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Home My WebLink About209-004 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑✓ ' Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAGE 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.: 6/5/2017 209-004/317-099 d 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 July 24,2009 50-733-20585-00-00,, 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 1035'FNL,592'FWL,Sec 33,T9N, R13W,SM,AK September 1,2009 TBU M-06 , Top of Productive Interval: 9. Ref Elevations: KB: 160' 17. Field/Pool(s): McArthur River Field GL:0 BF:72' Middle Kenai Gas Pool . Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 890'FSL,2024'FEL, Sec 21,T9N, R13W,SM,AK 7,279'MD/4,880'MD• ADL018730&ADL017594. 4b.Location of Well(State Base Plane Coordinates,NAD 27): ,.- 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 2142>2 y- 2499431 , Zone- 4 12,502'MD/8,770'TVD , N/A TPI: x- y- Zone- 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 217035 y- 2506603 Zone- 4 N/A N/A 5. Directional or Inclination Survey: Yes Lf (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) ,7 279 M Qnn_. snin 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 SEP 2 za��, RECEIVED SCANNED .AUG 0 2 2017 CCC 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. TOP BOTTOM TOP BOTTOM PULLED 28" X-56 Surface 470' Surface 470' Driven N/A • 13-3/8" 68# L-80 Surface 1,401' Surface 1,371' 17-1/2" 525 bbls 9-5/8" 47# L-80 Surface 7,279' Surface 4,880' 12-1/4" 573 bbls 24.Open to production or injection? Yes ❑ No Q 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number;Date Perfd): 4-1/2" Cut @ 8,594' N/A PtLAN+OoN 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. CO)AAP'LE T-1O1+ f)ATE Was hydraulic fracturing used during completion? Yes ElNo Q .",.9j5/117` Per 20 AAC 25.283(i)(2)attach electronic and printed information VERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED LL- 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period — Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate .—► Form 10-4_07 if /5/2017 y / CONTINUED ON PAGE 2 RBDMS (,1� AUG - 3 2017 Submit ORIGINIAL onl�� /z /lK� �i�)14-111 • • 28.CORE DATA Conventional Core(s): Yes ❑ No ❑., Sidewall Cores: Yes ❑ No Q 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 2 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 N/A information, including reports,per 20 AAC 25.071. RECEIVED AUG 0 2 2017 AOGCC Formation at total depth: 31. List of Attachments: Wellbore Schematic, Decomplete Reports. Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Paul Mazzolini Contact Name: Cody Dinger Authorized Title: Drilling Manager Contact Email: cdinger hilcorp.com Authorized ----LetContact Phone: 777.8389 Signature: Date: � �� I 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 III •• Steelhead Platform Well: M-06 Abandon Schematic Abandoned:6/5/2017 PTD: 209-004 Hilcorp Alaska,LLC API: 50-733-20585-00 RKBtoTBGHead-78' CASING DETAIL Size Wt Grade Conn ID Top Btm ECP Stage Cdlar @ 28" Conductor 27" Surf 470' 13-3/8" 68 L-80 BTC 12.415" Surf 1,401' 28 r I 44s 9-5/8" 47 L-80 BTC-M 8.681" Surf 7,279'(KOP) '2 .. Est TOC @92d 7" 26 L-80 DWC 6.276" 7,346' 12,494' TUBING DETAIL 4-1/2" 12.6 L-80 TC-II 3.958" 8,594' 8,902' / � 133/8" / JEWELRY DETAIL .. No Depth Depth ID OD Item (MD) (ND) 1 7,300' CIBP a 8,604' 5,665' 3.850 5.960 BOTS-3 Production Packer b 8,625' 5,678' 3.813 5.000 X Profile c 8,803' 5,783' 3.700 5.020 BOT Gun Drop Sub ' d 8,902' 5,840' E-Line Cut End of Tubing e 9,099' 5,950 Tubing Tail Fish ,` f 9,450' 6,141' 7"PosiSet Plug w/cement on top ,_; g 11,730' 8,011' 7"PosiSet Plug w/cement on top it Window Stage Collar h 12,330' 8,601' 7"PosiSet Plug w/cement on top ll milled F/ Mr @5,806' 7,279'to 7,296' ';. PERFORATION DETAIL 0 0.` Top Btm Top Btm Zone FT Date Status aBP7,301 4 '.. �. - .... ,, 1 (MD) (MD) (TVD) (TVD) r, s+'' 014 8,932' 8,940' 5,857' 5,861' 8' 3/1/2011 Open • TOC @±7881' D14 8,950' 8,966' 5,867' 5,876' 16' 3/1/2011 Open -0 v D16B 9,210' 9,230' 6,011' 6,021' 20' 2/27/2011 Open a i. ' ' D16B 9,235' 9,245' 6,024' 6,030' 10' 2/27/2011 Open u• +' D16C 9,278' 9,298' 6,047' 6,058' 20' 2/28/2011 Open D16C 9,308' 9,328' 6,064' 6,074' 20' 2/28/2011 Open '. '' D16C 9,341' 9,351' 6,081' 6,087' 10' 2/28/2011 Open a s F6 11,382' 11,390' 7,669' 7,677' 8' Plugged b 4 x F7 11,430' 11,442' 7,716' 7,728' 12' Plugged c F11 11,739' 11,762' 8,020' 8,043' 23' Plugged dE �,� G04 12,342' 12,366' 8,613' 8,636' 24' Plugged Top ofMtubirg ►g� -----•-- Tag fill @9386 Es[.9,099' RKB ELM , f , g;.,.. ''''''Sal r Tag TOC @9,417 R _RKB ELM Tag TOC @11,666 RIB am h ' ._ �' iTag TOC @32,317 - RKBAM PBTD:7,279' TD:12,502' p, t;ki Updated By:CJD 8/2/17 • • Hilcorp Energy Company Composite Report Well Name: MRF M-06RD Field: McArthur River County/State: Cook Inlet Offshore Steelhead,Alaska (LAT/LONG): 9vation(RKB): API#: Spud Date: Job Name: 1711197P M-06RD PreDrill Contractor AFE#: 1711197P AFE$: :.nom.:.................::v:;v:.�;r.;., .....................: ,,,........................:::::::.... ::'.:......:ii::i>:::.::.i:, ...........::...................:.:................................................::::.:.:.. 5/27/2017 Rig&blow down lines in upper well bay of B1 leg. Prep rip for skid.Rip accepted at 06:00 hrs.,Disconnect lines in lower well bay of B1 leg.Remove earthquake clamps,stairs,lay skate ramp over.,Skid upper section of sub base 9',to center weight load.Secure upper section&install earthquake clamps.,lnstall lower grippers,remove earthquake clamps on lower sub,install lower guide plates,&work on handrail install on top of SCR house.,Skid sub base 5'towards B-2 leg.,Rig down skate&move to center deck. Un-lug main power to the rig&secure for skid.Hook up umbilical electrical to rig.,Skid towards B-2 leg.Secure rig with earthquake clamps. Rig up wire line on M-06.,RIH with wire line,making a guage run 3.56"to 8600'MD.Rig down wire line.SIMOPS remove kill&choke hoses in the BOP deck.Disconnect Koomey hoses in upper well bay.,RIH with wire line,making a guage run 3.56"to 8600'MD. Rig down wire line.SIMOPS remove kill&choke hoses in the BOP deck.Disconnect Koomey hoses in upper well bay.,Skid rig to make room for crane to transfer service lines f/B-1 to B-2 leg.,Move service lines f/B-1 to B-2 with crane.Install new kill&choke lines in BOP deck.Install service lines in B-2 leg. 5/28/2017 Hook up service lines in NE wellbay. Install new kill&choke hoses w/new rotating cushion tees.,Rig up Pollard e-line.RIH w/3.5"jet cutter&cut 4-1/2"tubing at 8598'WLM(cut tubing in the middle of the pup below the packer).Rig down lubricator&move e-line unit.SIMOPS clean grease from skid rails,cont.kill& choke install,&store old kill&choke in crate for spare.,Crane NE hatch covers to NW leg.SIMOPS clean NW trough of mud debris.,Remove east side outer jack cylinder&gripper to west side outer of sub base.,Continue to skid rig towards NE leg.SIMOPS centrifuge OBM to drop weight to 8.9 ppg.,Remove east side inner jack cylinder&gripper to west side inner of sub base.Remove handrails,reroute umbilical cable,&prep/grease skid rails.,Skid rig to NE leg, centering over M-06.,Move north&south diverter lines to access wellhead.SIMOPS install hand rails.,Finish moving diverters&loosen earthquake clamps on upper sub box.Center rotary table over M-06.SIMOPS install hand rails&grating walkways.,Install&tighten earthquake clamps.SIMOPS install hand rails& grating walkways.,Install service lines from well bay to the rig.SIMOPS flush accumulator lines from unit to NE upper well bay.,Prepping deck to move skate into position.SIMOPS flush accumulator lines from unit to NE upper well bay. Production circulating down tubing taking returns from IA&shipping to Trading Bay.,M-06RD wellhead pressures;9-5/8X4-1/2=590 psi, 13-318X9-5/8=0 psi, 28X13-3/8=0 psi, Fluid loss to well today:0 bbls Total:0 bbls 5/29/2017 Prepping deck to move skate into position,install grating walkways,&flush accumulator lines from unit to NE upper well bay. Production circulating down tubing,3bpm,590 psi,taking returns from IA&shipping to Trading Bay.,Move skate via crane into position&rig up.Lug up electrical to the rig.Disconnect electrical umbilical&store.Flush accumulator lines from unit to NE upper well bay,filter accumulator oil,&C/O 4 way valve for choke on accumulator unit.Production circulated 557 bbls of FIW down tubing,3bpm,590 psi,taking returns from IA&shipping to Trading Bay.,String up cables on pipe skate.Change out saver sub on the top drive.Fill glycol lines on the rig.Cut out&remove mud trough box.,Rig up&route hose from the rig to the small vac unit.Rig up to re-position skate.,Reposition skate&rig back up.,lnstall BPV,nipple down the tree&flow line,remove same from wellbay.Clean& inspect hanger void.Function lock down screws&install blanking plug.SIMOPS grease choke manifold.,Nipple up spacer spool,lower&upper high pressure riser onto wellhead.,Finish nipple up of high pressure risers.Set BOP stack on risers,nipple up same.Install kill&choke hoses.Install Koomey lines in NE upper well bay&route up to BOPE.,"M-06RD wellhead pressures;9-5/8X4-1/2=0 psi,13-318X9-5/8=0 psi,28X13-3/8=0 psi, Fluid loss to well today:0 bbls Total:0 bbls" 5/30/2017 Cont.N/u BOPE,install flow nipple flanges&flow nipple,finish install of accumulator Iines.,Pressure up accumulator system,function test BOPE from all stations,m/u subs for 4 1/2"tj.,Pull flow nipple&modify,open&inspect upper ram blocks,re-install flow nipple.,Install 4 1/2 tj,r/u test eq.fill stack& manifolds,tighten leak on air boot flange on annular,shell test 250&3500psi,repair leak on riser hub connection,repair test pump,re-test good.,Test BOPE as per Hilcorp&AOGCC standards,test w/4 1/2"&5"tj's,250/3500psi,test Witnessed by AOGCC inspector Matt Herrera,had F/P on CMV#5,serviced& retested good,F/P on lower IBOP,changed out valve tested good,tested all gas alarms good.,Change out lower IBOP&gripper dies.,M-06RD wellhead pressures;9-5/8X4-1/2=0 psi,13-3/8X9-5/8=0 psi,28X13-3/8=0 psi, Fluid loss to well today:0 bbls Total:0 bbls 5/31/2017 C/o regulator on test pump,r/u&test HP line f/pump room to rig floor through TDS t/4600 psi f/15min good.,L/d test tools.,Troubleshoot&repair indicator lights on BOPE remote panels,housekeeping cellar,re-plumb,air to super choke,change out PRV on accumulator.,R/u pull blanking sub&BPV,m/u landing jt.,Pressure up well bore U500psi hold f/20 min.,Back out LD pins,pull hanger free w/string up wt 145k,CBU through gasbuster @ 6BPM,230 psi,shut down monitor well,static.,Pull&l/d hanger,r/u handling eq.t/l/d 4 1/2"completion.,POOH I/d 4 1/2"TC-II,f/8598't/6364'up wt 120k,dn wt 115k,I/d SSSV, 1- GLM,1 chem inj sub, 69 jts 4 1/2"tubing, SS ctrl line,recover 73 SS bands.,Cont.POOH I/d 4 1/2 completion f/6364',t/5728',up wt 115k,dn wt 110k.,Cont. POOH I/d 4 1/2"tubing,I/d 187jts,3 GLM,SSSV,chem inj sub.,M-06RD wellhead pressures;9-5/8X4-1/2=0 psi,13-3/8X9-5/8=0 psi,28X13-3/8= 0 psi, Fluid loss to well today:0 bbls Total:0 bbls • 6/1/2017 Cont.1/d 4 1/2"completion,1/d total of 263 jts,1-SCSSV,4-GLM,chem inj.sub,sliding sleeve, 14 pups, 1 cut jt 3.84'.,Clean&clear floor,c/o handling eq.p/u test eq.f/4".,Test BOPE,w/4"tj,250 low,3500 high,test upper&lower rams,annular,4"safety valves,&rebuilt lower Kelly valve(spare)good.,R/d test jt, install wear ring,clear test tools from floor.,M/U BHA#1,-6"mill tooth bit,7"csg scraper,2-4 3/4"boot baskets,bit sub w/float,xo,40 jts 4"dp,xo,double pin sub,9 5/8"csg scraper,2-7"boot baskets,bit sub,8.5"watermelon mill,flex jt,6-jts 5"HWDP,jar&bumper sub,11-jts 5"HWDP=1856.20'.,TIH w/5"dp from derrick,t12804',Training,cont.tih practice making connections w/new Driller t/3751', fill pipe.Up wt 12,dn wt 110.,Cont.tih U tag top of cut @ 8594'DP measurement,(clean through TOL @ 7346').,CBU @ 14 BPM,2000 PSI,while reciprocating,up wt 225k,dn wt 150k.,POOH t/7162'.,Service rig,Cut&slip Drill Iine.,M-06RD wellhead pressures;9-5/8=25 psi,13-3/8X9-5/8=0 psi,28X13-3/8=0 psi, Fluid loss to well today:0 bbls Total:0 bbls 6/2/2017 Service rig,cut&slip drill line,cut 110'.,Cont.POOH standing back 5"dp t/1856'.,1Jd 9 5/8 scraper assy.recover 10 pieces SS banding total length 4 bands.,Cont.POOH stand back 6 stands 4"DP, UD remaining 22 jts 4"dp,&7"scraper assy.recover one SS band.,C/o handling eq.prep&p/u cmt stinger assy,-Mule shoe cmt stinger,27 jts 3 1/2"tubing,dual xo,18 jts 4"dp,xo=1434.79.,Cont.TIN w/5"dp t/6172',up wt 160k,dn wt 13k.,Cont.tih t/top of tubing cut @ 8594',up wt 205k,dn wt 150k, (passed through liner top @ 7346'clean).,PJSM,r/u t/pump cmt,flushed cmt line from unit to rig floor,break circulation with cmt unit,pressure test lines 900psi/3000 psi,good.,Mixed&pumped 20 bbls 15.8 ppg class"G"cmt,balanced plug, spotted plug with rig pumps. EST TOC Cd)8082'.,POOH slow U7625'. 6/3/2017 Circulate surface to surface,drop wiper ball,circulate @ 12 bpm 770psi,clean returns.,POOH t/1434'standing back 5"dp,(pulled on double for pipe maint.).,Cont. POOH 1/d 18 jts 4"DP,& 27jts 3 1/2 tubing with diffuser,1/d handling eq.,R/u PT casing/cmt t/2700psi,had leakoff,troubleshoot&repaired surface leak,re-pressure 1/2700 hold f/30 min good,blow down Iines.,Ciean&clear floor of un-needed tools&subs.,R/U a-line,m/u GR/CCL tools,rih t/tag TOC @ 7881'wlm, POOH logging collars for,M/U 8.37"GR/junk basket,rih 1/7320', sat down @ 2810', 5804',6010',7030'wk through rih t/7320', POOH recovered 17 pieces of SS bands(equal TO 1 3/4 FULL BANDS+-).,Re-run junk basket/GR t/7320'POOH recover 9 smaller pieces&2 large pieces of SS bands(equal to+-1 1/2-2 Bands)wk through areas @ 4650',5804,7230'.,Re-run junk baskeUGR U7320',recover 2 large,5 medium&several small pieces SS banding(equal to+-1.5 bands)wk through 5804'.,Re-run junk basket/GR t/7320'work through 5804',POOH(rig crew workedon rig punch list projects& housekeeping during W/L operations).,M-06RD wellhead pressures;9-5/8=25 psi,13-3/8X9-5/8=0 psi,28X13-3/8=0 psi, Fluid loss to well today:0 bbls Total:0 bbls t P 6/4/2017 POOH recovered 2 medium pieces&30 small pieces of SS banding.,Re-head a-line,m/u 8.37"GR/junk basket rih t/5804',wk to fall through unable,POOH recover 6 small pieces SS bands.,M/U&run 9 5/8"CIBP,set w/top of plug @7297'WLM(casing collar @ 7302')POOH,r/d e-line.,P/U BHA.,Drill:abandon platform drill,good response,muster and discussion after.,P/U BHA:9 5/8 BOTTOM TRIP ANCHOR, 9 5/8 GEN II WHIPSTOCK SLIDE w/47#shear bolt, 8 1/2 WINDOW MILL,8 3/8 LOWER WATERMELON MILL, FLEX JOINT, UPPER WATERMELON MILL,1 JT 5"HWDP,FLOAT SUB,DM COLLAR,TM COLLAR,3ea FLEX COLLARS,15 JTS 5"HWDP=647.83', shallow test MWD tools good.,TIH @ 70FPM, f/647't/5574',up wt 175k,dn wt 140k.,Cont.tih t/7185'up wt 207k,dn 157 rot wt 175k.,Orientate whip stock,circ.10 bpm,850 psi,wk string t/orientate U61 L,cont.in hole tag CIBP @ 7300'pipe measurement,set @ 61L,shear anchor pins @ 12k dn, p/u 10k over verify anchor set,set dn shear bolt w/35k,p/u free 203k, dn wt 157k,rot 80 rpm,tq 11k,rot wt 175k.,Displace hole U OBM,dump upper pits t/pit 6&rinse while pump 25 bbl spacer ahead of 8.9ppg OBM,taking returns t/pit 6& transfer t/production,catch spacer&interface in trip tank.,Cont.drain FIW t/production,suck out interface from ft&clean pits.,M-06RD wellhead pressures;9- 5/8=30 psi,13-3/8X9-5/8=0 psi,28X13-3/8=0 psi, Fluid loss to well today:0 bbls Total:0 bbls 6/5/2017 Cont.Drain FIW t/production,clean pits,fill pits w/OBM.,Mill window f/7279'1/7296'Up wt 197k,dn wt,157k,rot 80 rpm,tq 9k off, 10-12 on, circ.10 bpm 1360 psi,pump high vis sweep no increase in metal returns.,Cont.drill rat hole 117340',circ 15bpm,2500 psi, 100 rpm,tq 10-15.,Drift window,pumps on rotating,pumps off no rotation,good,circulate Hi vis sweep w/nut-plug,150%increase in solids on returns.circulate clean. (capture total of 206#metal).,R/U &preform FIT,MW 8.9ppg, TVD 4879',pressure up t/960 psi=MWE 12.68 PPG,pumped 5.2 bbls,bleed back 2.9,blow down Iines.,Circulate&spot dry job,POOH 1/5385',up wt 170k,dn wt 140k.,Cont.POOH t/BHA 647'.,Wk BHA,stand back HWDP&flex collars,1/d window mill assembly,upper watermelon mill in gauge.Clean&clear floor.,Pull wear bushing,flush stack.,M-06RD wellhead pressures;9-5/8=30 psi,13-3/8X9-5/8=0 psi,28X13-3/8=0 psi, Fluid loss to well today:0 bbls Total:0 bbls • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, May 30,2017 4:24 PM To: Dan Marlowe Cc: Stan Golis;Juanita Lovett;Cody Dinger, Monty Myers Subject: RE: M-06 PTD 209-004 Sundry 317-099 Dan, Change as proposed below is approved. Balanced cement plug(tested to 2500 psi)on top of perfs is ok with CIBP set at 7300ft. update MOC as required. Guy Schwartz ,-,; 3 r,P Sr. Petroleum Engineer SCANNED Irl i ('a`}1 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: Dan Marlowe[mailto:dmarlowe@hilcorp.com] Sent:Tuesday, May 30,2017 11:41 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Stan Golis<sgolis@hilcorp.com>;Juanita Lovett<jlovett@hilcorp.com>;Cody Dinger<cdinger@hilcorp.com>; Monty Myers<mmyers@hilcorp.com> Subject: M-06 PTD 209-004 Sundry 317-099 Guy We are nippled up on M-06 and testing BOP's today with Mr Matt Herrera witnessing While circulating in step#2,the well held"650psi with minimal losses to formation giving us little hope of a successful retainer squeeze. At this point we would like to proceed as follows 1. MIRU Rig. -Completed 2. RU e-line and RIH to+1-7,960' and punch tubing.Work over fluid will be FIW. BOP's will be closed as needed to circulate the well. (cut made at 8598' instead of tubing punches) 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).—In Progress 4. Monitor well to ensure it is static. 5. • - - •-- _ • . _ - - _• :. (cut made at 8598' in step 2 instead of tubing punches) 6. Unseat hanger and POOH with completion. 1 . . • . • circulate hole clean. 11. RIH with tandem 9-5/8" x 7" cleanout assembly to top of tubing cut at±8,598' 12. RIH with workstring and spot±20 bbl cement balanced plug at ±8,598' placing estimated TOC at±8,080'. - 13. POOH with workstring to±7,500' and circulate clean, POOH. 14. Pressure Test casing to 2,500 psig for 30 minutes and chart. 16. RU e-line and RIH w/CIBP to±7,300',±5'above casing connection. POOH 17. PU whipstock and mills and RIH to CIBP. 18. Orient and set whipstock in 9-5/8". 19. Swap well to OBM drilling fluid. 20. Mill 8-1/2"window and 20' of new formation. POOH and LD mills. Thanks Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowehilcorp.com Hilcorp A Company Built on Energy 2 oFr� g ts,\ 1y/y', THE STATE Alaska Oil and Gas N � °fJ\ e c��1-1 Conservation Commission L!Z V It .1 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ALASMain: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 SCANNED MAR �' ' Anchorage,AK 99503-5832 Re: McArthur River Field,Middle Kenai Gas Pool, TBU M-06 Permit to Drill Number: 209-004 Sundry Number: 317-099 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, "4?-01 Cathy . Foerster Chair DATED this-7(41y of March, 2017. RBDIVIS 1' t ., - 6 2017 . • S • iFiEcEivED ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 1 2 117 APPLICATION FOR SUNDRY APPROVALS .1)7g20 AAC 25.280 �g �["��,�/� 1.Type of Request: Abandon ❑ Plug Perforations 121Fracture Stimulate ❑ Repair Well 0 4 � bel'' ions shutdown❑ Suspend 0 Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 0 Plug for Redrill 0. Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing 0 Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory 0 Development 0 209-004 ' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic CIService ❑ 6.API Number. Anchorage,AK 99503 50-733-20585-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A / Will planned perforations require a spacing exception? Yes 0 No 0 J Trading Bay Unit M-06 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594&ADL0018730 . McArthur River Field/Middle Kenai Gas Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 12,502 • 8,770 ., 9,099 . 5,950 • 897 psi 9,412, 11,666,12,317 9,099 Casing Length Size MD TVD Burst Collapse Structural Conductor 470' 28" 470' 470' Surface 1,401' 13-3/8" 1,401' 1,371' 5,020 psi 2,260 psi Intermediate Production 7,610' 9-5/8" 7,610' 5,080' 6,870 psi 4,760 psi Liner 5,148' 7" 12,494' 8,762' 7,240 psi 5,410 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8,932-9,351 • 5,857-6,087 4-1/2" 12.6#/L-80 8,902 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker S-3 Pkr &Wellstar TRSV 8,604'(MD)5,665'(ND)&444'(MD)444'(TVD) 12.Attachments: Proposal Summary ID Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 5/1/2017 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmariowe(D_hilcotp.com Printed Name Stan W.Golis Title Operations Manager Signature 31 r,..lPhone (907)777-9356 Date I tot "7 COMMISSION USE ONLY Conditions of approval: Notify ommission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test i Mechanical Integrity Test ❑ Location Clearance 0 ' ,1 1 t i , Other: -* 3SOD ps,: 4.6)pf' Th f— Post Initial Injection MIT Req'd? Yes CINo ❑ RB D J S ( ' ��i i 1 - B 26ii Spacing Exception Required? Yes ❑ No l� Subsequent Form Required: /0 --L{ 0 .I- -Approved by: COMMISSIONER THE COMMISSION Date: 3- 7- 1 7 IAate '/3// A 3�, /I O ,(1 1 Glc.j„�-L. // Submit Form and Form 10-403 Revised 11/2015 r v C I � td for 12 months from the date of approval. ��//�{ttachments in Duplicate • • • Well Work Prognosis Well: M-06 Hilrp Alaska,LLCDate: 02/21/2017 Well Name: M-06 API Number: 50-733-20585-00 Current Status: Gas Producer Leg: Leg B-2 (NE Corner) Estimated Start Date: May 01, 2017 Rig: Hilcorp Rig 51 r- Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett(8332) Permit to Drill Number: 209-004 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: 1,483 psi @ 5,857'TVD 0.253 lbs/ft(4.87 ppg)2011 SIBHP Maximum Expected BHP: 1,483 psi @ 5,857'TVD 0.253 lbs/ft(4.87 ppg)2011 SIBHP Maximum Potential Surface Pressure: 897 psi Using 0.1 psi/ft gradient per 20AAC25.280(b)(4) Brief Well Summary M-06 is a depleted Gas Producer drilled in 2009. This workover will plug back the existing completion and prepare the well to sidetrack into the West Foreland Sands with a fall back option of adding the G and Hemlock again at a later date. 5 re-4:6 He--/-1 ).7 Last Casing Test: 09/07/2009 3,000 psi at 12,408' for 30 minutes on chart Procedure: 1. MIRU Rig. 2. RU e-line and RIH to+/-7,960'and punch tubing. 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. 5. RU e-line and RIH to +/-8,600'and cut tubing. 6. Unseat hanger and POOH with completion. 7. RIH with bit and scraper to±7,346, circulate clean: POOH. `1 '� ~ 8. RIH with cement retainer and set at±7,340' �� 9. RIH and sting into cement retainer. 10. RU cementing equipment and establish an injection rate with FIW. a. Mix and pump 80 barrels cement to isolate existing completion. Un-sting from retainer and circulate hole clean. )t' 711' �6t, b. POOH w/work string. Cok �3b' ttc 7L ,� 11. Pressure Test casing tja2.500 psi for 30 minutes and chart. 12. RIH with bit and scraper to±7,335'circulate clean. POOH. 13. RU e-line and RIH w/CIBP to ±7,300', ±5' above casing connection. POOH 14. PU whipstock and mills and RIH to CIBP. rt-k 15. Orient and set whipstock in 9-5/8". 16. Swap well to OBM drilling fluid. 17. Mill 8-1/2" window and 20' of new formation. POOH and LD mills. w ***Remaining Procedure to be included on the Permit to Drill Sund ry for the sidetrack*** co,co r. 1 h e So�J CCS IMC(( 14/4‘ /9496/4/6"Y j (e u rigo LIQ fi 4.-44r- Q*, "Ca- rer/kr f/oo'vCe/ ieti The 1.0,td tvaf k,cf 5 vt r^ /1/9 . 14e li l S�vt i 4 w�af l'Olrtr- I tigh i�/lf " Thi( �l qft fate qr vvq,c t? vd i'�'�S d ' clod QOhow ,40 t/'• pv r' . 7� wtl i for (C II for Xd..C� �C(pv �yd/� SNCPO • • 11 Well Work Prognosis Well: M-06 Hilcorp Alaska,LLC Date: 02/21/2017 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 • 0 Steel:lhead Platform WelM-06 SCHEMATIC Completed:Last 09/17/2009 PTD: lliieoru Alaska,LLC API: 50-733-20585-00 RKB:M6L=96' CASING DETAIL Size Wt Grade Conn ID Top Btm 1 -4ECP Stage 28" Conductor 27" Surf 470' Cellar @ 28" 13-3/8" 68 L-80 BTC 12.415" Surf 1,401' II 9-5/8" 47 L-80 BTC-M 8.681" Surf 7,610' 1 Est.Toc7" 26 L-80 DWC 6.276" 7,346' 12,494' 1) .+i'ey @920',', a TUBING DETAIL-1 4-1/2" 12.6 L-80 TC-II 3.958" Surf 8,902' t *1 4.-7 1, ". JEWELRY DETAIL 13-3/8" ,' .T. Depth Depth ' 2 i 1 kik; No ID OD Item �I 1i (MD) (ND) °tyy':,o 1 444' 444' 3.813 6.625 4.5 WellStar TRSV 12.6 TCII "Ac1 ! , 2 1,606' 1,553' 3.833 6.250 4-1/2"SFO-1 Mandrel VI,, 3 . rii :K 3 2,235' 2,034' 3.813 5.950 4.5 XXO SVLN CIM 12.6 TCII , ,y; 4 3,642' 2,812' 3.833 6.250 4-1/2"SF0-1 Mandrel � 5 5,580' 3,897' 3.833 6.250 4-1/2"SFO-1 Mandrel •- 4 at y,4 6 7,226' 4,855' 3.833 6.250 4-1/2"SF0-1 Mandrel it`..; y,+q4 7 8,584' 5,654' 3.810 5.563 4-1/2"Dura Sleeve/GLV Ii` I ii^' 8 8,604' 5,665' 3.850 5.960 BOT S-3 Production Packer L 5 IMI 1 9 8,625' 5,678' 3.813 5.000 X Profile i 10 8,803' 5,783' 3.700 5.020 BOT Gun Drop Sub ` i stage collar i311 8,902' 5,840' E-Line Cut End of Tubing ■ @5. 6' 12 9,099' 5,950 Tubing Tail Fish 13 9,450' 6,141' 7"PosiSet Plug w/cement on top 'ytiTOC @6,100' 14 11,730' 8,011' 7"PosiSet Plug w/cement on top ?`, > 15 12,330' 8,601' 7"PosiSet Plug w/cement on top Al tai ` 6i 4" PERFORATION DETAIL y0° 6 1I ' W. Top Btm Top Btm 4 Zone FT Date Status �,, (MD) (MD) (TVD) (ND) ',,,,is. ,'t r y -1- D14 8,932' 8,940' 5,857' 5,861' 8' 3/1/2011 Open 3-IL D14 8,950' 8,966' 5,867' 5,876' 16' 3/1/2011 Open '= X , `'"4 L 003 D16B 9,210' 9,230' 6,011' 6,021' 20' 2/27/2011 Open 9- ^ ' It to '' .A D16B 9,235' 9,245' 6,024' 6,030' 10' 2/27/2011 Open 7 Eri "' D16C 9,278' 9,298' 6,047' 6,058' 20' 2/28/2011 Open 8 • . rt r, 9 '' D16C 9,308' 9,328' 6,064' 6,074' 20' 2/28/2011 Open 10 D16C 9,341' 9,351' 6,081' 6,087' 10' 2/28/2011 Open " 11 `' F6 11,382' 11,390' 7,669' 7,677' 8' Plugged y F7 11,430' 11,442' 7,716' 7,728' 12' Plugged ' F31 11,739' 11,762' 8,020' 8,043' 23' Plugged TEst9opofcu['o9stubirg 12I i Theo @9,385 RKB ELM G04 12,342' 12,366' 8,613' 8,636' 24' Plugged 13R;ti: J. Tag TOC @ 9,417 *:. RKB ELM 14 , Tag TOC@11,665 RKB ELM 15. * 1 Tag TOC @12,317 1*. RKB SIM PBTD:9,412' TD:12,502' Updated By:JLL 02/23/17 • 410 Steelhead Platform . Ili Well:M-06 PROPOSED Last Completed: FUTURE PTD:209-004 Hilcarp Alaska,LLC API: 50-733-20585-00 RKB toTBGHead-78' CASING DETAIL Size Wt Grade Conn ID Top Btm E�Stage 28" cellar@ Conductor 27" Surf 470' 28" r; 448' 13-3/8" 68 L-80 BTC 12.415" Surf 1,401' f A' Esc.roc 9-5/8" 47 7,300' @ezo L-80 BTC-M 8.681" Surf (KOP) #« 7" 26 L-80 DWC 6.276" 7,346' 12,494' TUBING DETAIL 4-1/2" 12.6 L-80 TC-II 3.958" ±8,600' 8,902' I t 133/8" JEWELRY DETAIL ' Depth Depth No (MD) (TVD) ID OD Item 1 ±7,300' ±4,898' CIBP set for Whip Stock N. 2 ±7,340' ±4,922' Cement Retainer a 8,604' 5,665' 3.850 5.960 BOT S-3 Production Packer b 8,625' 5,678' 3.813 5.000 X Profile 1 c 8,803' 5,783' 3.700 5.020 BOT Gun Drop Sub M", d 8,902' 5,840' E-Line Cut End of Tubing ;` e 9,099' 5,950 Tubing Tail Fish il f 9,450' 6,141' 7"PosiSet Plug w/cement on top Stage Collar g 11,730' 8,011' 7"PosiSet Plug w/cement on top ® @5' h 12,330' 8,601' 7"PosiSet Plug w/cement on top TOC @6,100 ti l .w,s PERFORATION DETAIL Top Btm Top Btm Zone (MD) (MD) (ND) (ND) FT Date Status 014 8,932' 8,940' 5,857' 5,861' 8' 3/1/2011 Open t • CIBPsettorwhipSt«K 4lii D14 8,950' 8,966' 5,867' 5,876' 16' 3/1/2011 Open +7,300' ILIA v +;- _ ,, D16B 9,210' 9,230' 6,011' 6,021' 20' 2/27/2011 Open c Cement a, 2 ; n}: D166 9,235' 9,245' 6,024' 6,030' 10' 2/27/2011 Open v tY r<., 4t,k4.'ti`^�I;'"t',ty; Retainer U f L L.'g. + , ' 'i 4'1 ++-7•�' D16C 9,278' 9,298' 6,047' 6,058' 20' 2/28/2011 Open 9-5/8' D16C 9,308' 9,328' 6,064' 6,074' 20' 2/28/2011 Open D16C 9,341' 9,351' 6,081' 6,087' 10' 2/28/2011 Open a 1, r r F6 11,382' 11,390' 7,669' 7,677 8' Plugged b F7 11,430' 11,442' 7,716' 7,728' 12' Plugged 1m, F11 11,739' 11,762' 8,020' 8,043' 23' Plugged d G04 12,342' 12,366' 8,613' 8,636' 24' Plugged Topof cit tubing ►e Est.9,099' / ""- Tagfill @9,386' ( RKB ELM f7. e!' Tag TOC @9,417 y 0RKB ELM g r ,7Tag TOC @11,666• -y RKB ELM L. h L, ".-`8 v- TagTOC@12,317 •"t ''r RKB REM 7, . 1LS r ?.Ic ' PBTD:9,412' TD:12,502' Updated By:JLL 02/23/17 • 0 Steelhead Platform , ll M-06 Current 03/02/2017 Hilrurp %iakn.1,1.(. Steelhead Platform Tubing hanger, M Vetco-MB 242,13 5/8 SM x 28x 133/8 x95/8 x41/2 4'ATC-2 suspz4.909 MCA Mt,w/4"type H BPV profile, 2-14 npt control line ports BHTA,Otis,4 1/16 5M FE x 7"Bowen quick union top Valve,Swab, �� 41/16 5M FE,HWO.HWO, EE trim , 1.1It■1.11111 .10 11116.07•1 CM Valve,Upper master,SSV, 0"'_—.0.' Valve,Wing,SSV,WKM-M, WKM-M,4 1/16 5M FE, 3 1/8 SM FE,w/15"operator HWO,w/18"operator, Y O O EE trim merman sat w .110 .iUi Valve,Master,WKM-M, 41/16 SM FE,HWO, 7r--.\g EE trim ,---- e Je - airr i. Egli ";_� Multibowl system,Vetco MB-242,13 5/8 5M Flanged ':up top z 20'h 3M NT-2 bottom, 3ii ii_14,..„... :iii. . x, IL _ �: : ; i_ _,.— .tel{j. , ** it . 1 �rli: : : ill _ t i p Starting head,Vetco MB-246, •. •i, II. 20%3M NT-2 top x 28"BW •,s �- bottom,w/2-3"LPO and 6" , ANSI 600 outlets -II I.- '' - 1 MikII 13 3/8" 9 5/8" 4W' • • Steelhead Platform 13 5/8 5M BOP (Oil Leg) 01/30/2017 Hilrnrp 1.IA: A Rig floor Bottomofdrippan 6.75' A 22"X 16"for air boot sleeve, 19'in length 10.92' 2613' / Moon pool deck to rig floor iii lil Iil lil lin • 4.54' Hydril ' rt it tat rat Iiiiil *1.141142.4 CICU t� 4.67' _ IIS- I— • Top ofMoonpool Moonpool deck top@ 55.95' Inns"ifiilnil deck 55.38' 9.60' w 14;" nn Il a ni Total BOP assembly ir 1�{r }' I` r"Iilnili 'I{" ~�'I. 2.26' lu tal lli lit ill en 2.83' lil Ill III IIn Ill 1.25' 111111 III III II, 3.86'flange above rig sub grating Rig sub grating Upper Wellhead Roo to Rig Sub Grating 2 23.47' rel;i 5.08'clamp above floor Upper wellhead room floor Wellhead floor to Upper Wellhead Roo 22.88' III 31 V Top of wellhead • • k I — (E31sns svD 1— I_U U 'Vn c' w H2 0 5 Alk U D O ,o 0D U Y up b.o U Z V U V w w / /1 w a U a N n7 410 U U 0 J I S LL Z#NNV1 dRll U U // ►� w L!7 < l#)INVI dIH1 Q U N 2 2ct CCQ U o\\- u) F- Q-J F��vNE a- a m m < w ci w3 LP 111111 III I ili J �� MO in W Z Y r, r, N, W3-N w I" w 2 F— _ ' ) U N v J aU) w a w 2 CO D p a_ 8 OUi W O U N ow Steelhead Rig#51 BOP Test Procedure Hilcorp Alaska,W. 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. o • Steelhead Rig#51 BOP Test Procedure Hilcorp 1la..ka, 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 Hiieori,ni,9ka.i.i.c 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, Cl, 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. • Steelhead Rig#51 BOP Test Procedure xacorN Alaska,LIA. 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. • • c CD CD a) ow0 / :.--c ow .- a , 2E So § / / 2 � °�§ m « E £ o f § f 7 § �� 2 » a ,4 aE = 0 / .0 � � � > = Icy \ \/ a 0_ 2 § / � � ■ ■ 0 ® 2s_ z as es $ / 2 �' C• o 2 CD CD ¢ . " Z h N / J V 2 k oa > co 2 /- a Co -• 0 _ \ -aC 0 � )k L. Em © 2 O k S .$cm a O a & - » G CO 0) nc th c D. E E -o jp -- w k 0o / // 0 a ■ o x % & -- E o 2 » ■ § c m � � § q § 0- ® k 0 � w / � • 2 ° q t E0 > 2 ¢ vl ® 2 > o 0 E 2 Cl) \ 9 � < 0_ • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend"boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon"box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial / then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, 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. • • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. . o - QQ l/- Well History File Identifier Organizing (done) ❑ Two -sided I I111111 11111 ❑ Rescan Needed II 11 1111 1111 RE AN DIGITAL DATA OVERSIZED (Scannable) V Color Items: ❑ Diskettes, No. ❑ Maps: ❑ Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: /s/ nl r Project Proofing III [1111 1111 I/4P BY: Maria Date: 3A, t +) 1 1 /s/ Scanning Preparation vL x 30 = + = TOTAL PAGES V q o unt does not include cover sheet) BY: Date: �" J 1 /s/ r 1 Production Scannin g ll 11111011H Stage 1 Page Count from Scanned File: qo (Count does include cover et) Page Count Matches Number in Scanning Pr / / paration: YES NO BY: Date: 3 & y f 1 /s/ ( / Y Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III 111111111 III ReScanned III 1E11111 I BY: Maria Date: /s/ Comments about this file: Quality Checked n1111111111 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA Al KA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate S Other ❑ Performed: Alter Casing ❑ Pull Tubin g❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other .❑ Re -enter Suspended Wellt❑ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development J Exploratory ❑ 209.004 3. Address: 3800 Centerpoint Drive, STE 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99503 50- 733 - 20585 -00 r 7. Property Designation (Lease Number): 8. Well Name and Number: Steelhead Platform / ADL 0018730 ADL0017594 Trading Bay Unit - M -06 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): - McArthur River Field / Middle Kenai Gas Poo 11. Present Well Condition Summary: � 9,412, 11,666 J/j Total Depth measured 12,502 feet Plugs measured 12,317 feet /[ � true vertical 8,770 feet Junk measured 9,099 , 4 De0 /2 Effective Depth measured 9,099 feet Packer measured 8,604 feet °CC true vertical 5,950 feet true vertical 5,665 feet Casing Length Size MD ND Burst Collapse Structural Conductor 470' 28" 470' 470' Surface 1,401' 13 -3/8" 1,401' 1,371' 5,020 psi 2,260 psi Intermediate Production 7,610' 9 -5/8" 7,610' 5,079' 6,870 psi 4,760 psi Liner 5,148' 7" 12,494' 8,762' 7,240 psi 5,410 psi Liner Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# / L -80 8,902' (MD) 5,840' (ND) Baker S -3 Packer 8,604' (MD) 5,665' (TVD) Packers and SSSV (type, measured and true vertical depth) Wellstar - TRSV 444' (MD) 444' (TVD) 12. Stimulation or cement squeeze summary: AlfilliNkij JUL 1 0 01, 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 1896 38 130 173 Subsequent to operation: 0 1844 37 130 174 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development O — Service ❑ Stratigraphic ❑ Daily Report of Well Operations 16. Well Status after work: Oil ❑ — Gas el 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 7/9/2012 H bms JUL 16 Mt ePYi A 7.,0_,Z- Form 10-404 Revised 11/2011 Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M -06 507332058500 209 -004 6/7/12 6/8/12 pally Operations: °' 06/07/12 - Thursday Rig up slickline. Pressure test to 300 psi low and 2,500 psi high. RIH with 3.5" gauge ring to 9,100' RKB. Pull out of hole and hit tight spot at 1,602' (GLM). Had to work tools several time to get thru tight spot. Rig down lubricator. 06/08/12 - Friday Mobe equip and rig up. Pressure test lubricator to 250 psi low and 3000 psi high. RIH with GR /CCL, 3- 1/8 "x7' HC, 6 spf,60 deg phase and tie into USIT GR /CCL dated 10- Sep -09. Tag fill at 9,102'. Spot perf gun from 9,027' to 9,034' per Final Approved Perforation Request Form dated 31- May -12. Fired gun. All shots fired. Had no problem at the first GLM at 1,606' where slickline hung up. Rig down lubricator off well. Turn well over to production. iti , .. • SCHEMATIC • Trading Bay Unit Steelhead Well: M -06 Hilcorp Alaska, LLC Actual Completion Date: 9/17/2009 Casing Detail SIZE WT GRADE CONN MIN ID TOP BTM BTM RKB to TBG Head = 78' (MD) (TVD) 28" Structural 27" Surface 470' 470' 13 -3/8" 68 L -80 BTC 12.415 Surface 1401' 1371' sssv 9 -5/8" 47 L -80 BTC -M 8.681 Surface 7610' 5079' 28° Conductor 7" 26 L -80 DWC 6.276 7346' 12494' 8762' ECPStage Collar Tubin Detail Chemical 4 -1/2" 1 12.60 L -80 TC -II g 3.958 Surface 11301' 7588' Injection Sub w/ 2 Jewelry check valves Est roc @ 920' Item Depth Depth OD ID MD TVD 4.5 WellStar TRSV 12.6 TCII 444' 444' 6.625 3.813 4 I 13 3/8" in 17 W Hole ECP Stage Collar 448' 448' 4 Y2" SFO -1 Mandrel 1,606' 1,559' 6.25 3.833 4.5 XXO SVLN CIM 12.6 TCII 2,235' 2,042' 5.95 3.813 4 SFO -1 Mandrel 3,642' 3,070' 6.25 3.833 4''A" SFO -1 Mandrel 5,580' 4,634' 6.25 3.833 Cement stage collar 5,806' 4,021' II . 4 'A" SFO -1 Mandrel 7,226' 4,855' 6.25 3.833 Stage Collar 4 Y2" Dura Sleeve / GLV 8,584' 5,653' 5.563 3.81 BOT S -3 Production Packer 8,604' 5,665' 5.96 3.85 TOC @ 6,100' X Profile 8,625' 5,678' 5 3.813 BOT Gun drop sub 8,803' 5,783' 5.02 3.7 Top of cut tubing WLEG 11,301' 7,588' 5 3.95 Est 9106' 7" PosiSet Plug w/ cement on top 11,730' 7" PosiSet Plug w/ cement on top 12,330' Top of cut tubing 1 Illi Est 9106' Perforation Detail 9 5/8" Casing in 12 %h" Zone MD TVD Density (SPF) Comments Hole 8,932' - 8,940' 5,857' - 5,861' 6 3/1/2011 7° x 4 W Production D14 8,950'-8,966' 5,867'- 5,876' 6 3/1/2011 Packer ,� 0-15 9,027'- 9,034' 5,910'- 5,914' 6 6/8/2012 • D166 9,210'- 9,230' 6,011'- 6,021' 6 2/27/2011 BOT Gun drop sub 9,235'- 9,245' 6,024'- 6,030' 6 2/27/2011 9,278'- 9,298' 6,047'- 6,058' 6 2/28/2011 016C 9,308'- 9,328' 6,064'- 6,074' 6 2/28/2011 9,341'- 9,351' 6,081'- 6,087' 6 2/28/2011 Top of cut = D-14 F -6 11,382' - 11,390' 7,675' - 7,683' 6 Perf 10/27/10 tubing 4 1 - ► 0 Est 9106' = D16B F -7 11,430' - 11,442' 7,722' - 7,734' 5,6 Reperf 10/23/10 4! F -11 11,739' - 11,762' 8,026' - 8,049' 5 Plugged Tag TOC at G-04 12,342' - 12,366' 8,619' - 8,642' 5 Plugged IS_ 11,666'RKBELM Logging Detail TOC at -" d 1231 KBSLM Hole Section LWD /MWD Wire Line Mud Logging Notes ItMali 7" Liner in 8 1/2" Hole gMWD, 17 /2 GR /RES Gas On Site Geologist MAX HOLE ANGLE = 57.5° @ 2502' MD I 12 h Triple Combo Mudlog On Site Geologist 8 Triple Combo Mudlog On Site Geologist Cementing Information Description Volume (BBL) Density (ppg) Yield (ft3 /sx) Notes ' Surface 1st stg 254 13.0/14.0 1.95 (B #2) Surface 2 stg 271 13 1.95 (B #2) Intermediate 1 stg 155 14 1.95 (B #2) Intermediate 2nd stg 418 13 1.95 (B #2) Production single stage 237 15.8 1.18 , (B #1) Well fletail Revised RY• MF 7 -9 -12 • • Sd 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: fcastro @chevron.com DATE April 13, 2011 To: AOGCC Shartzer, Christine R 333 W. 7th Ave. Ste #100 Anchorage, AK 99501 APR 1 9 2O1 DATA TRANSMITTAL WELL LOG TYPE LOG DATE INTERVAL 8- CD LOGGED LINE TBU M -06 PERFORATION RECORD 1- Mar -2011 8932 -8966 X X TBU M -06 PERFORATION RECORD 16- Mar -2011 9072 -9112 X X TBU M -06 PERFORATION RECORD 24- Feb -2011 9235 -9245 X X TBU M -06 PERFORATION RECORD 28- Feb -2011 9278 -9351 X X TBU M -06 PERFORATION RECORD 23- Feb -2011 9150 - 9438.5 X X TBU M -06 COMPLETION RECORD 23- Feb -2011 8803 -9450 X X TBU M -06 COMPLETION RECORD 22- Feb -2011 8757 -9233 X X TBU M -11 PERFORATION RECORD 10- Jan -2011 9270 -9290 X X TBU M -06 PERFORATION RECORD 27- Feb -2011 9210 -9230 X X TBU M -06 TEMPERATURE- PRESSURE- GR -CCL 27- Feb -2011 9112 - 9406.4 X X &gyp -115 59C 90 Q0 f1 77z Please acknowledge receipt by signing and returning one copy of this tr or FAX fo 907 263 7828. Received By: Da te: ' 11 J ! :11 1 _ BUR- STATE OF ALASKA 312e Izon ALASKAWAND GAS CONSERVATION COMMISSIOW REPORT OF SUNDRY WELL OPERATIONS 1. Abandon U Repair Well LJ Plug Perforations U Stimulate L1 Other U Tubing cut 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 egl Exploratory ❑ 209 -004 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic❑ Service ❑ 6. API Number: ,. 50- 733 - 20585 -00 A 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017594 & ADL0018730 [Steelhead Platform] Trading Bay Unit M -06 9. Field /Pool(s): McArthur River Field / Middle Kenai Gas Pool 10. Present Well Condition Summary: 9,412, 11,666, Total Depth measured 12,502 feet Plugs measured 12,317 feet true vertical 8,770 feet Junk measured 9,099 feet measured 9,099 feet Packer measured 8,604 feet true vertical 5,950 feet true vertical 5,665 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 470' 28" 470' 470' Surface 1,401' 13 -3/8" 1,401' 1,371' 5,020 psi 2,260 psi Intermediate Production 7,610' 9 -5/8" 7,610' 5,079' 6,870 psi 4,760 psi Liner 5,148' 7" 12,494' 8,762' 7,240 psi 5,410 psi Perforation depth Measured depth 8,932' - 8,940', 8,950'- 8,966', 9,210'- 9,230', 9,235'- 9,245', 9,278'- 9,298', 9,308'- 9,328', 9,341'- 9,351' True Vertical depth 5,857' - 5,861', 5,867'- 5,876', 6,010'- 6,021', 6,024'- 6,029', 6,047'- 6,057', 6,063'- 6,074', 6,081'- 6,086' Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 8,902' MD 5,840' TVD Baker S -3 Packer 8,604' MD / Packers and SSSV (type, measured and true vertical depth) (5,665' TVD) Wellstar TRSV 444'MD (444'TVD) 11. Stimulation or cement squeeze summary: M 1... � �F► Intervals treated (measured): MAR p q � y f � y MAP tr.. N/A Mt �[1 2 9 Egli !r� AP ,`� ' F r Treatment descriptions including volumes used and final pressure: N/A C 12. Representative Daily Average Production or Injection Data Commissi rt Oil -Bbl Gas -Mcf Water -Bbl Casing Press e,,. D -;, Jibing PressuPJ' Prior to well operation: 0 0 0 40psi 48psi Subsequent to operation: 0 4780 0 130psi 742psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development El 4 Service ❑ Stratigraphu 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: 310 -447 Contact Chris Kanyer 263 -7831 Printed Name Timothy C. Brandenburg Title Drilling Manager S � + Phone 276 -7600 Date 3/16/2011 RS el MAR 2 9 2011 Form 10-404 Revised 1 /2010 Submit Original Only a sed 0 Chevron • • %tio Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -06 TRADING BAY UNIT M -06 ADL017594 5073320585 LP0335 160.00 185.00 Primary Job Type Job Category Objective Actual Start Date Actual End Date Perforation - Post Production Well 2/22/2011 Services Primary Wellbore Affected Wellbore UWI Well Permit Number M -06 507332058500 2090040 2/22/2011 00:00 2123/2011 00:00 Operations Summary RU Eline, pressure test lubricator 250psi low /2500psi high. RIH w/ 2 -5/8" cutter, tie in and cut tubing at 9,182', RIH to 9,464', POOH. 2123/2011 00:00 - 2/24/2014 00:00 Operations Summary Pressured up on well with lift gas to push away water. RIH and set 7" PosiSet plug at 9,450' RKB ELM. RIH and made dump bail run of 16.2ppg cement on top of plug. ,2/24 12011" 00:00 2/2512011 00 :00 Operations Summary Continue to dump bail 16.2ppg cement on top of plug to 9,430' ELM (calculated). 2/25/2011 00:0 00:00 Operations Summary Continue to dump bail 16.2ppg cement on top of plug to 9,413.5' ELM (calculated). RD Eline. WOC. 2/25/201100 :004 2/27/2011 00:00 Operations Summary Continue to WOC. Production bled down well and performed a negative pressure test to 100psi. 2/2712: x - 2/28/2011 00:00::': Operations Summary RU Eline. Pressure test lubricator 250psilow /3000psi high. RIH and tag TOC at 9,412'ELM. RIH w/ 2 -7/8" PJ Omega 6spf 60deg guns, tie in, and perforate from 9,236- 9,245'. RD Eline, turn well over to production. 2/ 2812011;00 :00 - 311124 00:00 ..,�sw., rye, r Operations Summary RU Eline. Pressure test lubricator 250psilow /3000psi high. RIH w/ 2 -7/8" PJ Omega 6spf 60deg guns, tie in, and perforate from 9,341'- 9,351', 9,308'- 9,328', & 9,278'- 9,298'. RD Eline, turn well over to production. 3/1/2011 00:00-3/2/2011 Operations Summary RU Eline. Pressure test lubricator 250psilow /3000psi high. RIH w/ 2 -5/8" cutter, tie in and cut tubing at 8,902', RIH to 9,060', POOH. RIH w/ 2 -7/8" PJ Omega 6spf 60deg guns, tie in, and perforate from 8,950' - 8,966' & 8,932' - 8,940'. RD Eline, turn well over to production. 2011 00:00 -4/8/$'I (woo Operations Summary RU slickline, pressure test lubricator 250psi low /2500psi high. RIH w/ 2.8" GR and tag top of tubing fish at 9,099'SLM. RIH w/ pressure /temperature /spinner flowing survey to 9,090'SLM. RD slickline turn well over to production. Chevron head Platform 11%. We M -6 %. Casing &Tubing Detail RKB to TBG Head - 78' BTM BTM SIZE WT GRADE CONN MIN ID TOP (MD) (TVD) 11 28" Structural 27" Surface 470' 470' sssv 13 -3/8" 68 L -80 BTC 12.415 Surface 1401' 1371' 28" Conductor 9-5/8" 47 L -80 BTC -M 8.681 Surface 7610' 5079' a a jilkh 7" 26 L -80 DWC 6.276 7346' 12,494' 8762' ECPStageCollar 4 -1/2" 12.60 L -80 TC -II 3.958 Surface 8902' 5840' Chemical Injection Sub w/ 2 check valves Completion Equipment Information Est roc 920' Item Depth MD Depth TVD OD ID 4.5 WellStar TRSV 12.6 T CII 444' 444' 6.625 3.813 ECP Stage Collar 448' 448' 4 'h" SFO -1 Mandrel 1,606' 1,559' 6.250 3.833 4 1 13 3/8" in 17 %" Hole 4.5 XXO SVLN CIM 12.6 TCII 2,235' 2,042' 5.950 3.813 4'/" SFO -1 Mandrel 3,642' 3,070' 6.250 3.833 4'/s" SFO -1 Mandrel 5,580' 4,634' 6.250 3.833 Cement stage collar 5,806' 4,021' 4'/i' SFO -1 Mandrel 7,226' 4,855' 6.250 3.833 4'/2' Dura Sleeve / GLV 8,584' 5,653' 5.563 3.810 BOT S -3 Production Packer 8,604' 5,665' 5.960 3.850 IN ® Stage Collar X Profile 8,625' 5,678' 5.000 3.813 BOT Gun drop sub 8,803' 5,783' 5.020 3.70 Tubing Tail 8,902' 5,840' TOC @ 6,100' Tubing Tail (fish) 9,099' 5,950' 7" PosiSet Plug w/ cement on top 9,450' 6,141' 7" PosiSet Plug w/ cement on top 11,730' 8,017' 7" PosiSet Plug w/ cement on top 12,330' 8,607' Perforation Detail Density ) III Il k 9 MD TVD Zone Density Comments (SPF) /8" Casing in 12 W Ho le 8,932'-8,940' 5,857'- 5,861' D14 6 Perf 3/1/11 Ho 8,950'- 8,966' 5,867' - 5,876' D14 6 Perf 3 /1/11 • 9,210'- 9,230' 6,010'- 6,021' D16B 6 Perf 2/27/11 ' I 7" x 4 W Production 9,235'- 9,245' 6,024'- 6,029' 0166 6 Perf 2/27/11 Prnfila Ninnle 9,278'- 9,298' 6,047'- 6,057' D16C 6 Perf 2/28/11 BOT Gun drop sub 9,308'- 9,328' 6,063' 6,074' D16C 6 Perf 2/28/11 9,341'- 9,351' 6,081'- 6,086' D16C 6 Perf 2/28/11 11,382' - 11,390' 7,675' - 7,683' F -6 6 Plugged 11,430' - 11,442' 7,722' - 7,734' F -7 5,6 Plugged Tag fill at 11,739' - 11,762' 8,026' - 8,049' F -11 5 Plugged 9.386'RKB ELM Tag TOC at 12,342' - 12,366' 8,619' - 8,642' G -04 5 Plugged 9,412'RKB ELM f, Tag TOC at Logging Detail 11 ELM Hole LWD /MWD Wire Line Mud Logging Notes . Tag TOC at Section 14,'"?. 12,317'RKB SLM 17' gMWD, GR/RES Gas On Site Geologist 12 Y. Triple Combo Mudlog On Site Geologist 7" Liner in 81/2° Hole 8'% Triple Combo Mudlog On Site Geologist 11116 Cementing Information Description Volume Density Yield (ft3 /sx) Notes (bbls) (ppg) Surface 1st stg 254 13.0/14.0 1.95 (B #2) Surface 2 stg 271 13.0 1.95 (B #2) MAX HOLE ANGLE = 57.5° @ 2502' MD Intermediate 1 stg 155 14.0 1.95 (B #2) Intermediate 2 stg 418 13.0 1.95 (B #2) Production single stage 237 15.8 1.18 (B #1) Well f)ptail RPvisPd RY• SRJ 3 -1A -7011 DATA SUBMITTAL COMPLIANCE REPORT 3/24/2011 Permit to Drill 2090040 Well Name /No. TRADING BAY UNIT M -06 Operator UNION OIL CO OF CALIFORNIA API No. 50- 733 - 20585 -00 -00 MD 12502 TVD 8770 Completion Date 9/17/2009 Completion Status 1 -GAS Current Status 1 -GAS UIC N REQUIRED INFORMATION l eak "-- _,,-., Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: GAM /RES /NEU /DEN /USIT /CCL (data taken from Logs Portion of Master Well Data Maint • Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty Med /Frmt Number ,pame Scale Media No Start Stop CH Received Comments ED C Las 193036 Notes PPROF , Log Production 2 Blu 11370 12380 Case PPL, Ghost, Deft, Temp, Pres, Dens, GR, CCL (Log Induction /Resistivity 2 Col 450 12475 Open TVD Vision Service og Induction /Resistivity 2 Col 450 12475 Open MD Vision Service og Induction /Resistivity 5 Col 450 12475 Open TVD Vision Service I Induction /Resistivity 5 Col 450 12475 Open MD Vision Service E15 C Las 19304 r'(nduction /Resistivity 351 12502 Open Final Data OH CD Log Cement Evaluation 5 Col 400 12392 Case CEL, USIT, GR, CCL og Cement Evaluation 5 Col 300 12392 Case CEL, USIT, GR, CCL 0 1 C Las 19809 -- gud Log 0 0 Open 6/29/2010 Final and Mud log data in LAS and PDS graphics DML and Survey data .:✓ED C Pds 20249 ' roduction 11370 13260 Case 11/1/2010 PPL, Ghost, Deft, Temp, Pres, Dens, GR, CCL - b C Pds 20540 -'0erforation 11382 11390 Case 11/14/2010 Perf, HSD 2.875 in PJO, 6 SPF, 60 Deg Phase Perf Zone 6 ED C Pds 20540' Perforation 11430 11442 Case 11/14/2010 Perf, HSD 2.5 in PJO, 6 SPF, 60 Deg Phase Re- Perf Zone 7 DATA SUBMITTAL COMPLIANCE REPORT 3/24/2011 Permit to Drill 2090040 Well Name /No. TRADING BAY UNIT M -06 Operator UNION OIL CO OF CALIFORNIA API No. 50- 733 - 20585 -00 -00 MD 12502 TVD 8770 Completion Date 9/17/2009 Completion Status 1 -GAS Current Status 1 -GAS UIC N ED C Pds 20540-Perforation 11430 11442 Case 11/14/2010 Perf, HSD 2.5 in PJO, 6 SPF, 60 Deg Phase Re- 1 Pert Zone G01 Well Cores /Samples Information: Sample • Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y Daily History Received? 6/ N Chips Received? , j / S Formation Tops Y N Analysis - rnr Received? Comments: ----- _ Compliance Reviewed By: libia i Date: v( `( I"4-6 L1 ' • Page 1 of 1 Aubert, Winton G (DOA) From: Aubert, Winton G (DOA) Sent: Tuesday, March 01, 2011 12:29 PM • To: `Kanyer, Christopher V' • Subject: RE: M -06 PTD 209 -004 (Sundry # 310 -447) Chris, Proposed changes to Sundry y No. 310-447 (well TBU M-36, PTD 209-00.4), as described below, are hereby approved. Ail original Sundry approval stipulations apply, Wnton Auber AOGCC 793-1231 From: Kanyer, Christopher V [ mailto:Chris.Kanyer @chevron.com] Sent: Tuesday, March 01, 2011 11:57 AM To: Aubert, Winton G (DOA) Cc: Tyler, Steve L Subject: M-06 PTD 209-004 (Sundry # 310 -447) Wnton, The operations approved in sundry #310 -447 for plugback and perf operations for M-06 PTD 209 -004 have been completed. The well is currently unable to produce any measurable gas/water flow from either open zone. We have determined that these zones have zero effective permeability. The additional operations of cutting the tubing tail and adding additional perforations of the D14 zone have been attached. We would like to continue these operations as soon as possible and add these to the already approved sundry #310 -447, since we have crews on standby. Note that these operations do not require a spacing exemption. Please do not hesitate to call me if you have any questions. Chris Kanyer *40 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 • 3/1/2011 vv fist T. ..VI k _ 3/112011 OBJECTIVE: • Cut & drop tubing tail, and add D14 zone. PROCEDURE SUMMARY: 2 - = � , 2A '. 1 2B • - 3 Perforate D16B zone from --I 9,235' to 41 9,245', & +/ 9,212' to +1 9,232'. 4 RD.e v =' -'-- =' - - ' =' - - - - 6 RD -Eline,, 10 RU Eline. Pressure test lubricator to 250psi low /2,500psi high. 11 RIH & cut 4 -1/2" tubing at +f- 8,902', verify tubing cut. 12 Perforate D14 zone from +1- 8,932' to +1- 8,940', & +/- 8,950' to +/- 8,966'. 13 RD Eiine. 14 Turn well over to production to flow test well. M-06 REVISED BY: CVK 3 -1 -2011 plfr : 0 •teelhead Platform Well M -6 PROPOSED Casing &Tubing Detail RKB to TBG Head - 78' - BTM BTM SIZE WT GRADE CONN MIN ;D TOP (MD) (TVD) 28" Structural 27" Surface 470' 470' sssv 13 -3/8" 68 L-80 BTC 12.415 Surface 1401' 1371' 9-5/8" 47 L-80 BTC -M 8.681 Surface 7610' 5079' 28" Conductor 7" 26 L -80 DWC 6.276 7346' 12494' 8762' CI ::111, ECP Stage Collar 4-1/2" 12.60 L-80 TC -II 3.958 Surface 11301' 7588' Chemical Injection Sub w/ 2 check valves Est TOC r.' 920' 4.5 WellStar TRSV 12.6 TCIl 444' 444' 6.625 3.813 ECP Stage Collar 448' 448' - - - -- --- 414" SFO -1 Mandrel 1,606' 1,559' 6.250 3.833 4.5 XXO SVLN CIM 12.6 TCII 2,235' 2,042' 5.950 3.813 3 3 8" in 17'h" Hoe 4'A" SFO -1 Mandrel 3,642' 3,070' 6.250 3.833 414" SFO -1 Mandrel 5,580' 4,634' 6.250 3.833 Cement stage collar 5,806' 4,021' - - -- -- 4'/2' SFO -1 Mandrel 7,226' 4,855' 6.250 3.833 4'/" Dura Sleeve / GLV 8,584' 5,653' 5.563 3.810 BOT S -3 Production Packer 8,604' 5,665' 5.960 3.850 X Profile 8,625' 5,678' 5.000 3.813 E : Stage Collar BOT Gun drop sub 8,803' 5,783' 5.020 3.70 Propos TOC $2 6,100' Tubing Tail (cut) 9,182' 7" PosiSet Plug w/ cement on top 9,450' 7" PosiSet Plug w/ cement on top 11,730' 7" PosiSet Plug w/ cement on top 12,330' Perforation Detail MD • /D Zone Density Comments (SPF) 932'- +/ -8,94C D14 ,.,, ,t"el S s 5/8" casing in 12 v." 150'- +/ -8.96E D14 Hole 9,21U 6,010'- 6,021' D16B 6 Perf 2/27/10 Ili 9,235'- 9,245' 6,024'- 6,029' D16B 6 Perf 2/27/10 9,278'- 9,298' 6,047'- 6,057' D16C 6 Perf 2/28/10 C 3 7" x 4 'h" Production 9,308'- 9,328' 6,063'- 6,074' D16C 6 Perf 2/28/10 Profile Nirxile 9,341'- 9,351' 6,081'- 6,086' D16C 6 Perf 2/28/10 BOT Gun drop sub 11,382' - 11,390' 7,675' - 7,683' F -6 6 Perf 10/27/10 11,430' - 11,442' 7,722' - 7,734' F -7 5,6 Reperf 10/23/10 ❑ 11,739' - 11,762' 8,026' - 8,049' F -11 5 Plugged Tag fill at 12,342' - 12,366' 8,619' - 8,642' G-04 5 Plugged 9,386'RKB ELM Tag TOC at Li 9,412'RKBELM Logging In Detail TagTOCat Hole LWL ,Hire Mud Logging 11,666'RKB ELM $(at'tiOT: Tag TOC at 17'A gMWD, GR /RES Gas On Site Geologist 12,317'RKB SLM 12 'h Triple Combo Mudlog On Site Geologist 8'A Triple Combo Mudlog On Site Geologist 4 ■ 7° Liner in 8 12" Hole .en? Information ,scription Volume ly Yield (ft3 /sx) Notes ,;gi Surface 1st stg 254 13.0/14.0 1.95 (B#2) Surface 2 stg 271 13.0 1.95 (B#2) MAX HOLE ANGLE = 57.5° @ 2502' MD Intermediate 1'` stg 155 14.0 1.95 (B#2) Intermediate 2 " stg 418 13.0 1.95 (B#2) Production single stage 237 15.8 1.18 (B#1) Well fPtail Revised RV CVK 3 -1 -2011 y • • k Y W / SEANPARNELLGOVERNOR LA\ U g\ 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 04- Drilling Manager - Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519 Re: McArthur River Field, Middle Kenai Gas Pool, Trading Bay Unit M -06 Sundry Number: 310 -447 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. Sin Vran t Co , mission: DATED this /if day of February, 2011. Encl. • " nizt/Lo10 r r 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 El Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate 0 • Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Tubing Cut 0 , 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 • Exploratory ❑ 209 -004 ° 3. Address: Stratigraphic ❑ S ervice ❑ 6. API Number: PO Box 196247, Anchorage, AK 99519 50- 733 - 20585 -00 • 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 -06 5 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL018730 [Steelhead Platform] McArthur River Field / Middle Kenai Gas Pool . 1 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): • Total Depth TVD (ft): 4 Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12,502 8,770 11,666 7,954 11,666 & 12,317 N/A Casing Length Size - MD / TVD Burst Collapse Structural Conductor 470' 28" 470' 470' Surface 1,401' 13 -3/8" 1,401' 1,371' 5,020 psi 2,260 psi Intermediate Production 7,610' 9 -5/8" 7,610' 5,079' 6,870 psi 4,760 psi Liner 5,148' 7" 12,494' 8,762' 7,240 psi 5,410 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11,382'- 11,390' & 11,430'- 11,442' 7,675'- 7,683' & 7,722'- 7,734', 4 -1/2" 12.6 #, L -80 11,301' Packers and SSSV Type: ,ackers and SSSV MD (ft) and TVD (ft): Baker S -3 Packer / Wellstar TRSV 8,604'MD(5,665'TVD) / 448'MD(448'TVD) 12. Attachments: Description Summary of Proposal 0 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 El Gas El = WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer 263 -7831 Printed Name i r Timothy C. Brandenburg Title Drilling Manager Signature /�� • Phone 276 -7600 Date 12/28/2010 v COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31p-t-41-4,1 EUEIMErL D Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: DEC 2 8 2010 Alaska Oil & Gas Cons. Commission ncsir o �ysi.� •� fe Z o AA-c.. 2s. I t Z p-, (AAA ( �I d pv V4 tkt,c� i s a f pro ve Subsequent Form Required: I, t7 — Lf 0 • APPROVED BY /� Approved by: I OMMISSIONER THE COMMISSION Date: RBDMS of B 2011 „. 14. , , i c' Form 10 -403 Revised 1/2010 4 ? ORIGINAL Submit in Duplicate CheVrrin. • • Trading Bair 'Unit Well # M -06 1/2 OBJECTIVE: • Cut & drop tubing tail, isolate F -6 & F -7 zones, and perforate D16B zone, with contingency to perforate the D16C. PROCEDURE SUMMARY: 1 RU Eline. Pressure test lubricator to 250psi low /2,500psi high. 2 RIH & cut 4 -1/2" tubing at +/- 9,182', verify tubing cut. 2A Set 7" PosiSet plug at (+1-) 9,450'. 2B Dump bail at least 25' cement on top of PosiSet plug. 3 Perforate D16B zone from +/- 9,235' to +/- 9,245', & +/- 9,212' to +/- 9,232'. 4 RD Eline. 5 Tum well over to production to flow test well. Contingency (Pending results of flow test) 6 RU Eline. Pressure test lubricator to 250psi low /2,500psi high. 7 Perforate D16C zone from +/- 9,338' to +/- 9,348', +/- 9,308' to +/- 9,328', & +/- 9,278' to +/- 9,298'. 8 RD Eline. 9 Tum well over to production. M -06 REVISED BY: CVK 1 -27 -2011 Chevron • S•lhead Platform - Well M -6 PROPOSED rasing &Tubing Detail RKB to TBG Head = 78' - 83TM CONN MIN ID TOP (MD) 28" Structural 27" Surface 470' 470' sssv 13 -3/8" 68 L -80 BTC 12.415 Surface 1401' 1371' 28" Conductor 9-5/8" 47 L-80 BTC -M 8.681 Surface 7610' 5079' 7" 26 L-80 DWC 6.276 7346' 12494' 8762' - ECP Stage Collar 4-1/2" 12.60 L -80 TC -I I 3.958 Surface 11301' 7588' Chemical Injection Sub w/ 2 check valves -,2 Dept l Tyr. Est TOC @ 920' 4,5 WellStar TRSV 12.6 TCII 444' 444' 6.625 3.813 `.. ECP Stage Collar 448' 448' 4W SFO -1 Mandrel 1,606' 1,559' 6.250 3.833 L 1 13 3/8" in 17 /" Hole 4.5 XXO SVLN CIM 12.6 TCII 2,235' 2,042' 5.950 3.813 4 SFO -1 Mandrel 3,642' 3,070' 6.250 3.833 4 SFO -1 Mandrel 5,580' 4,634' 6.250 3.833 J Cement stage collar 5,806' 4,021' 4 W SFO -1 Mandrel 7,226' 4,855' 6.250 3.833 4 %2" Dura Sleeve / GLV 8,584' 5,653' 5.563 3.810 BOT S -3 Production Packer 8,604' 5,665' 5.960 3.850 X Profile 8,625' 5,678' 5.000 3.813 E J D Stage Collar BOT Gun drop sub 8,803' 5,783' 5.020 3.70 WLEG 11,301' 7,588' 5.000 3.950 TOC@6,100' - -' 7" PosiSet Plug w/ cement on top 11,730' 7" PosiSet Plug w/ cement on top 12,330' J MD [Vi.) (. , ,ent:- 12' - +/- 9,232 911' - ,u22' _,er Proposed 35'- +/ -9,245 024 029' 6B Proposed Z ' , 9 5/8" Casing in 12'/." '78'- +1 -9,298 047 - _ D16C Intingency Hole +/ -9,328 D16C , gency +' -9,348 016C 'ency ICE 11,382' - 11,390' 7,675' - 7,683' F-6 6 Pert 10/27/10 21r11. 7" x 4 %" Production 11,430' - 11,442' 7,722' - 7,734' F -7 5,6 Reperf 10/23/10 PrnfilP Ninnln. 11 ,739' - 11,762' 8,026' - 8,049' F -11 5 Plugged BOT Gun drop sub 12,342' - 12,366' 8,619' - 8,642' G 04 5 Plugged ■ Elgin Notes . _ 17'/2 gMWD, GR /RES Gas On Site Geologist J Tag TOC at 12'/ Triple Combo Mudlog On Site Geologist 11,666'RKB ELM 8 1 /2 Triple Combo Mudlog On Site Geologist Tag TOC at Cen' '.' 12,31TRKBSLM o s) hillMth 4bl 7" Liner in 81t2" He Surface 1st stg 254 13.0/14.0 1.95 (B#2) Surface 2 stg 271 13.0 1.95 (B #2) Intermediate 1 C stg 155 14.0 1.95 (B #2) Intermediate 2 stg 418 13.0 1.95 (B #2) Production single stage 237 15.8 1.18 (B #1) MAX HOLE ANGLE = 57.5° @ 2502' MD Well fleteil Revisers RY' CVK 12 -28 -201 n Chevron • Sthead Platform , %. WeTf M -6 %. Casing &Tubing Detail RKB to TBG Head = 78' BTM BTM SIZE WT GRADE CONN MIN ID TOP (MD) (TVD) 28" Structural 27" Surface 470' 470' sssv 13 -3/8" 68 L -80 BTC 12.415 Surface 1401' 1371' 28" Conductor 9 -5/8" 47 L -80 BTC -M 8.681 Surface 7610' 5079' 7" 26 L -80 DWC 6.276 7346' 12494' 8762' Mb ECP Stage Collar 4 -1/2" 12.60 L -80 TC -II 3.958 Surface 11301' 7588' Chemical CI, Injection Sub w/ 2 check valves Item Depth MD Depth TVD OD ID J Est TOC @ 920' 4.5 WellStar TRSV 12.6 TCII 444' 444' 6.625 3.813 ECP Stage Collar 448' 448' 4 %" SFO -1 Mandrel 1,606' 1,559' 6.250 3.833 t 4.5 XXO SVLN CIM 12.6 TCII 2,235' 2,042' 5.950 3.813 133/8" in 17 %" Hole 4%" SFO -1 Mandrel 3,642' 3,070' 6.250 3.833 4 '/2' SFO -1 Mandrel 5,580' 4,634' 6.250 3.833 J Cement stage collar 5,806' 4,021' 4 %" SFO -1 Mandrel 7,226' 4,855' 6.250 3.833 • 4'/" Dura Sleeve / GLV 8,584' 5,653' 5.563 3.810 BOT S -3 Production Packer 8,604' 5,665' 5.960 3.850 X Profile 8,625' 5,678' 5.000 3.813 ® J ] Stage Collar BOT Gun drop sub 8,803' 5,783' 5.020 3.70 WLEG 11,301' 7,588' 5.000 3.950 ` TOC @ 6,100' 7" PosiSet Plug w/ cement on top 11,730' 7" PosiSet Plug w/ cement on top 12,330' J Perforation Detail MD TVD Zone (SPF�y Comments 11,382' - 11,390' 7,675' - 7,683' F -6 6 Perf 10/27/10 • 9 5/8" Casing in 12''A" 11,430' - 11,442' 7,722' - 7,734' F -7 5,6 Reperf 10/23/10 Hole 11,739' - 11,762' 8,026' - 8,049' F -11 5 Plugged 12,342' - 12,366' 8,619' - 8,642' G -04 5 Plugged LEI 7" x 4 W Production Prnfila Ninnla BOT Gun drop sub Logging Detail Hole LWD /MWD Wire Line Mud Logging Notes Section 17 % gMWD, GR/RES Gas On Site Geologist 12'/. Triple Combo Mudlog On Site Geologist 8 % Triple Combo Mudlog On Site Geologist Tag TOC at 11,666'RKB ELM Tag TOC at Cementing Information 12,317'RKB SLM Description Volume Density Yield (ft3 /sx) Notes (bbls) (ppg) 7" Liner in 8 1/2" Hole Surface 1st stg 254 13.0/14.0 1.95 (B #2) Surface 2 stg 271 13.0 1.95 (B #2) Intermediate 1 stg 155 14.0 1.95 (B #2) Intermediate 2 stg 418 13.0 1.95 (B #2) Production single stage 237 15.8 1.18 (B #1) MAX HOLE ANGLE = 57.5° @ 2502' MD Well fPtail Revised RV* CVK 11 1R - 201n TBU M -06 Proposed Perfor ions \ `75U BU M -06 `` 2000 0-16B and D -16C Sands vs 110 1 2500 Existing Perforations in • @10 00 TBU M -12 f`' 3U M -32RD \13000 ___,_ __ '° ,T °°'f BU K -24 ( TBU K -05 FD 1213012010 - 1 - ' 0 Tyonek D16 , moo (Proposed) 500 /2_,-30'( 950 ,.00 ' /� —1850 800 • s000 T / T Y2 , 00 � r /5 M - 1 2 (Existing) ` / 6,:• 4412,tY4-0', T BUG18)1PN _ _ - — , :,:.0° TBU M -07 —37500 f —700 7000 ; '. _'�� ail / 5 �, ; n 0 / 6000 50 - / 8 U ,M -01 --1000 k, P f , ; 5500 TBU M -04 � 6000 "" + 'r imi ' 5000 / 'r - 5 , /5500 nnnn 2 , w ' j ' - i . • yV M'� • / 3500 J rr 4 ' 40 p t 7 / 40 0 0, -:a iu 1 ' � / i M- GTB BOW 16 —X500 ----WOO 3000 I 1 t,�h�, 350 X00 - -9,501 f 00 /f r --, II - y0000 ' * ' ' -1 BU M - 03 , ^0500 z- 1 •1� 250 ��., i II le i � . D r au¢� � — ii . !�� i1 � � 10 •C) U �'gt , 8500 " 000 `-, , rhi 7ij f %tiU50 ` - •.1,500 i , .14 • y _,-- i ' • • Davies, Stephen F (DOA) From: RUFF, CHRISTOPHER A [RuffCA @chevron.com] Sent: Wednesday, January 12, 2011 4:45 PM To: Davies, Stephen F (DOA) Cc: Flynn, Tim [ASRC]; Tyler, Steve L; Kanyer, Christopher V; VOORHEES, BRENT J Subject: Exemption to Rule 2 of CO 228 for M -6 Plugback to D16 'II Steve, This email is a follow -up to our phone conversation. The F6 /F7 is currently plugged up due to cross flow from the G04 sand which has been isolated. We have made every attempt to get it to flow and would like to add the D16 zone, but leave the F6/7 zone open in case the gas breaks through over time. The two zones are greater than 1000' TVD and we are requesting an exemption to Rule 2 of CO 228. Our current plan is NOT to set a plug which will isolate the zone, but if we encounter a high fluid level during our operation we most likely will go ahead and isolate the F6/7 prior to perforating the D16 sand. Please contact me if you need more information. Christopher Ruff Petroleum Engineer Office 907 - 263 -7677 Cell 907 -227 -8239 Chevron North America Exploration and Production Midcontinent/Alaska SBU 3800 Centerpoint Dr, Suite 100 Anchorage, AK 99503 From: Kanyer, Christopher V Sent: Wednesday, January 12, 2011 6:50 AM To: RUFF, CHRISTOPHER A; VOORHEES, BRENT J Cc: Flynn, Tim [ASRC]; Tyler, Steve L Subject: FW: M -06 spacing exemption Importance: High I need an answer to Steve's questions below in order to get approval for the M -06 sundry. Please reply to me and I will respond to Steve. Thanks, Chris Kanyer •• Technical Assistant Wellbore Maintenance Team Office: (907) 263 -7831 Cell: (907) 250 -0374 From: Kanyer, Christopher V [mailto:Chris.Kanyer @chevron.com] Sent: Tuesday, January 04, 2011 3:02 PM To: Davies, Stephen F (DOA) Cc: Aubert, Winton G (DOA) Subject: RE: M -06 & M -32RD spacing exemption 1 • Steve • • • I apologize for not getting this to you sooner. Our reservoir engineer overseeing the Steelhead work has been out of office. We would like to request an exemption 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, for proposed work for well M -06 (Sundry 310 -447 PTD 209 -004). This proposed work does not include the abandonment the lowered F -6 and F -7 intervals due to possibility for future production from these zones. The D -16 sands are expected to be lower pressure than the F sands and during recent attempts to inject gas and flow back from the open F zones it is believed that cross flow will not be an issue, as was discussed between Winton and myself on 12/30/10. Please let me know if you have any questions or if further clarification is needed. Thanks, Chris Kanyer o• 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: Tuesday, January 04, 2011 11:17 AM To: Kanyer, Christopher V Cc: Aubert, Winton G (DOA) Subject: RE: M -06 & M -32RD spacing exemption Chris, On December 30 you wrote: 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 currently reviewing this and will get back to you shortly. I thought I'd follow up with you to see what Chevron has decided about perforating this well. I'll hold the sundry application until I hear from you. Thanks, Steve Davies AOGCC 793 -1224 From: Kanyer, Christopher V [mailto:Chris.Kanyer @chevron.com] Sent: Thursday, December 30, 2010 11:49 AM To: Davies, Stephen F (DOA) Subject: RE: M -06 & M -32RD spacing exemption Thanks. Chris Kanyer •• Technical Assistant Wellbore Maintenance Team Office: (907) 263 -7831 2 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 11:48 AM To: Kanyer, Christopher V Subject: RE: M -06 & M -32RD spacing exemption Chris, I'll stamp the map "Confidential" and it will be stored in the Commission's confidential files. Steve Davies AOGCC 793 -1224 From: Kanyer, Christopher V [mailto:Chris.Kanyer @chevron.com] Sent: Thursday, December 30, 2010 11:45 AM To: Davies, Stephen F (DOA) Cc: Aubert, Winton G (DOA) Subject: RE: M -06 & M -32RD spacing exemption I do believe that it should be kept confidential and only used for the needs of the AOGCC and not be broadcasted publically. Thank you for requesting the clarification. 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 From: Davies, Stephen F (DOA) [mailto:steve.davies @alaska.gov] Sent: Thursday, December 30, 2010 11:42 AM To: Kanyer, Christopher V Subject: RE: M -06 & M -32RD spacing exemption Thanks for your help with this. Does Chevron consider the map you attached to your last email to be confidential? Thanks again, Steve Davies AOGCC From: Kanyer, Christopher V [mailto: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 3 • • 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 +/ -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 currently reviewing this and will get back to you shortly. Let me know if you have any additional questions. 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 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 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. 4 , . . ° M-32RD wilt attempt to perforate the F-15C, F-15B and F-14A zones. M-14 had produced from these inteats 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. Ptease let me know if you have any other questions. Thanko, Chris Kany*r Technical Assistant VVe||bore Maintenance Team Office: (907) 263-7831 Cell: (0O7) 25O-O374 Chevron North America Exploration and Production Miduontinent/A|ookaGBU 3800 Centerpoint Dr, Suite 100 Anchorage, AKD9503 5 • • Chevron Francisco Castro Chevron North America Exploration and Production Technical Assistant 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 0410 Tele: 907 263 7844 Fax: 907 263 7828 E -mail: fcastro @chevron.com DATE December 8, 2010 To: AOGCC sx ,� Shartzer, Christine R 333 W. 7 Ave. Ste #100 !. Anchorage, AK 99501 DATA TRANSMITTAL 'r� 01 ?.r°'� -* a } t a ' x x. - r5 ,.r -.- " � .• ' x a M a ._s sr`xw, �` * -"- , V; a. t ,„ x°'�."�", TBU M -06 PERFORATION RECORD F6 ZONE 10/27/2010 11382 -11390 X X TBU M -06 PERFORATION RECORD F7 ZONE 10/23/2010 11430 -11442 X X TBU M -06 PERFORATION RECORD GO1 ZONE 10/23/2010 11430 -11442 X X TBU M -03 PERORATION RECORD B5 ZONE 10/21/2010 3780 -3850 X X TBU M -03 PERFORATION RECORD B4 ZONE 10/22/2010 3624 -3564 X X L _Jd9 -604/ 066 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: Date: • . . • STATE OF ALASKA 0 / 11 J 2 3 � �'a t 0 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate Lf Other LJ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 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 ❑ 209 -004 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic ❑ Service ❑ 6. API Number: 50- 733 - 20585 -00" 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017594 & ADL0018730 [Steelhead Platform] Trading Bay Unit M -06 6 ' 9. Field /Pool(s): McArthur River Field / Middle Gas Pool 10. Present Well Condition Summary: Total Depth measured 12,502 feet Plugs measured 11,666 & 12,317 feet true vertical 8,770 feet Junk measured N/A feet Effective Depth measured 11,666 feet Packer measured 8,604 feet true vertical 7,954 feet true vertical 5,665 feet Casing Length Size MD / TVD Burst Collapse Structural Conductor 470' 28" 470' 470' Surface 1,401' 13 -3/8" 1,401' 1,371' 5,020 psi 2,260 psi Intermediate Production 7,610' 9 -5/8" 7,610' 5,079' 6,870 psi 4,760 psi Liner 5,148' 7" 12,494' 8,762' 7,240 psi 5,410 psi Perforation depth Measured depth 11,382'- 11,390', 11,430' - 11,442' feet True Vertical depth 7,676- 7,683', 7,722'- 7,734' feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" / 12.6# L -80 11,301' MD 7,596' TVD / Baker S -3 Packer 8,604' MD / Packers and SSSV (type, measured and true vertical depth) (5,665' TVD) Wellstar TRSV 448'MD (448'TVD) 11. Stimulation or cement squeeze summary: IECEN ED Intervals treated (measured): N/A Nov 1 9 2010 Treatment descriptions including volumes used and final pressure: a �� N/A 'ies'ke iii k os Coos. Gone► Iom 12. Representative Daily Average Production or Injektiretiyage Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 410 780 psi 139 psi Subsequent to operation: 0 0 0 60 psi 47 psi 13. Attachments: 14. Well Class after work: . Copies of Logs and Surveys Run N/A Exploratory❑ Development El 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: 310 -259 Contact Chris Kanyer 263 -7831 Printed Name Timothy C. Brandenburg Title Drilling Manager r IWO. Signature _ U Phone 276 -7600 Date 11/17/2010 ROOMS / NOV 19 1 Form 10-404 Revised 10/2010 Submit Original Only • • Chevron 1 11%. Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -06 TRADING BAY UNIT M -06 ADL017594 5073320585 LP0335 160.00 185.00 F •'�,: z.4' _ ..' �4 zesty, y _ Primary Job Type Job Category Objective Actual Start Date Actual End Date Plug - Permanent Well 9/1/2010 10/14/2010 Services Primary Wellbore Affected Wellbore UWI Well Permit Number M -06 507332058500 2090040 ' t „ 040 00 :0 912/2010 00;00 Operations Summary RU slickline, pressure test lubricator 250psi low /250psi high. RIH w/ 3.5" GR and tag in GLM at 1,598' SLM. RIH w/ 2.81 and 15' dummy gun and tag at 12,343'. RD slickline. RU Eline, pressure test lubricator 250psi low /2500psi high. RIH to 116', equipment issue at surface, POOH, shut down for night. 912/2010(0000, - 0 0IOOO100xs. Operations Summary RU Eline, pressure test lubricator 250psi low /2500psi high. Equipment failure at surface, suspend operations. 2010 00:00 - 9130/2010 00:00 Ika Operations Summary RU Eline, pressure test lubricator 250psi low /2500psi high. RIH, tie in, and set 7" PosiSet plug at 12,330'. SDFN. 0/3012010 00 :00 10111 .!,: 1 1 , . Operations Summary RIH and dump bail 15.8ppg cement on top of plug from 12,330' to 12,314'. SDFN. 20 1 0 I : 4 01212010 00,:,007,7777 , , x._ Operations Summary RIH and dump bail 15.8ppg cement on top of plug from 12,314' to 12,307' RKB ELM. RD Eline unit. 10/212010 00;00. 1013120100:00 w 'n r 1 7;x : , Operations Summary WOC. RU slickline, pressure test lubricator 250psi low /2500psi high. RIH w/ 3.5" GR, unable to pass obstruction at 1,598' WLM. SDFN. 101312'` 1 & 01 010Q0 04 477, v '., - Operations Summary RIH w/ 2.76" GR and tag top of cement at 12,317' RKB SLM. 1011212010 00:00 - 10113/2010 00 :00 ; , .;,.. 402::1:4?: Operations Summary RU Eline. Pressure test lubricator 250psi low /2500psi high. Begin to RIH set 7" PosiSet plug. 1011312010 1 :0 t3 1 e i,i,1. ; , ri n „ :s , Operations Summary Set 7" PosiSet plug at 11,730' RKB ELM. RIH and made multiple dump bail runs 16.3ppg cement on top of plug from 11,730' to 11,705' RKB ELM. RD Eline unit. 40/2312010 00 :00.101 0 010:00`00 Operations Summary RU Eline. Pressure test lubricator 250psi low /2500psi high. Tagged TOC at 11,666' RKB ELM. Perforate w/ 2.5" PowerJet Omega 60deg 6spf guns from 11,4 111,442'RKB RD Eline, turn well over to production. .4' 4 , :01000;00 -` F" 12 ' .6' . ; . , ��+«''.. � - Operations Summary RU slickline. Pressure test lubricator 250psi low /2500psi high. Tagged at 11,628' RKB SLM. Located fluid level at 7,642'. RD slickline, turn well over to production. 1. . , 1 00:00. 101 11 5!X 11 1 - 7.4 . � , x Operations Summary RU Eline. Pressure test lubricator 250psi low /2500psi high. Perforate w/ 2 -7/8" PowerJet Omega 60deg 6spf guns from 11,382' -1 1,390'RKB ELM. RD Eline, turn well over to production. it Chevron • eteelhead Platform %. Well M -6 %. Casing &Tubing Detail RKB to TBG Head = 78' BTM BTM SIZE WT GRADE CONN MIN ID TOP (MD) (TVD) 28" Structural 27" Surface 470' 470' sssv 13 -3/8" 68 L -80 BTC 12.415 Surface 1401' 1371' 28" Conductor 9 -5/8" 47 L -80 BTC -M 8.681 Surface 7610' 5079' 16 7" 26 L -80 DWC 6.276 7346' 12494' 8762' E CP Stage Collar 4 -1/2" 12.60 L -80 TC -II 3.958 Surface 11301' 7588' Chemical Injection Sub w/ 2 check valves Item Depth MD Depth TVD OD ID Est roc @ szo' 4,5 WeIlStar TRSV 12.6 TCII 444' 444' 6.625 3.813 ECP Stage Collar 448' 448' . 4%" SFO -1 Mandrel 1,606' 1,559' 6.250 3.833 4 XXO SVLN CIM 12.6 TCII 2,235' 2,042' 5.950 3.813 d 13 3/8° in 17 %s Hole 4 %' SFO -1 Mandrel 3,642' 3,070' 6.250 3.833 4'/2' SFO -1 Mandrel 5,580' 4,634' 6.250 3.833 Cement stage collar 5,806' 4,021' 4' /z' SFO -1 Mandrel 7,226' 4,855' 6.250 3.833 4'/2" Dura Sleeve / GLV 8,584' 5,653' 5.563 3.810 BOT S -3 Production Packer 8,604' 5,665' 5.960 3.850 X Profile 8,625' 5,678' 5.000 3.813 II II Stage Collar BOT Gun drop sub 8,803' 5,783' 5.020 3.70 WLEG 11,299' 7,588' 5.000 3.950 roc @ 6,100' 7" PosiSet Plug w/ cement on top 11,730' 7" PosiSet Plug w/ cement on top 12,330' Perforation Detail MD TVD Zone Density Comments (SPF) 11,382' - 11,390' 7,675 - 7,683' F -6 6 Perf 10/27/10 s 5/8° Casing in 12 ;." 11,430' - 11,442' 7,722' - 7,734' F -7 5,6 Reperf 10/23/10 ' Hole 11,739' - 11,762' 8,026' - 8,049' F -11 5 Plugged ' 12,342' - 12,366' 8,619' - 8,642' G -04 5 Plugged • ' I ► 7" x 4'/:" Production ' Prnf,Ie Ninnla BOT Gun drop sub Logging Detail Hole LWD /MWD Wire Line Mud Logging Notes Section 17 % gMWD, GR/RES Gas On Site Geologist 12 % Triple Combo Mudlog On Site Geologist 8'/s _ Triple Combo Mudlog On Site Geologist • -; Tag T at ,�y 11,666'RKB KB ELM �.. Tag TOC at Cementing Information , iul , ' 12,317'RKB SLM Description Volume Density Yield (ft3 /sx) Notes (bbls) (PPM '' 7" Liner in 81/2° Hole Surface 1st stg 254 13.0/14.0 1.95 (B #2) Surface 2 stg 271 13.0 1.95 (B #2) Intermediate 1 stg 155 14.0 1.95 (B #2) Intermediate 2 stg 418 13.0 1.95 (B #2) Production single stage 237 15.8 1.18 (B #1) MAX HOLE ANGLE = 57.5° @ 2502' MD WPII netail RPvis*d RY• CVK 11- 1R -2O10 • • 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: fcastro @chevron.com DATE October 27, 2010 To: AOGCC Mahnken, Christine R 333 W. 7` Ave. Ste #100 Anchorage, AK 99501 DATA TRANSMITTAL WELL LOG TYPE LOG DATE INTERVAL g_ CD LODGED LINE TBU M -06 PRODUCTION LOG 5/19/2010 11350 -13260 X X Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: Date: • • Page 1 of 1 Aubert, Winton G (DOA) From: Kanyer, Christopher V [Chris.Kanyer @chevron.com] Sent: Monday, October 18, 2010 11:27 AM To: Aubert, Wnton G (DOA) Subject: Trading Bay Unit M -06, PTD 209 -004, Sundry #310 -259 Wnton, We wanted to update you on the progress of the Trading Bay Unit M-06, PTD 209 -004, Sundry #310 -259 work. Currently we have set both 7" PosiSet plugs and dump bailed cement, as described in proposed operations in the approved sundry. Plug #1 set at 12,330RKB WLM and Est. TOC at 12,305`RKB. Plug #2 set at 11,730RKB WLM and Est. TOC at 11,705`RKB. In addition to these operations, we plan to reperforate the F -7 zone ( +/- )11,430' -( +/- )11,442' this week. We propose to add these perforating operations to the approved sundry and include these operations on the form 10 -404 for follow -up to sundry 310 -259. Please let me know if you have any questions regarding this request. 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 10/19/2010 r. • • o[F ALANKR SEAN PARNELL, GOVERNOR 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 Union Oil Company of California (� P.O. Box 196247 I Anchorage, AK 99519 Re: McArthur River Field, Middle Kenai Gas Pool, TBU M -06 Sundry Number: 310 -259 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 Zday of August, 2010. Encl. • g ► % .1 • ,(1(3 19 2010 STATE OF ALASKA f'1�SSi0n ALASKA OIL AND GAS CONSERVATION COMMISSION �r�;�. c °f u `,8`,- E,,*". � C APPLICATION FOR SUNDRY APPROVALS ,A0Ct 11 %.1 ' 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrili ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations El Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown Re -enter Sus p. Well Sti mulate Alter Casing OP ❑ p ❑ ❑ 9 ❑ ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development El Exploratory ❑ 209 -004 3. Address: . 6. API Number: Stratigraphic ❑ Service ❑ PO Box 196247, Anchorage, AK 99519 50- 733 - 20585 -00 . 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 -06 9. Property Designation (Lease Number): 10. Field / Pool(s): jf /� ADL- 17594, ADL18730 [Steelhead Platform] McArthur River Field / Grayling Gas Sands i'(,eic/al Ke L.4c.1 ‘4-5 i �v ( ! q, ZG 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12,502 8,770 12,395 8,671 N/A N/A / Casing Length Size MD / TVD Burst Collapse Structural Conductor 470' 28" 470' 470' Surface 1,401' 13 -3/8" 1,401' 1,371' 5,020 psi 2,260 psi Intermediate Production 7,610' 9 -5/8" 7,610' 5,079' 6,870 psi 4,760 psi Liner 5,148' 7" 12,494' 8,762' 7,240 psi 5,410 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): j 11,430'- 11,442', 11,739' -1 7,716'- 7,728', 8,020' - 8,043', 4 -1/2" 12.6 #, L -80 11,301' 11,762', 12,342'- 12,366' 8,613' - 8,637' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker S -3 Packer / Wellstar TRSV 8,604'MD(5,665'TVD) / 448'MD(448'TVD) 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Exploratory ❑ Development 0 ' Service ❑ 14. Estimated Date for 8/20 010 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas 0 . WDSPL ❑ Plugged ❑ 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 Phone 276 -7600 Date 8/18/2010 COMMISSION USE ONLY //�� Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ' i V Q eif Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: ( (40(4 APPROVED BY y/' 9 /l Approved by: COMMISSIONER THE COMMISSION Date: CJ `� / /O RBDMS AUG 3 010 ( ORIGINAL z Form 10-403 Revised 12/2009 Submit in Duplicate • Chevron • Trading Bay Unit %10. Well # M -06 8/18/2010 OBJECTIVE: • Isolate water producing sands. PROCEDURE SUMMARY: 1 RU slickline. Pressure test lubricator to 250psi low /2,500psi high. 2 RIH w/ 3.5" GR and tag PBTD at ( + / -) 12,395'. 7 3 RD Slickline. 4 RU Eline. Pressure test lubricator to 250psi low /2,500psi high. 5 Set 7" PosiSet plug at ( + / -) 12,330'. /- 6 Dump bail at least 25' cement on top of PosiSet plug. 7 RD Eline. 8 Turn well over to production to flow test well. Contingency (Pending results of flow test) 9 RU Eline. Pressure test lubricator to 250psi w /2,500psi high. 10 Set 7" PosiSet plug at ( + / -) 11,730'. 11 Dump bail at least 25' cement on top of PosiSet plug. 12 RD Eline. 13 Turn well over to production. M -06 REVISED BY: CVK 8 -18 -2010 Chevron • !head Platform 11%. At M-6 %. Actual 9 -23 -09 Casing &Tubing Detail RKB to TBG Head = 78' BTM BTM SIZE WT GRADE CONN MIN ID TOP (MD) (TVD) I 28" Structural 27" Surface 470' 470' sssv 13 -3/8" 68 L -80 BTC 12.415 Surface 1401' 1371' 28^ Conductor 9 -5/8" 47 L -80 BTC -M 8.681 Surface 7610' 5079' 7" 26 L -80 DWC 6.276 7346' 12494' 8762' ECP Stage Collar 4 -1/2" 12.60 L -80 TC -II 3.958 Surface 11301' 7588' Chemical Injection Sub w/ 2 check valves Item Depth MD Depth TVD OD ID Est TOC @ 920' 4.5 WellStar TRSV 12.6 TCII 444' 444' 6.625 3.813 ECP Stage Collar 448' 448' 4 %" SFO -1 Mandrel 1,606' 1,559' 6.250 3.833 4. . : 4 XXO SVLN CIM 12.6 TCII 2,235' 2,042' 5.950 3.813 13 s /e^ in 17 i" Hole 4' /z" SFO -1 Mandrel 3,642' 3,070' 6.250 3.833 4' /z' SFO -1 Mandrel 5,580' 4,634' 6.250 3.833 Cement stage collar 5,806' 4,021' 4'/i' SFO -1 Mandrel 7,226' 4,855' 6.250 3.833 4' /P" Dura Sleeve / GLV 8,584' 5,653' 5.563 3.810 BOT S -3 Production Packer 8,604' 5,665' 5.960 3.850 X Profile 8,625' 5,678' 5.000 3.813 • MI . Stage Collar BOT Gun drop sub 8,803' 5,783' 5.020 3.70 WLEG 11,299' 7,588' 5.000 3.950 . TOC @ 6,100' Perforation Detail MD TVD Zone Density Anticipated Pore (SPF) Pressure (psi) .45 psi ft 11,430' — 11,442' 7,716' — 7,728' F -7 5 9 5/8" Casing in 12 'A" Hole 11,739' — 11,762' 8,020' — 8,043' F -11 5 .45 psi ft 12,342' — 12,366' 8,613' — 8,637' G-04 5 .45 psi ft It 7" x 4 W Production Prnfila Ninnla '.... BOT Gun drop sub Logging Detail Hole LWD /MWD Wire Line Mud Logging Notes Section 17'/: gMWD, GR/RES Gas On Site Geologist 12'/a Triple Combo Mudlog On Site Geologist 8' /z Triple Combo Mudlog On Site Geologist Cementing Information = Description Volume Density Yield (ft3 /sx) Notes (bbls) (ppg) 7" Liner in 81/2" Hole Surface 1st stg 254 13.0/14.0 1.95 (B#2) Surface 2' stg 271 13.0 1.95 (B #2) Intermediate 1 stg 155 14.0 1.95 (B #2) Intermediate 2 stg 418 13.0 1.95 (B #2) Production single stage 237 15.8 1.18 (B #1) MAX HOLE ANGLE = 57.5° @ 2502' MD WPII nptail f)RAWN RY• f)R O9/n1 /(l9 Chevron • S Ihead Platform 1%0 M -6 %. PROPOSED RKB to TBG Head = 78' Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM BTM (MD) (TVD) 28" Structural 27" Surface 470' 470' sssv 13 -3/8" 68 L -80 BTC 12.415 Surface 1401' 1371' 28" Conductor 9 -5/8" 47 L -80 BTC -M 8.681 Surface 7610' 5079' 7" 26 L -80 DWC 6.276 7346' 12494' 8762' A ECP Stage Collar 4 -1/2" 12.60 L -80 TC -II 3.958 Surface 11301' 7588' Chemical ' Injection Sub w/ 2 check valves Item Depth MD Depth TVD OD ID • Est roc @ s2a 4.5 WellStar TRSV 12.6 TCII 444' 444' 6.625 3.813 ECP Stage Collar 448' 448' 4'/2' SFO -1 Mandrel 1,606' 1,559' 6.250 3.833 I 1 4.5 XXO SVLN CIM 12.6 TCII 2,235' 2,042' 5.950 3.813 13 3/8" in 17" Hole 4' /2' SFO -1 Mandrel 3,642' 3,070' 6.250 3.833 4 '/2' SFO -1 Mandrel 5,580' 4,634' 6.250 3.833 Cement stage collar 5,806' 4,021' 4 '/2' SFO -1 Mandrel 7,226' 4,855' 6.250 3.833 4'/2' Dura Sleeve / GLV 8,584' 5,653' 5.563 3.810 BOT S -3 Production Packer 8,604' 5,665' 5.960 3.850 X Profile 8,625' 5,678' 5.000 3.813 ® . Stage Collar BOT Gun drop sub 8,803' 5,783' 5.020 3.70 WLEG 11,299' 7,588' 5.000 3.950 TOC @ 6,100' Contingency: 7" PosiSet Plug w/ +/ - 25' cement 11,730' 7" PosiSet Plug w/ +/ -25' cement 12,330' Perforation Detail MD TVD Zone Density Anticipated Pore (SPF) Pressure (psi) 11,430' — 11,442' 7,716' — 7,728' F -7 5 .45 psi ft �' 9 5/8" Casing in 12'/." 11,739' — 11,762' 8,020' — 8,043' F 11 5 .45 psi ft Hole 12,342' — 12,366' 8,613' — 8,637' G -04 5 .45 psi ft g : 7" x 4 W Production 0 Profile Ninnla BOT Gun drop sub Logging Detail Hole LWD /MWD Wire Line Mud Logging Notes Section i 17'% gMWD, GR/RES Gas On Site Geologist 12 % Triple Combo Mudlog On Site Geologist 8'/z Triple Combo Mudlog On Site Geologist . r l30 . = X31 . Cementing Information _ 3, 7 Description Volume Density Yield (ft3 /sx) Notes (bbls) (PPM 7" Liner in 8 1/2" Hole Surface 1st stg 254 13.0/14.0 1.95 (B #2) Surface 2 stg 271 13.0 1.95 (B #2) Intermediate 1 stg 155 14.0 1.95 (B #2) Intermediate 2 stg 418 13.0 1.95 (B #2) Production single stage 237 15.8 1.18 (B#1) MAX HOLE ANGLE = 57.5° @ 2502' MD Well fletail DRAWN RY• CVK R -18 -2010 • i 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 June 28, 2010 To: AOGCC Mahnken, Christine R 333 W. 7 Ave. Ste #100 Anchorage, AK 99501 ..a DATA TRANSMITTAL Transmitted herewith is one DVD containing the following data. • D -48L1 �� • Formation evaluation logs - LAS /9 ( • Gamma ray logs - LAS • K -12RD2 aoca_ (541 / 1365 • K- 12RD2Final_Survey.xls • K- 12RD2__Tops.xlsx oot `6 l Q i 6L • MPR -Gamma ray logs - LAS, CGM, PDF • K -18RD 00/ -// /9.5 • K- 18RD_Final_Survey.doc • Density Neutron logs - LAS b f _ L $d �S • K- 18RDPB1 • UBI log - LAS, PDS, DLIS a0°5-661-1 ; 9' .bb • survey.xls t 9 / d • K -24RD2 c: • Density Neutron logs - LAS • Final Mudlog Report - LAS, DOC 002-406 /9v f • M -06 • Final logs; Depth, Formation Evaluation, Realtime, Time - LAS, PDS, DLIS • M -10 c9dlf ` /(O ` . /c7 • M- 10Tops.xlsx • USIT log - PDS 069 -05'3 /9 ff,(_? • Final logs; Depth, Formation Evaluation, Realtime, Time - LAS, PDS, DLIS • M -10PB1 • Final logs; Depth, Formation Evaluation, Realtime, Time - LAS, PDS, DLIS • M -16RD /' - 69 / 9 1 711 • M- 16RD_Tops.xlsx • Final logs; Cement Bond Log, Completion Record -PDS • M -17 • M- 17_Tops.xlsx • M17_MWD_Survey.pdf • Final Mudlog Report - LAS, DOC, DBF, MDX, PDF, DAT • Final logs; Depth, Formation Evaluation, Cement Bond, Plug Setting, Perforation - LAS, PDS, DLIS, TIFF Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: c..//, Date: 19 ccp�►C , , RECE • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 2 7 ?009 GAS WELL OPEN FLOW POTENTIAL TEST FiaQrilascons.Commission 1a. Test: U Initial U Annual U Special lb. Type Test: U Stabilized 0 Non StabAin@tiort ckd Multipoint ❑ Constant Time ❑ Isochronal ❑ Other 2. Operator Name: 5. Date Completed: 11. Permit to Drill Number: Union Oil Company of California 9/17/2009 209 -004 3. Address: 6. Date TD Reached: 12. API Number: PO Box 196247, Anchorage, AK 99519 September 1, 2009 50- 733 - 20585 -00 4a. Location of Well (Governmental Section): 7. KB Elevation (ft): 13. Well Name and Number: Surface: 1035 FNL 592' FWL, SEC 33 T9N, R13W, SM 160' Steelhead M -6 Top of Productive Horizon: 8. Plug Back Depth(MD +TVD): 14. Field /Pool(s): 716' FNL, 686' FWL, Sec 33, T9N, R13W, SM 12,395' MD (8,671' ND) McArthur River Field Total Depth: 9. Total Depth (MD + ND): Middle Kenia Gas Pool 890' FSL, 2,024' FEL, Sec 21, T9N, R13W, SM 12,502' MD (8,770' ND) 4b. Location of Well (State Base Plane Coordinates): 10. Land Use Permit: 15. Property Designation: Surface: x- 214209.43 y- 2499465.36 Zone- 4 N/A ADL- 17594, ADL 18730 TPI: x- 214310.18 y- 2499781.48 Zone- 4 16. Type of Completion (Describe): Total Depth: x- 217035.47 y- 2506603.27 Zone- 4 perforated casing 17. Casing Size Weight per foot, lb. I.D. in inches Set at ft. 19. Perforations: From To 7" 26 6.276 12,497 11,430- 11,442' 18. Tubing Size Weight per foot, lb. I.D. in inches Set at ft. 11,739- 11,762' 4-1/2" 12.6 3.958 11301 12,342-12,366' 20. Packer set at ft: 21. GOR cf /bbl: 22. API Liquid Hydrocardbons: 23. Specific Gravity Flowing Fluid (G): 8,605' NA NA NA 24a. Producing through: 24b. Reservoir Temp: 24c. Reservoir Pressure: 24d. Barometric Pressure (Pa): 0 Tubing ❑ Casing 144 F° 3169.7 psia @ Datum 7716 NDSS 14.7 psia 25. Length of Flow Channel (L): Vertical Depth (H): Gg: % CO % N2: % H2S: Prover: Meter Run: Taps: NA NA 0.57 0 0 0 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line X Orifice psig Hw F psig F° psig F Hr. Size (in.) Size (in.) 1. X 2630 60 0 NA 0 2. X 2377 50 0 NA 6 3. X 2323 51 0 NA 6 4. X 2288 53 0 NA 6 5. X 2220 59 0 NA 6 Basic Coefficient Flow Temp. Super Comp. No. (24 -Hour) h- Pressure Gravity Factor Rate of Flow Pm Factor Fg O Mcfd Fb or Fp Ft g Fpv 1. 0 2. 14250 3. 16200 4. 17800 5. 20200 Temperature for Separator for Flowing No. Pr T Tr z Gas Fluid Gg G 1. 604 1.760933 0.9229 2. 4.307773109 604 1.760933 0.8443 3. 4.211734694 604 1.760933 0.8438 Critical Pressure 666.4 4. 4.150210084 604 1.760933 0.8435 Critical Temperature 343 5. 4.028661465 604 1.760933 0.843 Form 10-421 Revised 1/2004 CONTINUED ON R kY j(Y1 mit in Duplicate r *. Pc 2644.7 pct 6994438.09 Pf 3169.7 pf 10046998.09 No. Pt Pt Pc Pw Pw Pc Ps Ps Pf -Ps 1. 2. 2391.7 5720229 1274209 479 229441 6764997.09 2870.7 8240918 1806079.6 3. 2337.7 5464841 1529597 469 219961 6774477.09 2806.7 7877565 2169433.2 4. 2302.7 5302427 1692011 463 214369 6780069.09 2765.7 7649096 2397901.6 5. 2234.7 4993884 2000554 450 202500 6791938.09 2684.7 7207614 2839384 25. AOF (Mcfd) 54,180 n 0.78073 Remarks: I hereby certify t hat the foregoing is true and correct to the best of my knowledge. Signed . t 1,„ a fi 4. Title Petroleum Engineer Date 10/26/09 DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia Fb Basic orifice factor Mcfd / ,I hwPm Fp Basic critical flow prover or positive choke factor Mcfd /psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= 4 dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air= 1.000), dimensionless Gg Specific gravity of separator gas (air= 1.00), dimensionless GOR Gas -oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet (TVD) L Length of flow channel, feet (MD) n Exponent (slope) of back - pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut -in wellhead pressure, psia Pf Shut -in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back- Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-421 Revised 1/2004 Side 2 'RECEINta T STATE OF ALASKA OCT g A�2,00� ALAS OIL AND GAS CONSERVATION COMMIS LU WELL COMPLETION OR RECOMPLETION REPORT ; i ,, , P • mg. Commission rI la. Well Status: Oil ❑ Gas 0 Plugged El Abandoned El Suspended El 1b. Well Cl. ` I Anttrr {� 20AAC 25.105 20AAC 25.110 Development el Q 'EScpQor a a1!ory❑ GINJ ❑ WINJ ❑ WDSPL ❑ WAG ❑ Other❑ No. of Completions: Service ❑ Stratigraphic Test 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Union Oil Company of California '' bead_; 9/17/2009 • 209 -004 3. Address: 6. Date Spudded: 13. API Number: PO Box 196247, Anchorage, AK 99519 7/24/2009 50- 733 - 20585 -00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1035 FNL, 592' FWL, Sec 33, T9N, R13W, SM • 9/1/2009 • Trading Bay Unit M -06 Top of Productive Horizon: 8. KB (ft above MSL): 160 • 15. Field /Pool(s): 716' FNL, 686' FWL, Sec 33, T9N, R13W, SM Ground (ft MSL): McArthur River Field Total Depth: 9. Plug Back Depth(MD+TVD): �y� 890' FSL, 2024' FEL, Sec 21, T9N, R13W, SM 12,395' MD (8,671' ND) Grayling Gas Sands \bK k� 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + ND): 16. Property Designation: Surface: x- 214209.43 • y- 2499465.36 • Zone- 4 . 12,502' MD (8,770' ND) • ADL- 17594, ADL -18730 TPI: x- 214310.18 y- 2499781.48 Zone- 4 11. SSSV Depth (MD + ND): 17. Land Use Permit: Total Depth: x- 217035.47 y- 2506603.27 Zone- 4 444' MD (444' ND) N/A 18. Directional Survey: Yes SI No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost (ND): (Submit electronic and printed information per 20 AAC 25.050) 185 (ft MSL) N/A 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): Gamma, Resistivity, Neutron, Density, USIT /CCL logs 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 28 -32 1/2 -1" WT X -56 84' 395' 84' 395' Driven N/A 118bb1 13.0ppg lead /136bb1 13-3/8" 68# L -80 79' 1,400' 79' 79' 17 -1/2" 14.0ppg Class G cement tail stage 1 & 271 bbl 13.0ppg Class G cement stage 2 155bb1 14.0ppg Class G cement 9 -5/8" 47# L -80 77' 7,598' 77' 77' 12 -1/4" stage 1 & 418bb1 13.0ppg Class G cement stage 2 7" 26# L -80 7,341' 12,497' 4,922' 8,771' 8- 1/2 "x9" 240bb1 15.8ppg Class G cement ' 23. Open to production or injection? Yes Ei No ❑ If Yes, list each 24. TUBING RECORD interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) 4 -5/8 "guns, 5spf 60 deg F -7 11,430'- 11,442'MD (7,722'- 7,734' ND) 4 -1/2" 11,301' 8,605' 4 -5/8 "guns, 5spf 60 deg F -11 11,739'- 11,762'MD (8,026' - 8,049' ND) 4 -5/8 "guns, 5spf 60 degG -04 12,342'- 12,366'MD (8,619' - 8,642' ND) 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Flowing ate of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 9/26/2009 24.00 Test Period —► 0 18200 0 N/A N/A Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 2,300psi 1,000psi 24 -Hour Rate .♦ 0 18200 0 N/A 27. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 • Sidewall Cores Acquired? Yes ❑ No li • If Yes to either question, list formations and intervals cored (MD+TVD 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. i (a(N .gyp Etiafi t M. e L ` � q Form 10 -407 Revised 2/2007 CONTINUED ON REVERSE Regn-3 1,4 "4 /0` � ' `� • • 28. GEOLOGIC MARKERS (List all formations and markers 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 See Attached Formation Top Information. Formation at total depth: 30. List of Attachments: Operations Summary, Directional Survey, Wellbore Schematic, Mud Weight Report, Formation Tops 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Flynn 263 -7824 Printed Nap ?: Timothy C. Brandenburg Title: Drilling Manager Signature: . Phone: 276 -7600 Date: 10/15/2009 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 1a: 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 ND 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. Form 10 -407 Revised 2/2007 Steelhead M -06 Formation Tops * , Chevron - _ API No: 50- 733 - 2058 -500 APD: 209 -004 %NO Well Surface ft MDbrf ft TVDbrf ft TVDss Well Surface ft MDbrf ft TVDbrf ft TVDss M -06 SZOCT 800 799 -639 M -06 BICT 4441 3249 -3089 M -06 SZOCT 863 861 -701 M -06 B3ST 4471 3266 -3106 M -06 SZ3CT 993 988 -828 M -06 B4ST 4649 3365 -3205 M -06 SZ5CT 1087 1080 -920 M -06 B2CT 4836 3468 -3308 M -06 SZ6CT 1188 1175 -1015 M -06 B3CT 4868 3486 -3326 M -06 SZ7CT 1241 1225 -1065 M -06 B5ST 4937 3525 -3365 M -06 SZ9CT 1375 1347 -1187 M -06 B4CT 5033 3579 -3419 M -06 SZIOCT 1455 1419 -1259 M -06 B6ST 5081 3606 -3446 M -06 SZIIBST 1564 1516 -1356 M -06 B6AST 5142 3641 -3481 M -06 SZ11CT 1643 1584 -1424 M -06 B5CT 5222 3688 -3528 M -06 SZ12ST 1679 1615 -1455 M -06 CCT 5398 3791 -3631 M -06 SZ12CT 1735 1662 -1502 M -06 C1ST 5449 3820 -3660 M -06 SZ13CT 1827 1737 -1577 M -06 C1CT 5615 3917 -3757 M -06 SZ14CT 1897 1793 -1633 M -06 C2CT 5688 3960 -3800 M -06 SZ15ST 1970 1848 -1688 M -06 C3AST 5718 3977 -3817 M -06 SZ15CT 1988 1861 -1701 M -06 C3ST 5718 3977 -3817 M -06 SZ16ST 2008 1876 -1716 M -06 C4ST 5843 4050 -3890 M -06 SZ16CT 2198 2009 -1849 M -06 C3CT 5870 4065 -3905 M -06 SZ17CT 2340 2098 -1938 M -06 C4CT 5999 4141 -3981 M -06 SZ18ST 2362 2111 -1951 M -06 DCT 6024 4155 -3995 M -06 SZ18CT 2528 2202 -2042 M -06 DIST 6064 4178 -4018 M -06 SZ19CT 2682 2286 -2126 M -06 DICT 6577 4477 -4317 M -06 SZ2OCT 2758 2327 -2167 M -06 D2ST 6690 4542 -4382 M -06 SZ21CT 2886 2397 -2237 M -06 D2CT 6924 4678 -4518 M -06 SZ22ST 2931 2422 -2262 M -06 D2ACT 7006 4726 -4566 M -06 SZ23CT 3040 2481 -2321 M -06 D3BST 7046 4750 -4590 • M -06 SZ23BST 3153 2543 -2383 M -06 D3CT 7194 4836 -4676 M -06 ACT 3233 2587 -2427 M -06 D4CT 7414 4964 -4804 M -06 A2ST 3322 2636 -2476 M -06 D5CT 7464 4993 -4833 M -06 A2CT 3488 2727 -2567 M -06 D6ST 7518 5026 -4866 M -06 A4CT 3710 2850 -2690 M -06 D6CT 7586 5066 -4906 M -06 A5ST 3756 2875 -2715 M -06 D7ST 7652 5104 -4944 M -06 A5CST 3869 2936 -2776 M -06 D7CT 7743 5158 -4998 M -06 A5CT 3938 2974 -2814 M -06 D8ST 7791 5186 -5026 M -06 A6ST 4019 3018 -2858 M -06 D8BST 7817 5202 -5042 M -06 BCT 4218 3126 -2966 M -06 D8CT 7897 5249 -5089 M -06 B2ST 4301 3172 -3012 M -06 D9ST 7910 5256 -5096 Page 1 of 2 Steelhead M -18 Formation Tops Chevron . - API No: 50- 733 - 2058 -300 kill. APD: 208 -162 NW Well Surface ft MDbrf ft TVDbrf ft TVDss Well Surface ft MDbrf ft TVDbrf ft TVDss M -06 D9CT 8167 5408 -5248 M -06 FICT 10987 7287 -7127 M -06 D10ST 8340 5509 -5349 M -06 F2CT 11025 7323 -7163 M -06 DIOCT 8460 5580 -5420 M -06 F3ST 11047 7344 -7184 M -06 D11CT 8538 5626 -5466 M -06 F3CT 11134 7427 -7267 M -06 D12ST 8568 5644 -5484 M -06 F4CT 11197 7488 -7328 M -06 D12CT 8787 5773 -5613 M -06 F5AST 11209 7499 -7339 M -06 D13CT 8894 5835 -5675 M -06 F5BST 11282 7570 -7410 M -06 D14ST 8930 5855 -5695 M -06 F6CT 11409 7695 -7535 • M -06 D14CT 8980 5884 -5724 M -06 F7ST 11429 7715 -7555 M -06 D15ST 9025 5909 -5749 M -06 F7CT 11502 7786 -7626 M -06 D15CT 9144 5974 -5814 M -06 F8BST 11516 7801 -7641 M -06 D16BST 9214 6012 -5852 M -06 F8CT 11590 7873 -7713 M -06 D16CST 9276 6046 -5886 M -06 F9ST 11605 7888 -7728 M -06 D16DST 9419 6124 -5964 M -06 F9CT 11629 7911 -7751 M -06 D16CT 9496 6166 -6006 M -06 F10ST 11664 7946 -7786 M -06 D17ST 9527 6184 -6024 M -06 FIOCT 11709 7990 -7830 M -06 D17CT 9599 6224 -6064 M -06 F11ST 11737 8018 -7858 M -06 D18ST 9629 6241 -6081 M -06 F11CT 11779 8059 -7899 M -06 ECT 9695 6280 -6120 M -06 F12ST 11792 8072 -7912 M -06 E1ST 9791 6338 -6178 M -06 F12CT 11800 8080 -7920 M -06 EICT 10019 6485 -6325 M -06 F13AST 11811 8091 -7931 M -06 E2ST 10062 6515 -6355 M -06 F13CT 11843 8122 -7962 M -06 E2CT 10158 6583 -6423 M -06 F14ST 11854 8133 -7973 M -06 E3CT 10200 6613 -6453 M -06 F15ST 11915 8193 -8033 M -06 E4ST 10242 6645 -6485 M -06 F15CT 12057 8332 -8172 M -06 E4CT 10349 6727 -6567 M -06 F16ST 12078 8353 -8193 M -06 E5ST 10398 6766 -6606 M -06 F17ST 12139 8413 -8253 M -06 E6ST 10646 6976 -6816 M -06 G01ST 12168 8441 -8281 M -06 E6CT 10669 6996 -6836 M -06 GO1 CT 12213 8486 -8326 M -06 E7ST 10709 7032 -6872 M -06 G02ST 12233 8505 -8345 M -06 E7CT 10730 7051 -6891 M -06 G03ST 12291 8563 -8403 M -06 E8ST 10779 7095 -6935 M -06 G04ST 12338 8609 -8449 M -06 E8CT 10795 7109 -6949 M -06 G05ST 12388 8657 -8497 M -06 E9ST 10798 7112 -6952 M -06 G06ST 12427 8696 -8536 M -06 FCT 10839 7149 -6989 M -06 Coal39 12463 8731 -8571 M -06 FIST 10870 7178 -7018 * All depths based on M -06 Cement Evaluation Utrasonic Imaging Tool (USIT) GR /CCL, Run 1, 9- Sept -2009 Page 2 of 2 Chevron • 11%. Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -06 TRADING BAY UNIT M -06 ADL017594 5073320585 LP0335 160.00 185.00 Primary Job Type Job Category Objective Actual Start Date Actual End Date Drill and Complete Drill and 7/19/2009 9/18/2009 Complete Primary Wellbore Affected Wellbore UWI Well Permit Number M -06 507332058500 2090040 7/19/200! 00:00 -747 + 9 +',° i 14'1- '1- Operations Summary Move Rig over Slot 6 on Leg 2. Nipple up diverter and stack,Notified AOGCC of diverter test on 21st. 7/2019 , 1.' . +:00 - 7/21/2: 000 Operations Summary Rig up surface sensors, Jim Regg waived witness of diverter test. J12009 60;66 `- 7/22/2009 00:00 f ` Operations Summary Functioned tested Diverter, continued rig up operations. 7/22/20] ++ 7/2312 +'4. Operations Summary Continue Rig up operations -00:66 ' 00 :00 $ �;;;, m .} x y n . . _ .YA F `4 h .. '•}'.: Operations Summary Finish Rig up operations, M/U 12.25" bit, clean out conductor to 345'MD. 7/24/200000:00 - Eni + r . x ., Operations Summary M/U BHA #1, Spud M -06 drill 17 -1/2" hole ahead to 578' MD. Required 2 runs to change out Gyro tool. rrkr 2009 ++ ' - 7/26/200=000 ,xx, Operations Summary Drill ahead to TD of 17 -1/2" surface hole @ 1405'MD. Circulate bottums up, POOH UD BHA. r 7/26/2009 00 :00 1 +9 00.i; . c.,; Operations Summary RIH, wash conductor @ 480', POOH, Rig up Casing running equipment, Run 13 3/8" 68# L -80 casing to 1400'MD, Land hanger. rr r ;;00 - 7/2812' 00:0 €t " Operations Summary F. se ' 2S alarm after • ing circulation resulted in C gas. Circulation resumed and CO gas returned to normal levels. Cemented 13 3/8" casing with 18b 13.Oppg lead : •bl 14.0ppg tail Class G 'ton the first stage b umped plug at 500psi over final circulating pressure, held. Dropped plug ' open ci e__ . rt w 600 psi an pumped 13 Class G ce m ent i n t he second stage, dropped closing plug, closed stage ports w/ 575psi. Retu were reporte at the end of both - ' -ges, cement to surface on 2nd stage. Nipple down diverter lines. Contacted AOGCC and notified of up coming BOP test ti °+ ' 00.y.,•• 7/29/200V+ r 00 Operations Summary Finished nipple down of diverter and lines, N/U BOP , Tested annular 250psi low /2000psi high, Tested Rams and valves 250psi low /3000psi high. — Performed accumulator pre- charge test. AOGCC John Crisp waived witness of BOP test. 7129/2' , 00.7130/2 9 00 :00 Operations Summary M/U BHA w/ 12.25" bit, RIH, Drill out stage tool, Perform casing test to 1500 psi, drill out shoe track, drill 20' of new hole, perform FIT to 12.8 ppg. 713012' +,+ + , ;00- Tabt2 +" 00'x+ Operations Summary Drill ahead in 12.25" hole from 1425'MD to 3061'MD. I 09 00: ! + 9 0000: r x Operations Summary Drill ahead in 12.25" hole from 3061'MD to 4199'MD . 8 / 2 1 2 0 0 d +' :0O Operations Summary Drill ahead from 4199'MD to 4658'MD, Short trip to shoe, TIH 8/2/2009`40:00 - . ! +9'00:00 - -, -'414,4, �.� ;x . Operations Summary Drill ahead from 4658'MD to 5522'MD. + , 00:004,4t2 � 00100 tv`., ,;�� `� ":.�' j.r �i Operations Summary Drill ahead from 5522'MD to 5710'MD, short trip to 4600'MD, TIH, Drill ahead from 5710'MD to 6374'MD 1I ii i9 ii 1 i :00 Operations Summary Drill ahead from 6374'MD to 6446'MD, Short trip to 5527'MD, TIH, Drill ahead to 6917'MD 8/512009 00: .+ 4 ' l airaii 4 - Operations Summary Drill ahead from 6917' to 7620' MD (TD of 12.25" hole section) Chevron I • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -06 TRADING BAY UNIT M -06 ADL017594 5073320585 LP0335 160.00 185.00 7 i :' ^., 8/61200900:00 - 81712009 00:00 Operations Summary Circulate hole clean, POOH to 1400', TIH to 7620', circulate 4 - 8/8/2009 940 Operations Summary POOH from TD, UD BHA, Prep to run 9 5/8" casing 8/8/2009 00:00 - 844009 00:90 Operations Summary P/U and run 9 5/8" 47# L -80 BTC -Mod casing to 7598'MD, circulate hole clean 'l , 4 . 00:00- 8/1012 :00 ._._ Operations Summary Cement 1st stage w/ 15 .bls 14.0 class G cemen os returns after 30 bbls in open hole, bumped plug w/ pressure up to 2000psi, bled off pressure & confirmed floats hel. •pen stage collar, pumped 418 .bls 13.0 ppg class G bumped plug to 2500 psi, recieved 41 bbls cement at surface. R/D cement equipment, change out 9 -5/8" rams to 7 ". 24 hr : given to AOGCC for upcoming BOP test 8/10/2009 00:00.8/11/.2009 Oo oo Operations Summary 13 3/8 "x9 5/8" packoff failed to test, N /D,BOP's, change out packoff, tested same, good test, N/U BOP's, AOGCC Chuck Scheve waived witness of upcoming BOP test 8 4 *a +S �.! :00 2 °, .00 :14; Operations Summary Test BOP's 250psi low /3000psi high, Test annular 250psi low /2000psi high. AOGCC Chuck Sheve waived witness of BOP test. Rig maintinence, P/U 8.5" drilling assembly w/ 9.0" rhino reamer, TIH r 09, 00:00 - `400900:00 Operations Summary TIH w/ 8.5 "/9.0" Drilling BHA, Drill Stage collar, test casing to 3000 psi for 30 min, Drill 20'MD past casing shoe, perform FIT to 12.8ppg EMW, Drill ahead from 7630'MD to 7966'MD. 8/1 .00:00 '204'9'00:00 t; v w Operations Summary Drill ahead from 7966'MD to 9040'MD 8/14/2009 00: ,-8/1 09 001 r . Operations Summary Drill ahead from 9040'MD to 9478'MD. $ , $;; 00:00- 8/18/2 00:00 Operations Summary Drill ahead from 9478'MD to 9492'MD, POOH to 6773'MD, install torque reduction equipment on drillpipe, TIH, Drill ahead From 9492 to 9600'MD 8116/2009 4w OO m 11A Operations Summary Drill ahead from 9600'MD to 9778'MD, POOH to change bit 8/17/2009 00 :0*4118:2 9 Operations Summary UD, P/U BHA, TIH, Drill ahead from 9778'MD to 9887'MD e, °:$ '} 00 :00 - 8/19/2000:00 Operations Summary Circ & Cond, POOH to change out power drive, Reconfigure power drive Shallow test tools, RIH to csg shoe, Circ & Cond mud, Worked on Top Drive, pipe handler, and IBOP. Cont. RIH 8/19/2009'0 Operations Summary Continue RIH to 9887' Began drilling 8 1/2" X 9" from9887' to 10,172' DPM. Power drive failed, Circ & Cond, Pooh UD BHA, Offloaded new tools began programing tool. ��. 012009 00:00 /200 -00:00 Operations Summary P/U Power Drive W/8 1/2" bit w /9" rhino reamer. RIH began drilling had power drive tool failure. Circ & cond and Pooh UD Tools. Pull wear bushing & R/U to test BOP's, BOP test witnessed waived by AOGCC Lou Gramaldi 81"4/2009 00:00 - 8/221200:00 Operations Summary R/U to test Bop's and tested Bop's to 250 low and 3000 psi high, test witness waived by AOGCC Lou Grimaldi. Tested Koomey unit and R/D testing equipment. Set wear bushing and P/U BHA. RIH Rotary Steerable assy. w/8 1/2" bit X 9" Reamer. 8/2 ° 00:00 - 131200$ t o ¢,! * ,.' Operations Summary Drilling ahead from 10,184' to 10,890' 8/23/2009 00 :00 ,./2009 00:00 -; Operations Summary Drilling ahead from 10,890' to 11052' Drilling stopped Began POOH. 2009 00:00 - 8/25/2009 00:00 > -;, _ Operations Summary POOH for bit, Trip in hole. Drill from 11052' to 11075'. Chevron Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -06 TRADING BAY UNIT M -06 ADL017594 5073320585 LP0335 160.00 185.00 a 8/2 ° °_ , 8126/2009 00 :00 Operations Summary Drill ahead From 11075'MD to 11694'MD. 8/26/2009 00:00 *27/2009 00100 Operations Summary Drill ahead from 11694'md to 11963'MD, Top Drive failure, POOH to shoe, work on top drive 8/2710000:00'- 8128/21 • 00 :00 Operations Summary Repair top drive 0128/2009 00:00 - 812912009 00:00 Operations Summary Continue to repair topdrive 812 S '. 00:00 - 8/30/2009 00:00 Operations Summary Continue to repair top drive 8/30/2009 00 :00 fit_'. -009 00:0.4,2"- Operations Summary Finish top drive repairs, TIH, drill ahead from 11963'MD to 12036'MD. k TL 009 °' ° z 00 - 9/1/200900:00 Operations Summary Drill ahead from 12036'MD to 12468'MD. 9/1/2009 00:00- 9/2)"009 00 .. . Operations Summary Drill ahead to TD @ 12502'MD, curculate, Short trip to 11911'MD, TIH, Circulate, POOH to run 7" liner. ° a 00:00- 9/3/200900000 Operations Summary POOH w/ drilling assembly, UD BHA, P/U Liner hanger assembly 9/3/2009 00:0+ .. 2019 00 s Operations Summary RIH w/ 7" 26# L -80 liner to 12,497', circulate on bottom, pump 240 bbls (1140 sks) 15.8 ppg class G, pressure up to 2000 psi for 5 minutes, floats good. Released from hanger. 9/412009.00x00 - 9/5/2009 t00 Operations Summary POOH w/ running tools, Test BOP's (250/2000 Annular, 250/3000 Rams - choke) Service rig, RIH w/ polish mill. BOP test witness waived by AOGCC Jim ^- Regg 9/6/2009 0000' 0/6/2009 00 :00: �;' Operations Summary Mill PBR POOH, P/U liner top packer, TIH, Packer failed to set, POOH, P/U backup packer assembly x a ¢? 00:00 - 9/7/2000,0:00 9v., Operations Summary TIH w/ packer, attempt to set pack. Mechanically release from packer, POOH, P/U fishing spear to retreive packer. 91712009 00a °eR:'„ 8/2009 604 , *: Operations Summary RIH w/ Spear, retrieve packer, POOH, RIH w/ modified packer, set in PBR, @ 7354'md, test seals to 1000 psi, pressure test annulus to 3000 psi for 30 minutes, good test, POOH. New top of liner at 7,341'. te'�t 00:00 - 919/2009 00:00 Operations Summary Layed down excess 5" DP f /Derrick, Cleaned pits and lines. P/U Bit, scraper assy RIH to Liner top, clean surface lines 919/ ° t` „ ! !. 00 - 9/10/200f00:00 Operations Summary Continue to TIH w/ cleanout assembly. Circulate well with FIW. Pump cleanup sweeps (32 bbls. Caustic, 37 bbls Baraklean and 40 bbl N -Vis) Catch sweeps at surface. Short trip assembly to the TOL and CBU. TIH to PBTD at 12,395' and continue circulating FIW @ 8 BPM Fluid returns —100 NTU and < 500 ppm solids. Finishi mixing 6% KCI in pits +/- 40 NTUs w/ a trace of solids. Prepare to displace well to brine. 9/10/2009 00:00 - 9114/2009 00 ;00 Operations Summary Pumped 40 bbl N -Vis pill and displaced well to completion brine. POOH w/ cleanout assembly to 5160' and cleaned 9 5/8" scraper and magnets. Continue to POOH to surface, recovered and cleaned 7" scraper and magnets. Total metal recovered from well 39 #s. R/U e-line for logging operations. RIH and logged from 12400' to 400' (CBL, GR & USIT). POOH layed down logging tools, R/U gyro tools and prepared to run same. ., f ° ° ' 00 :00" ' ° ; OM"' . Operations Summary RIH w/ Gyro -Data to 300' when tool shorted out. RIH to 3000' and logged up as per procedure. P/U 4 5/8" TCP assembly. Drifted all components above firing head before RIH. Guns loaded as per approved pert sheet. P/U 4 1/2" TC -II tubing and TIH to 5105'. Crossed over to 5" DP and continued to TIH to 6906' Chevron • • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface U M ChevNo Original RKB (ft) Water Depth (ft) M -06 TRADING BAY UNIT M -06 ADL017594 5073320585 LP0335 160.00 185.00 o e 1. ° 9/1212009 06:00 Operations Summary RIH w/ TCP guns, set on depth with wireline tie in, Drop bar, fire guns, perfed F -7 11430'- 11442', F -11 11739'- 11762', and G -04 12342'- 12366', unseat packer, POOH 00:00 9114/2009'00:00 '` Operations Summary POOH w/ 4 -5/8" Millenium 5spf 60 deg TCP guns, L/D Drillpipe and TCP spent guns. All guns fired. 9/14/2009 00:00 0/1612009 00 :00 Operations Summary RIH w/ 4 1/2" 12.6# L- 80TC -II tubing w/ S -3 production packer,(4) GLM's, Chemical injection sub and SSSV, w/ RHC -M plug in X- profile below packer, tubing tail at 11,301'. 9115/009 00 :0 =9116/2009 00:0(G'' Operations Summary Run in hold downs on tubing hanger, rig up Slickline, RIH with ball and rod, pressure up to 3500 psi set packer at 8,605', Pressure test annulus to 3000 psi for 15 min, packer set good. RIH with slickline, shift sliding sleeve open, spot packer fluid, shift sliding sleeve closed with slickline. O/ f t i � .09:0 72909 WOO Operations Summary RIH w/ selective shifting tool to open sliding sleeve @ 8580'. Opened sleeve, POOH and circulated and displaced 40 bbls of packer fluid into the annulus to the lower GLM. RIH w/ shifting tool and closed sleeve. Pressure tested to 500 psi to ensure sleeve was closed, POOH. RIH w/ pulling tool and retrieved the ball /bar prong from the RHC -M plug. RIH and retrieved the RHC -M plug, POOH and R/D slick line. Landing joint backed off at the crossover while breaking out from the hanger, had to pick -up stack to break out the landing joint. Set BPV and N/D BOP stack. . 9117 %2OV09:00 r ":)r"?'a a ti Odd Operations Summary N/U 4 1/8" tree and tested same. Tested void to 250/5000 psi for 30 mins, good test. Pulled BPV and installed 2 -way check and tested tree to 250/5000 psi for 30 mins, good test. Pulled 2 -way check and tested SSSV control line to 5000 psi for 30 min, good test. Removed diverter valves, LD 10 stands of DP and prepared rig to skid to M -02. Final report for M -06. Chevron .elhead Platform .0,,,., , , eII M -6 ---%1011- Actual 9 -23 -09 Casing &Tubing Detail RKB to TBG Head = 78' SIZE WT GRADE CONN MIN ID TOP BTM BTM (MD) (TVD) 28" Structural 27" Surface 470' 470' sssv 13 -3/8" 68 L -80 BTC 12.415 Surface 1401' 1371' 28" Conductor 9 -5/8" 47 L -80 BTC -M 8.681 Surface 7610' 5079' 7" 26 L -80 DWC 6.276 7346' 12494' 8762' C] — ECP Stage Collar 4 -1/2" 12.60 L -80 TC -II 3.958 Surface 11301' 7588' Chemical Injection Sub w/ 2 check valves Item Depth MD Depth TVD OD ID J Est TOC © 920' 4.5 WellStar TRSV 12.6 TCII 444' 444' 6.625 3.813 ECP Stage Collar 448' 448' 4 1 /2" SFO -1 Mandrel 1,606' 1,559' 6.250 3.833 I 4.5 XXO SVLN CIM 12.6 TCII 2,235' 2,042' 5.950 3.813 13 3/8" in 17 %" Hole 4' /z' SFO -1 Mandrel 3,642' 3,070' 6.250 3.833 4'/2' SFO -1 Mandrel 5,580' 4,634' 6.250 3.833 J Cement stage collar 5,806' 4,021' 4 Y2' SFO -1 Mandrel 7,226' 4,855' 6.250 3.833 4 %" Dura Sleeve / GLV 8,584' 5,653' 5.563 3.810 BOT S -3 Production Packer 8,604' 5,665' 5.960 3.850 X Profile 8,625' 5,678' 5.000 3.813 J Stage Collar BOT Gun drop sub 8,803' 5,783' 5.020 3.70 WLEG 11,299' 7,588' 5.000 3.950 TOC @ 6,100' J Perforation Detail MD TVD Zone Density Anticipated Pore (SPF) Pressure (psi) - 11,430' - 11,442' 7,716' - 7,728' F -7 5 .45 psi ft (` - -" " 9 5/8" Casing in 12''h" 11,739' - 11,762' 8,020' - 8,043' F -11 5 .45 psi ft Hole 12,342' - 12,366' 8,613' - 8,637' G -04 5 .45 psi ft 2 7" x 4''A" Production Prnfila Ninnle BOT Gun drop sub Logging Detail Hole LWD /MWD Wire Line Mud Logging Notes Section 17'/2 gMWD, GR/RES Gas On Site Geologist 12'/4 Triple Combo Mudlog On Site Geologist 8 % Triple Combo Mudlog On Site Geologist Cementing Information __ Description Volume Density Yield (ft3 /sx) Notes (bbls) (ppg) AMNIA 7" Liner in 8 1/2" Hole Surface 1st stg 254 13.0/14.0 1.95 (B #2) Surface 2' stg 271 13.0 1.95 (B #2) Intermediate 1 stg 155 14.0 1.95 (B #2) Intermediate 2 stg 418 13.0 1.95 (B #2) Production single stage 237 15.8 1.18 (B #1) MAX HOLE ANGLE = 57.5° @ 2502' MD WPII Detail DRAWN RY• nR 09/01/0g Chevron - - %0 %0 Schlumberger M -06 Survey Report Report Date: September , 2009 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: Chevron Vertical Section Azimuth: 20.000° Field: Trading Bay Unit Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: Steelhead / M -06 (leg B2 slot 6) TVD Reference Datum: Rotary Table Well: M-06 TVD Reference Elevation: 160.25 ft relative to Mean Sea Level • Borehole: M-06 Sea Bed 1 Ground Level Elevation: - 185.000 ft relative to Mean Sea Level UWIIAPI#: 507332058500 Magnetic Declination: 18.455 Survey Name I Date: M-06 / September 8, 2009 Total Field Strength: 55527.662 nT Tort/ AHD 1 DDI I ERD ratio: 180.678 / 7908.37 ft / 6.309 / 0.902 Magnetic Dip: 73.619° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: July 23, 2009 Location LatlLong: N 60 49 54.616, W 151 36 6.031 Magnetic Declination Model: BGGM 2009 Location Grid NIE YIX: N 2499465.360 ftUS, E 214209.430 ftUS North Reference: True North . Grid Convergence Angle: - 1.39865874 Total Corr Mag North -> True North: +18.455 • Grid Scale Factor. 0.99999294 _ Local Coordinates Referenced To: Well Head Measured Azimuth Vertical Along Hole NS EW Comments Depth Inclination True Sub -Sea TVD P/0 Section Departure Closure True North True North DLS Northing Easting Latitude Longitude (ft ) (deg) (deg) (ft) (ft ) (ft ) (ft) (ft) (ft) (ft ) (deg1100ft ) (ftUS) (ftUS) KBE 0.00 0.00 0.00 - 160.25 0.00 0.00 0.00 0.00 0.00 0.00 0.00 • 2499465.36 • 214209.43 N 60 49 54.616 W 151 36 6.031 Gyro Single Shots 310.17 0.12 164.47 149.92 310.17 -0.26 0.32 0.32 -0.31 0.09 0.04 2499465.05 214209.51 N 60 49 54.613 W 151 36 6.030 360.17 0.10 190.35 199.92 360.17 -0.35 0.42 0.42 -0.41 0.09 0.11 2499464.95 214209.51 N 60 49 54.612 W 151 36 6.030 410.56 0.07 215.58 250.31 410.56 -0.42 0.49 0.48 -0.47 0.07 0.09 2499464.88 214209.49 N 60 49 54.611 W 151 36 6.030 437.97 0.14 196.26 277.72 437.97 -0.47 0.54 0.52 -0.52 0.05 0.28 2499464.84 214209.47 N 60 49 54.611 W 151 36 6.030 466.71 0.86 327.28 306.46 466.71 -0.38 0.75 0.38 -0.37 -0.08 3.33 2499464.99 214209.34 N 60 49 54.612 W 151 36 6.033 - 490.92 2.23 338.89 330.66 490.91 0.09 1.40 0.41 0.22 -0.35 5.78 2499465.59 214209.09 N 60 49 54.618 W 151 36 6.038 522.08 3.65 336.74 361.78 522.03 1.27 3.00 1.95 1.70 -0.96 4.57 2499467.08 214208.52 N 60 49 54.632 W 151 36 6.051 553.79 4.70 341.32 393.40 553.65 3.02 5.30 4.24 3.85 -1.77 3.47 2499469.26 214207.75 N 60 49 54.654 W 151 36 6.067 581.60 5.52 345.70 421.10 581.35 5.01 7.78 6.70 6.23 -2.47 3.26 2499471.65 214207.12 N 60 49 54.677 W 151 36 6.081 611.36 5.34 352.02 450.73 610.98 7.42 10.59 9.48 8.99 -3.01 2.10 2499474.42 214206.64 N 60 49 54.704 W 151 36 6.092 641.70 5.66 354.99 480.93 641.18 10.02 13.50 12.34 11.88 -3.34 1.41 2499477.31 214206.38 N 60 49 54.733 W 151 36 6. 9 673.64 5.78 0.13 512.71 672.96 12.96 16.68 15.45 15.05 -3.47 1.65 2499480.49 214206.33 N 60 49 54.764 W 151 36 701.15 5.43 2.68 540.09 700.34 15.50 19.37 18.06 17.74 -3.41 1.56 2499483.18 214206.46 N 60 49 54.790 W 151 36 730.71 5.93 5.98 569.50 729.75 18.32 22.29 20.90 20.66 -3.18 2.02 2499486.09 214206.75 N 60 49 54.819 W 151 36 6.096 1 759.45 6.56 4.49 598.07 758.32 21.34 25.42 23.95 23.77 -2.90 2.26 2499489.19 214207.11 N 60 49 54.850 W 151 36 6.090 818.62 8.19 11.65 656.75 817.00 28.77 33.00 31.32 31.27 -1.79 3.16 2499496.66 214208.41 N 60 49 54.924 W 151 36 6.067 878.54 9.68 12.67 715.94 876.19 37.99 42.31 40.36 40.36 0.18 2.50 2499505.71 214210.60 N 60 49 55.013 W 151 36 6.028 938.13 10.77 15.56 774.59 934.84 48.51 52.88 50.69 50.61 2.77 2.02 2499515.89 214213.44 N 60 49 55.114 W 151 36 5.975 998.87 13.06 19.11 834.02 994.27 61.03 65.42 62.91 62.57 6.54 3.96 2499527.75 214217.50 N 60 49 55.232 W 151 36 5.899 1061.78 15.55 21.52 894.97 1055.22 76.57 80.96 78.05 77.13 11.97 4.07 2499542.18 214223.27 N 60 49 55.375 W 151 36 5.790 1122.93 17.68 21.54 953.56 1113.81 94.05 98.45 95.19 93.40 18.38 3.48 2499558.28 214230.09 N 60 49 55.535 W 151 36 5.661 1180.98 19.72 21.94 1008.55 1168.80 112.65 117.06 113.53 110.68 25.28 3.52 2499575.39 214237.40 N 60 49 55.706 W 151 36 5.521 1244.05 21.92 20.88 1067.50 1227.75 135.06 139.47 135.74 131.55 33.45 3.54 2499596.06 214246.08 N 60 49 55.911 W 151 36 5.357 SurveyEditor Ver SP 2.1 Bld( users) M -06 (leg B2 slot 6) \M- 06 \M- 06 \M -06 current Generated 10/13/2009 1:12 PM Page 1 of 5 Measured Azimuth Vertical Along Hole NS EW Comments Inclination Sub•Sea TVD Closure DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North (ft ) (deg) (deg) (ft) (ft) (ft) (ft) (ft ) (ft) (ft ) (deg/100ft ) (ftUS) (ftUS) 1308.85 24.13 19.87 1127.13 1287.38 160.40 164.81 160.96 155.31 42.26 3.46 2499619.59 214255.47 N 60 49 56.145 W 151 36 5.179 1361.89 25.34 20.45 1175.30 1335.55 182.59 187.01 183.08 176.15 49.92 2.33 2499640.23 214263.63 N 60 49 56.350 W 151 36 5.024 Inc +Trend 1399.66 25.59 19.00 1209.40 1369.65 198.83 203.25 199.29 191.43 55.40 1.78 2499655.38 214269.48 N 60 49 56.501 W 151 36 4.914 1460.13 25.84 17.00 1263.89 1424.14 225.05 229.48 225.51 216.38 63.50 1.49 2499680.13 214278.19 N 60 49 56.747 W 151 36 4.750 1555.36 28.69 15.78 1348.53 1508.78 268.58 273.10 269.13 258.23 75.79 3.05 2499721.67 214291.50 N 60 49 57.159 W 151 36 4.503 MWD- Standard 1650.64 31.42 15.94 1430.99 1591.24 316.17 320.82 316.84 304.13 88.83 2.87 2499767.23 214305.66 N 60 49 57.611 W 151 36 4.239 1742.21 34.05 17.59 1508.01 1668.26 365.60 370.33 366.35 351.53 103.13 3.03 2499814.26 214321.11 N 60 49 58.077 W 151 36 3.951 1798.17 35.66 19.12 1553.93 1714.18 397.57 402.30 398.31 381.88 113.21 3.27 2499844.36 214331.93 N 60 49 58.376 W 151 36 3.748 1838.46 37.10 18.58 1586.37 1746.62 421.46 426.20 422.18 404.49 120.93 3.66 2499866.78 214340.20 N 60 49 58.599 W 151 36 3.592 1887.57 38.68 19.41 1625.12 1785.37 451.61 456.36 452.32 433.01 130.75 3.38 2499895.04 214350.71 N 60 49 58.880 W 151 36 3.394 1934.85 40.07 20.62 1661.67 1821.92 481.61 486.35 482.27 461.19 141.02 3.36 2499922.96 214361.66 N 60 49 59.157 W 151 36 3.187 2030.74 43.15 20.39 1733.36 1893.61 545.27 550.02 545.83 520.82 163.32 3.22 2499982.04 214385.41 N 60 49 59.744 W 151 36 IIII 2127.76 46.31 20.15 1802.27 1962.52 613.54 618.29 614.03 584.87 186.97 3.26 2500045.48 214410.62 N 60 50 0.375 W 151 36 2223.12 49.57 19.97 1866.15 2026.40 684.33 689.08 684.76 651.36 211.25 3.42 2500111.37 214436.51 N 60 50 1.030 W 151 36 1.770 2319.99 52.97 20.82 1926.75 2087.00 759.89 764.64 760.26 722.18 237.59 3.58 2500181.52 214464.57 N 60 50 1.727 W 151 36 1.238 2409.13 56.66 19.69 1978.10 2138.35 832.73 837.48 833.06 790.52 262.79 4.27 2500249.22 214491.44 N 60 50 2.400 W 151 36 0.730 2502.28 57.51 18.64 2028.72 2188.97 910.91 915.68 911.24 864.38 288.46 1.31 2500322.44 214518.90 N 60 50 3.128 W 151 36 0.212 2593.92 57.11 17.98 2078.22 2238.47 988.00 992.80 988.37 937.60 312.69 0.75 2500395.04 214544.91 N 60 50 3.849 W 151 35 59.723 2692.08 57.10 16.35 2131.53 2291.78 1070.32 1075.22 1070.77 1016.35 337.01 1.39 2500473.17 214571.15 N 60 50 4.624 W 151 35 59.233 2785.15 56.80 16.74 2182.29 2342.54 1148.19 1153.23 1148.74 1091.13 359.23 0.48 2500547.38 214595.18 N 60 50 5.360 W 151 35 58.784 2883.60 56.80 17.55 2236.20 2396.45 1230.46 1235.61 1231.11 1169.85 383.51 0.69 2500625.49 214621.38 N 60 50 6.136 W 151 35 58.294 2978.92 56.81 18.40 2288.38 2448.63 1310.18 1315.37 1310.87 1245.72 408.13 0.75 2500700.73 214647.84 N 60 50 6.883 W 151 35 57.798 3072.86 57.06 17.84 2339.64 2499.89 1388.86 1394.10 1389.59 1320.54 432.61 0.57 2500774.93 214674.14 N 60 50 7.620 W 151 35 57.304 3168.71 56.93 19.17 2391.85 2552.10 1469.21 1474.48 1469.97 1396.76 458.12 1.17 2500850.51 214701.50 N 60 50 8.370 W 151 35 56.789 3260.90 56.93 19.25 2442.15 2602.40 1546.46 1551.74 1547.22 1469.72 483.54 0.07 2500922.82 214728.70 N 60 50 9.088 W 151 35 56.276 3357.21 56.94 19.37 2494.70 2654.95 1627.17 1632.45 1627.91 1545.89 510.23 0.10 2500998.32 214757.24 N 60 50 9.839 W 151 35 55.738 3449.22 56.50 19.50 2545.19 2705.44 1704.08 1709.37 1704.82 1618.42 535.82 0.49 2501070.21 214784.59 N 60 50 10.553 W 151 35 55.221 3547.59 56.36 20.67 2599.58 2759.83 1786.05 1791.33 1786.74 1695.40 563.97 1.00 2501146.48 214814.61 N 60 50 11.311 W 151 35 54.653 3643.09 56.22 21.20 2652.58 2812.83 1865.48 1870.77 1866.11 1769.60 592.36 0.48 2501219.96 214844.80 N 60 50 12.042 W 151 35 54.080 3738.50 56.95 21.71 2705.13 2865.38 1945.09 1950.41 1945.65 1843.72 621.49 0.89 2501293.34 214875.73 N 60 50 12.771 W 151 35 5 3831.92 57.24 20.45 2755.88 2916.13 2023.51 2028.84 2024.01 1916.90 649.69 1.17 2501365.81 214905.71 N 60 50 13.492 W 151 35 5 3927.73 56.90 19.67 2807.96 2968.21 2103.92 2109.26 2104.40 1992.44 677.28 0.77 2501440.65 214935.13 N 60 50 14.236 W 151 35 52.367 4023.52 56.94 19.24 2860.25 3020.50 2184.18 2189.52 2184.66 2068.12 704.01 0.38 2501515.66 214963.70 N 60 50 14.981 W 151 35 51.827 4117.41 57.11 18.68 2911.35 3071.60 2262.93 2268.29 2263.42 2142.61 729.60 0.53 2501589.50 214991.11 N 60 50 15.715 W 151 35 51.311 4210.85 56.76 18.65 2962.33 3122.58 2341.22 2346.60 2341.73 2216.80 754.66 0.38 2501663.06 215017.97 N 60 50 16.445 W 151 35 50.805 4305.63 56.57 18.38 3014.41 3174.66 2420.38 2425.78 2420.92 2291.88 779.81 0.31 2501737.51 215044.94 N 60 50 17.185 W 151 35 50.298 4401.60 56.35 18.19 3067.44 3227.69 2500.33 2505.77 2500.90 2367.84 804.90 0.28 2501812.82 215071.88 N 60 50 17.932 W 151 35 49.791 4497.82 56.46 17.98 3120.68 3280.93 2580.44 2585.92 2581.05 2444.03 829.79 0.21 2501888.38 215098.62 N 60 50 18.683 W 151 35 49.289 4590.07 56.45 17.98 3171.65 3331.90 2657.27 2662.81 2657.93 2517.16 853.52 0.01 2501960.91 215124.13 N 60 50 19.403 W 151 35 48.810 4686.07 56.11 17.62 3224.95 3385.20 2737.06 2742.66 2737.76 2593.18 877.93 0.47 2502036.32 215150.38 N 60 50 20.151 W 151 35 48.318 4780.89 56.39 17.80 3277.63 3437.88 2815.84 2821.50 2816.59 2668.29 901.91 0.33 2502110.81 215176.19 N 60 50 20.891 W 151 35 47.834 I SurveyEditor Ver SP 2.1 Bld( users) M -06 (leg B2 slot 6) \M- 06 \M- 06 \M -06 current Generated 10/13/2009 1:12 PM Page 2 of 5 ■ Comments Measured Inclination Azimuth Sub -Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North (ft ) (deg) (deg) (ft ) (ft) (ft) (ft) (ft) (ft ) (ft ) (deg1100ft ) (ftUS) (ftUS) 4873.99 56.04 18.60 3329.40 3489.65 2893.18 2898.87 2893.97 2741.79 926.08 0.81 2502183.71 215202.15 N 60 50 21.615 W 151 35 47.346 4970.50 56.37 18.84 3383.08 3543.33 2973.36 2979.08 2974.17 2817.75 951.82 0.40 2502259.01 215229.73 N 60 50 22.363 W 151 35 46.826 5066.34 54.46 18.87 3437.48 3597.73 3052.25 3057.98 3053.07 2892.42 977.32 1.99 2502333.04 215257.05 N 60 50 23.098 W 151 35 46.312 5160.45 54.41 19.02 3492.21 3652.46 3128.79 3134.53 3129.62 2964.83 1002.17 0.14 2502404.81 215283.66 N 60 50 23.811 W 151 35 45.810 5255.33 54.31 18.18 3547.50 3707.75 3205.87 3211.64 3206.73 3037.91 1026.77 0.73 2502477.27 215310.03 N 60 50 24.531 W 151 35 45.314 5350.76 54.32 18.69 3603.17 3763.42 3283.35 3289.15 3284.24 3111.44 1051.28 0.43 2502550.18 215336.33 N 60 50 25.255 W 151 35 44.819 5444.12 54.33 20.27 3657.62 3817.87 3359.19 3364.99 3360.07 3182.93 1076.57 1.37 2502621.04 215363.36 N 60 50 25.959 W 151 35 44.309 5539.18 54.17 21.09 3713.16 3873.41 3436.33 3442.14 3437.17 3255.11 1103.81 0.72 2502692.53 215392.35 N 60 50 26.670 W 151 35 43.759 5633.32 54.42 20.75 3768.10 3928.35 3512.76 3518.58 3513.56 3326.52 1131.11 0.40 2502763.25 215421.38 N 60 50 27.373 W 151 35 43.208 5728.34 54.59 20.87 3823.27 3983.52 3590.12 3595.94 3590.88 3398.83 1158.59 0.21 2502834.87 215450.63 N 60 50 28.085 W 151 35 42.653 5823.77 54.52 21.26 3878.61 4038.86 3667.85 3673.69 3668.56 3471.38 1186.53 0.34 2502906.71 215480.33 N 60 50 28.799 W 151 35 42.089 5919.03 54.42 20.51 3933.97 4094.22 3745.36 3751.21 3746.04 3543.81 1214.17 0.65 2502978.45 215509.73 N 60 50 29.512 W 151 35 41 1 6013.63 54.20 20.29 3989.16 4149.41 3822.19 3828.04 3822.84 3615.82 1240.95 0.30 2503049.78 215538.26 N 60 50 30.221 W 151 35 4 6108.41 54.80 19.40 4044.20 4204.45 3899.35 3905.20 3899.99 3688.40 1267.14 0.99 2503121.70 215566.21 N 60 50 30.936 W 151 35 4 . 6202.60 54.36 19.55 4098.79 4259.04 3976.11 3981.96 3976.75 3760.77 1292.73 0.48 2503193.42 215593.56 N 60 50 31.649 W 151 35 39.946 6296.40 54.52 19.64 4153.34 4313.59 4052.41 4058.27 4053.05 3832.66 1318.33 0.19 2503264.66 215620.90 N 60 50 32.357 W 151 35 39.429 6390.16 54.49 19.97 4207.78 4368.03 4128.75 4134.61 4129.38 3904.48 1344.19 0.29 2503335.83 215648.51 N 60 50 33.064 W 151 35 38.907 6487.39 54.32 20.99 4264.37 4424.62 4207.81 4213.67 4208.42 3978.54 1371.85 0.87 2503409.19 215677.97 N 60 50 33.793 W 151 35 38.349 6582.05 54.28 20.16 4319.61 4479.86 4284.67 4290.54 4285.26 4050.51 1398.87 0.71 2503480.48 215706.73 N 60 50 34.502 W 151 35 37.803 6676.15 54.56 20.11 4374.36 4534.61 4361.20 4367.07 4361.78 4122.36 1425.21 0.30 2503551.67 215734.82 N 60 50 35.209 W 151 35 37.272 6771.75 54.47 20.06 4429.86 4590.11 4439.05 4444.91 4439.61 4195.47 1451.94 0.10 2503624.10 215763.33 N 60 50 35.929 W 151 35 36.732 6865.97 54.42 19.21 4484.64 4644.89 4515.70 4521.57 4516.26 4267.67 1477.70 0.74 2503695.65 215790.84 N 60 50 36.640 W 151 35 36.212 6961.34 54.38 19.33 4540.16 4700.41 4593.24 4599.11 4593.80 4340.87 1503.29 0.11 2503768.20 215818.22 N 60 50 37.361 W 151 35 35.695 7056.06 54.29 18.79 4595.39 4755.64 4670.18 4676.07 4670.76 4413.60 1528.42 0.47 2503840.30 215845.11 N 60 50 38.077 W 151 35 35.188 7149.76 54.28 18.21 4650.09 4810.34 4746.23 4752.14 4746.83 4485.75 1552.56 0.50 2503911.84 215871.01 N 60 50 38.788 W 151 35 34.701 7246.02 54.14 16.48 4706.38 2 50398 5.77 215896.10 N 60 50 39.521 W 151 35 34.231 4866.63 4824.23 4830.23 4824.87 4560.28 1575.84 1.47 7340.10 54.29 16.67 4761.40 4921.65 4900.41 4906.54 4901.12 4633.42 1597.61 0.23 2504058.37 215919.65 N 60 50 40.242 W 151 35 33.791 7435.48 54.27 16.28 4817.08 4977.33 4977.70 4983.98 4978.48 4707.68 1619.57 0.33 2504132.06 215943.41 N 60 50 40.973 W 151 35 33.348 7528.60 54.15 16.04 4871.54 5031.79 5053.07 5059.52 5053.93 4780.23 1640.60 0.25 2504204.08 215966.20 N 60 50 41.687 W 151 35 32.923 7645.35 53.72 16.17 4940.27 5100.52 5147.22 5153.89 5148.19 4870.90 1666.77 0.38 2504294.08 215994.58 N 60 50 42.580 W 151 35 32.395 7742.20 53.76 16.87 4997.55 5157.80 5225.17 5231.99 5226.22 4945.77 1688.98 0.58 2504368.39 216018.61 N 60 50 43.317 W 151 35 3 7836.61 54.07 17.50 5053.16 5213.41 5301.38 5308.28 5302.48 5018.66 1711.52 0.63 2504440.71 216042.93 N 60 50 44.035 W 151 35 31. 1 7930.63 53.94 18.35 5108.42 5268.67 5377.39 5384.35 5378.54 5091.04 1734.93 0.74 2504512.49 216068.10 N 60 50 44.748 W 151 35 31.019 8025.43 54.09 18.29 5164.12 5324.37 5454.07 5461.06 5455.24 5163.86 1759.05 0.17 2504584.70 216093.98 N 60 50 45.465 W 151 35 30.532 8120.61 53.99 18.08 5220.01 5380.26 5531.07 5538.10 5532.28 5237.05 1783.09 0.21 2504657.28 216119.80 N 60 50 46.186 W 151 35 30.046 8216.11 54.05 17.43 5276.12 5436.37 5608.29 5615.38 5609.55 5310.65 1806.66 0.55 2504730.28 216145.16 N 60 50 46.910 W 151 35 29.571 8311.93 54.08 17.28 5332.35 5492.60 5685.79 5692.97 5687.11 5384.70 1829.80 0.13 2504803.75 216170.10 N 60 50 47.640 W 151 35 29.103 8403.27 53.52 18.18 5386.30 5546.55 5759.44 5766.67 5760.80 5454.91 1852.24 1.00 2504873.38 216194.25 N 60 50 48.331 W 151 35 28.650 8501.35 53.88 19.69 5444.36 5604.61 5838.47 5845.72 5839.84 5529.67 1877.89 1.29 2504947.50 216221.72 N 60 50 49.067 W 151 35 28.132 8597.57 53.49 22.97 5501.36 5661.61 5915.96 5923.24 5917.28 5601.88 1906.08 2.78 2505018.99 216251.66 N 60 50 49.778 W 151 35 27.563 8690.40 53.67 27.13 5556.49 5716.74 5990.34 5997.93 5991.51 5669.52 1937.70 3.61 2505085.85 216284.92 N 60 50 50.444 W 151 35 26.925 8784.13 54.44 30.44 5611.52 5771.77 6065.32 6073.80 6066.25 5736.01 1974.24 2.97 2505151.42 216323.07 N 60 50 51.099 W 151 35 26.187 SurveyEditor Ver SP 2.1 Bld( users) M -06 (leg B2 slot 6) \M- 06 \M- 06 \M -06 current Generated 10/13/2009 1:12 PM Page 3 of 5 Measured Azimuth Vertical Along Hole NS EW Comments Inclination Sub -Sea ND Closure DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North (ft ) (deg) (deg) (ft) (ft) (ft ) (ft) (ft) (ft ) (ft ) (deg1100ft ) (ftUS) (ftUS) 8878.54 54.89 30.17 5666.12 5826.37 6141.09 6150.82 6141.79 5802.50 2013.10 0.53 2505216.94 216363.55 N 60 50 51.753 W 151 35 25.403 8973.63 55.77 29.99 5720.21 5880.46 6218.09 6229.02 6218.59 5870.18 2052.30 0.94 2505283.64 216404.38 N 60 50 52.420 W 151 35 24.611 9070.31 56.62 30.14 5774.00 5934.25 6297.19 6309.36 6297.52 5939.70 2092.55 0.89 2505352.16 216446.31 N 60 50 53.104 W 151 35 23.799 9164.16 56.90 31.52 5825.45 5985.70 6374.28 6387.85 6374.48 6007.10 2132.78 1.27 2505418.56 216488.18 N 60 50 53.768 W 151 35 22.987 9258.45 57.49 35.00 5876.54 6036.79 6451.40 6467.10 6451.48 6073.35 2176.24 3.16 2505483.73 216533.24 N 60 50 54.420 W 151 35 22.109 9353.05 57.03 38.67 5927.72 6087.97 6527.54 6546.66 6527.55 6137.02 2223.92 3.30 2505546.22 216582.47 N 60 50 55.047 W 151 35 21.146 9446.41 56.08 38.08 5979.17 6139.42 6601.47 6624.56 6601.49 6198.09 2272.28 1.15 2505606.09 216632.30 N 60 50 55.649 W 151 35 20.170 9540.87 56.46 38.41 6031.62 6191.87 6676.08 6703.12 6676.20 6259.79 2320.91 0.50 2505666.58 216682.42 N 60 50 56.256 W 151 35 19.188 9635.77 55.13 39.24 6084.97 6245.22 6750.36 6781.60 6750.68 6320.93 2370.11 1.58 2505726.50 216733.10 N 60 50 56.858 W 151 35 18.195 9713.14 53.07 38.74 6130.33 6290.58 6809.62 6844.27 6810.16 6369.64 2409.55 2.71 2505774.23 216773.71 N 60 50 57.338 W 151 35 17.399 9732.75 52.81 38.23 6142.15 6302.40 6824.46 6859.92 6825.06 6381.89 2419.29 2.46 2505786.24 216783.75 N 60 50 57.458 W 151 35 17.202 9824.75 52.12 38.00 6198.20 6358.45 6893.80 6932.87 6894.73 6439.29 2464.32 0.78 2505842.52 216830.16 N 60 50 58.023 W 151 35 16 9918.52 50.04 37.81 6257.11 6417.36 6963.22 7005.82 6964.54 6496.85 2509.14 2.22 2505898.97 216876.37 N 60 50 58.590 W 151 35 1 10014.09 46.13 37.35 6320.94 6481.19 7031.00 7076.93 7032.75 6553.19 2552.51 4.11 2505954.24 216921.11 N 60 50 59.145 W 151 35 14.513 10103.34 44.81 37.07 6383.53 6543.78 7091.77 7140.55 7093.96 6603.86 2590.98 1.50 2506003.95 216960.81 N 60 50 59.644 W 151 35 13.736 10204.36 42.72 36.93 6456.48 6616.73 7158.59 7210.42 7161.29 6659.66 2633.04 2.07 2506058.71 217004.21 N 60 51 0.193 W 151 35 12.887 10300.39 39.62 36.93 6528.76 6689.01 7219.06 7273.63 7222.26 6710.19 2671.01 3.23 2506108.30 217043.41 N 60 51 0.691 W 151 35 12.120 10395.88 35.71 35.89 6604.33 6764.58 7275.01 7331.97 7278.69 6757.13 2705.66 4.15 2506154.37 217079.19 N 60 51 1.153 W 151 35 11.421 10491.12 33.45 34.22 6682.74 6842.99 7327.20 7386.02 7331.31 6801.35 2736.72 2.57 2506197.83 217111.32 N 60 51 1.588 W 151 35 10.794 10585.79 30.37 31.46 6763.10 6923.35 7375.96 7436.04 7380.42 6843.36 2763.89 3.60 2506239.15 217139.51 N 60 51 2.002 W 151 35 10.245 10680.71 27.49 27.04 6846.18 7006.43 7421.23 7481.94 7425.93 6883.35 2786.38 3.78 2506278.58 217162.97 N 60 51 2.395 W 151 35 9.791 10775.07 25.17 22.34 6930.75 7091.00 7462.90 7523.77 7467.70 6921.32 2803.91 3.30 2506316.11 217181.42 N 60 51 2.769 W 151 35 9.437 10868.63 22.43 16.92 7016.36 7176.61 7500.62 7561.50 7505.38 6956.81 2816.67 3.74 2506351.28 217195.04 N 60 51 3.119 W 151 35 9.179 10965.14 19.94 10.48 7106.35 7266.60 7535.24 7596.34 7539.86 6990.61 2825.03 3.53 2506384.87 217204.22 N 60 51 3.452 W 151 35 9.010 11059.51 17.95 6.94 7195.61 7355.86 7565.28 7626.97 7569.67 7020.88 2829.71 2.43 2506415.01 217209.64 N 60 51 3.750 W 151 35 8.916 11153.87 15.10 1.31 7286.07 7446.32 7591.10 7653.78 7595.23 7047.60 2831.75 3.46 2506441.68 217212.33 N 60 51 4.013 W 151 35 8.874 11248.30 12.98 350.78 7377.69 7537.94 7612.01 7676.63 7615.84 7070.37 2830.33 3.51 2506464.48 217211.47 N 60 51 4.237 W 151 35 8.903 11340.96 11.57 337.21 7468.24 7628.49 7627.91 7696.24 7631.38 7089.22 2825.06 3.45 2506483.45 217206.66 N 60 51 4.423 W 151 35 9.009 11438.28 9.80 321.31 7563.89 7724.14 7639.38 7714.18 7642.45 7104.68 2816.10 3.52 2506499.13 217198.08 N 60 51 4.575 W 151 35 9.190 11534.27 9.91 311.09 7658.47 7818.72 7646.60 7730.56 7649.26 7116.49 2804.77 1.82 2506511.21 217187.04 N 60 51 4.691 W 151 35 11628.16 10.43 303.36 7750.89 7911.14 7651.47 7747.12 7653.73 7126.47 2791.58 1.55 2506521.51 217174.10 N 60 51 4.790 W 151 35 11723.35 10.51 299.67 7844.50 8004.75 7654.92 7764.41 7656.78 7135.51 2776.84 0.71 2506530.90 217159.59 N 60 51 4.879 W 151 35 9. 2 11817.44 10.57 297.24 7937.00 8097.25 7657.45 7781.62 7658.96 7143.71 2761.71 0.48 2506539.47 217144.66 N 60 51 4.959 W 151 35 10.288 11882.63 10.50 295.82 8001.09 8161.34 7658.81 7793.54 7660.09 7149.03 2751.05 0.41 2506545.05 217134.13 N 60 51 5.012 W 151 35 10.503 11909.31 10.61 295.63 8027.32 8187.57 7659.29 7798.42 7660.49 7151.15 2746.65 0.43 2506547.28 217129.78 N 60 51 5.033 W 151 35 10.592 12006.80 10.80 294.78 8123.12 8283.37 7660.94 7816.53 7661.83 7158.86 2730.26 0.25 2506555.38 217113.59 N 60 51 5.109 W 151 35 10.922 12102.66 10.80 295.23 8217.28 8377.53 7662.50 7834.49 7663.15 7166.46 2713.98 0.09 2506563.37 217097.50 N 60 51 5.183 W 151 35 11.251 12193.72 10.67 299.23 8306.75 8467.00 7664.63 7851.45 7665.08 7174.21 2698.91 0.83 2506571.49 217082.62 N 60 51 5.260 W 151 35 11.555 12292.87 10.63 301.18 8404.19 8564.44 7667.88 7869.77 7668.15 7183.43 2683.07 0.37 2506581.09 217067.02 N 60 51 5.351 W 151 35 11.875 12372.26 10.69 302.77 8482.21 8642.46 7670.93 7884.46 7671.09 7191.20 2670.62 0.38 2506589.17 217054.76 N 60 51 5.427 W 151 35 12.126 Last Survey 12439.73 10.59 305.49 8548.52 8708.77 7673.96 7896.91 7674.06 7198.19 2660.31 0.76 2506596.41 217044.62 N 60 51 5.496 W 151 35 12.334 TD (Projected) 12502.00 10.59 305.49 8609.73 8769.98 _ 7677.02 7908.35 7677.07 7204.83 2650.99 0.00 2506603.27 217035.47 N 60 51 5.562 W 151 35 12.522 SurveyEditor Ver SP 2.1 Bld( users) M -06 (leg B2 slot 6) \M- 06 \M- 06 \M -06 current Generated 10/13/2009 1:12 PM Page 4 of 5 , Measured Azimuth Vertical Along Hole NS EW Comments Inclination Sub-Sea TVD Closure DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North (ft ) (deg) (deg) (ft) (ft ) (ft ) (ft) (ft ) (ft ) (ft ) _ (degl100ft )_ (ftUS) (ftUS) Survey Type: Definitive Survey Survey Error Model: SLB ISCWSA version 24 * ** 3 -D 95.00% Confidence 2.7955 sigma Surveying Prog: MD From ( ft) MD To ( ft ) EOU Freq Survey Tool Type Borehole -> Survey 0.00 345.25 Act -Stns SLB_NSG +SSHOT -Depth Only M -06 -> M -06 current 345.25 1361.89 Act -Stns SLB_NSG +SSHOT M -06 -> M -06 current 1361.89 1460.13 Act -Stns SLB_INC +TREND M -06 -> M -06 current 1460.13 12439.73 Act -Stns SLB_MWD -STD M -06 -> M -06 current 12439.73 12502.00 Act -Stns SLB BLIND M -06 -> M -06 current Legal Description: Northing (Y) fftUS] Eastinq (X) fftUS] Surface : 4245 FSL 4688 FEL S33 T9N R13W SM 2499465.36 214209.43 • BHL : 890 FSL 2024 FEL S21 T9N R13W SM 2506603.27 217035.47 • SurveyEditor Ver SP 2.1 Bld( users) M -06 (leg B2 slot 6) \M- 06 \M- 06 \M -06 current Generated 10/13/2009 1:12 PM Page 5 of 5 M -06 Mud Weight vs. Depth (MD & TVD) 0 1000 Surface Casing set at 1405'MD 2000 3000 +0.:. 4000 • 5000 — ` - - - - - — Intermediate set at 5088 TVD 6000 .--�� BMW vs. MD ' —U —MW vs. TVD 7000 - Intermediate set at 7620' MD 8000 ear 9000 - �� 10000 11000 12000 13000 8 8.5 9 9.5 10 10.5 2o'' oo cf Chevron Steelhead Platform Well M -06 Updated Drilling Procedure M -06 Basic Drilling Procedure 1. RU Steelhead rig over slot B2 -6. 2. Install A section wellhead and test. 3. Install 21 1 /4 2M /20 3 /4 3M combo diverter /BOP stack and dual 16" diverter lines. Function test diverter per AOGCC requirements. 4. MU 17'/2" bit and clean out conductor to 480'. 5. MU 17%2" directional BHA and drill to 1243'MD' taking gyro surveys as necessary. 6. _ MU jet wash tool and wash out conductor to 470'. 7. Run and cement 13 3/8" casing to surface in 2 stages utilizing an ECP stage collar. 8. Install 13 5/8 multi bowl wellhead system. NU BOP stack. Install blind flanges on diverter outlets. Install 9 5/8 rams. Test stack to 250/3000. 9. MU 12'/4" drill out BHA and drill out stage tool. Test casing to 1500 psi. 10. Drill out shoe track and perform FIT to 12.8 ppg EMW. 11. Trip. MU directional BHA. 12. Directionally drill to 6616'MD. 13. Run and cement 9 5/8 casing to ML in 2 stages. 14. Redress BOP's w/ 7" rams and test 250/3000 psi. Test 9 5/8" casing to 3000 psi a. Failed to test 13 3/8" x 9 5/8" pack off b. ,;f SOP's c. .;'ser - u , d. insta new p - Ru vim..± om !vc:,zdown. c/n € ' as h cnc i. �.; : EE d . r , . ..r ,.. --. ' n pins �� i�,a:; t..'u�ti i� i ce. `,A �� . ,�".J: tU e r � r l ..'>..�'.�'`.i c ......_s� i. : iii \ l -- .; s/ ec spa` L'.a i. r a. Iy BO' s ; a. ! Test 250/3000 f Test Casing 9 5t•8 casino " "3 3000 os 15. MU 8'/2" directional BHA and drill out. Perform FIT to 12.8 ppg EMW. 16. Directionally drill to section TD at 12475'MD. 17. Pull wiper trip. 18. Run 7" Liner, hanger, and liner top packer. Set liner hanger and cement. Set packer. 19. Redress BOP's and test 250/3000. Test 7" liner to 3000 psi. 20. PU clean out string and make bit and scraper runs to PBTD. Displace to completion fluid. 21. RU TCP guns and perforate productive intervals 22. Run 4 '/2 t ubi`'q. Space out and land tubing. Test void. 23. Install BPV and ND BOP. 8/11/2009 Page 1 of 2 • I Steelhead Platform Well M -06 Updated Dulling Procedure 24. NU tree and test. 25. RDMO Steelhead rig. 8/11/2009 Page 2 of 2 Page 1 of 2 ooh • 201 - Aubert, Winton G (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, July 20, 2009 7:15 AM To: Tim Flynn Cc: Aubert, Winton G (DOA) Subject: FW: TBU M -06 preparing to Spud Attachments: Updated M -06 Cement Calculations.doc Tim, I am forwarding your note to Tinton. He is handling Cook Inlet now, Tom From: Flynn, Tim [ASRC] [mailto:Tim.Flynn@chevron.com] Sent: Sunday, July 19, 2009 2:15 PM To: Maunder, Thomas E (DOA) Subject: TBU M -06 preparing to Spud Tom M -18 has been wrapped up and we are preparing to move the rig over this weekend to drill TBU M-06 on the Steelhead platform. We will look at spudding M -06 sometime mid week if all our rig prep operations are completed on schedule. Since the permit 209 -004 was submitted and approved back in January, a few changes will need to be addressed: Surface Casing Setting Depth: Permitted surface casing setting depth was 1243' MD (40' ND above the SV -11 sand interval). A mistake was made and this was based on SSTVD. The correct 13 3/8" casing shoe will be at 1403' MD (1243' SSND) which as planned in the permit approximately 40' ND above the SV -11 sand (The first productive gas interval). The planned casing setting depth will be very similar to M -18. Attached is the updated cement volumes planned to be pumped. Total Volume pumped: 542 bbls (3042 ftA3 or 1560 sks) Intermediate Casing Setting Depth: Permitted intermediate casing setting depth was 6616'MD. Based on updated findings from M -18, the 12.25" casing shoe has been lowered to 7700'MD. This will allow the liner lap to be in an area of no future production and shorten the 7" liner for a better cement job across productive intervals. The MASP for the section is still driven by the 13 3/8" casing shoe resulting in no change to what has been permitted. Attached is the updated cement volumes to be pumped. Total Volume pumped: 683 bbls (3834 ftA3 or 1966 sks) 7/20/2009 Page 2 of 2 • • Cement In Surface and Intermediate: Permitted cement in both surface and intermediate section was 13.0 Lite Crete w/ Gas block. Research was completed and confirmed that a class G blend with gas block would achieve the compressive strength and gas block required for these sections. It is planned to pump 2 stage cement jobs with the Class g blend, but add a 14.0 ppg tail to achieve compressive strength prior to drill out. Please let me know if you require more information for these changes to M -06 prior to spud. Thank you Tim Flynn Operations Drilling Engineer Chevron North America Exploration and Production 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 907- 263 -7824 phone 907- 317 -5504 cell 7/20/2009 Chevron • • Steelhead Platform Well M -06 Drilling Program 2009 Stage 1 Lead = 273 bbls of 13.0 ppg class G w/ gas block Stage 1 Tail = 55 bbls of 14.0 ppg class G w/ gas block Total Volume, Stage 1 = 322 + 5.86 4eybbls of 13.0/14.0 ppg class G w/ gas block 9 5/8 ", 47 ppf, Intermediate Casing in l 2 Hole, Stage 2 Cement from stage collar at 4400' to ML at 345' OH Volume w/75% excess = (4400- 1403)*0.0558 *1.75 = 292 bbls Cased Hole Volume = (1403 -345) *.0597 = 63 bbls Total Volume, Stage 2 = 292 + 63 bbls 355 bbls of 13.0 ppg class G w/ gas block Production Liner 7 ", 26 ppf, Production Liner in 8 %2" Hole Cement from section TD at 12462' to 7200' (500' inside the 9 5/8" casing) OH Volume w /50% excess = (1 2462 - 7700)*0.0226 *1.5 = 161.0 bbls Shoe Track Volume = 80*0.0383 = 3.1 bbls Cased Hole Annular Volume = 500*0.0256 = 12.8 bbls Total Cement Volume = 161 + 3.1 + 12.8 = 177 bbls of 15.8 ppg G LXT Slurry Chevron • • Steelhead Platform Well M -06 Drilling Program 2009 Updated (7 -15 -2009) M -06 Cement Calculations Surface Casing 13 3/8 ", 68 ppf, Surface Casing in 17 Hole, Stage 1 Cement from section TD at 1403' to the ECP stage tool at 470' OH Volume w/ 75% excess = (1403 -470) *0.1237 *1.75 = 201.0 bbls Shoe Track Volume = 80*0.149 = 12.0 bbls Stage 1 Lead = 93 bbls of 13.0 ppg class G w/ gas block Stage 1 Tail = 120 bbls of 14.0 ppg class G w/ gas block Stage 1 Total Volume = 201 +12.0 = 213 bbls of 13.0/14.0 ppg class G w/ gas block 13 3/8 ", 68 ppf, Surface Casing in 34 OD x Various ID Structural Pile Conductor, Stage 2 Cement from 470' to surface (ECP is 10' long) Annular Volumes = 470*0.7005 = 329 bbls Stage 2 Total Volume = 329 bbls of 13.0 ppg class G blend w/ gas block Notes: Used 30" ID as average for volumetric calculations. Intermediate Casing 9 5/8", 47 f, Intermediate Casing in 12 /4 Hole, Stage 1 PP 9 g Cement from section TD at 7700' to 4400' OH Volume w/75% excess = (7700- 4400)*0.0558 *1.75 = 322 bbls Shoe Track Volume = 80 *0.0732 = 5.86 bbls • 0 IT - F 1 E ir --,\ - R,L A r 1 :::1 /A i E t ` � SARAH PALIN, GOVERNOR IP 1� f ALASKA OIL AND GAS / 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION j ANCHORAGE, ALASKA 99501 -3539 J PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy Brandenburg Drilling Manager Unocal PO Box 196247 Anchorage AK 99519 Re: McArthur River Field, Middle Kenai Gas Pool, TBU M -06 Unocal Permit No: 209 -004 Surface Location: 1035' FNL, 592' FWL, SEC. 33, T9N, R13W, S Bottomhole Location: 886' FSL, 2013' FEL, SEC. 21, T9N, R13W, S Dear Mr. Brandenburg: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not I authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31,05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 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). . 'ncerely, - VP Daniel Z`. Seamount, Jr. Chair DATED this day of January, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA a --, A ASKA OIL AND GAS CONSERVATION COMMISSION , 07 1,, PERMIT TO DRILL hki?o Alaska 01; 6 a e r; L' 20 AAC 25.005 1a. Type of Work: lb. Current Well Class: Exploratory ❑ Development Oil El 1c. Specifyif well is propos�f(ora 4.310i: Drill p Redrill ❑ Stratigraphic Test ❑ Service ❑ Development Gas Q Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone ❑ Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11. Well Name and Number: Union Oil Company of California Bond No. 086S103515406BCM • Tradng Bay Unit M -06 3. Address: 6. Proposed Depth: 12. Field /Pool(s): PO Box 196247, Anchorage, AK 99519 MD: 12462 r TVD: • 8756 McArthur River Field 4a. Location of Well (Governmental Section): 7. Property Designation: G(ayling ands 27J� Surface: 1035' FNL, 592' FWL, Sec 33, T9N, R13W, S , ADL- 17594, ADL 18730 • kt + 4617,1 k ia_ `.5 ett Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2313' FNL, 2129' FWL, Sec 28, T9N, R13W, S 2/10 /2009 Total Depth: 9. Acres in Property: 14. Distance to Nearest 886' FSL, 2013' FEL, Sec 21, T9N, R13W, S • 5116, 3840 Property: >6000' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface: x- 214209 , y- 2499465. Zoi 4 (Height above GL): 160 AMSL ' feet Within Pool: 786' (M -12) 16. Deviated wells: Kickoff depth: 600 feet • 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 56 degrees Downhole: 3868 Surface: 2995 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) Cond 28 -32 1/2 - 1" WT X -56 Weld 390 0 0 • 470 470 Driven 17 1/2" 13 3/8" 68 L -80 BTC 1163 0 0 (4° 3 .3243' 12 `f 51.23e- 285fft3 in 2 stages o il Z .4.3 12 1/4" 9 5/8" 47 L -80 BTC -M 6536 0 0 770o-6646 -45530 3075 - ft3 - i n 2 stages 3 g 3 c/ (5 t , 8 1/2" 7" 26 L -80 DWCSR 6062 f Zao -64e0 .4422 12462 - 8756 1.336-ft31n 1 stage ii V 'i s . .1 ) ' \ ,.\' �ti 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth ND (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor /Structural 401.00 28 -32 Driven 470 470 Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ❑ BOP Sketch 0 Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat El Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program El 20 AAC 25.050 requirements El 21. Verbal Approval: Commission Representative: Date 12/23/2008 22. I hereby certify that the foregoing is true and correct. Contact Tim Flynn, 907 - 263 - 7824 Printed Name Timothy Brandenburg Title Drilling Manager Signature' ��i�� Phone Date j 5 D Commission Use Only Permit to Drill API Number: / Permit Approval See cover letter for other Number: 2t5-j -CPC */ 50- 733 - 2.0 5 Date: I ' a l. nGI requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:[ Other: V `c,\ k I xQOQst G , Ns a ck` 1 Samples req'd: Yes❑ NoE ' Mud log req'd: Yes❑ No[✓ T H measures: Yeses NoL Directional svy req'd: Yes['No❑ t i- a."‘.e) \E iii( kto Cc°V-c \ ir e CkCig- Q \ >\t Af\C a() SChCa -. APPROVED BY THE COMMISSION 27 DATE: � COMMIISSIONER - Form 10 -401 Revised 12/2005 , - . t N Subm in Df"ip tcca �7'4)1 I 1 long �� / Page 1 of • • Maunder, Thomas E (DOA) From: Flynn, Tim [ASRC] [Tim.Flynn @chevron.com] Sent: Monday, January 19, 2009 2:56 PM To: Maunder, Thomas E (DOA) Subject: RE: TBU M -06 -- AGAIN Importance: High Tom I spoke with Gary Orr and he was able to pull a copy of the formation test that was recorded in the GGS GO6 sand in Well K -30 in 1970. The GGS GO6 sand is the deepest GGS sand and although it was tested it has never been produced. The pressure recorded results in a .44 psi /ft gradient. The pressure test was recorded at 8538' TVD. We plan on drilling to the base of the GGS sand at 8483'TVD in M -06. This is the highest "expected" pressure in the area. If calculating from the base of the GGS sand: MASP © .42 and 8538' TVD = 2884 psi In the calculations for MASP for the 401 for M -06, a conservative approach was taken but still under the 3000 psi limit of our BOP stack. Let me know if you need further information. Thank you Tim Flynn Operations Drilling Engineer Chevron North America Exploration and Production 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 907- 263 -7824 phone 907- 317 -5504 cell From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, January 14, 2009 1:41 PM To: Flynn, Tim [ASRC] Subject: RE: TBU M -06 -- AGAIN Tim, The tvd on this well is much deeper than M -18. The pore pressure at TD is based on 8.5 EMW pore pressure. How likely is encountering that pressure? Calculating MASP according to the AOGCC requirements results in a value of 2995 psi. I know it is unlikely that that surface pressure would be seen in a drilling mode, however that is getting close to the BOP rating. I look forward to your reply. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) 1/20/2009 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Flynn, Tim [ASRC] [Tim.Flynn ©chevron.com] Sent: Wednesday, January 14, 2009 2:00 PM To: Maunder, Thomas E (DOA) Subject: RE: TBU M -06 Tom Here is the cement information: Surface: (Both stages) Yield: 1.46 ft3 /sk Total sks: 1956 Intermediate (Both stages) Yield: 1.45 ft3 /sk Total sks: 2120 Production Yield: 1.20 ft3 /sk Total sks: 1113 Tim Flynn Operations Drilling Engineer Chevron North America Exploration and Production 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 907- 263 -7824 phone 907 - 317 -5504 cell From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, January 14, 2009 1:19 PM To: Flynn, Tim [ASRC] Subject: TBU M -06 Tim, I am reviewing the application to drill this well. 1. Could you provide the sack count and yield for the various cement slurries? Thanks in advance. Tom Maunder, PE 1/15/2009 • • Chevron Timothy C Brandenburg Union Oil Company of California MNOI Drilling Manager P.O. Box 196427 Anchorage, AK 99519 -6247 Tel 907 263 7657 Fax 907 263 78888 4 Email brandenburgt @chevron.com December 23, 2008 Commissioner ECE Alaska Oil & Gas Conservation Commission JAN 0 2009 333 W. 7 Avenue Alaska Oil & Gas t;oi �°o� mission Anchorage, Alaska 99501 Anchorage Re: Steelhead M -06 Dear Commissioner, Enclosed for review and approval is the application for the Permit to Drill the Steelhead M -06 well. Drilling operations are expected to commence approximately February 10, 2009 depending on the progress of M -18. In accordance with 20 AAC 25.005 (c)(4)(A -C). (A) MASP calculations are attached for review. (B) The Grayling Gas Sands are potentially gas bearing throughout the section. Potential target reservoirs and their predicted pore pressures are indicated in the attached M -06 Well Design Summary. (C) Due to ongoing production operations in this field, sub - normally pressured sands occur in multiple places. Lost circulation and • differential sticking are potential problems. Conventional solutions such as LCM and good drilling practice are intended to ameliorate the problems. An exception to 20 AAC 25.035 (c)(1)(B) is requested. The diverter system at Steelhead includes two 16" diameter diverter lines. • The surface hole section of M -06 is planned to be drilled with a 17 %" bit. Union Oil Company of California / A Chevron Company Page 1 of 2 1 • In accordance with 20 AAC 25.050 (b)(2)(B)... Union Oil Company of California is the only operator of wells within 200' of the . planned trajectory of M -06. Pursuant to 20 AAC 25.005 (c)(14)... Qualified drilling waste will be discharged in accordance with NPDES permit • AKG -31 -5000 which became effective 7/2/2007 and expires 7/2/2012. At this time, Union Oil Company does not intend to apply for annular disposal approval. The remainder of the requirements of 20 AAC 25.005 are attached for review or are • on file with the Commission. If you have any questions, please don't hesitate to contact myself or Tim Flynn at 907 - 263 -7824. Sincerely, Cc Timothy C. Brandenburg Drilling Manager Attachments: Form 10-401 in Duplicate M -06 Cementing Calculations M -06 Well Design Summary M -06 Casing Design M -06 Summary Drilling Procedure M -06 MASP Calculations M -06 Summary Mud Program M -06 FIT / LOT Procedure M -06 Planned Well Sketch M -06 Spider Plots M -06 Planned Well Trajectory M -06 Combo BOP /Diverter Schematic M -06 Drilling Hazards Notice M -06 Choke Manifold Schematic M -06 Plat Cc: File Union Oil Company of California / A Chevron Company Page 2 of 2 Chevron i S Steelhead Platform Well M-06 1%0 Well Design Summary M -06 Well Design Summary Steelhead M -06 is a development well drilled in a NNE direction from slot B2- 6. The well penetrates multiple primary and secondary Grayling Gas Sand targets from the SZ11 to TD 80+ ft and below Base GGS /Coa139 and in upper . G oil sands. M -06 is designed as an "S" shaped, well reaching 55 degrees inclination in . the tangent section and reaching a total depth of 12462' MD, 8756' TVD. . Basic Well Information Platform: Steelhead Well Name: M -06 Estimated Spud Date: 02/10/09 Field: McArthur River Productive Horizon: Grayling Gas Sands PTD: TBD Total Depth: 12462' MD, 8756' TVD Slot: Slot B2 -6, NE Leg Surface Location: 1035' FNL, 592' FWL, Sec 33, T9N, R13W, S X= 214209, Y= 2499465, NAD27, ASP, Zone 4 Planned BHL: 886' FSL, 2013' FEL, Sec 21, T9N, R13W, SSM Original KB Elevation: 160' AMSL KB to THF: TBD Casing and Tubing Program Hole Tube Weight Length Top Btm Size (in) O.D. (lbs / ft) Grade Conn (ft) MD /TVD MD /TVD (in) (ft) (ft) Driven 28 -32 X -56 Weld 390 BF 470 17 1 /2 13 3/8 68 L -80 BTC 1163 BF 1243/1230 12 '/4 9 5/8 47 L -80 BTC -M 6536 BF 6616/4550 8 7 26 L -80 DWCSR 6062 6400/4422 12462/8756 TBG 3 1 /2 9.2 L -80 HSO3 TBD THF TBD 12/23/2008 Page 1 of 4 S Chevron 4111. Steelhead Platform Well M -06 Well Design Summary Well Control Summary Hole Section Equipment Test Pressure (psi) „ 21 1/4 2M Diverter c/w 2 ea 16" 600 psi Diverter 171/2,9 Valves* Function 21 V4 2M Annular, 20 3 /4 3M Double Gate, 12'/4" 20 3 /4 3M Mud Cross, 20 3/ 3M Single Gate 250/3000 3 1/8 5M Choke Manifold* (Annular 1000 psi) 21 1/4 2M Annular, 20 3 /4 3M Double Gate, 8'/2" 20 3/4 3M Mud Cross, 20 3/ 3M Single Gate 250/3000 3 1/8 5M Choke Manifold* (Annular 1000 psi) * Schematics of the well control equipment are attached for reference Anti- Collision Evaluation Summary There are two close approach wells. With the exception of M -7 that is behind the conductor, and M -5 at 612' all other nearby wells pass major risk criteria. Collision risk will be mitigated procedurally by monitoring annular pressures of adjacent wellbores and placing an observer in the wellhead room to listen for indications of a collision. A Gyro MWD tool will be used to accurately survey the wellbore in the surface hole while drilling. Close Approach M -06 Path Ellipse Separation Diverging From Well (MD ft) (ft) (ft) M -5 612 -1.31 612 M -7 377 -1.16 438 12/23/2008 Page 2 of 4 0 0 Chevron 1%0 Steelhead Platform Well M-06 %0 Well Design Summary Formation Integrity Testing Test Point, 20' Projected Projected Test Projected Below... Depth Test Type (EMW ppg) Casing Test (TVD) (PSI) 13 3/8" Csg Shoe 1263 FIT 12.8 1500 9 5/8" Shoe 6636 FIT 12.8 3000 7" liner 3000 Mud Program Summary Section Depth Mud Type Density Viscosity PV YP API FL (MD ft) (ppg) (sec) 17 1 /2" Surf. 0 -1243 Pre -Hyd Gel 9.0 -9.3- 60 -85 10 -28 25 -35 <12 12 V4 Interm. 1243 -6608 KCL /GEM /Pmr 9.1 -9.3 40 -53 6 -15 13 -20 <_6 8 1 /2" Prod. 6608 -12462 KCL /GEM /Pmr 9.2 -9.3 • 40 -53 6 -15 13 -20 <_6 Cementing Summary See Attachments Formation Markers Target Top TVD /SS Depths Measured Pore Pressure EMW Requirement Depth (RKB) V8 (PSI) (ppg RKB) SZ11 -1288 1478 675 SZ12 -1456 1672 300 SZ17 -1897 2263 615 SZ22 -2258 2887 615 A2 -2486 3287 510 B3 -3113 4386 368 B5 -3369 4835 299 Cl -3671 5364 995 C5 -3962 5874 995 D1 -4041 6012 995 D2 -4409 6658 995 12/23/2008 Page 3 of 4 . S Chevron %WW1 Steelhead Platform Well M -06 %.1 Well Design Summary Formation Markers cont. Target Top TVD /SS Depths Measured Pore Pressure EMW Requirement Depth (RKB) V8 (PSI) (ppg RKB) D3 Absent 675 D6 -4903 7524 300 D14 -5726 8966 615 D16C -5913 9295 615 D17 -6048 9530 510 EFG Sand -7573 11437 3800 , 12/23/2008 Page 4 of 4 I Chevron Steelhead Platform Well M-06 %10 Basic Drilling Procedure M -06 Basic Drilling Procedure 1. RU Steelhead rig over slot B2 -6. 2. Install A section wellhead and test. 3. Install 21 1 /4 2M /20 3/ 3M combo diverter /BOP stack and dual 16" diverter lines. Function test diverter per AOGCC requirements. 4. MU 17 1 /2" bit and clean out conductor to 480'. . 5. MU 17'/2" directional BHA and drill to 1243'MD' taking gyro surveys as necessary. 6. MU jet wash tool and wash out conductor to 470'. 7. Run and cement 13 3/8" casing to surface in 2 stages utilizing an ECP stage collar. 8. Install 13 5/8 multi bowl wellhead system. NU BOP stack. Install blind flanges on diverter outlets. Install 9 5/8 rams. Test stack to 250/3000. 9. MU 12 '/4" drill out BHA and drill out stage tool. Test casing to 1500 psi. 10. Drill out shoe track and perform FIT to 12.8 ppg EMW. 11. Trip. MU directional BHA. \ 12. Directionally drill to 6616'MD. 13. Run and cement 9 5/8 casing to ML in 2 stages. 14. Redress BOP's w/ 7" rams and test 250/3000 psi. Test 9 5/8" casing to 3000 psi `o_ n 15. MU 8 directional BHA and drill out. Perform FIT to 12.8 ppg EMW. g i f V 16. Directionally drill to section TD at 12475'MD. ‘0 .16 4. „1U 17. Pull wiper trip. 18. Run 7" Liner, hanger, and liner top packer. Set liner hanger and cement. Set packer. 19. Redress BOP's and test 250/3000. Test 7" liner to 3000 psi. 20. PU clean out string and make bit and scraper runs to PBTD. Displace to completion fluid. 21. RU TCP guns and perforate productive intervals Li 12 22. Run. tubing. Space out and land tubing. Test void. vtc" 23. Install BPV and ND BOP. 24. NU tree and test. 25. RDMO Steelhead rig. 12/22/2008 Page 1of1 • Halliburton BAROID Chevron Mud Program Steelhead Producer Introduction: The following mud program was prepared for a deviated well on the Steelhead platform in Cook Inlet, Alaska. The well will be spudded with a pre- hydrated gel drilling fluid and the 17 -1/2" interval will then be drilled to section TD at 1,230' MD where 13 -3/8" casing will be run and cemented. 12 -1/4" hole will be drilled to section TD at 6,080' where 9 -5/8" casing will be run. The 8 -1/2" production hole will be drilled to TD at 12,320'. 7" production liner will then be run and cemented in place. 3% KCI brine and corrosion inhibitor will be required. Spud the well with a FW Aquagel mud at 9.2 ppg. The mud weight will then be held in the 9.2 ppg mud weight range to the surface hole TD unless hole conditions dictate otherwise. Our primary focus for surface hole drilling operations will be adequate mud weight for well control and sufficient mud viscosity for efficient hole cleaning. LCM will be added to help strengthen the wellbore. A 2% KCI /Clayseal /GEM mud will be maintained through the 12 -1/4" interval. This mud offers good LCM responses if losses are encountered. Special emphasis should be placed on maintaining low ECD's and surge /swab pressures to minimize the potential for lost circulation and disturbing the coal beds. This mud is formulated with three mechanisms to provide waste minimization and effective wellbore stabilization: glycol (GEM CP), ionic inhibition (KCI), and polymer encapsulation (Clayseal). Barotrol can be used to help stabilize the coal seams. The filtrate will be tightened in the lower section of the interval. The production interval will use the existing 2% KCI /Clayseal /GEM system. Baracarb will be strung into the system while drilling to help prevent differential sticking and reduce formation damage. The mud weight will be held in the 9.2 ppg range or as required for hole stability. Primary Drilling Objectives: • Not exceeding the maximum allowable concentration of any product • Monitoring all discharges • Zero fluid related HSE incidents • Achieve wellbore stability • Achieve good hole cleaning considering hole angle, geometry and anticipated ROP rates • Lost circulation mitigation /control • Achieve good Zonal Isolation as per plan • Achieve minimal formation damage • Minimize fluids related NPT • Minimize drilling wastes Critical Fluid Issues: • Eliminating /controlling losses in the under pressured zones. • Maintaining a low ECD in the production zone to reduce risk of lost returns. • Maintaining a stable wellbore through coal seams. • Reducing drilling wastes with the inhibited drilling fluid system. • Follow new NPDES regulations M -06 v2.0 2 12/15/08 • . Halliburton BAROID Chevron Mud Program Well Specifics: Casing Program MD Footage 17 -1/2" hole (13 -3/8" csg) 1243 1243 12 -1/4" hole (9 -5/8" csg) 6616 5373 8 -1/2" Hole (7" liner) 12475 5859 Surface Hole Recommendations - (17 -1/2" hole, 13 -3/8" casing to 1243') Properties: Density Viscosity Plastic Viscosity Yield Point API FL �H 485' -1243' 9.2 60 - 85 10 - 28 25 - 35 <10 8.5 -9.0 System Formulation: pre hydrated gel /fresh water spud mud Product Concentration Water 0.905 bbl Soda Ash 0.5 ppb Aquagel 12 -15 ppb Caustic 0.1 ppb (9 pH) Barazan D as needed Baroid as required for 9.2 ppg PAC /Dextrid if required for <10 FL Concerns and Contingencies Surface Interval - (1,230'MD - 17-1/2" hole, 13 -3/8" casing) Mud Type: Pre - hydrated gel /fresh water spud mud 1. Mud weight: Maintain the 9.2 ppg density or as directed. . 2. Rheology: Maintain a YP between 25 -35 or as needed to achieve adequate hole cleaning. 3. Filtrate control: Maintain the filtrate <10 using Dextrid and /or Pac L. Additions of Condet may be required to control screen blinding /BHA balling. Losses in this interval can be controlled with additions of 1 -2 ppb BAROFIBRE and 1 -2 ppb of Baracarb 50 or by dedicated LCM pills. Operations Summary: Mix a -50 bbl LCM pill prior to drilling out. The pill formulation will be: 45 bbls base mud, 9 ppb Barofibre, 9 ppb Wallnut F, and 12 ppb of Baracarb 50. Pre - hydrated Aquagel should be used to maintain rheological parameters. Maintain the mud as clean as possible while drilling. Should sweeps be required a high viscosity sweep or Barolift is recommended. Run DFG (Drilling Fluid Graphics) to confirm hole cleaning efficiency based on current rheology, flow rates, angle and cuttings size. Sweep Formulation: 25 bbl of mud with -1 ppb of Barazan D added or 0.25 ppb of Barolift. Dextrid and /or PAC L should be used for filtrate control. While drilling, monitor the torque and drag to determine if liquid lubricant is required. Additions of Condet are recommended to reduce the incidence of bit balling and shaker blinding when penetrating high -clay content sections. Maintain the pH in the 8.5 - 9.0 range with caustic soda. Daily additions of X -Cide 207 should be made to control bacterial action. M -06 v2.0 3 12/15/08 Halliburton BAROID Chevron Mud Program At TD, a Wallnut "flag" (30 bbl pill with 15 ppb of Wallnut) should be pumped to gauge hole washout and to calculate the required cement volume. Spot the above LCM pill in the bottom of the hole. If it has been used, mix a duplicate pill to spot on bottom. The cement will then be pumped and drilling mud will be used to bump the plug. Pretreat this chase mud with 1 ppb Bicarb and 0.5 ppb citric acid. Losses have historically occurred in this interval. Baracarb(s), Barofibre and /or Wallnut M should be strung into the system as we drill this section. Maintain -5 -8 ppb in the system at all times. Ensure that the mud weight is maintained in the 9.2 ppg range through this area. Stress slow pipe movement to the drillers to reduce surge /swab on the zone. Stage pumps on slowly after connections and begin rotation prior to pumping (this will break the gels and reduce the pressure required to break the gels). Reduce system YP with Barathin or Carbonox as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 20 (check with the cementers to see what yp value they have targeted). Consider spotting a Steelseal LCM pill prior to running the 13 -3/8" casing if losses have been seen in this interval. This well is a large borehole. Modeling shows that it will become much more difficult to clean if flowrates drop below 800 gpm. Maintain a minimum 25 YP at all times. Be prepared to increase the YP if hole cleaning becomes an issue. Run DFG (Drilling Fluid Graphics) to confirm hole cleaning efficiency based on current rheology, flow rates and cuttings size. Maximum Acceptable ROP in fph at Specified GPM and RPM GPM-> 700 800 900 80 rpm 91 105 121 120 rpm 92 107 123 Baroid recommends a flowrate in the 800 gpm range to maximize hole cleaning efficiencies at these higher penetration rates. However if losses occur, the flow rate can be reduced in conjunction with a slower penetration rate which would reduce the ECD /losses. Hazards / Concerns - Surface Interval: • Optimize solids control equipment to maintain density and sand content. • Maintain YP between 25 -35 to optimize hole cleaning and to control ECD. • Pump high viscosity or Barolift sweeps to enhance hole - cleaning efforts. Monitor sweep effectiveness. • Successfully land and cement casing. M -06 v2.0 4 12/15/08 ....._.. __ • Halliburton BAROID Chevron Mud Program Intermediate Hole Section Recommendations Mud Type: 2% KCI, Clayseal, GEM Properties: Density Viscosity Plastic Viscosity Yield Point API FL �H 1250' -6616' 9.1 40 -53 6 - 15 13 - 20 <6 8.5 -9.5 • Additional mud weight may be required for effective coal or shale stabilization. System Formulation: 2% KCI, Clayseal, GEM Product Concentration Water 0.905 bbl KCI 7 ppb (9K chlorides) Caustic 0.2 ppb (9 pH) Barazan D 1.0 ppb (as required 18 YP) Dextrid 1 -2 ppb PAC L 1 ppb Clayseal 4 ppb (initial 1 ppb) GEM GP 1.5% by volume Baroid as needed for 9.1 ppq Special Mixing Instructions: • Mix in order as listed • Add polymers slowly to minimize fisheyes. Intermediate Interval (12 -1/4" hole, 9 -5/8" casing to 6616' MD) Mud Type: 9.1 ppg KCl/ ClayseaV GEM System. 1. Mud weight: Maintain the density at 9.1 ppg or as needed; use solids control and whole mud dilution. Increase density as required for hole stability /coal sloughing. Maximize solids control usage. 2. Rheology: Maintain a YP between 13 and 20. Pump high viscosity or Barolift sweeps throughout the interval as needed, particularly prior to POH for casing. Optimized mud theology and flow rate will be the primary mechanisms for achieving hole cleaning in this deviated wellbore. Maximize pipe rotation (ideally > 100 RPM). 3. Other issues: The use of good drilling practices to minimize excessive swab and surge pressure should be employed to minimize the chances for losses and differential sticking. Operations Summary: Mix a -50 bbl LCM pill prior to drilling out. The pill formulation will be a 70 ppb pill. Mix the recommended LCM material in thinned back base mud. Drill out the cement/casing with the existing mud system. Soda ash and citric acid should be used to pretreat for any negative effects of the cement. After obtaining a leak off, begin drilling ahead displacing to the KCI based fluid. Baracarb 5, 25 and /or 50 should be strung into the system at 4 -8 sx/hr for losses. Barofibre can be added to this mix. The Clayseal concentration should be 1 ppb in the initial mix. As the mud shears, slowly raise the Clayseal concentration to its full 4 ppb concentration. BARAZAN -D should be used to maintain rheological parameters. Maintain the mud as clean as possible while drilling. Should sweeps be required a high viscosity or Barolift sweep is recommended. Sweep Formulation: 50 bbl of mud with -1 ppb of Barazan D added or .25 ppb of Barolift. Dextrid and PAC L should be used for filtrate control (6cc range). Baranex treatments can be made to bring the filtrate down. 2 ppb Barotrol should be added to help control coals and shales. While drilling, monitor the torque and drag to determine if liquid lubricant is required. If so, approval from town will be M -06 v2.0 5 12/15/08 • • Halliburton BAROID Chevron Mud Program required prior to additions of lubricants. Additions of Condet are recommended to reduce the incidence of bit balling and shaker blinding when penetrating high -clay content sections. Maintain the pH in the 8.5 — 9.5 range with caustic soda. Daily additions of Aldacide G / X -Cide 207 should be made to control bacterial action. Maintain Cl- in the 8 -9K range with KCI. Spot the above LCM pill in the bottom of the hole. If it has been used, mix a duplicate pill to spot on bottom. Reduce system YP as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 15 (check with the cementers to see what yp value they have targeted). Consider spotting a Steelseal LCM pill prior to running the casing if losses have been seen in this interval. Suggested Drilling Parameters Pump rate and drill string rotation should be optimized through the real -time use of the DFG software for the actual ROP while drilling. The table below highlights the maximum ROP recommendations above which hole cleaning will become an issue in this interval. Maximum Acceptable ROP in f h at Specified GPM and RPM GPM—. 550 650 750 80 rpm 81 91 100 100 rpm 106 124 136 Rotary speed is the most critical factor in cleaning this highly deviated wellbore. Maximize rpms at all times. ROPs above these levels or with no rotation (sliding) or low rpm will require an increased frequency of the following remedial hole cleaning practices: • extended periods of circulation (with maximum pipe rpm, targeting > 100 rpm) • hole cleaning sweeps (change flow regime of base mud by using fibers, density or rheology for carrying capacity) • connection practices - employing extended gpm, rpm and back reaming during the connection M -06 v2.0 6 12/15/08 Halliburton BAROID Chevron Mud Program 8 -1/2" Hole Recommendations (7" liner) to 12475' Mud Type: 2% KCI, Clayseal, GEM Properties: Density Viscosity Plastic Viscosity Yield Point API FL �H 6616' — 9.2 40 -53 6 - 15 13 - 20 <5 8.5 -9.5 12475' System Formulation: 2% KCI, Clayseal, GEM Product Concentration Water 0.905 bbl KCI 7 ppb (8 -9 K chlorides) Caustic 0.2 ppb (9 pH) Barazan D 1.0 ppb (as required 18 YP) Dextrid 1 -2 ppb Clayseal 4 ppb GEM GP 1.5% by volume Baracarb 50 10 ppb Baroid as needed Mud Type: 9.2 ppg KCI /Clayseal /GEM System. 1. Mud weight: Maintain the density at 9.2 ppg or as directed; use solids control and whole mud dilution. Increase density as required for hole stability/coal sloughing. Maximize solids control usage. 2. Rheology: Maintain a YP between 13 and 20. Pump high viscosity sweeps throughout the interval as needed, particularly prior to POH for casing. Optimized mud rheology and flow rate will be the primary mechanisms for achieving hole cleaning in this deviated wellbore. Maximize pipe rotation (ideally > 80 RPM). 3. Other issues: The use of good drilling practices to minimize excessive swab and surge pressure should be employed to minimize the chances for losses and differential sticking. Operations Summary: Mix a -50 bbl LCM pill prior to drilling out. The pill formulation will be the 70 ppb pill. Mix the recommended LCM material in thinned back base mud. Drill out the cement/casing with the existing mud system. Soda ash and citric acid should be used to pretreat for any negative effects of the cement. BARAZAN -D should be used to maintain rheological parameters. Maintain the mud as clean as possible while drilling. The mud may need centrifuged prior to adding 10 ppb of Baracarb 50 (bridging agent for the "weak" zones). Should sweeps be required a high viscosity sweep or Barolift is recommended. Sweep Formulation: 20 bbl of mud with -1 ppb of Barazan D added or .25 ppb of Barolift. Maintain Clayseal concentrations at 4 ppb and GEM GP at 1.5 -3 %. Dextrid and /or PAC L should be used for filtrate control (5cc range) to TD. While drilling, monitor the torque and drag to determine if liquid lubricant is required. If so, approval from town will be required prior to additions of lubricants. Additions of Condet are recommended to reduce the incidence of bit balling and shaker blinding when penetrating high -clay content sections. Maintain the pH in the 8.5 - 9.5 range with caustic soda. Daily additions of X- Cide 207 should be made to control bacterial action. The GEM GP can be raised above the 1.5% level to help reduce torque. Do not exceed 3% v/v of GEM GP. Spot the above LCM pill in the bottom of the hole. If it has been used, mix a duplicate pill to spot on bottom. Reduce system YP with Barathin as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 15 (check with the cementers to see what yp value they have targeted). The plug will be bumped with 3% KCI brine. M -06 v2.0 7 12/15/08 • Halliburton BAROID Chevron Mud Program Suggested Drilling Parameters: Maximum Acceptable ROP in fph at Specified GPM and RPM GPM— 400 450 500 80 rpm 134 195 233 100 rpm 178 232 249 Increasing the flowrate from 450 to 500 GPM does NOT improve hole cleaning very much. However it does cause a 0.2 ppg increase in the ECD. Production Hole - Hazards / Concerns: • Optimize solids control equipment to minimize colloidal solids build up and dilution requirements. • Maintain flow profile based on PV, YP and tau flow parameters. • Pump sweeps as required to enhance hole - cleaning efforts. Follow the hole cleaning guidelines to assist in drilling parameter selection. Use connections for high RPM and pump rate support when these parameters are limited during drilling operations. • Follow the coal drilling guidelines. Coal Drilling The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The hole stability risks when drilling coal seams are often high, and the fluid design and drilling operations have been optimized to combine reduced risk with reduced costs. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt -type additives to further stabilize coal seams. • Increase fluid density as required to control the running coal. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. In the event that sloughing coal is encountered, consider spotting a 30 ppb BAROTROL pill across the coal seam. The pill can be safely "squeezed" into the coal by closing the bag and applying pressure not to exceed the total annular pressure loss (based on ECD values using the DFG software). System density increases can also be employed in increments of 0.5 ppg. Solids Control Equipment Maximize the use of all solids control equipment to ensure that the solids content of the system is kept to a minimum during this interval. 1. Run the shale shakers with as fine a screen size as possible. • Size shakers screens with coarse mesh initially • Adjust screen size as solids loading, mud rheology and flowrates allow • Inspect the shakers frequently, taking time to repair / replace damaged screens 2. Maximize the use of the centrifuge, keeping the fluid as clean as possible. Running Casing / Cementing Preparation Monitor hole fill /returns closely while running the liner to insure losses haven't occurred. Refer to Baroid's DFG+ program if calculated surge /swab values are needed. Condition the mud prior to the cement job. Completion The well will be completed with a 3% KCI brine. If rig ops allow, bump the plug with the brine, then finish displacing the casing after coming off the liner hanger. M -06 v2.0 8 12/15/08 Chevron . •teelhead Platform 1110 Well M -6 Proposed 12/22 CASING AND TUBING DETAIL RKB to TBG Head = 78' SIZE WT GRADE CONN MIN ID TOP BTM (MDrkb) 1 28" Structural 27" Surface 470' I 13 -3/8" 68 L -80 BTC 12.415 Surface 1243' 28 Conductor 9 -5/8" 47 L -80 BTC -M 8.681 Surface 6608' 7" 26 L -80 GP or Hyd 6.276 6400' 12462' Chemical Injection Tubing Sub w/ 2 check 3 -1/2" 9.2 L -80 IBTM 2.992 Surface TBD' valves Est TOC Q 920' Logging Detail Hole LWD /MWD Wire Line Mud Logging Notes l3 a /s" in 17 i" Hole Section • 17 14 gMWD, GR/RES Gas On Site Geologist 12'/4 Triple Combo Mudlog On Site Geologist 8'14 Triple Combo Mudlog • On Site Geologist Stage Collar • Perforation Detail MD Zone Density (SPF) Notes 1 ' 9 5/8" Casing in 12 ' '4" Hole 1/ _ Dz Miscellaneous Equipment Informtion Item Depth OD ID Notes • Profile Nipple ECP Stage Collar 480' Cement stage collar 4400' 9 5/8" Production Packer TBD 7" HALCO Chemical Injection collar 1200' 3.5" 3/8" injection line Cementing Information Description Volume Density Yield Notes (bbls) (ppg) (ft3 /sx) Surface 2 stage 509 13.0 1.46 2857 ft^3 / 1956 sks 7" Liner in8 1/2" Hole Intermediate 2 stage 548 12.0 1.45 3075 ft^3 / 2121 sks Production single stage 238 15.8 1.20 1336 ft ^3 / 1113 sks MAX HOLE ANGLE = 55° @ 2410' MD Well Detail DRAWN BY: TSF 12/22/08 M Chevron MRS 11%10 IN. Chevron Nu DES Location: Cook Inlet, Alaska (Offshore) Slot: slot #B2 -6 INTEQ Field: McArthur River Field Well: M -06 Facilitv: STEELHEAD Platform Wellbore: M -06 Plot reference wellpath is M -06 version #6 True vertical depths are referenced to Actual Datum (RKB) Grid System: NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Measured depths are referenced to Actual Datum (RKB) North Reference: True north Actual Datum (RKB) to mean sea level: 180.25 feet I Scale: True distance mean sea level to Mud line (Facility: STEELHEAD Pbtfonn): 0 feet Depths are in feet '^ Coordinates are in feet referenced to Sbt Created by ulricard on 12/22/2008 Well Profile Data Design Comment MD (ft) Inc ( °) Az ( °) TVD (ft) Local N (ft) Local E (ft) DLS (7100ft) VS (ft) Tie On 0.00 0.000 0.000 0.00 0.00 0.00 0.00 0.00 End of Tangent 600.00 0.000 0.000 600.00 0.00 0.00 0.00 0.00 End of Build 800.33 5.725 0.000 800.00 10.00 0.00 2.86 9.38 End of 3D Arc 2410.64 55.221 21.385 2146.70 753.75 257.65 3.10 796.33 End of Tangent 9282.01 55.221 21.385 6066.25 6009.00 2315.61 0.00 6439.12 End of Tangent 9782.01 55.221 21.385 6351.46 6391.40 2465.36 0.00 6849.73 End of 3D Arc 11615.94 3.501 295.920 7911.53 7178.62 2708.61 3.00 7672.45 End of Tangent 12305.95 3.501 295.920 8600.25 7197.03 2670.72 0.00 7676.58 End of Tangent 12381.84 3.501 295.920 8676.00 7199.06 2666.55 0.00 7677.04 • End of Tangent 12462.00 3.501 295.920 8756.01 7201.20 2662.15 0.00 7677.52 °.,inn °,anon Easting (ft) 0 750 1500 2250 3000 8250 M-06 Tgt F7 Polygon (4- Dec-08)' 7500 M -06 Tgt B (2Apr-0 6750 Vertical Section (ft) M-06 Tgt A (2Apr -08) 4 6000 ,.=-1500 R MI 5250 a 0 - Tie On 1_1\ 28in Cmdudor End of Tangent - 2867100ft End of Buld 1 4500 Z o 13.375in Casing 1500 3.10° /1008 0 nd of 3D Arc 9.629n Casing ➢ P 5 3750 9 3000 t n a> 0 3000 1 4500 d 9.625n Casing C N > 2250 H 6000 nd of Tangent M -06 Tgt A (2Apr -08) nd of Tangent 3.007100ft 1500 7500 M-06 Tgt F7 Polygon (4- Dec-08) Lnd of 33 Arc 750 M -06 Tgt B (2Apr -08) End of Tangent 9000 In Ca 0 rn 13.375in Casing 28in Cmdudor 10 slot # B 2 -6 1500 0 1500 3000 4500 6000 7500 9000 Vertical Section (ft) Seale 1 Inch .30001S Azimuth 20.29 °with reference 0.00 R 0.00 E Steelhead M -06 Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE 17 -1/2" Hole Section • Shallow gas sands will be encountered that have the potential to flow and cause a loss of well control. All operations shall proceed with the necessary precautions to prevent a kick. Special attention is required in the following areas: 1. Monitor trip tank on each trip into and out of the hole. 2. Carefully monitor PVT for gain / loss. 3. Have LCM material onboard and ready for use in the event significant losses occur. 4. Minimize surge and swab pressures while tripping. 5. Review cement spacers and washes to ensure the well is not under balanced at any point during cementing operations. 6. Perform diverter drills until the crews are familiar with the procedure. • M -5, M -7,are all critical close approach wells. Record annulus pressures on these wells prior to spud and monitor during the drilling of the surface and 1St intermediate hole sections. 12 -1/4" Hole Sections • Shallow gas sands will be encountered that have the potential to flow and cause a loss of well control. All operations shall proceed with the necessary precautions to prevent a kick. Special attention is required in the following areas: 1. Monitor trip tank on each trip into and out of the hole. 2. Carefully monitor PVT for gain / loss. 3. Have LCM material onboard and ready for use in the event significant losses occur. 4. Minimize surge and swab pressures while tripping. 5. Review cement spacers and washes to ensure the well is not under balanced at any point during cementing operations. 8 -1/2" Hole Section • Significantly under pressured reservoir sands will be encountered A heightened awareness of kick detection, pre -job planning and trip tank calibration will be essential while drilling /trip ping the intermediate interval. • Loss circulation is considered to be a major risk due to the depleted reservoir sands which will be encountered. Loss circulation materials will be readily available for adding to the mud system should significant losses be encountered. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures • Differential sticking is a considerable risk while drilling these depleted sands. Keep the drill string moving whenever possible. • Numerous coals will be drilled through. Unocal coal drilling strategy; limiting the amount of coal drilled ( <10') prior to back reaming should be followed. HYDROGEN SULFIDE - H2S • Steelhead is designated as an H2S drill site. Standard Operating Procedures for H2S precautions should be followed at all times. Version 1.0 Rigsite Hazards and Contingencies 0 Chevron ..,..„...on Coo 4111E% Ala;h:a , Cls lc .. e: C •:..': sicl, PE 2-E = eld: Martr, = 3..:: AV: STE EL - HAD Dly:fory , ....:e bc F.•-:.5 Easing '1 1. 1050 2100 2250 2400 2550 2700 MOO 860 3 E0 150 2300 34 - 0250 6250 i i 1 1 All wells, K-30 K-24 and , •oo-K-09 are not producingi-00; from M-06 planned ., ... '° horizon. to't. -.AG 4. 71300 -, 72Ce \ 10 7860W le -7S60 \ \ 1010 7100 - \40 - MO d \ 7350 1.1-35. Ti 8 !.7.- r-C2! 06 % TWO , Qs • .- 7,0:1 - -7860 . istIo 90 s. Qi ...,.. ... — 1 7050 - 70111) i C4 CI, i 0 0 0, f. .., f 2 .. \ ocot, :,.. - eice . N ' / eill OA /else Faso - 1 ‘it ' 4 . rid40 , / 100004,',, / - , . moo 0800 - \ , ..l. lie IFI,.. 11 500 1 ' , . 0450 rit - MO , 15300 ■ I, 'r� -. 0300 .#1.6° 11500* t 6150 - / ■ ins° = ... t It , az , NM ,.. / 11 f. 5050 4 ,. a- 1 I I I r 1 1 I I I I I I a00. IND 211X1 2860 MOO nod MO MO WOO se0 5500 3420 SIMI I IMR.11111 II Easting :-1: ADL018772 ADL017594 Grayling/ ADL018730 Steelhear E N A Chevron McArthur River Field o I eet ' Steelhead Platform State Plane Alaska Union Oil Company Zone 4 NAD 27 of California M -06 Proposed December 16, 2008 Chevron Steelhead Platform Well M -06 I M O Drilling Program 2008 M -06 Cement Calculations Surface Casing • 13 3/8 ", 68 ppf, Surface Casing in 17 1/2" Hole, Stage 1 Cement from section TD at 1243' to the ECP stage tool at 470' OH Volume w/ 75% excess = (1243- 470) *0.1237 *1.75 = 167.0 bbls Shoe Track Volume = 80 *0.149 = 12.0 bbls Stage 1 Total Volume = 167 +12.0 = 180 bbls of 13.0 ppg LiteCrete Slurry 13 3/8 ", 68 ppf, Surface Casing in 34 OD x Various ID Structural Pile Conductor, Stage 2 Cement from 470' to surface (ECP is 10' long) 41 Annular Volumes = 470 *0.7005 = 329 bbls Stage 2 Total Volume = 329 bbls of 13.0 ppg LiteCrete Slurry Notes: I Used 30" ID as average for volumetric calculations. Chevron Steelhead Platform Well M -06 Drilling Program 2008 Intermediate Casing 9 5/8 ", 47 ppf, Intermediate Casing in 12 Hole, Stage 1 Cement from section TD at 6616' to 4400' OH Volume w/75% excess = (6616- 4400) *0.0558 *1.75 = 216 bbls Shoe Track Volume = 80 *0.0732 = 5.86 bbls Total Volume, Stage 1 = 216 + 5.86 = 222 bbls of 12.0 ppg LiteCrete Slurry 9 5/8 ", 47 ppf, Intermediate Casing in12 1/4" Hole, Stage 2 Cement from stage collar at 4400' to ML at 345' OH Volume w/75% excess = (4400 - 1243) *0.0558 *1.75 = 308 bbls 11 Cased Hole Volume = (1243 -345) *.0597 = 53.6 bbls Total Volume, Stage 2 = 308 + 53.6 bbls = 362 bbls of 12.0 ppg LiteCrete Slurry Chevron Steelhead Platform Well M -06 Drilling Program 2008 Production Liner 7 ", 26 ppf, Production Liner in 8 '/2" Hole Cement from section TD at 12462' to 5900' (500' inside the 9 5/8" casing) OH Volume w /50% excess = (1 2462 - 5900 *0.0226 *1.5 = 222.0 bbls • Shoe Track Volume = 80 *0.0383 = 3.1 bbls Cased Hole Annular Volume = 500 *0.0256 = 12.8 bbls Total Cement Volume = 223 + 3.1 + 12.8 = 238 bbls of 15.8 ppg G LXT Slurry S Calculation & Casing Design Factors 40 C h evron Steelhead Platform M -06 Cook Inlet, Alaska WELL: M -06 FIELD: Trading Bay Field DATE: 17- Dec -08 DESIGN BY: Tim Flynn Sect. 1 17.5" hole MUD WT. 9.20 PPG MASP= 0 psi Sect. 2 12.25" hole MUD WT. 9.20 PPG MASP= 1065 psi Sect. 3 8.5" hole MUD WT. 9.20 PPG MASP= 2995 psi Production Mode TENSION MINIMUM COLLAPSE COLLAPSE WEIGHT TOP OF STRENGTH PRESS @ RESIST. MINIMUM • DESCRIPTION W/O BF SECTION TENSION WORST CASE BOTTOM w/o TENSION WORST CASE MASP YIELD WORST CASE SECTION CASING BOTTOM TOP LENGTH WT. GRADE THREAD LBS LBS 1000 LBS SF TENSION PSI* PSI SF COLL. PSI ** PSI SF BURST 1 13.375" 1,230 0 1230 68 L -80 Butt 83,640 83,640 1556 18.60 551 2,260 4.11 1,250 5,020 4.02 TVD 1,218 0 2 9 5/8" 6,300 0 6300 47 L -80 Butt 296,100 296,100 1086 3.67 1,973 4,750 2.41 1,055 6,870 6.51 TVD 4,365 0 3 7" 12,305 6100 6205 26 L -80 DWC 161,330 161,330 604 3.74 3,887 5,410 1.39 2,812 7,240 2.57 TVD 8,600 * Collapse pressure is calculated; Normal Pressure Fluid Gradient for external stress (.437 psi/ft) and the casing evacuated for the internal stress (.1 psi/ft) ** See attached sheet for calculation of MASP Ilk • ' a Chevron Maximum Anticipated Surface Pressure Calculation Steelhead Platform Well M -06 Cook Inlet, Alaska Assumptions: 1. Based on offset drilling & well test data, the pore pressure gradient is predicted to be a 0.440 psi /ft gradient (8.7 EMW) from surface to planned total depth at 8756.0 TVD BRT. 2.The 17 W surface hole will be drilled to approximately 1243'/1230' MD/TVD under an existing structural pile conductor and will use a diverter system for well control. The diverter system is not designed to shut the well in and contain pressure. Therefore, MASP is 0 psig for this hole section. 3. The M.A.S.P. during drilling operations will be governed by pore pressure at TD. The calculations take into account a gas gradient to surface of .1 psi /ft. 4. The M.A.S.P. during production operations will be the estimated SIBHP minus the gas hydrostatic pressure between TD & the surface. 17.5" Hole Fracture Pressure Conductor (470 ND): Max. Est. Frac pressure at KOP = 470 ft. x 0.000 psi /ft = 0 psi M.A.S.P. from pore pressure: Max. pore pressure at T.D. = 1,230 ft. x 0.440 psi /ft = 541 psi M.A.S.P. (tbg leak at surface) = 541 psi - (0.1 psi /ft * 1230 ft) = = 418 psi 12.25" hole Fracture Pressure at Casing Shoe (1230' TVD) Max. Est. Frac pressure at 13 3/8" shoe = 1230 ft. x 0.866 psi /ft = 1065 psi M.A.S.P. from pore pressure: Max. pore pressure at T.D. = 4,550 ft. x 0.440 psi /ft = 2002 psi M.A.S.P. (tbg leak at surface) = 2002 psi - (0.1 psi /ft * 4550 ft) _ = 1547 psi 8.5" Hole Fracture Pressure at Casing Shoe (10100' ND) Max. Est. Frac pressure at 9 5/8" shoe = 4550 ft. x 0.866 psi /ft = 3940 psi M.A.S.P. from pore pressure: Max. pore pressure at T.D. = 8,756 ft. x 0.442 psi /ft = 3870 psi M.A.S.P. (tbg leak at surface) = 3870 psi - (0.1 psi /ft * 8756 ft) = = 2995 psi Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Note that the terms used in the procedures and the spreadsheet of FIT /LOT results are defined as follows: • Formation Integrity Test (FIT) - Formation is tested to a pre- determined equivalent mud weight. • Leak -Off Test (LOT) - Pressure is exerted against the formation until fluid begins to discernibly pump away. Pressure at which this first occurs is the leak -off point. • LOT Limit - 16.0 ppg EMW for all surface casing shoe tests; determined from previous experience with formation breakdown problems by attempting higher leak -offs. • Open Hole LOTs (OH LOTs)- Leak -off tests performed with open hole from the casing shoe to some point above the target reservoir. Generally done when leak -off is required but could not be achieved just below the casing shoe; or where weaker formations are suspected above the target reservoir but below the casing shoe, and assurance is required of being able to achieve estimated mud weight. Procedure for FIT: 1. Drill 20' of new hole below the casing shoe. 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drillpipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1- minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre- determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Formation integrity tests are conducted on all casing shoes with the exception of some surface casing situations. Where annular pumping will be done on a well, the formation below the surface shoe is taken to leak -off. This ensures that future disposal fluids can pumped away without risk of damage to the surface shoe. If two attempts at establishing leak -off at the shoe are unsuccessful (using 16.0 ppg EMW LOT limit per definition above), then an open -hole LOT is performed. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre- determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. reference INot % ° • • e e• _ Well Profile Data True vertical depths are ielxense4 t* 643430S um(556) Gri4 Sysiarn. MAD27/ TM Alex° SWIM Mane,Zm. 49009. U8 feel .u.ree a.,..... Wrens. As1wi Dates m.. m. north Design Caren tint MD 00 Inc (7 AZ (7 TVO ( local N 69 load E (5) Dl8 (/1005) VS 00 Tip On 000 0.000 0000 0.00 0.00 0.00 0.00 0.00 c a um(fta9) t•� w le mean ta0.2566 Sw.'. True e.encs n sea 0 o u iin.79207 D,EEtrtEA0 eleaemq. o.x 0.pda.n in .x End of Targant 800.00 0.000 0.000 800.00 0.00 0.00 000 0.00 End of Build 800.11 5.725 0.000 800.00 1000 0.00 2.88 838 Coordinates are in feet r..mwd m Sig 044404 q•: 6.6 on 1197/005 End of 3D Arc 2 ann 55.221 vans 2145.70 753.75 257.85 3.10 798.30 End of Tangent 9282.01 55221 21.385 8068.25 8008.00 2315.61 0.00 643923 _ E -. n nd of Tangent 8792.01 55.221 21.385 8851.48 81.40 2483.38 0.00 6849.84 End of 30 Arc 11615.94 3.501 295920 7911.53 7179.52 2706.81 3.00 7672.51 End of Tangent 12305.95 3501 295920 860025 7187.03 2670.72 000 767659 Scale inch East (dlqq ) t5 0 15 a 45 60 75 s 1400 -- 1 120 120 'fie " 40 105 105 1 155 90 d$ 90 40 75 75 e 72 00 60 60 z O 0) s c O 9 z / r240 45 45 M '�- 10p At 30 30 ��>> S Al 1 4 y % 15 ? 3dD a yg 1 5 z,4 2000 1900 1600 800 if 1700 At 7o, 16M 1400 700 / : • eir 6a. 13 Y 0 , • 9:26 2 „ j 8 0 1 6. OB2 -11 .,„ o_.. iB UI ne Qa -15 0 15 30 p 45 60 75 Scale 1 inch .15ft Easting (ft) I . Chevron Location: Cook Inlet, Alaska (Offshore) Slot: slot #B2 -6 Field: McArthur River Field Well: M -06 Facility: STEELHEAD Platform Wellbore: M -06 Scale _300 ry Easting (ft) 8250 1800 1950 2100 2250 2400 2550 2700 2850 3000 3150 3300 3 8250 8100 1156 8100 7950 7950 8 7800. 7800 IC I 62 0 7650 066 -666 7650 65 60 7500 g2 be 7500 7350 M-06 Tgt B (2 . .r-08) 615° 7350 666 i S 7200 7200 775 9 DD 6 66 7 500 6 61 Z 7050 - , 50 7050 0 a) \ 2 c L t 0 7000 6900 9 5p0 \ 6900 \ ,, 95 6 166 9 150 6750 67S0 6750 9 156 ' g250 10000 6600 6600 1666 6600 1 , "1 {=� 6450 950 ® 6450 102 6300 .166 1ti66 10500 6300 6250 l a 6150 ® 6150 M-06 Tgt A (2- Apr -08) 1666 6000 6000 600 5850 1 16 6 , 5850 P 1800 1950 2100 2250 2400 2550 2700 2860 3000 3150 3300 3450 Scala 1 mil a300R Easting (ft) Planned Wellpath Geographic Report Report Generated 12/22/2008 at 11:52:12 AM Projection System NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Operator Chevron North Reference True Area Cook Inlet, Alaska (Offshore) Scale 0.999993 Field McArthur River Field Horizontal Reference Point Slot Facility STEELHEAD Platform Vertical Reference Point Actual Datum (RKB) Slot slot #B2-6 MD Reference Point Actual Datum (RKB) Well M -06 Field Vertical Reference mean sea level Wellbore M -06 Actual Datum (RKB) to Facility Vertical Datum 160.25 ft • Wellpath M -06_version #6 Actual Datum (RKB) to mean sea level 160.25 ft Wellbore Last Revised 12/02/2008 Facility Vertical Datum to Mud Line (Facility) 0.00 ft Sidetrack from (none) Section Origin X E 0.00 ft User Ulricard Section Origin Y N 0.00 ft Calculation method Minimum curvature Section Azimuth 20.29° Local North Local East Grid East Grid North Latitude Longitude [ft] [ft] [USft] (USft) Slot Location - 1034.50 594.21 214209.43 2499465.36 60 °49'54.616 "N 151°36'06.031"W Facility Reference Pt 213640.71 2500514.08 60 °50'04.803 "N 151 °36'18.018 "W Field Reference Pt 213640.71 2500514.08 60 ° 50'04.803 "N 151 °36'18.018 "W TVD from MD Inclination Azimuth TVD Fld Ref North East Grid East Grid North Latitude Longitude DLS Toolface Build Rate Turn Rate Vert Sect Comments [ft] [ °] [ °] [ft] [ft] [ft] [ft] [ft] [ft] [ °I100ft] [ °] [ ° /100ft] [ ° /100ft] [ft] • 0.00 0.00 0.00 0.00 - 160.25 0.00 0.00 214209.43 ' 2499465.36 60 °49'54.616 "N 151°36'06.031'W 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 -60.25 0.00 0.00 214209.43 2499465.36 60 °49'54.616 "N 151 °36'06.031'W 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 39.75 0.00 0.00 214209.43 2499465.36 60 °49'54.616 "N 151 °36'06.031'W 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 139.75 0.00 0.00 214209.43 2499465.36 60 °49'54.616 "N 151 °36'06.031'W 0.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 400.00 239.75 0.00 0.00 214209.43 2499465.36 60 °49'54.616 "N 151 °36'06.031'W 0.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 339.75 0.00 0.00 214209.43 2499465.36 60 °49'54.616 "N 151 °3506.031'W 0.00 0.00 0.00 0.00 0.00 600.00 0.00 0.00 600.00 439.75 0.00 0.00 214209.43 2499465.36 60 °49'54.616 "N 151 °36'06.031'W 0.00 0.00 0.00 0.00 0.00 700.00 2.86 0.00 699.96 539.71 2.49 0.00 214209.49 2499467.86 60 °49'54.640 "N 151 °3506.031'W 2.86 0.00 2.86 0.00 2.34 800.00 5.72 0.00 799.67 639.42 9.97 0.00 214209.68 2499475.33 60 °49'54.714 "N 151 °36'06.031'W 2.86 0.00 2.86 0.00 9.35 800.33 5.73 0.00 800.00 639.75 10.00 0.00 214209.68 2499475.36 60 °49'54.714 "N 151 °36'06.031'W 2.86 23.04 2.86 0.00 9.38 900.00 8.65 8.06 898.88 738.63 22.40 1.05 214211.03 2499487.73 60 °49'54.836 "N 151 °36'06.010'W 3.10 15.04 2.94 8.09 21.37 1000.00 11.67 12.04 997.30 837.05 39.74 4.22 214214.62 2499504.99 60 °49'55.007 "N 151 °36'05.946'W 3.10 11.13 3.02 3.98 38.74 1100.00 14.73 14.39 1094.64 934.39 61.96 9.49 214220.43 2499527.07 60 °49'55.226 "N 151 °36'05.840'W 3.10 8.84 3.05 2.35 61.40 1200.00 17.80 15.95 1190.63 1030.38 88.97 16.85 214228.45 2499553.89 60 °49'55.492 "N 151 °36'05.691'W 3.10 7.34 3.07 1.56 89.29 1243.00 19.12 16.47 1231.42 1071.17 102.04 20.65 214232.57 2499566.87 60 °49'55.621 "N 151 °36'05.615'W 3.10 6.85 3.08 1.21 102.87 133/8 "Csg 1250.00 19.34 16.55 1238.03 1077.78 104.25 21.31 214233.28 2499569.06 60 °49'55.642 "N 151 °36'05.602'W 3.10 6.77 3.08 1.12 105.17 30' Away from all offset Wellbores Ver#4 1300.00 20.88 17.06 1284.98 1124.73 120.70 26.28 214238.65 2499585.39 60 °49'55.804 "N 151 °36 3.10 6.29 3.08 1.03 122.33 1400.00 23.96 17.90 1377.41 1217.16 157.07 37.75 214251.00 2499621.46 60 °49'56.162 "N 151 °36'05.270'W 3.10 5.52 3.08 0.84 160.41 1 1500.00 27.05 18.55 1467.66 1307.41 197.95 51.22 214265.47 2499662.01 60 °49'56.565 "N 151 °36'04.998'W 3.10 4.93 3.09 0.66 203.43 1600.00 30.14 19.08 1555.45 1395.20 243.24 66.66 214282.01 2499706.90 60 °49'57.011 "N 151 °36'04.687'W 3.10 4.46 3.09 0.53 251.27 1700.00 33.23 19.52 1640.54 1480.29 292.80 84.03 214300.58 2499756.02 60 °49'57.499 "N 151 °36'04.336'W 3.10 4.09 3.09 0.44 303.77 1800.00 36.32 19.89 1722.67 1562.42 346.48 103.27 214321.12 2499809.22 60 °49'58.028 "N 151 °36'03.948'W 3.10 3.78 3.09 0.37 360.79 1900.00 39.41 20.22 1801.61 1641.36 404.14 124.32 214343.58 2499866.34 60 °49'58.595 "N 151 °36'03.523'W 3.10 3.53 3.09 0.32 422.17 2000.00 42.51 20.50 1877.11 1716.86 465.59 147.12 214367.88 2499927.22 60 °49'59.201 "N 151 °36'03.063'W 3.10 3.31 3.09 0.28 487.72 III 2100.00 45.60 20.75 1948.97 1788.72 530.66 171.61 214393.95 2499991.67 60 °49'59.841 "N 151 °36'02.569'W 3.10 3.13 3.10 0.25 557.24 2200.00 48.70 20.97 2016.97 1856.72 599.16 197.72 214421.72 2500059.51 60 °50'00.516 "N 151 °36'02.043'W 3.10 2.98 3.10 0.23 630.54 2300.00 51.80 21.18 2080.91 1920.66 670.88 225.37 214451.11 2500130.54 60 °50'01.222 "N 151 °36'01.485'W 3.10 2.85 3.10 0.20 707.41 2400.00 54.89 21.37 2140.60 1980.35 745.63 254.47 214482.03 2500204.56 60 °50'01.958 "N 151 °36'00.898'W 3.10 2.74 3.10 0.19 787.61 2410.64 55.22 21.39 2146.70 1986.45 753.75 257.65 214485.40 2500212.60 60 °50'02.038 "N 151 °36'00.834W 3.10 0.00 3.10 0.18 796.33 2500.00 55.22 21.39 2197.67 2037.42 822.10 284.41 214513.82 2500280.27 60 °50'02.711 "N 151 °36'00.294'W 0.00 0.00 0.00 0.00 869.71 2600.00 55.22 21.39 2254.71 2094.46 898.58 314.36 214545.63 2500355.99 60 °50'03.464 "N 151 °35'59.689'W 0.00 0.00 0.00 0.00 951.83 2700.00 55.22 21.39 2311.76 2151.51 975.06 344.31 214577.44 2500431.72 60 °50'04.217"N 151 °3559.085W 0.00 0.00 0.00 0.00 1033.95 2800.00 55.22 21.39 2368.80 2208.55 1051.54 374.26 214609.25 2500507.44 60 °50'04.971 "N 151 °35'58.481'W 0.00 0.00 0.00 0.00 1116.07 2900.00 55.22 21.39 2425.84 2265.59 1128.02 404.21 214641.05 2500583.17 60 °50'05.724 "N 151 °3557.877'W 0.00 0.00 0.00 0.00 1198.19 3000.00 55.22 21.39 2482.88 2322.63 1204.50 434.16 214672.86 2500658.89 60 °50'06.477 "N 151 °35'57.272'W 0.00 0.00 0.00 0.00 1280.31 3100.00 55.22 21.39 2539.92 2379.67 1280.98 464.11 214704.67 2500734.62 60 °50'07.230 "N 151 °35'56.668'W 0.00 0.00 0.00 0.00 1362.43 3200.00 55.22 21.39 2596.96 2436.71 1357.46 494.06 214736.48 2500810.35 60 °50'07.983 "N 151 °35'56.064'W 0.00 0.00 0.00 0.00 1444.55 3300.00 55.22 21.39 2654.01 2493.76 1433.94 524.01 214768.28 2500886.07 60 °50'08.736 "N 151 °35'55.460'W 0.00 0.00 0.00 0.00 1526.67 3400.00 55.22 21.39 2711.05 2550.80 1510.42 553.96 214800.09 2500961.80 60 °50'09.489 "N 151 °35'54.855'W 0.00 0.00 0.00 0.00 1608.79 3500.00 55.22 21.39 2768.09 2607.84 1586.90 583.91 214831.90 2501037.52 60 °50'10.242 "N 151 °35'54.251'W 0.00 0.00 0.00 0.00 1690.92 3600.00 55.22 21.39 2825.13 2664.88 1663.38 613.86 214863.71 2501113.25 60 °50'10.996 "N 151 °35'53.647'W 0.00 0.00 0.00 0.00 1773.04 3700.00 55.22 21.39 2882.17 2721.92 1739.86 643.81 214895.51 2501188.98 60 °50'11.749 "N 151 °3553.042'W 0.00 0.00 0.00 0.00 1855.16 3800.00 55.22 21.39 2939.21 2778.96 1816.34 673.76 214927.32 2501264.70 60 °5012.502"N 151 °35'52.438'W 0.00 0.00 0.00 0.00 1937.28 3900.00 55.22 21.39 2996.26 2836.01 1892.82 703.71 214959.13 2501340.43 60 °50'13.255 "N 151 °35'51.834'W 0.00 0.00 0.00 0.00 2019.40 4000.00 55.22 21.39 3053.30 2893.05 1969.30 733.66 214990.93 2501416.15 60 °50'14.008 "N 151 °3551.229'W 0.00 0.00 0.00 0.00 2101.52 4100.00 55.22 21.39 3110.34 2950.09 2045.78 763.61 215022.74 2501491.88 60 °50'14.761 "N 151 °35 0.00 0.00 0.00 0.00 2183.64 4200.00 55.22 21.39 3167.38 3007.13 2122.26 793.56 215054.55 2501567.61 60 °50'15.514 "N 151 °3550.021'W 0.00 0.00 0.00 0.00 2265.76 Page 1 of 3 TVD from MD Inclination Azimuth TVD Fld Ref North East Grid East Grid North Latitude Longitude DLS Toolface Build Rat( Turn Rate Vert Sect Comments [ft] [1 [1 [ft] [ft] [ft] [ft] [ft] [ft] ( /100ft] [1 [° /100ft] [ [ft] 4300.00 55.22 21.39 3224.42 306417 2198.74 823.51 215086.36 2501643.33 60 °50'16.267 "N 151 °35'49.416 "W 0.00 0.00 0.00 0.00 2347.88 4400.00 55.22 21.39 3281.47 3121.22 2275.22 853.46 215118.16 2501719.06 60 °50'17.020 "N 151°35'48.812'W 0.00 0.00 0.00 0.00 2430.00 4500.00 55.22 21.39 3338.51 3178.26 2351.70 883.41 215149.97 2501794.78 60 °50'17.774 "N 151 °35'48.207"W 0.00 0.00 0.00 0.00 2512.12 4600.00 55.22 21.39 3395.55 3235.30 2428.18 913.36 215181.78 2501870.51 60 °50'18.527 "N 151 °35'47.603'W 0.00 0.00 0.00 0.00 2594.24 4700.00 55.22 21.39 3452.59 3292.34 2504.66 943.31 215213.59 2501946.23 60 °50'19.280 "N 151 °35'46.999'W 0.00 0.00 0.00 0.00 2676.36 4800.00 55.22 21.39 3509.63 3349.38 2581.14 973.26 215245.39 2502021.96 60 °50'20.033 "N 151 °35'46.394'W 0.00 0.00 0.00 0.00 2758.48 4900.00 55.22 21.39 3566.67 _ 3406.42 2657.62 1003.21 215277.20 2502097.69 60 °50'20.786 "N 151 °35'45.790'W 0.00 0.00 0.00 0.00 2840.60 5000.00 55.22 21.39 3623.72 3463.47 2734.11 1033.16 215309.01 2502173.41 60 °50'21.539 "N 151°35'45.185'W 0.00 0.00 0.00 0.00 2922.72 5100.00 55.22 21.39 3680.76 3520.51 2810.59 1063.11 215340.82 2502249.14 60 °50'22.292 "N 151 °35'44.581'W 0.00 0.00 0.00 0.00 3004.84 5200.00 55.22 21.39 3737.80 3577.55 2887.07 1093.06 215372.62 2502324.86 60 °50'23.045 "N 151 °35'43.977'W 0.00 0.00 0.00 0.00 3086.96 5300.00 55.22 21.39 3794.84 3634.59 2963.55 1123.01 215404.43 2502400.59 60 °50'23.798 "N 151 °35'43.372'W 0.00 0.00 0.00 0.00 3169.08 5400.00 55.22 21.39 3851.88 3691.63 3040.03 1152.96 215436.24 2502476.32 60 °50'24.552 "N 151 °35'42.768 "W 0.00 0.00 0.00 0.00 3251.20 5500.00 55.22 21.39 3908.92 3748.67 3116.51 1182.90 215468.04 2502552.04 60 °50'25.305 "N 151 °35'42.163'W 0.00 0.00 0.00 0.00 3333.32 5600.00 55.22 21.39 3965.97 3805.72 3192.99 1212.85 215499.85 2502627.77 60 °50'26.058 "N 151 °3541.559'W 0.00 0.00 0.00 0.00 3415.44 5700.00 55.22 21.39 4023.01 3862.76 3269.47 1242.80 215531.66 2502703.49 60 °5026.811 "N 151 °35'40.954'W 0.00 0.00 0.00 0.00 3497.56 5800.00 55.22 21.39 4080.05 3919.80 3345.95 1272.75 215563.47 2502779.22 60 °50'27.564 "N 151°35'40.350'W 0.00 0.00 0.00 0.00 3579.68 5900.00 55.22 21.39 4137.09 3976.84 3422.43 1302.70 215595.27 2502854.94 60 °50'28.317"N 151 °35'39.745W 0.00 0.00 0.00 0.00 3661.81 6000.00 55.22 21.39 4194.13 4033.88 3498.91 1332.65 215627.08 2502930.67 60 °50'29.070 "N 151 °35'39.141'W 0.00 0.00 0.00 0.00 3743.93 6100.00 55.22 21.39 4251.18 4090.93 3575.39 1362.60 215658.89 2503006.40 60 °50'29.823 "N 151 °35'38.536'W 0.00 0.00 0.00 0.00 3826.05 6200.00 55.22 21.39 4308.22 4147.97 3651.87 1392.55 215690.70 2503082.12 60 °50'30.576 "N 151 °3537.932'W 0.00 0.00 0.00 0.00 3908.17 6300.00 55.22 21.39 4365.26 4205.01 3728.35 1422.50 215722.50 2503157.85 60 °50'31.329 "N 151 °35'37.327'W 0.00 0.00 0.00 0.00 3990.29 6400.00 55.22 21.39 4422.30 4262.05 3804.83 1452.45 215754.31 2503233.57 60 °5032.082 "N 151 °35'36.723W 0.00 0.00 0.00 0.00 4072.41 6500.00 55.22 21.39 4479.34 4319.09 3881.31 1482.40 215786.12 2503309.30 60 °50'32.836 "N 151 °3636.118m 0.00 0.00 0.00 0.00 4154.53 • 6600.00 55.22 21.39 4536.38 4376.13 3957.79 1512.35 215817.92 2503385.03 60 °50'33.589 "N 151 °35'35.514'W 0.00 0.00 0.00 0.00 4236.65 6616.00 55.22 21.39 4545.51 4385.26 3970.03 1517.14 215823.01 2503397.14 60 °50'33.709 "N 151°35'35.417'W 0.00 0.00 0.00 0.00 4249.79 9 518" Csg 6700.00 55.22 21.39 4593.43 4433.18 4034.27 1542.30 215849.73 2503460.75 60 °50'34.342 "N 151 °35'34.909W 0.00 0.00 0.00 0.00 4318.77 6800.00 55.22 21.39 4650.47 4490.22 4110.75 1572.25 215881.54 2503536.48 60 °50'35.095 "N 151 °35'34.304'W 0.00 0.00 0.00 0.00 4400.89 6900.00 55.22 21.39 4707.51 4547.26 4187.23 1602.20 215913.35 2503612.20 60 °50'35.848 "N 151 °3533.700'W 0.00 0.00 0.00 0.00 4483.01 7000.00 55.22 21.39 4764.55 4604.30 4263.71 1632.15 215945.15 2503687.93 60 °50'36.601 "N 151°35'33.095'W 0.00 0.00 0.00 0.00 4565.13 7100.00 55.22 21.39 4821.59 4661.34 4340.19 1662.10 215976.96 2503763.66 60 °50'37.354 "N 151 °3512.491'W 0.00 0.00 0.00 0.00 4647.25 7200.00 55.22 21.39 4878.64 4718.39 4416.67 1692.05 216008.77 2503839.38 60 °50'38.107 "N 151°35'31.886'W 0.00 0.00 0.00 0.00 4729.37 7300.00 55.22 21.39 4935.68 4775.43 4493.15 1722.00 P 216040.58 2503915.11 60 °50'38.860 "N 151 °35'31.281'W 0.00 0.00 0.00 0.00 ' 4811.49 7400.00 55.22 21.39 4992.72 4832.47 4569.63 1751.95 1 216072.38 2503990.83 60 °50'39.613 "N 151 °3530.677'W 0.00 0.00 0.00 0.00 4893.61 7500.00 55.22 21.39 5049.76 4889.51 4646.11 1781.90 r 216104.19 2504066.56 60 °50'40.366 "N 151 °35'30.072'W 0.00 0.00 0.00 0.00 4975.73 7600.00 55.22 21.39 5106.80 4946.55 4722.59 1811.85 1 216136.00 2504142.28 60 °50'41.120 "N 151 °3529.468W 0.00 0.00 0.00 0.00 5057.85 7700.00 55.22 21.39 5163.84 5003.59 4799.08 1841.80 216167.81 2504218.01 60 °50'41.873 "N 151°35'28.863'W 0.00 0.00 0.00 0.00 5139.97 7800.00 55.22 21.39 5220.89 5060.64 4875.56 1871.75 216199.61 2504293.74 60 °50'42.626 "N 151 °35'28.258'W 0.00 0.00 0.00 0.00 5222.09 7900.00 55.22 21.39 5277.93 5117.68 4952.04 1901.70 216231.42 2504369.46 60 °50'43.379 "N 151 °35'27.654'W 0.00 0.00 0.00 0.00 5304.21 8000.00 55.22 21.39 5334.97 5174.72 5028.52 1931.65 216263.23 2504445.19 60 °50'44.132 "N 151 °35'27.049'W 0.00 0.00 0.00 0.00 5386.33 8100.00 55.22 21.39 5392.01 5231.76 5105.00 1961.60 216295.03 2504520.91 60 °50'44.885 "N 151 °3526.4449 0.00 0.00 0.00 0.00 5468.45 8200.00 55.22 21.39 5449.05 5288.80 5181.48 1991.55 216326.84 2504596.64 60 °50'45.638 "N 151 °35'25.840'W 0.00 0.00 0.00 0.00 r. 5550.57 8300.00 55.22 21.39 5506.09 5345.84 5257.96 2021.50 216358.65 2504672.37 60 °50'46.391 "N 151 °35'25.235'W 0.00 0.00 0.00 0.00 5632.70 8400.00 55.22 21.39 5563.14 5402.89 5334.44 2051.45 216390.46 2504748.09 60 °50'47.144 "N 151°35'24.630'W 0.00 0.00 0.00 0.00 5714.82 8500.00 55.22 21.39 5620.18 5459.93 5410.92 2081.40 216422.26 2504823.82 60 °50'47.897 "N 151 °35'24.026'W 0.00 0.00 0.00 0.00 5796.94 8600.00 55.22 21.39 5677.22 5516.97 5487.40 2111.35 216454.07 2504899.54 60 °50'48.650 "N 151°35'23.421'W 0.00 0.00 0.00 0.00 5879.06 8700.00 55.22 21.39 5734.26 5574.01 5563.88 2141.30 216485.88 2504975.27 60 °50'49.403 "N 151°3522.816'W 0.00 0.00 0.00 0.00 5961.18 8800.00 55.22 21.39 5791.30 5631.05 5640.36 2171.25 216517.69 2505051.00 60 °50'50.157 "N 151°3522.211'W 0.00 0.00 0.00 0.00 6043.30 8900.00 55.22 21.39 5848.35 5688.10 5716.84 2201.20 216549.49 2505126.72 60 °50'50.910 "N 151 °35'21.607'W 0.00 0.00 0.00 0.00 6125.42 III 9000.00 55.22 21.39 5905.39 5745.14 5793.32 2231.15 216581.30 2505202.45 60 °50'51.663 "N 151 °35'21.002"W 0.00 0.00 0.00 0.00 6207.54 9100.00 55.22 21.39 5962.43 5802.18 5869.80 2261.10 216613.11 2505278.17 60 °50'52.416 "N 151 °3520.397W 0.00 0.00 0.00 0.00 6289.66 9200.00 55.22 21.39 6019.47 5859.22 5946.28 2291.05 216644.92 2505353.90 60 °50'53.169 "N 151°35'19.792'W 0.00 0.00 0.00 0.00 6371.78 9282.01 55.22 21.39 6066.25 5906.00 6009.00 2315.61 216671.00 2505416.00 60 °50'53.786 "N 151 °3519.296'W 0.00 0.00 0.00 0.00 6439.12 9300.00 55.22 21.39 6076.51 5916.26 6022.76 2321.00 216676.72 2505429.62 60 °5053.922 "N 151 °3519.188'W 0.00 0.00 0.00 0.00 6453.90 9400.00 55.22 21.39 6133.55 5973.30 6099.24 2350.94 216708.53 2505505.35 60 °50'54.675 "N 151 °3518.583'W 0.00 0.00 0.00 0.00 6536.02 9500.00 55.22 21.39 6190.60 6030.35 6175.72 2380.89 216740.34 2505581.08 60 °50'55.428 "N 151 °35'17.978'W 0.00 0.00 0.00 0.00 6618.14 9600.00 55.22 21.39 6247.64 6087.39 6252.20 2410.84 216772.14 2505656.80 60 °50'56.181 "N 151 °35'17.373'W 0.00 0.00 0.00 0.00 6700.26 9700.00 55.22 21.39 6304.68 6144.43 6328.68 2440.79 216803.95 2505732.53 60 °50'56.934 "N 151°3616.769'W 0.00 0.00 0.00 0.00 6782.38 9782.01 55.22 21.39 6351.46 6191.21 6391.40 2465.36 216830.04 2505794.63 60 °50'57.552 "N 151 °3616.273'W 0.00 - 175.74 0.00 0.00 6849.73 9800.00 54.68 21.34 6361.79 6201.54 6405.12 2470.72 216835.73 2505808.21 60 °50'57.687 "N 151 °3516.164' 3.00 - 175.71 -2.99 -0.27 6864.45 9900.00 51.69 21.05 6421.71 6261.46 6479.76 2499.66 216866.49 2505882.12 60 °50'58.422 "N 151 °3515.580'W 3.00 - 175.54 -2.99 -0.29 6944.49 10000.00 48.70 20.74 6485.71 6325.46 6551.52 2527.06 216895.63 2505953.19 60 °50'59.128 "N 151 °3515.026'W 3.00 - 175.34 -2.99 -0.31 7021.30 10100.00 45.71 20.40 6553.64 6393.39 6620.21 2552.85 216923.09 2506021.23 60 °50'59.805 "N 151 °35'14.506'W 3.00 - 175.11 . -2.99 -0.34 7094.67 10200.00 42.72 20.02 6625.31 6465.06 6685.64 2576.94 216948.77 2506086.05 60 °51'00.449 "N 151 3.00 - 174.84 -2.99 -0.38 7164.40 10300.00 39.74 19.60 6700.51 6540.26 6747.64 2599.29 216972.62 2506147.49 60 °51'01.059 "N 151 °3513.568 "W 3.00 - 174.52 -2.99 -0.42 7230.30 10400.00 36.75 19.12 6779.04 6618.79 6806.03 2619.81 216994.57 2506205.36 60 °51'01.634 "N 151 °3513.153'W 3.00 - 174.15 -2.99 -0.48 7292.18 10500.00 33.77 18.57 6860.68 6700.43 6860.65 2638.47 217014.55 2506259.50 60 °51'02.172 "N 151°35'12.776'W 3.00 - 173.70 -2.98 -0.55 7349.89 10600.00 30.79 17.93 6945.22 6784.97 6911.35 2655.20 217032.52 2506309.78 60 °51'02.672 "N 151 °3612.438M 3.00 - 173.15 -2.98 -0.64 7403.25 10700.00 27.81 17.16 7032.42 6872.17 6958.00 2669.97 217048.42 2506356.06 60 °51'03.131 "N 151 °3612.140'W 3.00 - 172.49 -2.98 -0.77 7452.12 10800.00 24.84 16.23 7122.04 6961.79 7000.46 2682.73 217062.21 2506398.20 60 °51'03.549 "N 151 °35'11.883'W 3.00 - 171.65 -2.97 -0.93 7496.37 10900.00 21.88 15.06 7213.84 7053.59 7038.63 2693.44 217073.85 2506436.09 60 °51'03.925 "N 151 °3511.666'W 3.00 - 170.57 -2.96 -1.17 7535.88 11000.00 18.92 13.55 7307.56 7147.31 7072.39 2702.08 217083.31 2506469.63 60 °51'04.257 "N 151 °35'11.492'W 3.00 - 169.15 -2.95 -1.51 7570.54 11100.00 15.98 11.50 7402.94 7242.69 7101.65 2708.62 217090.56 2506498.72 60 °51'04.545 "N 151 °35'11.359'W 3.00 - 167.20 -2.94 -2.05 7600.26 Page 2 of 3 TVD from MD Inclination Azimuth TVD Fld Ref North East Grid East Grid North Latitude Longitude DLS Toolface Build Ratc Turn Rate Vert Sect Comments [ft] [1 [1 [ft] [ft] [ft] [ft] [ft] [ft] ( /100ft] (1 [° /100ft] ( /100ft] [ft] 11200.00 13.08 8.56 7499.74 7339.49 7126.33 2713.05 217095.59 2506523.29 60 °51'04.788 "N 151 °35'11.270'W 3.00 - 164.35 -2.91 -2.94 7624.95 11300.00 10.22 3.99 7597.67 7437.42 7146.37 2715.35 217098.38 2506543.26 60 °51'04.986 "N 151°35'11.223'W 3.00 - 159.88 -2.86 -4.56 7644.54 11400.00 7.47 356.04 7696.47 7536.22 7161.71 2715.52 217098.93 2506558.59 60 °51'05.137 "N 151 °35'11.220' W 3.00 - 152.01 -2.75 -7.96 7658.99 11500.00 5.02 339.75 7795.88 7635.63 7172.31 2713.55 217097.22 2506569.23 60 °51'05.241 "N 151 °35'11.259W 3.00 - 135.82 -2.45 -16.29 7668.24 11600.00 3.55 303.66 7895.62 7735.37 7178.13 2709.46 217093.27 2506575.16 60 °51'05.298 "N 151 °35'11.342'W 3.00 -99.82 -1.47 -36.09 7672.29 11615.94 3.50 295.92 7911.53 7751.28 7178.62 2708.61 217092.43 2506575.66 60 °51'05.303 "N 151 °3611.359'W 3.00 0.00 -0.31 -48.56 7672.45 11700.00 3.50 295.92 7995.43 7835.18 7180.86 2704.00 217087.87 2506578.02 60 °51'05.325 "N 151 °35'11.452'W 0.00 0.00 0.00 0.00 7672.95 11800.00 3.50 295.92 8095.24 7934.99 7183.53 2698.50 217082.45 2506580.82 60 °51'05.352 "N 151 °3511.563'W 0.00 0.00 0.00 0.00 7673.55 11900.00 3.50 295.92 8195.06 8034.81 7186.20 2693.01 217077.02 2506583.62 60 °51'05.378 "N 151 °3611.674W 0.00 0.00 0.00 0.00 7674.15 12000.00 3.50 295.92 8294.87 8134.62 7188.87 2687.52 217071.60 2506586.43 60 °51'05.404 "N 151 °3511.7869 0.00 0.00 0.00 0.00 7674.75 12100.00 3.50 295.92 8394.68 8234.43 7191.54 2682.03 217066.17 2506589.23 60 °51'05.431 "N 151 °3611.896W 0.00 0.00 0.00 0.00 7675.35 12200.00 3.50 295.92 8494.50 8334.25 7194.21 2676.54 217060.75 2506592.03 60 °51'05.457"N 151 °3612.007'W 0.00 0.00 0.00 0.00 7675.95 12300.00 3.50 295.92 8594.31 8434.06 7196.87 2671.04 217055.32 2506594.83 60 °51'05.483 "N 151 °3612.117'W 0.00 0.00 0.00 0.00 7676.55 12305.95 3.50 295.92 8600.25 8440.00 7197.03 2670.72 217055.00 2506595.00 60 °51'05.485 "N 151 °3612.124'W 0.00 0.00 0.00 0.00 7676.58 12381.84 3.50 295.92 8676.00 8515.75 7199.06 2666.55 217050.88 2506597.13 60 °51'05.505 "N 151 °3612.208'W 0.00 0.00 0.00 0.00 7677.04 12400.00 3.50 295.92 8694.12 8533.87 7199.54 2665.55 217049.90 2506597.64 60 °51'05.509 "N 151 °3612.228'W 0.00 0.00 0.00 0.00 7677.15 - 12462.00 3.50 295.92 8756.01 8595.76 7201.20 2662.15 217046.53 2506599.37 60 °51'05.526 "N 151°3612.297'W 0.00 0.00 0.00 0.00 7677.52 7" CSS1 • ID Page 3 of 3 S M -18 20 3/4" BOP / Diverter Stack up 21114"2M Hydril Annular 4.22' I I HUB CLAMP I I 20 3/4" 3 M Gate Hydril DBL y G Pipe Rams d 71' 20 3/4" 3M Blind Rams I I HUB CLAMP 20 3/4" 3M Mud 200' Cross HCR T u 1 HUB CLAMP I I I 20 3/4" 3M Single Gate 2.71' I HUB CLAMP I 6" Ansi 600 Diverter Valves 20 3/4 3M 2.00 NT2 Connector XO Drt Spool iveer 3.00' 20 3/4 3M NT2 Connector 20 3/4" 3M Riser 20 3/4" 3M Riser VETCO 20 3/4" NT2 Connector VETCO NT2 HEAD 6" ANSI 600 RTJ . CHOKE MANIFOLD • • • • • • • TO GAS BUSTER TO DERRICK VENT TO SHALE SHAKERS A.• Mi �� d *� ��.� maim • 7 II se • • :/ 4 .• , .ta 'il-,' : :VI.' 1 n - - • I( Mini . • . _ mil �_, — me r .., Ems 1 I I -111 III • • mesa \, y t7:� �/ ,'tom s��II .ice �M =IMO �, r!!1` ss � � �a iAir/� it . - , e — • ; is � 1 ; f IC ;I -. i RE f = SWACO mrdir C HOKE UNE U • 1 •111111111M A SECTION AA * AU. VALVES IN FLOW PATH ARE 3 -1/16' 5000 PSI CAMERON GATE TYPE • • TRANSMITTAL LETTER CHECKLIST WELL NAME T VA-0 PTD# is/ Development Service Exploratory Stratigraphic Test P p Non - Conventional Well FIELD: Vkc-0'a Lc V.V. `) POOL: c %a(.. �\ Ci ciS Vohs Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - . API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for ( name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1 /11/2008 ."` 4 l Field & Pool TRADING BAY, UNDEFINED GAS - 800500 Well Name: TRADING BAY UNIT M -06 Program DEV Well bore seg PTD #:2090040 Company UNION OIL CO OF CALIFORNIA Initial Class/Type __ DEV / PEND GeoArea 815 Unit 12070 On /Off Shore On _ Annular Disposal Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Surface location in ADL 18730; top prod interval & TD in ADL 17594 j3 Unique well name and number Yes A previous permit for M -06 (PTD 1900700) expired on 6/6/1992 14 Well located in a defined pool Yes MCARTHUR RIVER, MID KENAI GAS - 520550, governed by CO 228. 5 Well located proper distance from drilling unit boundary Yes Rule 1 of CO 228 established 10 -acre drilling units for the pool at the D -1 sand, which lies at the vertical 6 Well located proper distance from other wells Yes mid -point of the pool becaues of the lenticular nature of the reservoir sands. Well conforms to spacing rule. 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes SFD 1/7/2009 13 Can permit be approved before 15 -day wait Yes e 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For Yes 15 All wells within 1/4 mile area of review identified (For service well only) Yes 16 Pre-produced injector: duration of pre - production less than 3 months (For service well only) Yes 17 Nonconven. gas conforms to AS31.05,030(j.1.A),(j.2.A -D) Yes 18 Conductor string provided Yes Engineering 19 Surface casing protects all known USDWs NA All aquifers exempted, 40 CFR 147.102(b)(2)(ii). 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie -in long string to surf csg Yes 22 CMT will cover all known productive horizons Yes 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Platform rig. Drilling wastes to be discharged in accordance with NPDES. 25 If a re- drill, has a 10 -403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Proximity analysis performed. Close approaches identified and mitigation strategies listed. 27 If diverter required, does it meet regulations No 16" diverter lines. 17 -1/2 " hole planned. This request has been previously approved. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Maximum possible formation pressure 8.5 EMW. MW planned 9.2 ppg. TEM 1/20/2009 129 BOPEs, do they meet regulation Yes Stack has 3K rams and 2K annular. 3000 psi BOP test. 30 BOPE press rating appropriate; test to (put psig in comments) Yes 3000 psi BOP test 131 Choke manifold complies w /API RP -53 May 84) Yes 1 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S is present in Steelhead oil production. No H2S in gas production. Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) _ NA 35 Permit can be issued w/o hydrogen sulfide measures No Steelhead Platform is a designated H2S site. Geology ,36 Data resented on potential overpressure zones Yes Expected maximum reservoir pressure is 8.4 EMW, but many sands will be under pressured as indicated in th P P p p P ppg Y P Appr Date 37 Seismic analysis of shallow gas zones NA Formation Markers table and as discussed in the Summary of Drilling Hazards. SFD 1/7/2009 1 38 Seabed condition survey (if off - shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering Public Commissioner: Date: Commissioner: Date —� y of Date 044 A, /ze-D1� M INA 1 t o —0 9 IlI .