/00 G-5 10060' 1/19/00 H-1 1/19/00 H-2 TD = 13,835' MD/9660' TVD Builds to 80 de# at 11,129' MD 86 deg at TD 13,835' MD Perforations BTM Comments 9665' 12 spf 9737' 12 spf 9990' 12 spf 10210' 12spf 10430' 10480' 12spf 10510' 10530' 12spf RECEIVED JI~N ~ ,~ 2001 Alaska 0il & Gas Cons. Commission Anchorage M-32RD 1-20-01.doc REVISED: 1/11/01 DRAWN BY: TCB Unocal Alaska Resources Unocal Corporation 909 West 9th Ave. Anchorage, AK 99519-6247 Tele: (907) 263-7889 Fax: (907) 263-7828 E-maih childersd@, unocal, cam UNOCAL Debra Childers ®eotech Assistant DATA TRANSMITTAL May 18, 2000 To: Lori Taylor 3OO1 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From' Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items: [,%'Z.'0~,~,.5/17/00 TBU G-6 RD Completion Record i5 inch 12120199 9800-10155 1 B-Line !AOGCC : i TBU G-6 RD TBU M-32 !TBU M-32 i TBU M-32 TBU M-32 15117100 !5117100 i-sL!7/°° ~5/17/00 Completion Record Pluq Setting record ~ Setting_record Plug Setting record Pluq_Setti_ng record MD RES/GR Film JAOG.C._.C .......... 1_. B~-__L i_n_e_ ...... ~.A..P_GC.C ..... B-Line !AOGCC i .Ejl~_ ....... LA0_G_CC. ....... , 'Film i AOGCC ~1~ ~,-{ i5/17/00 ~7/00 i~,/i7/oo ~5-~ 7/00 5/17/00 5/17/00 ~o, oi ~ 5/17/00 5/17/00 5/17/00 5/17/00 5/17/00 5/17/00 5/17/00 5/17/00 5/17/00 L/-i5/17/00 i5 inch 12/20/99 9800-10155 5 inch 11/14/99 9200-9450 i5 inch 11/17/99 9200-9450 i5 inch 11/14/99 9200-9450 15 inch 11/17/99 TBU M-32 RD 12/5 inch 1 TBU M-32 RD MD RES/GR !2/5 inch 1 TBU M-32 RD i TCP Depth Control 15 inch TBU M-32 RD' iTCP Depth Control !5 inch TBU M-32 RD iTVD RES/GR 12/5 inch 1 TBU M-32 RD iTVD RES/GR i2/5 inch 15 inch 9200-9450 M-4 i Completion Record TBU TBU M-4 !Completion Record , 5 inch 11/22/99i 1400-5800 TBU M-4 !GammaRa¥-CCL 15inch 2/19/99 10690-13835 1 B-Line iAOGCC 1/19/00 9500-9625 liB-Line ......... J_A_0_G_C_C_ ....... 1/19/00i9500-9625 ....... _l.i_FjJ~ .......... 2/19/99!10690-13835 liB-Line ;AOGCC~ 2/19/99~i 10690-13835 l lFilm !AOGCC 11/4/9913400-6314 TBU M-4 i Gamma Rav-CCL 15 inch 11/4/9913400-6314 TBU M-4 Perforatinq Record .5 inch 11/7/99i5400-5630 TBU M-4 Perforatinq Record 15 inch 11/7/99i5400-5630 15 inch B-Line ........ i._A_O.G.__C.C ........ . Film ! AOGC..__C_ ..... TBU M-4 RST Sigm_a_L_og iTBU M-4 iRST S~m__a__Lo_g____ i5 inch i 11/22/99i 1400-5800 i TBU M-4 i UItra Sonic 15 inch i 11/4/99i3400-6314 11/22/99! 1400-5800 :TBUM-4 iUItraSonic' 15inch i 11/4/99!3400-6314 l iFilm :AOGCC ............. ~§7~ ......... !~iS~i~'C_;- ...... _]_!_F_i!_m_ ......... i.A.._ .O_G_C_C .... 1 B-Line .~A_OG._C__C.. ..... . 1 Film ,AOGCC Please acknowl .edge receipt by signing and returning Received b . one copy of this transmittal B ~f(~-(~01~) ~828. Do're' MA'( 19 2000 Alaska 0ii & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: X GAS: SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Unocal Oil Company of California (UNOCAL) 199-97 3. Address 8. APl Number P. O. Box 196247, Anchorage, Ak 99519 50- 733-20462-01 4. Location of well at surface Leg B1, Slot 10 Steelhead Platform 9. Unit or Lease Name 969' FNL, 527' FWL, Sec. 33, T9N, R13W, SM i ~L~i,.;?L!~'~'!~,~ i-'~ Trading Bay Unit At Top Producing Interval ~ 2,... i~ ~ ~'-~--,~"~i~ 1749' FSL' 1411 FWL' Sec' 28' T9N' 13W' SM } '~:%'~'~"-"-~f'~'-i'i i~il i-~-ii i ~~ 10. WellNumber:~ M-32RD At Total Depth (13835' MD/9660' TVD) i ~:';:i;~ ~; i ~ 11. Field and Pool 110' FSL, 2382' FEL, Sec. 21, T9N, 13W, SM -.'-~:~2~-./-~, ~-.~..~-U_% ~. ....... 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial ~ McArthur River Field 160' KB above MSL[ ADL-18730 & ADL-17594 G zone and Hemlock 12. Date Spudded11/18/99 13' Date T'D' Roached I 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re i 16' N°' °f C°mpleti°nsl 16/00 1/25/00 187 feet MSL 1 17. Total Depth (MD+TVD)18. Plug Back Depth (MD+TVD)13835, MD/9660' TVD 13835' MD/9660' TVD 19' Directi°nal Survey I 20' Depth where SSSV set I 21' Thickness °f Permafr°Styes: X No: NA feet MD NA 22. Type Electric or Other Logs Run Anadrill GR/Res 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 75# K-55 0 1347' 22" 1933 sx 0 13-3/8" 61# K-55 0 3767' 17-1/2" 2244 sx 0 9-5/8" 53.5# L-80 0 10588' 12-1/4" 2607 sx 0 7" 29# L-80 9301' 10731' 8-1/2" 343 sx 0 4-1/2" 12.6# L-80 10694' 13835' 6" none (slotted liner) 0 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) G-1 9625'-9665' MD 8671'-8693' TVD 12 spf 0.36" die 4-1/2" 9268' None G-2 9697'-9737' MD 8713'-8736' TVD 12 spf 0.36" die G-4 9915'-9990' MD 8839'-8883' TVD 12 spf 0.36" die 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. G-5 10060'-10210' MD 8923'-9007' TVD 12 spf 0.36" die DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED HK-1 10430'-10480' MD 9123'-9148' TVD 12 spf 0.36" die HK-2 10510'-10530' MD 9162'-9172' TVD 12 spf 0.36" die HK3-7 10731'-13835' MD 9258'-9660'TVD Slotted liner 27. PRODUCTION TEST ~ ~ I ~"""~ ! ~ Date First Production I Method of Operation (Flowing, gas lift, etc.) uKIUii IAL 1/25/2000 Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 2/10/2000 24 TEST PERIOD => 2076 744 ## NA] 358 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 105 98 24-HOUR RATE => 2076 744 ## 33 28. CORE DATA ..... ~ ..~ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~'( ~ (,_-, ~.~ kl,~.ska 0ii & Gas C0~s. Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 4' 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. 'Gl sand top 9625 8676 G2 sand top 9697 8720 G3 sand top 9814 8788 G4 sand top 9918 8849 G5 sand top 10062 8932 G6 sand top 10297 9062 G7 sand top 10350 9090 Hemlock bench 1 top 10423 9128 Hemlock bench 2 top 10510 9170 Hemlock bench 3 top 10689 9249 Hemlock bench 4 top 11135 9356 Hemlock bench 5 top 11836 9448 Hemlock bench 6 top 12989 9555 Hemlock bench 7 top 13652 9646 31. LIST OF ATTACHMENTS Wellbore schematic, Daily Summary of Rig Operations, Directional Survey Record 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~ Titl"~ Drilling Manager Date '-~ 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 measuremenr~i~'~:f,:.-'-.~,,~,,.~ 0il ~?.. u given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, submersible, Water In- jeotion, Gas Injection, ,Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 UNOCAL Alaska Drilling Drilling Summary Report M-32RD 11/12/99 to 11/11/99 11/12~99 11/13/99 11/14/99 11/15/99 11/16/99 11/17/99 11/18/99 11/19/99 11/20/99 11/21/99 Finish rig move form M-4 to M-32. ND tree, NU and test BOPE. Pull 4-1/2" tubing seals from packer. POOH and stand back 4-1/2" tubing. RIH with 8.5" packer mill assy. Prepare rig for oil based mud. Tag packer at 9396'. Mill packer and chase to 9587'. POOH with packer mill. RU E-line. Set bridge plug at 9507' elm. Pressure test casing to 2000 psi. RIH with whipstock assy. Tight spots at 6392', 7757' and 9216'. Could not go below 9468' with upper 8.51" string mill at 9431'. Decide to POOH with whipstock, 20k overpull on first 30' then normal drag to surface. RU 2 its of 9-5/8" casing in top of wellhead to strip whipstock through. Did not retrieve whipstock, bolt had sheared and whipstock either fell or was left on bottom. RIH with 8-1/2" box tap fishing assy to retrieve whipstock. Unable to get below 9431'. POOH with box tap. Deep gouges on side of box tap. Decide to run second whipstock. RU E-line unit and set bridge plug at 9427'. RD E-line unit. RIH with whipstock and undersized mills of 7.75" and 8.00" (no 8.51" upper mill). Set whipstock on bridge plug at 9427' elm. Change over well to oil based mud. Mill window from 9392' to 9400' dpm. Perform formation integrity test to 1000 psi, 11.2 ppg EMW. POOH with mills. RIH with triple mill assy: 7.77" starter mill, 8.00" lower watermelon mill, 8.51" upper watermelon mill. Change out kelly hose. Finished RIH with triple mill assy. Mill from 9400' to 9410' dpm. Bottom of window at 9408'. Penetration rate slowed to 1' in 1-1/2 hrs. POOH for new mill. Starter mill worn out and 3~8" under gauge. RIH with third mill assembly (triple mill), mill from 9410' to 9417', penetration rate stopped. POOH with third mill assembly; starter mill = 1-1/2" undergauge, middle string mill = 13116" undergauge on bottom and ~ ~g~uge~ ~-~ ~ 11/22/99 11/23/99 11/24/99 11/25/99 11/26/99 11/27/99 11/28/99 11/29~99 11/30/99 12/1/99 12/2/99 12/3/99 12/4/99 8.00" on top, top mill in gauge at 8.51". RIH with 4th mill assy of two mills (7.865" starter mill and 8.51" string mill). Mill from 9415' to 9419'. Work mills through window with no problem. POOH, starter mill = 7/16" undergauge, string mill in gauge at 8.51". RIH with 8.5" bit on 1.0 AKO ADM motor. Drill from 9419' to 9549'. Drill from 9549' to 10,005'. Drill from 10,005' to 10,138'. POOH for bit change, no hole problems. RIH with Bit #2, wash and ream from 10015' to10110', stuck pipe at 10079'. Work free and circ up 30 drums of coal. Ream to 10,138'. Drill from 10,138' to 10,387'. Drill from 10386' to 10445'. POOH for bit. RIH with bit #3. Ream from 10010' to 10025'. Tagged fill at 10025', packed off several times while reaming to 10099'. Recover 45 drums of coal cuttings, coffee ground size with some half-dollar size pieces. Ream to 10385', pump hi-weight vis sweep. Recover 4 more bbls of coal. Ream to 10,445'. Drill from 10445' to 10662'. Drill from 10662' to 10800'. Temporarily plugged all three jets, unplugged two jets, recovered piece of rubber (motor?) on shakers. POOH due to possible motor deterioration. Back ream with packing off at 10404', 10372', 10360', 10348', and 10068'. Finished POOH. Test BOPE. RIH with Bit #4, set down at 9600' and work through. Set down and had to ream through 10090' to 10098'. Set down and ream thru 10370'-10398' and 10650'-10680'. Total coal circulated up was only 5 drums. Drill from 10800' to 10865'. Drill to 10948'. Pull bit due to penetration rate. backreaming to 10398', pipe stuck. Good circulation. torque and slump. Back ream out of hole. POH with no Free pipe by RIH with bit #5. Ream thru 10060' to 10100' with 17 drums of coal circ out. Drill from 10943' to 10970'. Drill from 10970' to 11111'. POOH due to washout, no backreaming required. Finished POOH, found washout between lead collar and upper stabilizer. RIH with bit #6, could not work past 10123'. POOH. RIH with hole opener, tag up at 10135' and could not work past 10135'. Circ up only 1-1/2 drums of coal. POOH and nose of hole ope .r!~..rrw.~3s~.~ flattened. RIH with slick drilling assembly with motor and MW~~'~ii':~..~ i ~:ii 12/5/99 12/6/99 12/7/99 12/8/99 12/9/99 12/10~99 12/11/99 12/12/99 2/13/99 12114199 12/15/99 12/16/99 12/17/99 at 10135', PU and attempt to ream back to bottom. Stuck pipe at 10093', packed off with no circulation. Work pipe up to 9998' with jars. RIH with string shot and back off drill string at 9912'. POOH with drill sting. RIH with fishing assembly. Screw in to fish at 9932', jar up and down with no success. RIH with string shot and back off at 9964'. POOH with fishing assy. RIH with wash pipe and wash over fish from 9964' to 9992', shoe quit drilling. POOH and left wash pipe on bottom with top of wash pipe at 9943'. RIH with 2-7/8" cement stinger and lay in 42 bbl cement plug from 9964'. POH to just below window at 9415' and circ 3 bbl mud. POH to 8880' and circ drill pipe clean. POOH with cement stinger. RIH with 8- 1/2" insert bit on 1.1 AKO motor, no resistance except for small stringers until 9530'. Increase mud weight from 10.2 to 10.5 ppg. Drill soft cement to 9690', drill harder cement from 9690' to 9816'. Unable to kick-off plug. POOH for sidetrack bit. Test BOPE. Change to 8-1/2" PDC sidetrack bit and 1.3 AKO XL motor and RIH. Time drill from 9816' to 9820'. Drill from 9820' to 10080'. Drill from 10080' to 10132'. Spot 49 bbl Ventrol pill on bottom and POH to casing. Squeeze Ventrol pill with 200 psi. RIH and drill from 10132' to 10167'. Lost 300 psi, POOH and found washout in circ sub. RIH with insert bit. Drill from 10167' to 10481'. POOH for bit ROP. RIH with CDR and log with MAD pass from 9420' to 10481'. Drill from 10481' to 10506'. Drill from 10506' to 11732', casing point. Spot Ventrol pill and POOH. Run 1430' of 7" 29#, L-80 KC buttress liner to bottom at 11731'. Drop ball, set hanger and release running tool. Reengage liner and rotate while pumping 72 bbls of 15.8 ppg cement. Displace with mud and bump plug. Good returns and rotation throughout job. PU and set ZXP liner top packer with 70K lbs down wieght. POH to 7700' and circ drill pipe clean. No cement in returns. Continued POOH. Cement on stinger OD. Test BOPE. RIH with 8-1/2" cleanout bit. Tag cement at 9214', drill cement to top of liner at 9301'. :~.~-.,,~'~ /.~ ;~'~ 12/18/99 Circ out 3 bbls of cement. Tested liner top packer and casing to 2000 psi, no bleed off. POOH with cleanout assy. FiniShed POOH. Change rams to 3-1/2" and test same. Failed test. Found leak in tool it. Retest rams, OK. 12/19/99 12/20/99 12/21/99 PU 3-1/2" drill pipe. RIH with 6" bit, drill cement from 10582' to 10719'. Test casing to 2000 psi. Drill 10' new formation to 10742'. Perform FIT to 2000 psi with no leakoff, 14.4 ppg EMW. Drill from 10742' to 10773'. Drill from 10773' to 10870'. POOH for bit change. RIH with new bit. Drill from 10870' to 11027'. POOH for new bit. 12122199 RIH with new bit. Drill from 11027' to 11166'. 12/23/99 Drill from 11027' to 11170'. POOH for new bit. RIH with no hole problems. Drill from 11170' to 11297'. 12/24/99 POOH for new bit. Test BOPE. Annular failed. Replace same with annular element flown in by helicopter from Anchorage. 12/25/99 RIH with new bit. Ream from 10944' to 11049' and 11185' to 11197'. Rotary drill from 11297' to 11420', POOH for bit. 12/26/99 POOH with no problems. RIH with 6" PDC bit, no problems. Rotary drill from 11420' to 11574'. 12/27/99 POOH, no problems. PDC worn out. RIH with insert bit. 12/28/99 Drill from 11574' to 11668', inadvertent angle build. POOH and discover MWD tool face was 180 deg off. 12/29/99 RIH with new bit, drill from 11668' to 11837'. 12/30/99 Spot Ventrol pill, POOH for new bit. 12/31/99 RIH with new bit, wash and slow ream thru coal at 11690'-11802'. Drill from 11837' to 11890', POH to shoe for Y2K. 1/1/00 RIH and drill from 11890' to 11978'. POOH for new bit. Test BOPE. 1/2/00 RIH with PDC bit and drill from 11978' to 12165'. 1/3/00 POOH with PDC bit. RIH with insert bit and drill from 12165' to 12280'. 1/4/00 1/5/00 POOH with insert bit. RIH with new bit, drill from 12280' to 12292'. Continue drilling from 12292' to 12477'. POOH for new bit. 1/6/00 117100 1/8/00 1/9/00 1110/00 1/11/00 1/12/00 1/13/00 1/14/00 1/15/00 1/16/00 1/17/00 1/18/00 1/19/00 RIH and drill from 12477' to 12655'. POOH for new bit. RIH and drill from 12655' to 12696'. Continue drilling from 12696' to 12771'. POOH for new bit. Test BOPE. RIH with new bit. Drill from 12771' to 12880'. POOH for new bit. Drill from 12880' to 13176'. Spot Ventrol pill, POOH. RIH with new bit. Drill from 13176' to 13314'. POOH for new bit. RIH with new bit. Drill from 13314' to 13474'. POOH for new bit. RIH with new bit. Drill from 13474' to 13645'. Spot Ventrol pill. Trip for new bit. Drill from 13645' to 13730'. Drill from 13730' to 13835'. (Called TD = 13835' MD/9660' TVD) POOH with final 6" bit. Run 102 jts of 4-1/2" 12.6#, L-80, Hydril 511 slotted liner. Set liner in slips and run 100 its of 2-1/16" CS Hydril inner string. MU liner hanger to inner string and to 4-1/2" liner. RIH with liner on drill pipe. Tag bottom at 13835'. Drop ball and set liner hanger with 2000 psi, release running tool with 2800 psi, blow ball seat with 3900 psi. Circ through inner string, displace 4-1/2" x 6" open hole annulus with 95 bbls of base oil @ 7.4 ppg. PU to unsting inner string from packoff collar at bottom of liner. Continue displacing additional 45 bbls of base oil inside 4-1/2" slotted liner. Drill pipe was displaced with 10.5 ppg mud. POH with drill pipe and inner string to top of 4-1/2" liner at 10694'. Circ and treat mud to change well over from 10.5 ppg to 9.5 ppg. Spot 39 bbls of lease oil in 7" liner from 10694' to 9625'. POOH with drill pipe and inner string. RIH with Halliburton TCP guns and time-delayed tubing pressure actuated firing head on drill pipe. RU Schlumberger E-line and run GR correlation log to place guns on depth. POOH with E-line. Pressure up drill pipe to fire guns. At 1550 psi, circ sub opened early. (Circ sub was pinned to open at 3500-3800 psi). Guns fired after a 5 minute delay (guns were pinned to fire at 1200-1800 psi). Circ 1-1/2 BU, no losses and some shot gas to surface. Perf interval = 9625'-9665', 9697'-9737', 9915'-9990', 10060'-10210', 10430'-10480', 10510'-10530'. 1/20/00 1/21/00 1/22/00 1/23/00 1/24/00 1/25/00 POOH with guns. All shots fired. Test BOPE. RIH with electric submersible pump on 4-1/2" tbg. Check continuity every 1500', cable had short on check at 4060'. Pull tbg and cable looking for damage. Found short to be at flat motor cable/pothead interface at motor. Replace same and rerun tubing and cable checking conductivity every 7 stands. Run 4-1/2" tbg and submersible pump to 9268'. ND BOPE. Nu tree and test to 5000 psi. MU flowline. MU landing jt and start electric submersible pump taking returns to rig mud pits while loading annulus with 650 bbl FIW. Stop loading annulus and switch pump returns to production separator. Turn well over to production at 03:00 on 1/25/00. UNOCAL RKB = 75.15' Rig Floor to TBG Spool STEELHEAD PLATFORM WELL #: M-32RD As of 1-23-00 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID MD TOP MD BTM. 16 75 K-55 13-3/8" 61 K-55 9-5/8" 53.5 N-80 Window 7" 29 L-80 4-1/2" 12.6 L-80 4-1/2" slotted liner has 2-1/2" x Tubing: 4-1/2" 12.6 L-80 Buttress 15.124 Buttress 12.515 Buttress 8.535 Buttress 6.184 Hydril 511 3.958 1/16" slots, 48/ft Surf. 1,347' Surf. 3,767' Surf. 10,588' 9392' 9408' 9,301' 10,731' 10,694' 13,835' BTC AB mod 3.958 Surf 9,145' NO Depth ID JE'WELRY Item 1 42.9' 2 2379' 3780' 4686' 5200' 5611' 6061' 3 9122' 9268' 4.930" 3.958 3.958 3.958 3.958 3.958 3.958 FMC TC-1A-ENS 16-3/4" TBG Hanger, 4-1/2" Mod Butt connection W/CIW type H BPV profile With ESP cable, ¼" I wire for downhole pressure and 3/8" chem inj line. #6 4-1/2" MMG GLM w/1-1/2" R-2 valve #5 4-1/2" MMG GLM w/1-1/2" R-2 valve #4 4-1/2" MMG GLM w/1-1/2" R-2 valve #3 4-1/2" MMG GLM w/1-1/2" R-2 valve #2 4-1/2" MMG GLM w/1-1/2" R-2 valve #1 4-1/2" MMG GLM w/1-1/2" R-2 valve Baker Sentry pressure gauge (8319' TVD) Centrilift ESP pump bottom TOL ~ 9,301' TOL ~ 10,694' M-32RD 1-23-00.doc Date Perforations Zone Top BTM Comments G-1 9625' 9665' 12 spf G-2 9697' 9737' 12 spf G-4 9915' 9990' 12 spf G-5 10060' 10210' 12 spf 1/19/00 1/19/00 1/19/00 1/19/00 1/19/00 1/19/00 HK-1 10430' 10480' 12 spf HK-2 10510' 10530' 12 spf TD = 13,835' MD/9660' TV]) REVISED: 1/23/00 DRAWN BY: TAB ANADRILL SCHLUMBERGER Survey report Client ................... : UNOCAL Field .................... : McArthur River Well ..................... : M-32RD Spud date ................ : 15-Nov-99 API number ............... : 50-733-20462-01 Engineer ................. : St.Amour/Brown/Nutter Rig: ..................... : Steelhead State: ................... : Alaska 17-Jan-2000 00:11:06 Last survey date ......... : 16-Jan-00 Total accepted surveys...: 92 MD of first survey ....... : 9644.90 ft MD of last survey ........ : 13835.00 ft Survey calculation methods ............. Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference --- Permanent datum .......... : Mean Sea Level Magnetic dip ............. : 73.52 degrees Depth reference .......... : Driller's Pipe Tally GL above permanent ....... : -350.00 ft KB above permanent ....... : 0.00 ft DF above permanent ....... : 160.25 ft Vertical section origin Latitude (+N/S-) ......... : 0.00 ft Departure (+E/W-) ........ : 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 19.19 degrees Geomagnetic data Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 22-Nov-1999 Magnetic field strength..: 1104.83 HCNT Magnetic dec (+E/W') ..... : 21.29 degrees MWD survey Reference Criteria Reference G .............. : 1002.03 mGal Reference H .............. : 1104.83 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-) ..... : 21.29 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 21.29 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 ANADRILL SCHLUMBERGER Survey Report 17-Jan-2000 00:11:06 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ # depth angle angle length depth section +N/S- +E/W- - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) 1 9644.90 51,50 15.60 0.00 8680.30 2904,18 2729,80 991.20 2 9768,67 55,41 16.82 123,77 8753,99 3003,38 2825.25 1018,98 3 9803,72 55.34 18.78 35,05 8773,90 3032,20 2852,71 1027.79 4 9835,11 54,16 19.89 31,39 8792,02 3057,83 2876,90 1036,28 5 9866,72 54,13 18,79 31,61 8810.54 3083.45 2901,07 1044,76 6 9886.91 54,12 19.90 7 9957.00 54.41 19,00 8 9963,00 54,41 19,00 9 10024 , 50 55,17 19,00 10 10057,40 55.00 19.00 11 10147,05 55,79 18.34 12 10213,18 56.79 18,41 13 10241.74 57.02 19.80 14 10297.46 57,54 21,71 15 10367.02 58,56 24,91 16 10429.73 60,08 18,16 17 10495.68 61.38 19.34 18 10522.94 61,85 19,74 19 10616.53 64.12 17.67 20 10669.38 65,38 18.81 21 10732.10 67.24 19.25 22 10795,35 75,33 15.95 23 10870.17 77,58 16,07 24 10912,17 77,65 17.57 25 10986.40 78.79 17,90 26 11036.98 79.37 19.71 27 11105,55 79,89 18,24 28 11129.81 80.31 17,89 29 11199,72 80.31 20.76 30 11245.97 80.39 18.72 20.19 70,09 6,00 61,50 32,90 89,65 66,13 28,56 55,72 69.56 62,71 65,95 27,26 93,59 52,85 62.72 63.25 74,82 42.00 74,23 8822,37 3099,81 2916,51 1050,18 8863.30 3156.70 2970,16 1069.13 8866,79 3161,58 2974,77 1070,71 8902,25 3211.82 3022.28 1087.07 8921.08 3238.79 3047.79 1095,86 8972,00 3312,56 3117.69 1119.48 9008.70 3367.55 3169,90 1136,82 9024,29 3391.47 3192,51 1144,65 9054.42 3438,34 3236.34 1161,26 9091.23 3497.25 3290.53 1184,62 9123,25 3551,12 3340.66 1204,38 9155,50 3608,63 3395,13 1222,87 9168,46 3632,61 3417,73 1230,89 9210,.97 3715,96 3496.70 1257,61 9233.51 3763,73 3542.10 1272.58 9258,71 3821.16 3596.39 1291,30 9279.00 3880.95 3653.45 1309,36 9296,52 3953,51 3723.36 1329,42 9305.53 3994.47 3762.63 1341.29 9320,68 4067,08 3831,84 1363,43 50,58 9330,26 4116,73 3878.85 1379,44 68.57 9342.61 4184.16 3942.63 1401.37 24,26 9346.78 4208,05 3965.35 1408,78 69,91 9358,55 4276.95 4030,38 1431,58 46,25 9366,30 4322.54 4073,29 1446,98 49.11 9374.47 4370.96 4119.16 1462.50 35.72 9380,42 4406,17 4152,52 1473.81 29,79 9385.36 4435.54 4180.24 1483.52 31 11295,08 80.46 18.67 32 11330.80 80,36 18,77 33 11360.59 80.57 19,87 Total disp1 (ft) 2904.18 3003.39 3032,21 3057,85 3083,47 At Azim (deg)' 19.96 19.83 19.81 19,81 19,81 3099 3156 3161 3211 3238 .82 .72 ,59 .84 ,81 19,80 19,80 19,80 19.78 19.78 3312 3367 3391 3438 3497 ,59 ,58 .51 ,37 ,27 19.75 19,73 19.72 19,74 19,80 3551 3608 3632 3715 3763 ,13 .65 .63 ,98 ,76 19,83 19,81 19.81 19,78 19,76 3821 3880 3953 3994 4067 .19 ,99 .58 .55 .18 19.75 19,72 19,65 19,62 19,59 4116 4184 4208 4277 4322 ,83 .28 ,17 ,07 ,67 19.58 19.57 19,56 19.55 19.56 4371,09 4406,30 4435.68 19,55 19.54 19,54 DLS (deg/ 100f) 0.00 3,26 4.61 4,74 2.82 4,45 1,12 0,00 1.24 0,52 1,07 1.51 4,16 3,03 4,17 9,57 2,51 2.15 3.12 3,08 3.03 13,71 3.01 3,49 1,60 3.70 2.24 2.24 4.05 4.35 0,17 0,39 3,71 S rvy tool type TIP MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 1TWD MWD MWD MWD MWD MWD "34 35 36 37 38 39 4O 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 72 11394.71 11487.16 11513.36 11581.00 11614.54 11631.56 11682.00 11702.03 11738.03 11770.01 11796.24 11821.80 11847.14 11893.27 11919.69 11973.15 12 015.61 12076.88 12103.20 12 137.09 12160.18 12178.71 12221.01 12292.00 12315.03 12341.02 12392.22 12423.87 12477.24 12505.23 12542.49 12560.16 12590.68 12614.86 12658.74 12690.26 12712.13 12771.03 12798.74 81 82 82 85 85 85 .03 .40 .85 .65 .20 .45 .33 85.50 85.35 82.90 82.50 82.73 81.33 81.15 81.38 81.53 82.01 81.92 81.59 80.95 81.85 82.65 83.58 86.00 86.80 86.93 88.78 90.68 90.15 90.28 88.55 87.40 87.13 87.13 87.38 87.13 86.30 84.53 82.85 19.17 20.36 20.96 20.62 19.62 20.92 21.04 21.27 20.12 20.17 20.29 20.67 20.87 20.29 21.69 20.68 20.55 21.06 21.11 23.82 25.37 25.64 26.02 26.04 26.24 26.39 24.49 23.04 21.69 21.77 21.92 22.02 22.24 22.49 22.49 22.09 22.09 21.62 20.96 34.12 92.45 26,20 67,64 33.54 17.02 50,44 20.03 36.00 31.98 26.23 25.56 25.34 46.13 26.42 53.46 42.46 61.27 26.32 33.89 23.09 18.53 42.30 70.99 23.03 25.99 51.20 31.65 53.37 27.99 37.26 17.67 30.52 24.18 43.88 31.52 21.87 58.90 27.71 9390.81 9404.13 9407.50 9415.45 9418.71 9420.09 9424.15 9425.76 9428.63 9431.90 9435.23 9438.52 9442.04 9449.07 9453.08 9461.03 9467.11 9475.67 9479.45 9484.59 9488.05 9490.54 9495.62 9502.07 9503.52 9504.94 9506.85 9507.00 9506.62 9506.51 9506.89 9507.52 9508.97 9510.18 9512.29 9513.79 9515.05 9519.76 9522.80 4469.22 4560.70 4586.69 4653.85 4687.23 4704.19 4754.46 4774.42 4810.31 4842.11 4868.13 4893.48 4918.57 4964.16 4990.27 5043.12 5085.14 5145.80 5171.85 5205.31 5228.06 5246.34 5288.12 5358.42 5381.27 5407.06 5457.99 5489.57 5542.89 5570.87 5608.10 5625.75 5656.22 5680.35 5724.13 5755.59 5777.41 5836.09 5863.62 4211.99 4298.08 4322.39 4385.19 4416.53 4432.44 4479.39 4498.01 4531.58 4561.44 4585.85 4609.60 4633.06 4675.74 4700.12 4749.41 4788.75 4845.46 4869.76 4900.72 4921.48 4938.05 4975.85 5039.37 5060.00 5083.27 5129.46 5158.43 5207.78 5233.78 5268.37 5284.74 5312.98 5335.32 5375.81 5404.94 5425.18 5479.67 5505.33 1494.78 1525.72 1534.88 1558.72 1570.21 1576.08 1594.08 1601.29 1613.97 1624.93 1633.92 1642.79 1651.69 1667.72 1677.07 1696.17 1710.97 1732.52 1741.89 1754.68 1764.18 1772.09 1790.38 1821.40 1831.52 1843.03 1865.00 1877.76 1898.06 1908.42 1922.28 1928.89 1940.37 1949.56 1966.32 1978.26 1986.47 2008.32 2018.32 4469.36 4560.84 4586.82 4653.98 4687.35 4704.32 4754.58 4774.54 4810.41 4842.22 4868.24, 4893.58 4918.67 4964.26 4990.36 5043.21 5085.22 5145.88 5171.92 5205.38 5228.12 5246.39 5288.15 5358.43 5381.27 5407.06 5457.99 5489.57 5542.89 5570.87 5608.11 5625.76 5656.22 5680.35 5724.14 5755.60 5777.42 5836.11 5863.64 19.54 19.54 19,55 19.57 19.57 19.57 19.59 19.60 19.60 19.61 19.61 19.62 19.62 19.63 19.64 19.65 19.66 19.67 19.68 19.70 19.72 19.74 19.79 19.87 19.90 19.93 19.98 20.00 20.03 20,03 20.05 20.05 20.06 20.07 20.09 20.10 20.11 20.13 20.13 2.43 1.95 2.85 1.28 5.49 7.75 0.35 1.46 3.21 7.66 1.59 1.71 5.58 1.30 5.30 1.89 1.17 0.84 1.27 8.10 7.70 4.57 2.34 3.42 3.58 0.76 5.18 7.55 2.72 0.53 4,66 6.53 1.16 1.03 0.57 1.50 3.80 3.11 6.50 MWD MWD MWD MWD MWD MWD MWD M-WD MWD MWD MWD MWD MND MWD MWD MWD MWD MWD MWD MWD MWD MWD M'WD M'WD MWD MWD MWD MWD lv[WD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 73 12819.17 82.88 20.71 74 12904.36 82.63 20.44 75 12975.56 82.50 20.35 76 13063.76 82.23 20.24 77 13125.80 81.95 19.98 78 13190.41 82.00 20.14 79 13262.49 82.40 20.34 80 13288.72 82.33 18.84 81 13354.01 82.95 17.87 82 13420.29 83.75 17.64 83 13455.01 83.75 17.37 84 13478.00 82.48 17.54 85 13522.00 80.90 17.34 86 13593.28 80.50 16.46 87 13645.00 80.13 17.24 88 13665.00 80.32 17.32 89 13752.68 83.97 17.14 90 13782.65 84.50 16.94 91 13787.65 84.68 16.96 Projected to TD 92 13835.00 86.40 16.96 20.43 85.19 71.20 88.20 62.04 64.61 72.08 26.23 65.29 66.28 34.72 22.99 44.00 71.28 51.72 20.00 87.68 29.97 5.00 47:35 9525.34 9536.08 9545.29 9557.02 9565.56 9574.58 9584.37 9587.85 9596.22 9603.90 9607.68 9610.44 9616.80 9628.32 9637.02 9640.42 9652.40 9655.41 9655.88 9659.56 5883.89 5968.40 6039.00 6126.41 6187.86 6251.84 6323.25 6349.25 6413.97 6479.75 6514.23 6537.04 6580.53 6650.77 6701.68 6721.36 6808.10 6837.88 6842.85 6889.99 5524.28 5603.40 5669.57 5751.56 5809.26 5869.36 5936.36 5960.85 6022.31 6085.01 6117.92 6139.70 6181.23 6248.54 6297.33 6316.15 6399.09 6427.60 6432.37 6477.52 2025.53 2055.23 2079.84 2110.16 2131.28 2153.23' 2177.93 2186.65 2207.04 2227.12 2237.50 2244.34 2257.39 2277.84 2292.62 2298.47 2324.20 2332.93 2334.39 2348.16 5883.91 5968.42 6039.02 6126.44 6187.88 6251.86 6323.27 6349.27 6413.99 6479.77 6514.24' 6537.04 6580.53 6650.77 6701.68 6721.36 6808.10 6837.89 6842.86 6890.00 20.14 20.14 20.15 20.15 20.15 20.15 20.15 20.14 20.13 20.10 20.09 20.08 20.06 20.03 20.00 20.00 19.96 19.95 19.95 19.93 1.22 0.43 0.22 0.34 0.60 0.26 0.62 5.68 1.76 1.26 0.77 5.62 3.60 1.34 1.65 1.03 4.17 1.89 3.62 3.63 MWD MWD MWD MWD MWD MWD MWD MWD M'WD MWD MWD MW'D MWD MWD MWD MWD MWD MWD MWD DD [(c)2000 Anadrill IDEAL ID6 0C 07] Client ................... : UNOCAL Field ............... , ..... : Trading Bay ANADRILL SCHLUMBERGER Survey report Well ..................... : M-32RDPB1 API number ............... : 50-733-20462-70 Engineer ................. : Nutter Rig: ..................... : 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 .......... : GL above permanent ....... : -350.00 ft KB above permanent ....... : 0.00 ft DF above permanent ....... : 160.25 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: 19.95 degrees 3-Dec-1999 02:40:37 Page 1 of 2 Spud date ............ ' .... : 15-Nov-99 Last survey date ......... : 02-Dec-99 Total accepted surveys...: 26 MD of first survey ....... : 9392.00 ft MD of last survey ........ : 11059.70 ft Geomagnetic data Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 22-Nov-1999 Magnetic field strength..: 1104,.83 HCNT Magnetic dec (+E/W-) ..... : 21.29 degrees Magnetic dip ............. : 73.52 degrees MWD survey Reference Criteria Reference G .............. : 1002.03 mGal Reference H .............. : 1104.83 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-) ..... : 21.29 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 21.29 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [ (c) 1999 Anadrill IDEAL ID6 0C 07] ANADRILL SCHLUMBERGER Survey Report 3-Dec-1999 02:40::37 Page 2 of 2 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) : TVD Vertical Displ Displ depth section +N/S- +E/.W- (ft) (ft) (ft) (ft) 1 9392.00 44.59 17.62 0.00 8517.67 2 9449.89 48.74 19.00 57.89 8557.39 3 9484.80 48.74 19.00 34.91 8580.41 4 9543.00 49.10 19.00 58.20 8618.66 5 9579.89 51.03 19.00 36.89 8642.33 6 9610.92 51.12 19.00 31.03 8661.83 7 9636.32 51.48 15.63 25.40 8677.71 8 9731.61 55.54 15.99 95.29 8734.37 . 9 9799.15 57.05 16.60 67.54 8771.85 10 9893.23 59.79 16.85 94.08 8821.11 11 10017.76 62.96 18.28 124.53 12 10079.87 64.46 19.45 62.11 13 10136.38 66.08 19.72 56.51 14 10235.77 66.78 19.30 99.39 15 10270.00 67.38 19.28 34.23 16 10385.34 67.92 20.36 115.34 17 10488.15 71.67 19.07 102.81 18 10610.27 74.70 19.16 122.12 19 10702.60 78.58 19.51 92.33 20 10745.49 79.62 19.25 42.89 21 10798.01 80.82 19.72 52.52 22 10862.72 81.91 19.51 64.71 23 10919.89 82.18 19.43 57.17 24 11015.30 85.34 19.13 95.41 25 11044.95 84.91 19.48 29.65 26 11059.70 84.93 19.71 14.75 8880.77 8908.28 8931.92 8971.66 8984.99 90281. 85 9064.35 9099.68 9121.01 9129.12 9138.04 9147.75 9155.67 9166.04 9168.56 9169.86 2720.77 2556.01 932.44 2762.85 2595.97 945.68 2789.09 2620.78 954.22 2832.96 2662.26 968.51 2861.24 2689.01 977.72 2885.37 2711.83 985.58 2905.17 2730.75 991.47 2981.57 2804.45 1012.35 3037.64 2858.37 1028.11 3117.65 2935.12 1051.18 3226.85 3039.31 1084.18 3282.52 3092.00 1102.19 3333.84 3140.36 1119.39 3424.94 3226.22 1149.82 3456.46 3255.98 1160.23 3563.14 3356.33 1196.40 3659.60 3447.15 1228.93 3776.47 3557.59 1267.21 3866.28 3642.34 1296.95 3908.39 3682.07 1310.92 3960.15 3730.86 1328.19 4024.12 3791.12 1349.66 4080.74 3844.50 1368.53 4175.57 3934.02 1399.85 4205.11 3961.90 1409.61 4219.80 3975.74 1414.54 Total displ (ft) At Azim (deg) 20.04 20.02 20.01 19.99 19.98 19.97 19.95 19.85 19.78 19.70 2720 2762 2789 2832 2861 2885 2905 2981 3037 3117 3226 3282 3333 3425 3456 .78 .85 .09 .96 .24' .38 .17 .57 .65 .68 .90 .57 .90 .00 .52 3563.20 3659.66 3776.54 3866.35 3908.47 3960 4024 4080 4175 4205 4219 .22 .20 .82 .65 .19 .88 19.63 19.62 19.62 19.62 19.61 19.62 19.62 19.61 19.60 19.60 19.60 19.60 19.59 19.59 19.59 19.59 DLS (deg/ 100f) 0.00 7.38 0.00 0.62 5.23 0.29 10.45 4.27 2.36 2.92 2.74 2.95 2.90 0.80 1.75 0.98 3.83 2.48 4.22 2.50 2.45 1,71 0.49 3.33 1.87 1.56 S rvy tool type TIP MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual t,~Pe 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis -- 6-axis 6-axis [(c)1999 Anadrill IDEAL ID6 0C 07] Re: M-32RD mechanical sidetrack PTD - 99-097 Subject: Re: M-32RD mechanical sidetrack PTD - 99-097 Date: Thu, 09 Dec 1999 14:16:38-0900 From: Blair Wondzell <blair_wondzell@admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: "Billingsley, Tim-Contract" <billita~unocal.com> CC: "Byrne, Don S" <bymeds~Orion. Unocal.com>, "Williamson, Dan R" <williamsond@Orion.Unocal.com>, Tom Maunder <torn_maunder~admin.state. ak.us> Tim, Thanks for the e-mail Nothin9 else is necessary at this time. Blair Wondzell 12/9/99 "Billingsley, Tim -Contract" wrote: M-32RD (Permit #199-97) has experienced drilling problems which have resulted in a mechanical sidetrack. The well was sidetracked from M-32 on 11/19/99 at 9392' MD. The well was drilled to 11,111' MD at which time a bit trip was unable to re-enter the original hole at 10,120' due to coal sloughing and possible ledges. In an attempt to reaquire the original hole, the drill string became stuck 10,093' MD. After several attempts to free the stuck pipe, a fish was left in the original hole with top of fish at 9943'. A 42 bbl cement plug was spotted above the fish and the well is being sidetracked with a kick-off point of 9690' on 12/9/99. The original bottom hole target has not changed. Tim Billingsley 263-7659 1 of 1 12/9/99 2:17 PM MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson,~/~ DATE' November 22, 1999 Chairman tv' THRU: Blair Wondzell, ~~ P. !. Supervisor FROM: Lou Grimaldi,~~ SUBJECT: Petroleum InCpector BOPE Test, Steelhead Unocal #M-32RD McArthur River Field PTD #t9F=9~ ic~c~ .097 Sunday, November 21, 1999: I witnessed the weekly BOPE test on the Steelhead platform which was redrilling Unocal well #M-32RD in the McArthur river field. The rig was breaking down the bottomhole assembly when I arrived and we began testing shortly thereafter. All BOPE equipment was tested with No failures observed. The rig was in good order although there was some evidence of the oil-based mud being used. The crew seemed to be working diligently to contain this to the rig. The accumulator still seems to be working too hard to keep up with the BOP hydraulic demands. The system pressure after closurejstabilized at 1300 psi (1200 psi minimum allowed). It was relayed to me that modifications to the plumbing will be made in order to reduce the excess line capacity which should help this problem. A location change moving the accumulator closer to the BOP stack may also help. This test time was much shorter than the previous test I witnessed due largely to the addition of a triplex pump to the rig for test purposes. SUMMARY: ! witnessed the weekly test of the BOPE on the Steelhead platform redrilling Unocal well # M-32RD in the McArthur River Field. There were NO failures observed. Test time 6 hours. . Attachments: BOP STEELHEAD M-32RD 11-21-99 LG.XLS CC: Dan Williamson (Unocal drilling supervisor) NON-CONFIDENTIAL BOP STEELHEAD M-32RD 11-21-99 LG STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: Pool Rig No. Stlhd PTD # UNOCAL Rep.: M-32RD Rig Rep.: Set @ Location: Sec. Weekly Other DATE: I 1/21/99 199-97 Rig Ph.# 776-6833 Shane Hauck Dave Lancaster 33 T. 9N R. 13W Meridian Seward MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign P Drl. Rig P Hazard Sec. P Quan. Test Press. P/F 250/3500 P I 25O/5, OOO P 1 25O/5, OOO P 1 25O/5, OOO P I 25O/5, OOO P 1 250/5, O0O P 3 250/5,000 P N/A 250/5, 000 N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P p Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Quan. Test Pressure P/F 25O/5, OOO P 250/5,000 P 25O/5,0OO P 250/5, 000 P CHOKE MANIFOLD: No. Valves 12 J I No. Flanges 32 Manual Chokes 1 Hydraulic Chokes I Test Pressure P/F 250/5, 000 P 250/5,000 P P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: Eight Bottles 2,95O P 1,300 P* minutes 50 sec. minutes 14 sec. P Remote: P 2000 average Psig. 'Number of FailureS:. ' 0 ,Test Time: ~...(r~_/l~llo'Urs. N'umber of valves te.~ted' 21 Repair ~'r Replacer~ent of Faiied Equipment will be made within' N/A bta.y.s~. Notify the Inspector and follow with ~i'~en or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Outstanding Test! New triplex test pump greatiy decreased test time, (thanx). PJg in good shape. *Accumulator still working too hard, Location change may help. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspel~.~1L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: M-32RD 11-21-99 LG2 Louis R. Grimaldi TON Y KNO WL ES, GO VERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 2, 1999 Dan Williamson Drilling Manager UNOCAL P O Box 190247 Anchorage, AK 99519-0247 Re~ Trading Bay Unit M-32RD UNOCAL Permit No: 199-97 Sur Loc: 969'FNL. 527'FWL. Sec. 33. T9N. R13W. SM Btmhole Loc. 137'FSL. 2600'FWL. Sec. 21. T9N, R13W. SM Dear Mr. Williamson: Enclosed is the approved application for permit to drill the above referenced well. On October 28, 1999. UNOCAL advised the Commission bv telephone of its intent to dispose of drilling mud and waste from this operation in an approved Class II disposal well rather than down the annulus of the G-22 well (Grayling Platform) as originally requested. Therefore, UNOCAL's original request for authorization under 20 AAC 25.080 for annular disposal is denied. The permit to drill does not exempt you from obtaining additional permits required bx,' law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to xvitness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission at 279-1433. ~~Sinc ~ ' ~ Robert N. Christenson. P. E. Chairman BY ORDER OF THE COMMISSION dlffEnclosures CC; Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o cncl. TON Y KNO WL ES. GO VERNOR AL&SKA OIL AND GA~ CONSERVATION COMMISSION 3001PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 2. 1999 ADMINISTRATIVE APPRIOVAL NO. 80.77 Re: The application of Union Oil Company of California. operator of the Trading Bay Unit (TBU), to drill and complctc the TBU M-32RD well as part of the pressure maintenance project. Shannon W. Martin Land/Lcgal Analvst UNOCAL Corporation P O Box 190247 Anchorage, AK 99519-0247 Dear Ms. Martin: Your application dated Scptembcr 22. 1999 for a "Permit to Drill" TBU xvell M-32RD is proposed to recover additional oil from thc Hemlock Oil Pool. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling and completion of the TBU M-32RD well pursuant to Rule 5 of Conservation Ordcr 80 Donc at :~a~chorage, Alaska and datcd November 2. 1999 Robert N. Christenson. P.E. Chairman Camill60echsli David W. Johnston Commissioner Commissio BY ORDER OF THE COMMISSION Unocal Alaska Resou Unocal Corporation 909 W. 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 UNOCAL Tuesday, October 05, 1999 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Attn: RE: Ms. Wendy Mahan Application for Permit to Drill Steelhead Platform M-32RD Dear Ms. Mahan' UNOCAL is requesting to dispose of M'32RD's.~(Steelhead Platform) Oil Based Mud (OBM) and OBM liquid waste down the G-22's (Grayling Platform) 9-5/8" by 13-3/8" annulus. After performing a technical review of the existing Steelhead annuli, UNOCAL could not find a well that is suitable for disposal of OBM in the annulus. No candidate was identified; because the location of the Steelhead platform is on top of the Grayling Gas Sand structure. The existing Steelhead wells do not extend far enough from the platform or the Grayling Gas Sands. If OBM and OBM liquid waste were disposed of in a Steelhead annulus, the liquid waste would be into injected into an existing or future producing gas sand(s). UNOCAL does not want to jeopardize the overall gas recovery from the Grayling Gas Sands; therefore, we are requesting approval to dispose of OBM and OBM liquid waste in G-22's annulus. CC: Robert Christensen, Blair Wondzell AOGGC disposal letter, doc Sincerely, Dan Williamson Drilling Manager UNOCAL Alaska Naska 0il & Oas Cons. O0mmissi0~_" Anchorage Unocal Alaska Reso s Unocal Corporation 909 W. 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 UNOCAL '. ~ September 22, 1999 Mr. Robert N. Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Trading Bay Unit, Steelhead Platform, Well M-32RD REQUEST FOR SPACING EXCEPTION ADL 18730/17594 Dear Chairman Christenson: RECE!VED :;E.P 2. 1999 -h, jHSKEt. Oil & GaS CODS. Anchorage Enclosed and submitted in triplicate is our application for Permit to Drill Trading Bay Unit, Steelhead Platform Well M-32RD (form 10-401) pursuant to 20 AAC 25.005 and our check No. 2003576 in the amount of $100.00 as required under 20 AAC 25.005(c)(1). Verification of Application by the undersigned stating that applicant is acquainted with the facts, pursuant to 20 AAC 25.055(b), is attached as part of this application. It is requested that the Commission approve an exception to the statewide spacing regulation 20 AAC 25.055(a)(4) for the drilling of Well M-32RD, ADL 18730/17594. Trading Bay Unit Well M-32RD: The specific location, interval and depth are as follows: Surface Location: 969' FNL, 527' FWL, Sec 33, T9N, R13W, SM Top of productive Interval: 1763' FSL, 1449' FWL, Sec 28, T9N, R13W? SM Total Depth and Location: 13,600' MD, 9710' TVD; 137' FSL, 2600' FWL, Sec 21, T9N, R13W, SM Unocal and Forcenergy are working interest owners in the Well M-32RD. Furthermore, Ut.~ocal and Forcenergy are the ownerswand Unocal is the operator of all directly or diagonally offsetting sections. Therefore notices by registered mail pursuant to 20 AAC 25.055(b) are not necessary. If you require additional information, please contact Shannon Martin at 907-263-7882, or Mitch Damm, Drilling Department at 907-263-7679. Very truly yours, on W. Martin Enclosures VERIFICATION OF APPLICATION FOR SPACING EXCEPTION COOK INLET, ALASKA ADL #18730/17594 Well: Trading Bay Unit, Well M-32RD I, SHANNON W. MARTIN, Land/Legal Analyst, Union Oil Company of California, do hereby verify the following: I am acquainted with the application submitted for the drilling of the Trading Bay Un/t, Well M-32RD. I have reviewed the application submitted for the exception to 20 AAC 25.055 (a)(4) (statewide spacing) and all facts therein are true. I have reviewed the plat attached to said application, and it correctly portrays pertinent and required dam. DATED at AnchOrage, Alaska this 22nd day of September 1999. Land/Legal Analyst STATE OF ALASKA THIRD JUDICIAL DISTRICT ) ) ss ) SUBSCRIBED TO AND SWORN before me this 22nd day of September 1999. NOT~ARY PUB/L~~'X~OR THE STATE OF ALASKA My Commission expires: --- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C .MMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill: Redrilh X I lb. Type of well Exploratory: Stratigraphic Test: Development Oil: X Re-Entry: Deepen:I Service: Developement Gas: Single Zone: Multiple Zone: X 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool UNOCAL 160ft KB from MSL McAuthur River Field 3. Address 6. Property Designation Hemlock P.O. Box 19-0247 Anchorage, AK. 99519-0247 ADL-18730/17594 4. Location of well at surface Steelhead Platform Leg B1/Slot # 10 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 969' FNL, 527" FWL, Sec. 33 T9N-13W-SM Trading Bay Unit At top of productive interval 8. Well number Number U62-9269 1763' FSL, 1,449' FWL, Sec 28 T9N-13W-SM M-32RD At total depth 9. Approximate spud date Amount $200,000 137' FSL, 2,600' FWb, Sec 21 T9N-13W-SM ~ [~.l$1et~t 0.413043478 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MO and TVD) property line ADL 18730 = 2,880 acres 137 feet 437 feet ADL 17594 = 4,945 acres 13,600/9,710 MD & ' TVD feet 16. To be completed for deviated wells 17, Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 10490 feet Maximum hole angle: 95 Maximumsurrace 3,233 psig Attotal depth ('rvD) 4,204 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) 8.5 7 29 L-80 Butt-TKC 2,300 9,200 8,378 11,500 9,300 None--slotted liner 6 4.5 12.4 L-80 Butt 2,200 11,400 9,280 13,600 9,710 56 BBLS 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: truemeasuredvertical 10,37812'660 feetfeet Plugs(measured) 105600 Effective depth: measured 10,560 feet Junk (measured) true vertical 9,197 feet Casing Length Size Cemented Measured depth True vertical depth Structural 320 34 Driven 480 480 Conductor 821 26 2445 sacks 981 981 Surface 1187 16 1933 sacks 1347 1347 Intermediate 3607 13-3/8 2244 sacks 3767 3766 Production 10428 9-5/8 2607 sacks 10588 9208 Liner PeRoration depth: measured 9555-9615; 9615-9723; 9846-9883; 9904-9980; 10056-10170; 10170-10200 true vertical 8,630-8669; 8669-8737; 8809-8830; 8841-8883; 8924;8984; 8984-9000 20. Attachments: Filing fee: X Property Plat: X BOP Sketch: X Diverter Sketch: Drilling program: X Drilling fluid program: X Time vs. depth plot: Refraction analysis: Seabed report: 20 AAC 25.050 requirements: 21. I herby certify that the foregoing is true and correct to the best of my knowledge: ~ ~/~ __ Signed: Dan Williamson (~/~ ~///~//( Title: Drilling Manager Date: 9/20/99 Commission Use Only Permit Number I APl number?_ ~'~'-'~"- °,/I- I ApprOVg/al date ,, ,~ /""~'~ ~"~'~' I See cover letter /t¢ ¢- ~' F 50- ~' ..~.~'- .~- for other requirements Condi ions of approval Samples required: [ ] Yes ~No Mud Io required: [ ] Yes Jx~ No Hydrogen sulfide measures ~;~ Yes [ ] No Directional survey required D~JYes [ ] No Required working pressure for BOPE []2M; []3M; ~]5M; []10M; []15M Other: by order of Approved by ORIGINAL. , SIGNED ............ BY Commissioner the Commission ~:.--~,a~: Eobe~ N. Christenson Form 10-401 Rev. 12-1-85 Arl'chor'~gterri Ii ate Sut)mi[~n p c Trading Bay Unit Steeihead Platform Well M-32Rl) PROPERTY PLAT ADL-17594 Unocal Forcenergy ~9 GRAYLING KING h,~--'3 2 RD _28 STEELHEA 33., ADL-18729Unocal TSN Forcenergy Trading Bay Unit Boundary ADL-18772 Unocal 27 ADL-18730 Unocal Forcenergy Unocal UNOCAL STEELHEAD Platform Mo32 slot #B1-10 McArthur River Field TBU, Cook Inlet, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref: M-32Rd Version #9 Our ref: prop3316 License: Date printed: 20-Sep-1999 Date created: 9-Feb-1999 Last revised: 20-Sep-1999 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 50 4.803,w151 36 18.018 Slot location is n60 49 55.256,w151 36 7.381 Slot Gdd coordinates are N 2499532.024, E 214144.151 Slot local coordinates are 969.45 S 527.32 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Measured InclinationAzimuth TVD Depth 9,498.00 9 500.00 9 510.00 9 600.00 9 610.00 9 700.00 9 710.00 9 800.00 9 810.00 9 900.00 10 000.00 10 100.00 10 150.79 10 500.00 11 11 11 12 12 13 13 13 13 000.00 500.00 677.10 000.00 500.00 000.00 500.00 603.67 603.74 Rectangular Coordinates Dogleg Vertical Degree 46.79 46.95 47.80 51.36 51.76 55.35 55.75 59.35 59.75 64.16 69.08 73.99 76.49 76.49 76.49 76.49 76.49 76.49 76.49 76.49 76.49 76.49 76.49 17.36 8,591.75 2,628.32 N 955.19 E 17.60 8,593.12 2,629.72 N 955.63 E 18.77 8,599.89 2,636.71 N 957.93 E 21.30 8,658.24 2701.04 N 981.43 E 21.57 8,664.46 2 23.90 8,717.92 2 24.15 8,723.57 2 21.94 8,771.86 2 21.70 8,776.93 2 20.71 8,819.23 2 19.69 8,858.90 3 18.74 8,890.57 3 18.27 8,903.50 3 708.33 N 984.30 E 775.07 N 1 012.30 E 782.61 N 1 852.49 N 1 860.49 N 1 934.53 N 1 020.65 N 1 110.19 N 1 156.76 N 1 .015.66 E 045.35 E 048.55 E 077.26 E 108.93 E 140.13 E 155.71 E 18.27 8,985.07 3,479.20 N 1 18.27 9,101.85 3,940.86 N 1 18.27 9,218.64 4,402.52 N 1 18.27 9,260.00 4,566.04 N 1 18.27 9,335.42 4,864.17 N 1 18.27 9,452.20 5,325.83 N 1 18.27 9,568.99 5,787.49 N 2 262.17 E 414.59 E 567.01 E 621.00 E 719.44 E 871.86 E 024.28 E 18.27 9,685.77 6,249.15 N 2,176.70 E 18.27 9,709.99 6,344.88 N 2,208.31 E 18.27 9,710.00 6,344.93 N 2,208.33 E Deg/100ft Setction 0 2,795.28 12.07 2,796.74 12.07 2,804.09 4.5 2 872.56 4.5 2.880.38 4.5 2 952.53 4.5 2 960.74 4.5 3 036.40 4.5 3 045.01 5 3 124.32 5 3 216.02 5 3 310.83 5 3 359.94 0 3 699.49 0 4 185.66 0 4,671.83 0 4,844.04 Hmlk B-3 Top 0 5,158.01 0 5,644.18 0 6,130.35 0 6,616.52 0 6,717.32 5 6,717.38 M-32Rd Hmlk Base 15-APR- All data is in feet unless otherwise stated. Coordinates from slot #B1-10 and TVD from wellhead (160.25 Ft above mean sea level). Bottom hole distance is 6718.25 on azimuth 19.19 degrees from wellhead. Total Dogleg for wellpath is 31.99 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 18.27 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Comments in wellpath MD TVD Rectangular CooRs. Comment 11677.10 9260.00 4566.04 N 1621.00 E Hmlk B-3 Top 13603.74 9710.00 6344.93 N 2208.33 E M-32Rd Hmlk Base 15-APR-99 Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bet MD Bet TVD Rectangular Coords. Casing n/a 8591.75 2628.32N 955.19E n~ 8591.75 2628.32N 955.19E 26" Casing n~ 8591.75 2628.32N 955.19E n~ 8591.75 2628.32N 955.19E 16" Casing n/a 8591.75 2628.32N 955.19E n/a 8591.75 2628.32N 955.19E 13 3/8" Casing n~ 8591.75 2628.32N 955.19E n~ 9710.00 6344.93N 2208.33E 9 5/8"Casing n~ 8591.75 2628.32N 955.19E n~ 9710.00 6344.93N 2208.33E 7" Casing n/a 8591.75 2628.32N 955.19E n/a 9710.00 6344.93N 2208.33E 5 l~"Liner Ta~ets associated with this wellpath Tarot name Geographic Location T.V.D. Rectangular Coo~inates Revised M-32Rd Hmlk B-3 Top 215582.000,2503958.000,0.0000 9260.00 4459.85N 1329.17E 15-Ap~1999 M~32Rd Hmlk Base 15-216507.000,2505821.000,0.0000 9710.00 6344.93N 2208.33E 15-Ap~1999 UNOCAL RKB = 75.15' Rig Floor to TBG Hanger Bridge Plug: ~ 10,560' l'.~?'.?'..':'..':'.?'.. ~'.~ Cement Plug: :;.................,.- 11,632'-10,578' :k~ 11,111L11,757' TD = 12,660' MD; PBTD = 10,560' 23° ~ 1,800'; 58° ~ 10,400'; 89° ~ 11,255' Steelhea0_ ,atform Well # M-32 Completed: 2/15/95 S~E WT Casing and Tubing Detail GRADE CONN ID MD TOP MD BTM. 16" 75 13-3/8" 68,61 9-5/8" 47 Tubing: 4-1/2" 12.6 K-55 Buttress 15.124 Surf. 1,345' K-55 Buttress Surf. 3,722' N-80 Buttress 8.835 Surf. 10,588' L-80 AB Mod- 3.958 Surf' 9,528' Buttress NO Depth ID Jewelry Item 40' 4.00" 410' 3.812" 1,850' 3.833" 2,878' 3.833" 3,433' 3.833" 4,013' 3.833" 4,562' 3.833" 5,114' 3.833" 5,727' 3.833" 6,376' 3.83Y' 7,084' 3.83Y' 7,787' 3.833" 8,517' 3.833" 9,220' 3.833" 9,413' 3.875" 9,417' 4.75" 9,431' 4.75 9,480' 3.813" 9,526' 3.725" 9,528' 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 locator and seal assembly Baker 96A4-60 SC-1LR Packer Baker sealbore extension Camco X nipple Camco XN nipple Mule Shoe Fish/Fill Information: A. 2.25" G.R. set down in GLM #12. Tag fill ~ 10,496' on 2/22/99. B. 3.375" SWS CCL tag fill ~ 10,622' on 3/24/98. Perforations Date Zone Top BTM Comments 2-7-95 SQZ 9,566'; 9,568' 2/95; 6/95; 3/98 G-1 9,555' 9,615' 2/95; 6/95; 3/98 G-2 9,615' 9,723' 2/95; 6/95; 3/98 G-3 9,846' 9,88Y 2/95; 6/95; 3/98 G-4 9,904' 9,980' 2/95; 6/95; 3/98 G-5 10,056 10,170 2/95 G-5 10,170 10,200 Squeezed with 30 BBLs of cement 6 SPF, 3-3/8" HC 6 SPF, 3-3/8" HC 6 SPF, 3-3/8" HC 6 SPF, 3-3/8" HC 6 SPF, 3-3/8" HC 6 SPF, 3-3/8" HC M-32 2-15-95.doc REVISED: 8/30/99 DRAWN BY: MWD Project Team Well M-32 RD Keith Olson _.: Tony Tykalsky ~ Jim Brown FieldEnginee~~ 2,~ l'i ;: ?ra. igBieber ~ Warehouse Manager~~ .... ~ Deen Bryan Tech Service MI Project Engineer and Tech Service Engineer will coordinate between the Unocal office, rig, ware- house, and the M-I field engineers. Well progress will be monitored to look for any changes which will improve the efficiency of the opera- tion or avert trouble.. Project Team Title Work Cellular Craig Bieber District Manager 907 274-5051 907 229-1196 Deen Bryan Tech Service 907 274-5003 907 223-1634 Tony Tykalsky Project Engineer 907 274-5011 907 227-2412 Gus Wik Warehouse Manager 907 776~8680 907 252-4218 Jim Brown Field Engineer 907 776-6833 Kieth Olson Field Engineer 907 776-6833 Iii i I I · M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax I II I I I · DRILLING FLUID5 Dri~ing F~uids Program UNOCAL Stee]head Platform We~ M--32 RD Prepared by: Reviewed by: Presented to: Deen Bryan Mitch Damm ~;~ ~ ~ember I999 M-[ Drilt~ng F1uids L.L.C. ~,~o~,or~,, ^~k~ 99~01 (907) 274~5564 (907) 279-6729 Fax DRILLING FLUIDS M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 P~one (907) 274-5564 Fax (907) 2709-6729 .. September 21 st, 1999 UNOCAL 909 West 9th Avenue Anchorage, Alaska 99501 ATTN: Mitch Damm Mitch; Enclosed is a recommended mud program for the M-32 RD Well to be drilled on the Steelhead Plat- form this fall. Included is a project summary, interval summaries, an economic summary for each in- terval, and the project team. This well (like Well G-15RD, Grayling Platform, 1998), will be drilled using the oil mud stored on the Granite Point Platform as the base fluid. Cost estimates have been based on the average cost per foot of Well G- 15RD. Approximately 1000 to 1100 barrels of fluid w/il be needed initially to begin drilling the 8 1/2" interval. This fluid can be transferred from the Granite Point Platform using the three 120 barrel ISO tanks that MI Dlqlling Fluid has in Kenai. These tanks can also be used for hauling base fluid to the platform for dilution purposes. A centrifuge is recommended for this well in order to keep the mud weight down to a minimum and to keep the dilution rate as low as possible. The completion portion of this well will use 3% KC1 brine unless a change is dictated by Unocal. Please call me if you have any questions regarding the mud program. Tony Tykalsky Project Engineer M-I Drilling Fluids Project Summary i i I II I I I II Well M-32RD Casing Hole Size Size Casing Program Depth TVD Mud Mud Cumulative System Weight Mud Cost Existing 9 5/8" 12 1/2" 7" 8 1/2" 4 1/2" 6" 9,500' 8,593' 11,500' 9,300' 13,600' 9,170' N/A Versaclean 8.8 - 9.4 $58,875 Versaclean 8.6 - 8.9 $155,575 Completion 13,600 9,170' 3% KC1 8.6 $163,100 Key Iss u e No. 1 Hole Cleaning · Consider pumping weighted high viscosity sweeps to aid in hole cleaning. Key Issue No. 2 Lost Circulation Maintain an adequate stock of LCM products on location to use in case of lost circulation. Key Iss. e No. 3 Drill Solids Run as fine a mesh shaker screen as possible. Run centrifuge during trips to reduce drill so lids in mud. / M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax I i I I i i rl~ BRILLIN6 FLUIDS Economics Summary Well M-32RD · i .iiii I I I II I ii I i i i i Well Target Cumula- Product Engineering Cumulative M-32 RD DaYs rive Days Costs Costs Cost ~ ($) ($) ($) , 9,500 - 11,500' 19 19 $47,000 $11,875 $58,875 11,500- 13,600' 22 41 $82,950 $13,750 $96,700 Completion 4 45 $4,495 $2,500 $7,525 · Well cost includes full time engineering service. · Completion fluid cost includes spacer and 3% KC1 brine. · Cost does not include any provisions for lost circulation, etc. · Cost assumes 1100 bbls of initial fluid brought from storage on the Granite Point Plat- form. · Overall cost are based on average cost from Well G-15RD, Grayling Platform, 1998. · Cost assumed 1600 bbls of 3% KC1 brine needed for completion. II I I II ii i i M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax i i i i i II I I I i i i i i DRILLINC; FLUIDS Interval Summary (8 1/2" hole) Well M-32RD ii i i i i I I ! I I I i 9,500 - 11,500' Drilling Fluid System Key Products Solids Control Potential Problems Mapco 200 Oil Base Mud VG-69 / M-I BAR / Mapco 200 / Versacoat / Versawet / VersaHRP Versamod / Alcomer 274 / Lime / CaC12 Shale Shakers / Desander / Desilter / Centrifuge Hole cleaning, lost circulation, coal sloughing, high gels Interval Drilling Fluid Properties Depth Mud Plastic Yieid HTHP Interval Weight Viscosity Point Fluid Loss O/W Ratio Gels (ft) (ppg) (cp) (lb/100fF) (rnl/30min) (Ib/100fF) "'915i30 - 11,500" 9.0 - 9.3' " 25 - 35 15 - 20 4 - 6 cc's 80/20 15/30 · Transfer oil mud from Granite Point Platform. Initial volume required should be 1000 - 1100 barrels. · Blend and roll the drilling fluid in the pit system and condkion as needed to bring the fluid up to the recommended specification. · For building new volume use the following mixing procedure. · Prernix 10.8 ppg calcium chloride brine · Place Mapco 200 oil in a clean mixing tank Add VG-69 and lime slowly through a shear pump if possible to minimize bailing. Shear for at least thirty minutes. Add primary emulsifier, Versacoat and blend for th/try minutes. Add CaC1 brine and blend for at least minutes. Add Versawet, check rheology, and add Versamod as needed. ii ii I M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) ~79-6729 Fax i I II I I I I I II I i i i i rll DRILLING FLUIDS Interval Summary (6" hole) i i i I I I I I I Well M-32RD i i I I I II 11,500 - 13,600' Drilling Fluid System Key Products Solids Control Potential Problems Mapco 200 Oil Base Mud VG-69 / M-I BAR / Mapco 200 / Versacoat / Versawet / VersaHRP Versamod / Alcomer 274 / Lime / CaC12 Shale Shakers / Desander / Desilter / Centrifuge Coal sloughing, drill solids buildup, lost circulation ' Interval Drilling Flu'id ProPerties Depth Mud Plastic 'Yieid ' HT~P Interval Weight Viscosity Point Fluid Loss O/W Ratio Gels (fi) (PPg) (cP) (Ibd 00ft2) (ml/30min) (Ib/100ft 11,500 - 13,600, 8.6 - 8.9 25 - 35 15 - 20 4 - 6 cc's 80/20 15/30 ~~'-~- ~..~i~ '-~ '.'-~ ~ '~-~ ........ k..~ ~, ~,.~. -~ ~,., ~_.~.. ...... , .~ .~ . ~ . .; ~ ..,._~.. ~ ....... . ~ ..~- After running and cementing 7" liner, run centrifuge to lower mud weight as much as possible. · Use Mapco 200 to reduce mud weight back to 8.6 - 8.9 as needed. · Maintain low shear rate values with VG-69, versamod, Alcomer 274, and VersaHRP. · Drill 6" hole to T.D. Run and cement 5" liner. · Displace well to brine/diesel after running tubing. Use a Safekleen spacer for cleanup purposes. ~1 i ii i i i II I II I I I i · M-I Drilling Fluids L.L.C. 721 West Fkst Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRILLING FLUIDS UNOCAL RKB = 75.15' Rig Floor to DCB TBG Spool TOL ~ 9,200' TOL ~ 11,600' TD = 13,60Y ~4 ~,. STEELI-L ,I) PLATFORM WELL #: M-32RD PROPOSED COMPLETION SIZE WT CASENG AND TUBING DETAIL 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. 10,588' Window 7" 29 L-80 Buttress 6.184 9,200' 11,700' 4-1/2" 12.6 L-80 Hydrill 511 3.958 11,600' 13,603' 4-1/2" pre-drilled liner has ~" predrilled holes~8 hpf Tubing: 4-1/2" 12.6 L-80 LTC 4.892 Surf 9,150' JEWELRY NO Depth ID Item 1 42.9' 4.930" 2 FMC TC-1A-EN 16" TBG Hanger, 4-1/2" Mod Butt connection W/CIW type H BPV profile #6 5-1/2" SF-02 McMurry GLM w/1-1/2" R-2 valve #5 5-1/2" SF-02 McMurry GLM w/1-1/2" R-2 valve #4 5-1/2" SF-02 McMurry GLM w/1-1/2" R-2 valve #3 5-1/2" SF-02 McMurry GLM w/1-1/2" R-2 valve #2 5-1/2" SF-02 McMurry GLM w/1-1/2" R-2 valve #1 5-1/2" SF-02 McMurry GLM w/orifice Centralift ESP Perforations Date Zone Top BTM Comments Proposed G-Zone M-32RD Proposed. doc REVISED: 9/21/99 DRAWN BY: MWD Unocal Alaska Busim.., Unit Steelhead Platform Well #M-32 UNOCAL ) Preliminary Abandonment and Drilling Program Kill Well Kill well with FIW. Pull 1 2 3 4 5 6 7 8 9 Completion Set BPV in hanger. ND Tree. NU BOPE. Pull BPV and set two-way check. Test BOPE. RIH with landing joint and engage tubing hanger. Pull hanger loose and circualate well. LD tubing hanger and POOH and LD tubing. Run wear bushing. Abandon M-32 10 PU 9-5/8" cement retainer. 11 RIH with brdige plug on wireline. t2 Set brdige plug @ 9,500'. 13 POOH and RD wireline unit. Mill Window 14 MU whipstock/milling BHA 15 RIH with one trip whipstock assembly. 16 Orient whipstock. Set packer/whipstock @ 9490'. 17 Mill window in 9-5/8" casing. 18 Circulate bottoms up. 19 POOH with setting tool. 20 LD mills and MU drilling BHA. 21 Test BOPE. 22 RIH with BHA. 23 Drill 8-1/2" hole. 24 Circulate and condition mud system. 25 POOH with BHA. Run 26 27 28 29 30 31 32 33 and Cement 7" Liner RU casing crews for 7" liner Change casing rams and test BOPE RIH with 7" liner. Continue to RIH with 7" liner on 5" drillpipe. Circulate and condition hole for cement. RU for cement job. Pump cement job and set liner hanger. POOH and circulate out cement. Continue to POOH. AOGCC Procedure.xls Page 1 of 2 9/17/99 Unocal Alaska Busim..~ Unit Steelhead Platform Well #M-32 UNOCAL ) Preliminary Abandonment and Drilling Program Drill 34 35 36 37 38 39 4O 41 6" hole to TD. MU 6" BHA. PU 3-1/2" Drillpipe while RIH RIH with BHA. Ream to bottom. Drill 6" hole. Circulate and condition mud system. POOH with BHA. BHA handling. Run 42 43 44 45 46 47 48 49 $0 51 $2 54 §6 ~7 Slotted Liner Change top pipe rams Test BOPE. RU casing crews. RIH with slotted liner. RIH with 2-3/8" PAC drillpipe. Continue to RIH with liner on drillpipe. Set liner hanger and release running tool. POOH with running tool. Change well over to diesel. MU stinger, 6" bit, 7" csg scraper, and 9-5/8" cg scraper. RIH with cleanout assembly. Wash down to top of slotted liner. Circulate hole clean. POOH with scrapers LD 6" bit and scrapers LD BHA. Run Completion 58 Pull wear bushing. 59 RU ESP completion. 60 PU, rabbit and run 4-1/2" completion 61 Space out and PU hanger. 62 Land hanger. 63 ND BOPE. 64 Install tree and test. 65 Turn well over to Production. AOGCC Procedure.xls Page 2 of 2 9/17/99 Kill Line Choke Line M-32 BOP Drawing.doc Revised by MWD 9/17/99 Mud Return Equalizer Agitator Mud Gun Steell~ead Pit Drawi~g.doc Revised by MWD 9/17/99 DATE 22-SEP-99 INVOICE/CRED T MEMO NO, DRILLPERMITM32R FORM 4-2B181 (REV. 11-95) PRINTED IN U.S.A. l).~: i)t..'.~i ~ ~i;'~" .i~l ~.~.~ l i~ t"i~ .; ',. ~:'.;I ~ il ~l ... <, ,i VOUCHER NO. 09993000553 GROSS 100.00 DATE CHECK NO. 9-22--99 2003576 DISCOUNT VENDOR NO. 1031548 100.00 NET 100.00 100.00 CITIBANK DELAWARE 62-20 A Subsidiary of Citicorp '31'1" ONE PENN'S WAY NEW CASTLE, DE 19720 Union Oil Company of California Accounts Payable Field Disbursing UNOCAL P~ One Hundred Dollars And 00 *********************************** 2005576 To the order of STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DR ANCHORAGE, AK 99501 200~S?GI1' m:O:',l,i, OOi]Oqm: Date Check Amount V 22-SEP-99 ******100.00 Void after six months from above date. WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION COMPANYc/",./4,J¢9~,/~ WELLNAMET"~.,.,~'/' /¢~-..~.2.,v'~/PROGRAM:exp dev ,~ redrll ? serv__wellboreseg__ INIT CLASS ,~/'~_,,y_.~.,' /'",~,? GEOL AREA ~'.2_.(~ UNIT# ,/-~(~ ~'~ ENGINEERING .TyP P R DATE 1. Permit fee attached ....................... 2. Lease number appropriate ........ ........... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is 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 ........... GEOLOGY 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 ..~Q)~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... ann. disposal para req_ ON/OFF SHORE O~-/' APPR DA~E/ ,,Cz Y N /~.~ 31. Data presented on potential overpressure zones ....... ./m ~(.~- 'Y' '~ /~ )j 32. Seismic analysis of shallow gas zones ............. ~ ,, 33. Seabed condition survey (if off-shore) ............. ,,~ N 34. Contact name/phone for weekly progress reports [exploratory onljc]/Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N APPR DATE GEOLOGY: ENGINEERING: ~0iC/~nnular JDH ' - COMMISSION: DWJ ,~ ~-~ RNC '"- CO cc) ~/,[~! Comments/Instructions: / .,' 0 Z 0 ---I c:\m soffice\wordian\diana\checklist
