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Home My WebLink About207-039• Well Histo File Co~r Pa e Image Project ry g 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. ~~~- ~~q Well History File Identifier __ Organizing (done) ^ Two-sided II I II II II II II I II III ^ Rescan Needed ~~ ~ ~~ ~~ II ~~ (~ ~~ ~ ~~~ RES N DIGITAL DATA OVERSIZED (Scannable) Color Items: iskettes, 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:: Maria Date: tV ~s~ i3Y: " Proogn (I I II II II I ~ II I I II I Project g BY: Maria Date: ~s~ Scanning Preparation _ ~~ x 30 = ~ a o + ~ =TOTAL PAGES~~ (Count does not include cover sheet) ~ /~ /~ BY: Maria Date: ~/~ ~ /~~' /s/ ~-LV~t Production Scanning Stage 1 Page Count from Scanned File: -k-~ (Count does include cove sheet) tches Number in Scannin Pre aration: V YES NO Page Count Ma 9 BY: Maria Date: ~ ~ 4- ~ ~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO ~ r BY: Maria Date: Scanning is complete at this point unless rescanning is required. "uumuiiiiiuii Rescanned III IIIIIIIIIII IIIII BY: Maria Date: ~s~ Comments about this file: Quality Checked II I II'lll III (I'I III 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ' "A z ALIA OIL AND GAS CONSERVATION CO M SION ' REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon Repair welt 1--- . �` p r Plug Perforations .Perforate r Other .�. �' ��` �; a Alter Casing r Pull Tubing Stimulate-Frac Waiver r Time Extension Change Approved Program "`Operat. Shutdown r Stimulate-Other r Re-enter Suspended Well 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: _ConocoPhillips Alaska, Inc. • Development Exploratory _ 207-039 • 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-23349-60 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25662,380058 1J-135L1 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/West Sak Oil Pool . 11.Present Well Condition Summary: Total Depth measured 17935 feet Plugs(measured) none true vertical 3420 feet Junk(measured) none Effective Depth measured 17921 feet Packer(measured) 9033, 9167 true vertical 3420 feet (true vertical) 3518, 3539 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 121 121 SURFACE 3422 13.375 3463 2213 INTERMEDIATE 9778 9.625 9819 3604 D-SAND LINER 8830 5.5 x 4.5 17923 3420 Perforation depth: Measured depth: slots from 9375-12949, 12951-17878 IV)\I 13 13?0'1 ' True Vertical Depth: 3549-3495,3495-3420 SCAt4t4CD Tubing(size,grade,MD,and ND) 4.5, L-80,9075 MD,3525 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER PREMIER PACKER W/29/32"BALL @ 9033 MD and 3518 TVD PACKER-MLZXP LINER TOP PACKER @ 9167 MD and 3539 TVD NIPPLE-CAMCO'DB'LANDING NIPPLE @ 478 MD and 478 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): not aplicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 5 2085 1 -- 215 Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory `" Development Service r Stratigraphic 16.Well Status after work: Oil W. Gas WDSPL Daily Report of Well Operations XXX GSTOR im WINJ r WAG r GINJ r SUSP r 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: none Contact Dan Bearden @ 263-4864 Email James.D.Bearden( cop.com Printed Name Dan Bearden Title Drilling Engineer Signature Phone:263-4864 Date / �t g- V t---P /der O�� RBDMS JUL - 2 201St 73 / Form 10-404 Revised 10/2012 1 3 Submit Original Only 1J-135 Pre-Rig Workover Well Work Summary DATE SUMMARY • 4/15/2013 Displaced IA w/360 bbls and tubing with 63 bbls of 180 deg F diesel @ 1-1.3 bpm. DHD to return in a few days to take pressure and get fluid levels.Note: See attached pump report for more detail. 4/18/2013 (RWO) : T FL @ 3206' (28 BBLS), IA FL @ 3146' (139 BBLS). VALVE SHOP HAS NOT BEEN CALLED TO SET BPV. r KUP 1J-135L1 , tilLo ConocoPhillips I Well Attributes Max Angle&MD TD Inc, Wellbore API/UWI Field Name Well Status Intl(°) MD(RKB) Act Btm(ftKB) ALaska. 500292334960 WEST SAK PROD 93.65 13,201.90 17,935.0 ""' Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date w Gonna MULTIPLE LATERALS ,�-,3su'.sazo,3 oaz.o1 AM SSSV:NIPPLE 120 8/14/2012 Last WO: 5/27/2013 44.00 5/23/2007 Schematic Actu,I Annotation Depth(ftKB) (End Date (Annotation Last Mod By End Date Last Tag:SLM j 7,400.0 10/28/2009 Rev Reason:WORKOVER osborl 6/6/2013 HANGER.24 1 Casing Strings F----1 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...Str ng... String Top Thrd I I _-- __-- D SAND LINER 4 1/2 3.476 9,308.8 17,923.0 3,420.2 I 11.60 L-80 I BTC _— Liner Details Top Depth (ND) Top Intl Noon... Top(ftK8) (,58) (8 ItLE Description Comment ID(in) 9308.8 3,546.8 88.30 SLEEVE BAKER HR SETTING SLEEVE 5.750 9,369.9 3,549.2 89.31 XO Reducing 5 1/2"Hydril 521 Box X 4 1/2'Hydril 521 Pin X/O(3.94"I.D.) 3.940 17,8780 3,420.1 89.91 BENTJT BENT JOINT 3.950 Perforations&Slots Shot Top(ND) Btm(TVD) Dens • Top(MB)Btm(ftKB) (MB) (ftKB) Zone Date CO,- Type Comment CONDUCTOR 9,375.0 12,949.0 3,549.3 3,494.5 WS D,1J-135L1 5/17/2007 32.0 SLOTS 2.5"Long x.125"wide,4 (enacted 3P,-- -44122 dreumferencial rows/ft,3"centers, staggered,18 deg. NIPPLE,478 12,951.0 17,878.0 3,494.5 3,420.1 WS D,1J-135L1 5/17/2007 32.0 SLOTS 2.5"Long x.125"wide,4 IIIII circumferential rows/ft,3"centers, staggered,18 deg. Notes:General&Safety End Date Annotation 5/23/2007 NOTE: MULTI-LATERAL WELL-1J-135(B-SAND),1J-135L1(D-SAND) 3/18/2008 NOTE:WORKOVER 8/9/2008 NOTE:View Schematic w/Alaska Schematic9.OREV GAS z a 2 2/9/2010 NOTE:WORKOVER 5/27/2013 NOTE:WORKOVER CONVERTED WELL FROM ESP TO GAS LIFT SURFAE,_. , , 443,463 GAS LIFT, 7,380 I PROTECTOR. I 8,931 SLEEVE,8.932 •{I 1I PROTECTOR. 8,937 r= GAUGE,8,953 LOCATOR,_ 8,970 S SEAL A 9 .-! 8,,571 1 SETTING SLV, �.. 8,988 SSE,8.999 ) ( 14—, PACKER,9,033- j NIPPLE,9,058 'K1 1 WLEG,9,074 D-SAND NIB 1 WINDOW. 9,0979,107 D-SAND LINER HH, • 9,0949,352 • • NTERM1-SO , / ' 4 41-9,8t19 ,- _. • • IF if S ill LOTS, 9.375-12,949 Mandrel Details Top Depth Top Port (ND) Intl OD Valve Latch Size TRO Run SLOTS, N...Top(ftKB) (ftKB) F) Make Model (in) Sery Typo Type (in) (psi) Run Date Com... 12,95 -7.8 N8 D 1 A 1 2,471.6 1,959.3 73.28 CAMCO MMG 1 1/2 GAS LIFT SOV RKP 0.000 0.0 5/26/2013 81 LINER,7.923\\ 3 2 7,360.4 3,214.3 76.32 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/26/2013 9,309-17, _ 17,935 S • Conocopphillips Time Log & Summary Wellview Web Reporting Report 1,-.«.:_ 04,1, 14:711,01 1, N Well Name: 1J-135 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 5/20/2013 2:30:00 PM Rig Release: 5/27/2013 3:00:00 PM �I �) R� ��' �' 14 4 „4,4,4'1,7-f Time Logs i �� , bate ' ”' From Tu Our 'Al S.liebtli'E DeRth`Phase Code Subctide TI ©mm nt _ ,. 35/20/2013 24 hr Summary Accept rig @ 1430 hrs 5/20/2013 after rig commissioning and BOP test. Blow down the choke and kill lines, choke manifold. Rig down testing equipment.Check pressures on IA(4 psi),bleed off pressure. Remove blanking plug, pull BPV. Rig up to pull ESP. 14:30 16:00 1.50 0 0 COMPZ WHDBOOTHR P Blow down the choke manifold,kill line and choke line. 16:00 16:30 0.50 0 0 COMPZ WHDBO OWFF P Monitor the IA(9-5/8"x 3-1/2"),bleed off 4 psi. 16:30 17:30 1.00 0 0 COMPZ WHDBOOTHR P Pick up the 3-1/2"IF drill pipe test joint.Make up Vetco gray tool to retrieve the blanking plug. Retrieve plug. Pull the type"H"4"BPV. 17:30 00:00 6.50 0 0 COMPZ RPCOM RURD P Pickup third party tools to the rig floor. Rig up to pull the 3-1/2"ESP completion. Rigging up Baker Centralift 35/21/2013 Pulled 3 1/2"ESP Completion. Recovered complete. 00:00 01:00 1.00 0 0 COMPZ RPCOM RURD P Complete rigging up the Floor to handle the 3 1/2"ESP Completion. 01:00 03:00 2.00 7,341 7,317 COMPZ RPCOM THGR P Make up Landing Joint. Record well head pressures as follows: Tbg=0 psi, IA=10 psi,OA=250 psi. Bleed IA to"0"psi. BOLDS. Tubing Hanger broke free at 150 K. Pulled Tubing Hanger to the Floor at 125 K. Lay down same. Fill hole with 9 bbls. Estimated static fluid level was at 140-ft. 03:00 00:00 21.00 7,310 89 COMPZ RPCOM PULL P Single down the 3 1/2"Completion Tubing while spooling ESP Cable. Lay down jewelry pieces. (Note:the Sliding Sleeve was jammed in the closed position by a piece of rubber. Also the ESP Cable had been impregnated by gas in manny areas). 9 5/8"Y-Tool/ESP Assembly at surface. Hole fill= 10 bbls. Monitor fluid falling very slowely. 05/22/2013 Pulled and singled down the 3 1/2"ESP Completion. 00:00 00:30 0.50 89 89 COMPZ RPCOM SFTY P Hold PJSM with crew coming on Tower. Discuss laying down the Y-Tool/ESP Assembly. Page,-1 of 7 , „ • • Time Ohl P t" li 1,■"o iini ll �� r i11l1 i ii q �4 1I1Ipi Date ''I' lhdll'o hFro To tar,'; ASS.Depth.E„Death Phase°„..Code iSubcod T Comment 411 Illh mmi i� �- 61i' 00:30 06:00 5.50 89 0 COMPZ RPCOM PULL P Lay down 2 7/8”Flush Joint Tailpipe Tubing, ESP Assembly,and the Y-Tool. Recovered 120 ea Cannon Clamps,complete. Recovered 5 ea Y-Tool Clamps,complete. Note: ESP Motor had areas on the housing with bad corrosion pits. The Pump was packed with sand...no rotation. Rig down floor. Clear and clean floor. 06:00 06:30 0.50 0 0 COMPZ WELLPF RURD P Install Wear Bushing(10 1/8”I.D.). 06:30 09:30 3.00 0 90 COMPZ WELLPF PULD P Make up BHA#1 as follows: Bull Nose Jet Nozzle,X-Treme Magnet, XO,8 1/2"Smooth OD String MIII, Flex Jt, Flex Jt, 8 1/2"Smooth OD String Mill, Double Pin Sub,7"Boot Basket,7"Boot Basket, Bit Sub, X-Treme Magnet,4 3/4"Bumper Sub,4 3/4"Oil Jar, Pump-Out-Sub. Total Length=89.73-ft. 09:30 00:00 14.50 90 6,396 COMPZ WELLPF PUTB P Pickup 165 ea joints of 3 1/2" E-Grade Drill Pipe. Rattle Drill Pipe. Break circulations every 30 joints to clear Drill Pipe. Beging to pick-up 3 1/2"Heavy Weight Drill Pipe. 05/23/2013 Clean-out Well Bore to 9,066-ft.Trip out with BHA#1,standing back 3 1/2" Drill Pipe. Make-up Lower Baker Completion Assy.Start TIH. 00:00 04:30 4.50 6,396 9,010 COMPZ WELLPF PULD P Finish in with 126 jts of heavy weight 3 1/2"S Grade Drill Pipe. (Note: Set down on a bridge at 8,139-ft. Second attempt fell through). Continue down to 9,010-ft with no problems. 04:30 06:00 1.50 9,010 9,066 COMPZ WELLPF WASH P Park Jet Nozzle at 9,010-ft. With the Drill Pipe side shut in,line up pump #1 down the IA and perform an injection step rate test as follows: 1.0 bpm/60 psi,2.0 bpm/117 psi,3.0 bpm/222 psi,4.0 bpm/319 psi,5.0 bpm/420 psi. Wash down to 9,066-ft at 5.0 bpm/620 max pressure with no problems. Pull back up to 9,010-ft. Bring on both pumps at 8.0 bpm, pumping down the Drill Pipe and the IA. Wash down to 9,066-ft at 8.0 bpm/1,026 psi. Pull back up to 9,010-ft End Washing. Total fluid volume injected=85 bbls. 06:00 07:30 1.50 9,010 9,010 COMPZ WELLPF OWFF P Monitor Well and observe a slight flow due to"ballooning effect". Continue to monitor.Allow well to go static.Continue to observe well to see fluid falling in the stack. 07:30 13:30 6.00 9,010 90 COMPZ WELLPF TRIP P Trip out of hole observing proper displacement.Monitor well at the BHA.Static. Page2of7 r^ i iii - - rni a 0 .oi ii i„"t Date From To Dur l S.t eoth E.Deoth Phase Code 'Subcode T Comment z �r iPP 66i1. 13:30 16:00 2.50 90 0 COMPZ WELLPF PULD P Break out and lay down BHA. Observed Crude cap in well and taking time to clean tools.Observed approximately 1/2 gallon of sand& sludge recovered in Junk Baskets, and approximately 2 lbs of scale recovered on magnets.Jet sub was plugged with sand. Well static. SIMOPS: Load pipe shed with 4 1/2" Completion tubing. Load Lower completion assembly in pipe shed. 17:15 1.25 0 0 COMPZ WELLPF PULD P Clean&clear rig floor area of BOT 16:00 5 g clean out tools.Continue clean crude form rig floor area and manage housekeeping issues. Load tools on truck. 17:15 18:15 1.00 0 0 COMPZ WELLPF RURD P Pull GBR power tongs to rig floor. Rig up to run Lower completion assembly. Install 4 1/2”tubing elevators.Secure safety valve& crossover.Verify 4 1/2"hand slips ready. 18:15 18:45 0.50 0 0 COMPZ WELLPF SFTY P Held PJSM with crew, BOT rep and Co.Man. Discuss safety and hazard recognition issues. Discuss procedure to make up and run Lower completion assembly as per detail. 18:45 21:30 2.75 0 96 COMPZ RPCOM PULD P Make-up the Lower Baker Completion pre Baker Rep as follows: WLEG, Pup Jts, DB Nipple w/3.750"profile(verified x 2), Baker 9 5/8"x 4 1/2"Premier Packer Assembly, Baker Seal Bore Extension Assembly. Dump 5 gals of Pal Mix down the Tie-Back Sleeve (to keep any debris form getting into the Running Tool). 21:30 00:00 2.50 96 5,424 COMPZ RPCOM RCST P Trip in the hole with the Lower Completion section on 3 1/2"Drill Pipe. Up Weight=55K. Down Weight=45K. Running speed @ 90 ft/minute as per BOT rep. 05/24/2013 Ran Lower completion.Set Packer. Release Setting Tool.Test Annulus. POOH and single down Drill Pipe. Prep for the Upper 4 1/2"Completion. 00:00 06:30 6.50 5,424 9,075 COMPZ RPCOM RCST P Continue to trip in with the Lower Completion Assembly on 3 1/2"Drill Pipe from 5,424-ft. Drift Heavy Weight Drill Pipe w/1.90"Drift(Baker Back up Setting Ball=1.750"). Running speed at 90 ft/minute as per BOT rep.Observed changing out 5 jnts of HWDP as they would not drift. Edit tally as needed. Observed proper displacement and no issues getting packer on depth. UP WT= 125K,SO WT=55K. Page 3 of 7 • Time Log "v piri iwr d i 4� r is��a h��; �� 7 4,Mblh .00111. LDae l=rom fo , Dur. S. Depth E :Depth Phase Code i ,Subbode T-, Comtnetit1,4, 06:30 06:45 0.25 9,075 9,075 COMPZ RPCOM SFTY P Held PJSM with Crew, BOT rep,and Co.Man. Discuss safety&hazard recognitioon issues. Discuss procedure to pump and set packer. Discuss High Pressure issues. 06:45 08:30 1.75 9,075 9,075 COMPZ RPCOM RCST P Drop 29/32"Ball down drill string. Pump down DP at 2.7 BPM-765 PSI,chasing ball.Observed ball on seat in 10 Min with 819 stks. Pressure to 500 PSI-5 minutes. Pressure to 3000 PSI-10 minutes. Bleed pressure to 0 PSI.Set down 20K, PU to 150K.Set down 20K. Pressure to 3000 PSI to release Hydraulic setting tool. Bleed pressure to 0 PSI.Work string to verify setting tool released. Note: RKB difference from Doyon 15 to Nabors 7ES=12.36'.WLEG @ 9075', Baker Premier Packer setting depth=9033'MD. 08:30 09:00 0.50 9,075 9,075 COMPZ RPCOM PRTS P Rig up,close upper pipe rams and pressure test annulus to 3500 PSI- 30 minute test. Record on chart. Good test. Bleed all pressure. 09:00 09:30 0.50 9,075 9,075 COMPZ RPCOM RCST P Pressure down drill string to 4365 PSI to shear ball seta in setting tool. Bleed ressure,and slowly pull up P YP hole to observed setting tool free of Liner Setting Sleeve. Rack back one stand of DP. 09:30 11:30 2.00 9,075 9,000 COMPZ RPCOM CIRC P Circulate bottoms up staging pumps to 6 BPM-2160 PSI.Observed minimal fluid loss. No gas. 11:30 12:00 0.50 9,000 9,000 COMPZ RPCOM OWFF P Monitor well-static. Establish static loss rate of 5.5 BPH. Pump 42 BBLS of 90 deg, heated brine with surfactant wash down Drill pipe to clean same. 12:00 22:30 10.50 9,000 45 COMPZ RPCOM PULD P POOH laying down 3 1/2"DP. Observed proper displacement. Observed pipe coming very clean as surfactant wash over top of hole aidiing in cleaning crude off of DP. 22:30 23:00 0.50 45 0 COMPZ RPCOM PULD P Break out and lay down Baker Liner Hanger Running Tool Assy. Found the Setting Ball on seat. However, there was also a lot of scale in the Ball Seat. 23:00 00:00 1.00 0 0 COMPZ RPCOM RURD P Clear and Clean Floor. Continue to load and tally the 4 1/2"Completion Tubing in the Pipe Shed. Rig up GB&R tubing handling equipment. Rig up Centrilift Air Spooler w/TEC Wire. Verify Upper Completion equipment with Baker Service Rep. , Pap 4 of 7 • • • Time yLegs ' 1,104 I' om S Death E.Deoth Phase r odes. . Subdode .T o meat 05/25/2013 24 hr Summary Lay down the 3 1/2"Drill Pipe. Finish loading,drifting,and tally the 4 1/2"Upper Completion Tubing. Rig up to run the 4 1/2"Upper Completion. 00:00 05:30 5.50 0 0 COMPZ RPCOM RURD P Continue to load,drift,and tally 4 1/2"Tubing. Continue to rig up GB&R equipment. Continue to rig up Centrilift Air Spooler w/TEC Wire. Pull Wear Bushing. 05:30 06:00 0.50 0 0 COMPZ RPCOM SFTY P PJSM. Discussed hand,eye,and hearing safety. Discussed overhead loads keeping the work area clear of tripping hazards,and line of fire. Also working around several operations going on at the same time. Reviewed the running order of the Upper Completion. 06:00 06:30 0.50 0 65 COMPZ RPCOM RCST P Pick up Jewelry as follows: Baker GBH-22 Seal Assembly, Locator Sub,3 ea 4 1/2"12.6 lb/ft L-80 IBTM Pup Joints,Guardian Sensor Gauge Carrier Assembly,2 ea 4 1/2"12.6 lb/ft L-80 IBTM Pup Joints, Fluted Wire Protector Sub, Baker CMU Sliding Sleeve(in the closed position)w/3.812"DB profile, Fluted Wire Protector Sub,4 1/2"12.6 lb/ft L-80 IBTM Pup Joint. 06:30 00:00 17.50 65 6,696 COMPZ RPCOM RCST P Begin to single in with the 4 1/2 12.6 lb/ft, L-80, IBTM Upper Completion Tubing with TEC Wire as per designed program to 6,696-ft. Up Weight=78K. Down Weight=47K. Check TEC Wire every 1,000-ft. 35/26/2013 Finish running 4 1/2"Completion. Circulate Corrosion Inhibited 3%KCL. Land Completion.Set TWCV and test. ND BOPE. NU Production Tree. 00:00 05:00 5.00 6,696 24 COMPZ RPCOM RCST P Continue running the 4 1/2"Upper Completion Tubing with TEC Wire from 6,696-ft as per program. Check TEC Wire every 1,000-ft. 05:00 06:00 1.00 24 24 COMPZ RPCOM RCST P Up Weight=95K. Down Weight= 48K. Sting into the SBR at 8,988.5-ft.. Space out the final Completion as follows: No-Go on Jt# 288 with 18-ft in. Lay down Jts# 288,287,and 286. Add 23.88-ft KB to the Lock Down Screws,2.13-ft Tubing Hanger, 1 Jt Tbg 31.28-ft (note:this jt is not in the running tally...it is bucked up to the bottom of the Vetco Gray Hanger),7.0-ft of Seal Section"stick-up"from No-Go, Pup Joints needed=13.49-ft. Page 6•of 7 ' II DIalnitee From fo Dur S.Depth E.Detrth Phase =Code Subcode 'i,T . Comment lli h N m 4 06:00 07:00 1.00 24 24 COMPZ RPCOM RCST P Add Pup Joints as needed(1 ea 9.83-ft and 3.81-ft) Pick up a full Joint along with the Tubing Hanger. Blow down Top Drive. Install the dummie ESP Penetrator in the Tubing Hanger. Check TEC Wire. Good. Final Cannon Clamps used= 293 ea. 285 tallied Jts ran. 15 tallied Jts remain in the Pipe Shed. 20 Jts outside not in the tally. 320 total Jts delivered to Location. 320 Jts accounted for. 07:00 10:00 3.00 24 24 COMPZ RPCOM CIRC P Circulate and condition Well with Corrosion Inhibited 3%KCL Brine. 10:00 11:00 1.00 24 0 COMPZ RPCOM RCST P Drain BOP Stack. Land Completion. RILDS. Test Upper and Lower Hanger Seals as per Vetco-Gray Rep at 5,000 psi x 10 minutes. Good test. Lay down Landing Joint. 11:00 13:00 2.00 0 0 COMPZ RPCOM PRTS P Pressure test the 9 5/8"x 4 1/2"IA in 500 psi steps x 10 minutes each. Good test. The SOV sheared at 3,400 psi. 13:00 14:00 1.00 COMPZ RPCOM SFTY P After Action Drill. Rig Evacuation Drill with Rig Crew, Drill Site Operator,Company Man,and others on Location. Drill went well. 14:00 19:00 5.00 COMPZ WHDBO NUND P Install TWCV. Blown down Choke Line, Fill Line,and Mud Line. Nipple down BOPE and set back on Stump. 19:00 23:30 4.50 COMPZ WHDBO NUND P PJSM. Nipple up new Adaptor Flange. Nipple up Vetco-Gray 4 1/16"x 5 K Horizontal Production Tree. 23:30 00:00 0.50 COMPZ WHDBO PRTS P Test Hanger void at 250/5,000 psi x 10 minutes. Good. Attempt to perform a low pressure test on the tree. Leak on the top flange. Abort test to tighten. 05/27/2013 Continue nipple down BOP's and Nipple up tree.Test same. Rig up with Little Red, and held PJSM. Displace well with 185 BBLS of freeze protect diesel at 2 BPM-650 PSI.Allow to U-tube until balance.SITP-200 PSI,SICP-150 PSI.Secure tree and valves. Both crews reported to KOC-EMOC room for completion of IFC training as planned. Return to rig. Clean cuttings tank,and cellar. Rig released at 1500 HRS form 1J-135. Prep to move to 2W-12. 00:00 01:00 1.00 COMPZ WHDBO PRTS P Pressure test the Production Tree at 250/5,000 psi. High pressure test lost—100 psi in 10 minutes. Good test. Recorded test on chart. 01:00 01:30 0.50 COMPZ WHDBO MPSP P PJSM. Pull TWCV. 01:30 05:00 3.50 COMPZ WHDBO FRZP P PJSM with Lil'Red and Rig Crew. Rig up lines to Freeze Protest. Pressure test line at 2,500 psi. Lil' Red pump 190 bbls of Diesel down the IA at 2.0 bpm/650 psi. End pumping. Page 6 of 7 • Time,Logs iii , iipi ';r From ,To but w ipiM' l diII P tl ow, ;Date �,�� 5.Depth E,�Dep#h Phase Code� Su�iooiie, �' Common# 05:00 06:00 1.00 COMPZ WHDBO FRZP P Hook up line and allow well to U-Tube. Well freeze protected to 2,600-ft and/2,000-ft tvd. Retest I-Wire and observed good test with the bottom hole pressure reading of 1540 PSI, Bottom hole temperature of 69 Deg. Phase to ground reading- 70K OHMS.All Good. 06:00 06:30 0.50 COMPZ WHDBO FRZP P Blow down lines and rig down equipment in cellar. 06:30 08:00 1.50 COMPZ WHDBO SEQP P Rig up lubricator with Wetco wellhead rep. Install BPV as planned.Observed well underbalanced with 200 PSI on gauge. 08:00 09:00 1.00 COMPZ WHDBO SISW P Secure tree and install gauges. Observed 200 PSI on the tubing. Observed 150 PSI on the IA.Secure tree cap.Suck out fluid in celalr. 09:00 14:00 5.00 COMPZ WELLPFSFTY P Both crews reported to KOC-EMOC room for planned IFC training.3 hands left on rig to remove remaing fluid from pits and monitor rig. SIMOPS:Check all tire pressures with Peak tire man. 14:00 15:00 1.00 COMPZ WELLPF RURD P Crews back to rig.Suck out cuttings bin.All fluid gone. Rig released form 1J-135 at 1500 HRS. Page 7 of°7 STATE OF ALASKA ' - ALA• OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well Rug Perforations S � Ot ESP to temp gas P r 9 lift Alter Casing r Rill Tubing r Perforate New Fool r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well [ j 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r _ 207 -039 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 23349 -60 - ®o 7. Property Designation (Lease Number): 8. Well Name and Number: ADL- 380058, ADL- 25662, ADL -25661 , 1 J -135L1 9. Field /Pool(s): m Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 17935 feet Plugs (measured) None true vertical 3420 feet Junk (measured) None Effective Depth measured 17723 feet Packer (measured) N/A true vertical 3513 feet (true vertucal) N/A Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 20 122 122' SURFACE 3419 13.375 3463 2215 INTERMEDIATE 9056 9.625 9097 3604 D LINER 8614 4 17923 3420 Perforation depth: Measured depth: 9375-12949;12951-17878 t � True Vertical Depth: 3549 - 3495;3495 -3420 ECE ,V eQ JUN Tubing (size, grade, MD, and TVD) 3.5, L -80, 7340 MD, 3210 TVD 1 9 20/2 Packers & SSSV (type, MD, and TVD) A 00CC No Packer or SSSV 11. Stimulation or cement squeeze summary: Intervals treated (measured): NIA Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation Shut in Shut in Shut in Shut in Shut in Subsequent to operation 183 80 0 1306 179 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development n Service r Stratigraphic r 15. Well Status after work: s Oil it Gas r WDSPL r l! Daily Report of Well Operations X GSTOR r WINJ r WAG r GINJ T SUSP r SPLUG r 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt N/A Contact Bob Christensen / Darrell Humphrey Printed Name Darrell Humphrey Title NSK Production Engineering Specialist Signature Phone: 659 -7535 Date ®SAS JUN 2 0 2012 6. 41.11_, Form 10-404 Revised 10/2010 0 , fr< d• it Original Only Y 1J -135L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 05/28/12 SET 1/4 OV @ 2299' RKB. PULLED SLIP STOP CATCHER @ 2284' RKB. COMPLETE 1 1 1 1 I 1 1 1 I 1 1 • KUP 1J -135L1 Y COnoCOPhilllpS ' &vii Well Attributes Max Angle & MD TD Alaska Inc We(WUore APIIUWI Field Name Well Status Inci ( ") MD (ftKB) Act Btm (RKB) ,,,. 500292334960 WESTSAK PROD 93.65 13,201.90 17,935.0 Comment 142S (ppm) Date Annotation End Date KB - Ord (R) Rig Release Date Wall cont9 MULTIPLE LATERALS - 1a - 735u , 529/2012 103762 AM SSSV: NONE 120 8/8/2010 Last WO: 2/9/2010 44.00 5/23/2007 Schematc Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date ------ Last Tag: SLM 7,400.0 10/28/2009 Rev Reason: GLV C/O ninam 5/29/2012 Casing Strings • AHr:�3B_ _ _ .. f -- - Casing Description Strip 0... Strip ID To RKB Set Depth (f... Set Depth (TVD) String Wt... String String Top Thrd 9 P 9 9 Pl 1 P P 1 ) 9 9 g P HANGER D 6.03 4.950 9,093.7 9,352.4 3,548.7 15.50 L BTC - mod :sing Description String 0... String ID ... Top MKS) Set Depth (f,.. Set Depth (TVD) ... String Wt... String ... String Top Thrd D LINER 5 4.000 9,308.8 17,923.0 3,420.2 11.60 L-80 BTC Liner Details Top Depth (TVD) Top Incl Nomi.,. Top (RKB) (MB) 1 ") item Description Comment ID (in) 9,308.8 3,546.8 88.30 SLEEVE 5 1/2" Baker "HR" Liner Setting Sleeve (6.43" O.D. x 5.75" I.D.) 5.750 CONDUCTOR, 9,369.9 3,549.2 89.31 XO 5 1/2" Hydril 521 Box X 4 1/2" Hydril 521 Pin X/O (3.94" ID.) 3.940 4a - 1.z 17,878.0 3,420.1 89.91 BENT JT 4 -1/2 ", 11.6 ppf, L -80, BTC Blank (Bent) Joint 3.950 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (WEB) Btm (MB) ((MB) (RKB) Zone Date (sh••. Type Comment Mandrels, 2,299 _' 9,375 12,949 3,549.3 3,494.5 WS D, 1J -135L1 5/17/2007 32.0 SLOTS 2.5" Long x .125" wide, 4 W dreumferendal rows/ft, 3" centers, staggered, 18 deg. • 12,951 17,878 3,494.5 3,420.1 WS D, 1J -135L1 5/17/2007 32.0 SLOTS 2.5" Long x .125" wide, 4 circumferential rows/ft, 3" centers, SURFACE, staggered, 18 deg. 44 -3,483 SLIPSTOP, PI Notes: General & Safety 7,144 - End Date Annotation NIPPLE, 7,148 440 5/23/2007 NOTE: MULTI - LATERAL WELL - 1J -135 (B- SAND), 1J -135L1 (D-SAND) IE 8/9/2008 NOTE: View Schematic w/ Alaska Schematic9.0 SLEEVE, 7,163 at PUMP SUB, 7,203 - M SENSOR77,. 7,212 PUMP TBG, gli 7.212 DISCHARGE, 1.224 ESP PUMP, 7224 • DISCHARGE, . 7237 ESP PUMP, 72 , a Gas separator, 7,251 —, NIPPLE, 7,257 SEPARATOR,' 7,C 11 Y-BLOCK, 4 - 7,259 NIPPLE, 7,280 O. Teleavn"el, E' 7,262 Seal Awy, e- 7262 MOTOR, 7,278 _ ' SEAL ASSY, _ 7267 MOTOR, 7,301 - J 7 SENSOR,_ 7,312 Plug, 7,314 - SENSOR, 7,315 PLUG, 7,317 WLEG, 7,340 • 1 D -SAND WINDOW, 9,097 -9,107 HANGER D -SAND, 9,094 -9,352 NTERMEDIATE, 41 -9,819 Ili iir Mandrel Details Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run Stn Top (RKB) IItKB) ( °) Make Model (in) Seers Type Type (in) (psi) Run Date Com... 1 2,298.8 1,908.7 70.98 CAMCO KBMG 1 ESP OV BK 0.250 0.0 5/28/2012 SLOTS, Jii II i 9,375- 12,949 SLOTS. 12,951 - 17,8713 D LINER, 9,30917,923 TD (1J- 135L1), 12935 • .MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMIS N REPORT OF SUNDRY WELL OPERATIONS ~. operations Pertormed: Abandon Repair well ,, Plug Perforations ~ Stimulate ~""' Other '"" Alter Casing ~" Pull Tubing Perforate New Pbol """ Waiver Time Extension Change Approved Program Operat. Shutdown '"` Perforate "` Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory „"" 207-039 3. Address: Stratigraphic ~"" Service 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23349-60 7. roperty Designation: 8. Well Name and N~ ber: ADL 25662, 380058 1J-135L1 9. Field/Pool(s): \ Kuparuk River Field TWest Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 17935 feet Plugs (measured) None true vertical 3420 feet Junk (measured) None Effective Depth measured 17921 feet Packer (measured) 9218 true vertical 3420 feet (true vertucal) 3543 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 121 121' SURFACE 3421 13.375 3462 2215' INTERMEDIATE 9778 9.625 9819 3546' D LINER 8615 5.5 17923 3420' ~~1`1~9~ ~~i~~? 't ~a ~'3 ~ R~~br~~~~ fi i Perforation depth: Measured depth: 9375'-12949', 12951'-17878 True Vertical Depth: 3549'-3495', 3495'-3420' ~AR 0 g Z~~a ~&~e~ Tubin size, rade, MD, and TVD 9 ( 9 ) tbg in main wellbore Packers & SSSV (type, MD, and TVD) PACKER - D-SAND BAKER PAYZONE ECP @ 9218 MD and 3543 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): none Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation si Subsequent to operation 312 45 11 -- 218 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run E~loratory Development Service . Well Status after work: Oil ~'' Gas "` WDSPL Daily Report of Well Operations XXX GSTOR WAG j"" GASINJ "°''; WINJ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: none contact Erik Nelson (a) 263-4693 Printed Name Er Title Wells Engineer ~, Signature / Phone: 263-4693 Date s /) ~! ~~~~v RBDMS MAR 0 91010 ~~~ ~" 3 •/o. /o Form 10-404 Revised 7/2009 Stabmlt Orlglnal Only ,:. ,ter„ .,, COI'tOCO~l1~~1pS • ' KUP ',Well Attribute 'Wellbore APVII WI s Fieltl Name 500292334960 WEST SAK - C ent H25 (Ppmi NONE ~SSSV~ ~ 10 ,M r In u emF. IG..A n~1n 1J-135L1 r'~ _ m9~5 +'+rtyrc Well Status Intl (°) MD (' (PROD 93.65 1 ~0 5/23/2007 I act Mntl Entl Date -HANGER. 3A. - _ - ~ q"1-_ Mandrels.2295 SURFACE, 44-3,463 NIPPLE, 1,146 SLEEVE. 7.163 SENSOR??, 7.212 NIPPLE. ].26] - V$LOCK, ].255 NIPPLE, ] 26(1 Teleswivel,~ 7,262 PUMP SUB, ].260 ^ISCHARGE, _ 7.271 ESP PUMP, 7,271 SEPARATOR,_ ],284 ~' SEAL ASSY._ 7.290 MOTOR, 7,304- SENSOR,_ ],315 PLUG, 7.317-- WLEG, 7.340 D SAKI ~ WINDOW 9.097~5.'.u~ HANG_-; SLOTS, 9.3]512 545 7 400 0 102 109 9 Rev Reason' Workover, Set Slipstop/CAI SV Imosnor ~ 2/22;2010 CdSln Strin 9s - Cas ng Descnption Str g O Sh y ID .- - Top (ftKB) Set Depth (f .. Set D pth (NDI .. Str g Wt-_ Str g 51 ing Top Thrd 1 4 d 1 HANGER D SAND 6 03 L 80 B I C-mod 9 352 4 I 3 `.v38J 15 50 9,093 ~ Cas ng Descnpt on String O .. Str g ID ... . Top (ftKB) Set Depth (f .. Sat Depth (NDI .. String Wt... Str ng String Top Thrd D LINER 5 4tOU 9,3088 17,9230 34202 1160 L80 B1C _ Liner Details _ - __-- Top Depth _. (NDI Top Intl Nomi... Top (ftKBI (ftKB) (°) Item Descriptio n Comment ID (in) 9,30A.8 3,546.8 88.30 SLEEVE S 1/2" Baker "HR" Liner Setting Sleeve (6.43" O.D. x 5.75" LD.) 5.7501 9.369.9 3.549.2 A9.31 XO 5 1/2" Hydril 521 Box X 4 1/2" Hyddl 521 Pin X/O (3.94" LD.) 3.94Q if 17,878.0 1420 1 89.91 , BENZ-J1 4-1/2". 11.6 ppf, L-80, BTC Blank (Bent) Joint 3.950' ',Perforations & Slots. _, l shot Top (TVD) Btm (TVDi ii Dens To (ftKB) BM (ftKB) (ftKB) (HKBj Zone Date (sh,,, Type Comment 9,375 12,949 3,549.3 ,3,494.5 WS D, 1J-136L7 5/17/2007 32-0 SLOTS 25" Long x .125" wide, 4 circumferential rows/ft, 3" centers, staggered, 18 deg. 12,951 17,878 3 494.5 3,420.1 WS D, 1 J-135L1 ~ 5/1X2007 32 0 SLOTS 25" Long x .125" wide, 4 ~~. circumferential rows/ft, 3" centers, ' ~ staggered, 18 tleg Notes: General & Safety _ _ End Date Annotation 5/23/2007 NOTE MULTI-LAI EI?AL WELL- 1J-135 (BSAND), 1J-135L7 (0-SAND) _ ___ _. _. 8/9/2008 NOTE: VIEW SChiEINA I IC w/9.0 SLOTS, 12.551-1],678 D LINER, 9.309-1].913 f0 (1 J~135L1), 1],935 .1J-135 Pre and Post Rig Events DATE SUMMARY 12/3/09 PRE RWO T-POT (PASSED ), T-PPPOT (PASSED ), UT-POT (PASSED ), UT- PPPOT (PASSED ), LT-POT (PASSED ), LT-PPPOT (FAILED ), JC-POT PASSED ), IC- PPPOT (PASSED ), FT-LDS ALL NORMAL. 1/4/10 MEASURED SBHP @ 7011' SLM( 1170 psi ). GRADIENT @ 1300' SLM (514 psi) & GRADIENT @ 100' SLM (98 psi ). COMPLETE 1/30/10 PERFORMED TRACTOR DEPLOYED MIT CALIPER LOGGING PREPARATION: SWAPPED UNIT TO BIG CABLE; OPERATIONAL CHECKS OF HEAD AND WELTEC TRACTORS; OPERATIONAL CHECKS OF HES AND PDS SONDEX 24- FINGERAND 40-FINGER CALIPER TOOLS. 1/31/10 PERFORMED TRACTOR DEPLOYED MIT CALIPER LOGGING PREPARATION: SWAPPED UNIT TO BIG CABLE; OPERATIONAL CHECKS OF HEAD AND WELTEC TRACTORS; OPERATIONAL CHECKS OF HES AND PDS SONDEX 24- FINGER AND 40-FINGER CALIPER TOOLS. 2/1/10 STANDBY FOR TRACTOR DEPLOYED MIT (PDS) CALIPER LOG. 2/4/10 STANDBY FOR TRACTOR DEPLOYED MIT (PDS) CALIPER LOG. 2/5/10 CABLE HEAD SHORTED ON OUR FIRST WELLTEC TRACTOR/ PDS 40 ARM CALIPER RIH. REHEADED CABLE AND MAKING SECOND ATTEMPT TO COMPLETE CALIPER RUN AT THIS TIME. IN PROGRESS... 2/6/10 ATTEMPTED TRACTORING PDS MIT TOOL. TRIED USING 2 DIFFERENT CABLEHEADS THAT BOTH CHECKED GOOD ON SURFACE BUT FAILED DOWNHOLE. TOOLSTRING WORKED ON 3RD ATTEMPT BUT TRACTORS COULDN'T GET ENOUGH POWER TO OPERATE. POOH AND RIGGED DOWN PER COMPANY MAN. CURRENTLY INVESTIGATING PROBLEM ON E-LINE UNIT. 2/13/10 SET 2.812" D CAT STANDING VALVE IN DS NIPPLE AT 7149' RKB. SET 2.72" SLIP STOP ON TOP OF STANDING VALVE. FREEZE PROTECT TUBING W/ 30 BBLS DIESEL. WELL LEFT SHUT-IN. JOB COMPLETE ConocoPhiflips Time Log & Summary welNfew web ReAOrt/ng Re Y O ..1 Well Name: 1J-135 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 1/21/2010 3:00:00 PM Rig Release: 2/9/2010 11:59:00 PM Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment' 1/21/2010 24 hrsummarv RDMO off 1J-162, Move and spot double mats, MIRU Nordic Rig 3. 12:00 19:00 7.00 COMPZ MOVE MOB P Move Nordic Rig 3 off of 1J-162 and spot at 1 J-135. Move and set double rig mats on well Accepted Nordic Rig 3 at 15:00 hrs on 01/21/2010 b R. Dolcater. 19:00 23:00 4.00 COMPZ MOVE RURD P Move Rig over 1J-135 Wellhead. Center and level Rig. Spot and rig up support equipment. Load Pits with 8.7 KCL water. Rig up circulating lines in cellar. 23:00 00:00 1.00 COMPZ WELCTL MPSP P Pick up Lubricator. Pull BPV. Lay down same. Tubing pressure = 40 psi, IA pressure = 990 psi. OA = 500 psi. No communications between the Tubin and the IA. 1 /22/2010 Complete rig up on 1 J-135. Test lines. Bleed gas from IA. Circulate and kill well. Install BPV. ND Tree and NU BOPE. Test BOPE. Pull Blanking Plug and BPV. Un-seat Tubing Hanger. Pump HOT Seawater/6% KCL down Tubin to clean u Well. 00:00 00:30. 0.50 COMPZ WELCTL SFTY P Held PJSM on PT lines @ 250/2,500 si . 00:30 06:30 6.00 COMPZ WELCTL CIRC P Pressure test lines at 250/2,500 psi. with water. Blow down lines. Open IA with 990 psi and bleed gas through choke to Tiger Tank. Bleed IA from 990 psi down to 250 psi. Pressure has stabilized at 250 psi. Line up to pump down the IA with Pump #2. Open Tubing. "0" pressure. Bring Pump on line at 2.0 bpm/340 psi. Increase rate to 4.0 bpm (69 spm) at 450 psi. 50 bbls pumped away at 350 psi. Increase rate to 5.0 bpm (86 spm) at 330 psi with 100 bbls pumped away. 200 bbls pumped away at 210 psi. With 440 bbls pumped away at 230 psi. Noticed a slight diesel "dripple" comin from the tubin . Page 1 of 19 'Time Lo s :Date From To Dur S. De th E. De th Phase Code Subcode T Comment 06:30 08:00 1.50 COMPZ WELCTL CIRC P Strap tank and had recovered 197 bbls of diesel. Pump down TBG @ 6 bpm ICP of 350 psig and FCP 90 psig after 121 bbls pumped. Strap kill tank and monitor well -had 100 psig on the IA. Pump 100 bbls down TBG @ 100 psig @ 6 bpm with IA on Full O en choke. 08:00 09:30 1.50 COMPZ WELCTL OWFF P Monitor well with 0 psig on the TBG and 20 psig on the IA. Bleed IA off to Kill tank and Blow down lines. Open up well and SITP @ 250 psig. and SIICP 30 si . 09:30 10:00 0.50 COMPZ WELCTL CIRC P Pump 50 bbls 6% KCL Seawater down TBG. 10:00 11:30 1.50 COMPZ WELCTL OWFF P Monitor well while emptying Kill Tank and Loading pits w/ 6% KCL. Pit Volume @ 621 bbls. SITP @ 90 psig and SIICP @ 90 psig, Open TBG and IA to choke and slowly bleed off ressure to 0 si . 11:30 12:15 0.75 COMPZ WELCTL CIRC P Fill TBG w/ 134 bbls 6% KCL Seawater using rig charge pump with IA o en to kill tank. 12:15 12:45 0.50 COMPZ WELCTL OWFF P Monitor well -TBG and IA both on a vacuum. 12:45 13:00 0.25 COMPZ WELCTL OTHR P Blow down lines to kill tank. 13:00 13:30 0.50 COMPZ WELCTL MPSP P Install 4" HBPV 13:30 14:00 0.50 COMPZ WELCTL SFTY P Held PJSM on Nipple down of tree. 14:00 15:00 1.00 COMPZ WELCTL NUND P ND Tree and Adapter, set Blanking lu . 15:00 15:30 0.50 COMPZ WELCTL SFTY P Held PJSM on NU ROPE. 15:30 19:30- 4.00 COMPZ WELCTL NUND P PU and Install 13 5/8 BOP and riser. (Spot Crane and swap out ESP reels on S oolin Unit . 19:30 00:00 4.50 COMPZ WELCTL BOPE P Test BOPE per CPAI/AOGCC requirements at 250/2,500 psi. Perform Koomey draw down test. State's right to witness test was waived b C. Scheve. 1 /23/2010 Clean up well with Hot SW/6% KCL. Pull Hanger to floor. Begin to single down 4 1/2" ESP Completion. 00:00 01:30 1.50 COMPZ WELCTL BOPE P Complete ROPE test. Good tests. Blow down lines. Rig down test e ui ment. 01:30 02:00 0.50 COMPZ WELLPF MPSP P Pull Blanking Plug and BPV. Lay down same. Well on vacuum. 02:00 04:00 2.00 COMPZ RPCOM THGR P Ready floor to un-seat Tubing Hanger, Pick up Landing Joint. Back out lock down pins. Pull Tubing Hanger free at 145K. Tubing movin free at 120K. Page 2 of 19 'Time Lo s Date From To Dur S_ De th E. De th Phase Code Subcode T Comment 04:00 04:30 0.50 COMPZ RPCOM SFTY P PJSM with Lil' Red, Rig Crew, Mud Man, and Vac Truck Drivers. Discussed Pressure testing and working around hot water. Reviewed tanned o erations. 04:30 13:30 9.00 COMPZ RPCOM CIRC P Lil' Red pressure test line at 250/2,500 psi. Good test. Stage Vac Trucks. Lil' Red began pumping 180+ degree Seawater/6%KCL down the Tubing at 2.0 bpm/500 psi. No returns from IA. Pumped away 230 bbls at 2.0 bpm/0 psi. No returns. Change over to the IA and pump 253 bbls of 880 bbls @ 2 bpm @ 500 psi and started taking returns. Pumped 627 bbls after gaining circulation and recovered a total 13:30 14:00 0.50 7,566 7,557 COMPZ RPCOM SFTY P Held PJSM on laying down pipe and awareness of hot tubulars. 14:00 15:30 1.50 7,557 7,530 COMPZ RPCOM PULD P Pull hanger to rig floor, String sheave, and continue to POOH and Laying down decompletion, Stra in and tall in all. 15:30 00:00 8.50 7,530 3,332 COMPZ RPCOM PULD P Have 135 Joints of 4 1/2" Tubing singled down at Midnight. Continue pulling from 3,332-ft spooling ESP Cable. Strin wei ht 75K. 1 /24/2010 Lay down ESP Assembly. Set test plug and test 5" Pipe Rams and Hydril. Finish loading Pipe Shed with remaining 5" Drill Pipe. Make up 6 1/4" Hybred and rack back in derrick. MU BHA #1. RIH picking up Drill Pi e. 00:00 06:30 6.50 3,332 222 COMPZ RPCOM PULD P Continue to single down 4 1/2" ESP Com letion. 140 ~ts total. 06:30 07:00 0.50 222 71 COMPZ RPCOM OTHR P Strip flat guards, Protectolizers, and la down u er'ewel above intake 07:00 09:30 2.50 71 0 COMPZ RPCOM ALFT P Tear down and inspect ESP components, Found Heavy scale around the top of the motorsection in the Pot head area, Coupling was stuck in the intake and TTC Crossover. Burn on the pot head. Brunt oil in the motor and the motor was also grounded. The Lower Splice megged good. Recovered: 15 of 20 SS Bands, 128 Cannon Clamps, 3 Protectolizers, and 2 Flat wards. 09:30 11:30 2.00 0 0 COMPZ RPCOM OTHR P Wrap ESP Cable spool, Clean and clear rig floor, and RD TBG Equipment. Load ESP in Boxes and offload all decom letion. 11:30 14:30 3.00 0 0 COMPZ RPEQPI OTHR P Continue to load 5" DP in pipe shed. Ran out of stri in . 14:30 16:00 1.50 0 0 COMPZ WELCTL BOPE P Install test plug on 5" DP and RU Test equipment. Test Lower VBR's, Upper VBR's and Annular, Ibop and TIW valve 250/2,500 si . Page-3 of 19 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T .Comment 16:00 16:30 0.50 0 0 COMPZ RPEQPI OTHR P Set wear ring 16:30 19:00 2.50 0 0 COMPZ RPEQPI OTHR P Continue to load 5" DP and 8 - 6.25" DC's in Pipe shed. Load Baker E ui ment and Tall all. 19:00 19:30 0.50 0 0 COMPZ RPEQPI SFfY P PJSM. Discuss the hazards in picking up 6 1/4" Drill Collars and making up the stands of Push Pipe. Also-covered picking up the BHA for the drift run 19:30 22:00 2.50 0 0 COMPZ RPEQPI PULD P Make up Push Pipe Assemblies (4 stands and stand in Derrick. 22:00 00:00 2.00 0 91 COMPZ RPEQPI PULD P Make up BHA #1. Dummy Drift Run for LEM Assembl . 1 /25/2010 RIH with BHA #1 to 7,400-ft. Reverse in with a 30 bbl 776 Mud Lube sweep and chase with 400 bbls SW/KCL. Continue RIH to 8,556-ft. Wash and ream through sections of scale down to the final target depth of 9,080-ft with no roblems. Circulate Well. 00:00 10:00 10.00 91 7,396 COMPZ RPEQPI PULD P RIH with BHA #1, Dummy Drift for LEM Assembly. Single in with 5" " Drill Pipe from Pipe Shed. Begin gathering T & D @ 5,900' 135k up wt, 65k do wt.; 6,900' 150k up wt, 60k do wt.; 7,396' jt# 231 155k up wt, 58k do wt. 10:00 14:00 4.00 7,396 7,396 COMPZ RPEOPI CIRC P RU to reverse circ. Pump 30 bbl 1% 776 Mud tube / .5 Ib bbl polymer 34 funnel visc 6% KCL water (Apparent Visc of 10 cps. w/ PV of 5 and YP of 10) followed by 400 bbls of 6% KCL water 14:00 14:30 0.50 7,396 8,778 COMPZ RPEQPI PULD P Continue to RIH to 8,655' and set down 20k, picked and ran back down to 8,685' took wt. Ream thru @ 25 rpm's W/ 7k torque. Ream thru from 8,653' to 8,778'. 14:30 17:30 3.00 8,778 8,778 COMPZ RPEQPI CIRC P Reverse circulate 300 bbls (2 DP Vol.) had gas and oil influx, Shut down and RU to tiger tank to send returns to. Continue to reverse circulate 5 b m 120 si . 17:30 20:30 3.00 8,778 8,935 COMPZ RPEQPI REAM P Continue to ream down from 8,778' to 8,935'. Attempt to make a connection. However, Well is out of balance and flowing back up the tubing. Circulate Tubing volume x 2 at 5.0 b m/125 si. Page 4 of 19 Time Lo s Date From To Dur S. De th E. De th:Phase Code Subcode T Comment 20:30 22:00 1.50 8,935 9,080 COMPZ RPEQPI REAM P Continue to ream and wash down with no problems from 8,935-ft. to 9,065-ft. at 4.5 bpm/120 psi. Non-rotating up weight = 150k. Non-rotating down weight = 65k. Rotating up weight = 125k. Rotating down weight = 95k. RPMs = 25. Torque = 10k. Short-trip each joint. "Slide" the final 15-ft down to the target depth at 9,080-ft. Back ream to 9,065-ft. Run back in to 9,080-ft and ark BHA. 22:00 00:00 2.00 9,080 9,080 COMPZ RPEQPI CIRC P Reverse circulate tubing volume x 2 at 5.0 bpm/150 psi. Swap over to circulate the long way. Pump a 20 bbl 776 Mud Lube sweep and chase with 161 bbls of SW/KCL. 1 /26/2010 Continue chase pill. POOH from 9080'. Breakout, lay down BHA. Clean JB's recovering 20# of iron debris. Sli & cut drillin line. Load tools, Mu BHA #2, TIH to 6073 with Snozzolator assm . 00:00 03:30 3.50 9,080 9,080 COMPZ RPEQPI CIRC P Continue with circulating the long way. Pumped a second 20 bbl 776 Mud Lube sweep and chase with 650 bbls SW/KCL. Estimated 60 - 70 returns through out circulation. Saw both sweeps go across the Shaker. However, saw no solids. 03:30 09:30 6.00 9,080 91 COMPZ RPEOPI TRIP P Ready floor. Trip out with 5" Drill Pipe and BHA#1, standing Drill Pipe back in Derrick. Pick up weight off target depth = 165k. Pulled 5 stands with normal weight. Monitor hole. Good. Test Crown-O-Matic. Good. Double pipe displacement while TOOH. From 8,000-ft up to 7,750-ft notice a 10 k over pull increase, then dropped back to normal up weight. Weight check at 7,000-ft, up 165k, down 68k. Weight check at 6,000-ft, up 155k, down 65k. Continue POOH. 09:30 12:00 2.50 91 0 COMPZ RPEQPI PULD P Clean magnet's and empty boot baskets. Recovered 4.5 SS Bands. 20 Ibs of metal shavings and misc. metal from cutting window at start of well. Off load BHA #1 from ri . 12:00 14:00 2.00 0 0 COMPZ RIGMNT RGRP P Slip and Cut 84' of drill line. 14:00 14:30 0.50 0 0 COMPZ RPEQPI SFTY P Held PJSM w/ crew and third party services on Snozzlator BHA #2- 14:30 15:30 1.00 0 COMPZ RPEQPI PULD P Pull tools to rig floor. Prep rig floor for makin u BHA. 15:30 21:00 5.50 202 202 COMPZ RPEQPI PULD P Make up BHA #2. BHA consisted of Snozzolator assembly with wash tools spaced out accordingly, with junk baskets and string magnets. Total BHA len th = 202.28' Page 5 of 19 • ! 'Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 21:00 00:00 3:00 202 6,073 COMPZ RPEQPI TRIP P Trip in hole with BHA #2 from 202' - 6073'. Up Wt - 127K, SO WT - 70K. Observed well taking entire displacement plus. Fill hole with 10 - 15 bbls / hr. Fluid loss for the day = 244 BBLS. 1 /27/2010 Continue TIH with Snozzolator assmy from 6073' - 9040'. RU and wash down through Hook Hanger down to 9135' DPM. Observed hard tag and could not wash past this point. RU & Reverse circulate annulus volume pumping a 45 BBL Hi Visc sweep with 776 Lube. Re- attempt to make hole with no success. POOH, rack back DP. Lay down BHA, recovering approximately 20# of iron and aluminum debris, & SS bands. Make up 2 7/8" Mule shoe assembly, Trip in hole to wash down from 903' - 9324' DPM midnigt depth. No hard tag observed. Fluid loss for 24 HRS - 1543 BBLS 00:00 01:30 1.50 6,073 9,040 COMPZ RPEQPI TRIP P Continue trip in hole with BHA #2 from 6073' - 9040' DPM. lJp Wt - 152K, SO WT - 67K. Observed well taking entire displacement plus. Fill hole with 10 -15 bbls / hr. 01:30 04:00 2.50 9,040 9,135 COMPZ RPEQPI CIRC P Obtain parameters. Begin washing down @ 5 BPM - 750 PSI, no rotation, from 9040' through hook hanger assmy @ 9093', down to 9135' with the bullnose. We observed the assembly stop, and repeated attempts to gain hole, with various pump rates from 2 to 9 BPM. Max set down weight = 8-10K. Up WT - 152K, SO WT - 67K. The drill string had free movement when working it. Fluid losses remained steady taking everything we pumped, with no returns. Suspect bullnose may be plugging or packing off, as we observed a slight increase in pump pressure when setting on bottom at 9135'. 04:00 06:30 2.50 9,135 9,135 COMPZ RPEQPI FCO T Discuss options with engineer. Decision to close annular, pump down annulus at rates to flush the annulus, and spot a 45 BBL pill on bottom. After 50 BBLS, pull on drill string to verify assembly remained in free movement. rates from 3-8 BPM. Continue checking free movement in strin . 06:30 07:00 0.50 9,135 9,138 COMPZ RPEQPI FCO T Attempt to clean out fill and made 3' and was unable to get any deeper. Blow down To drive. 07:00 13:00 6.00 9,138 202 COMPZ RPEQPI TRIP T Pooh for BHA change to 202' 13:00 15:00 2.00 202 0 COMPZ RPEQPI PULD T POOH w/ BHA #2 and clean magnet's -recovered mist metal shavings and chunks of iron approximately 10 lbs., boot baskets had small amount of fines and 1 large piece of aluminum -looks like 9 5/8" cmt equipment. Nogo showed no si ns han u in hook han er. Page 6 of 19 • Time Lo s 'Date From To Dur S. De th E. De th Phase Code Subcode T Comment 15:00 16:00 1.00 0 0 COMPZ RPEQPI OTHR T Load and Un-load tools, prep pipe shed for BHA ick u .Held PJSM. 16:00 18:00 2.00 0 352 COMPZ RPEQPI PULD T PU and MU BHA #3. 2 7/8" Mule shoe assembly with 289' of 2 7/8" DP. Total BHA len th = 351.76'. 18:00 22:30 4.50 352 9,063 COMPZ RPEQPI TRIP T Trip in hole from 351' - 9063'. Observed well taking displacement lus. 22:30 00:00 1.50 9,063 9,324 COMPZ RPEQPI WASH T Make up Top Drive and obtain parameters. UP WT = 160K, SO WT = 63K. Pumps at 5 BPM. - 180 PSI. Begin washing down, observing mule shoe through Hook hanger with no issues. Continue to 9150'. Pull up, and repeat. Pull up and turn mule shoe to attempt identify wellbore we are entering. Slack off and tag at 9110' DPM. repeat. Suspect that we had tagged up on bottom of the window. Pull up and turn mule shoe again, slacking off to tag at g16T, which is the top of the MLZXP in mother bore. Work through 9167, contiuing washing down to 9324' with no issues. Observed 2-5K WOB, allowing sand to wash away. Fluid loss for the da = 1543 BBLS total. 1 /28/2010 Continue wash down from 9324' - 9354'. reverse circulate a 30 BBL pill, and chase with 670 BBLS. POOH, racking back DP. Make up Snozzilator wash tool assmy. TIH. Wash through Hook Hanger assmy down to 9137'. Tagged up, contnue work string to gain hole to 9142' (5'). Reverse Circulate while pumping a sweep to aid in cleanin tools. Unsuccessful in ainin more hole. 00:00 01:00 1.00 9,324 9,354 COMPZ RPEQPI WASH T Continue washing down with 2 7/8" mule shoe assembly from 9324' - 9354' DPM. Observed 2-5 K WOB allowing sand to wash away. Repeat wash last stand. Pumps at 5 BPM - 200 PSI 01:00 03:30 2.50 9,354 9,354 COMPZ RPEQPI CIRC T RU, Reverse Circulate 30 BBLS of Hi Visc pill with 776 Lube, chase with 670 BBLS of 6% KCI, at 5 BPM - 120 PSI. Observed minimal returns of approximately 1/2 to 1 BBU min: Work string every 50 BBLS to verify free movement. O en annular. 03:30 04:00 0.50 9,354 9,354 COMPZ RPEQPI OWFF T Monitor well, verify fluid dropping in stack.Held PJSM. Discuss safety ~ hazard recognition issues. Discuss rocedure to POOH, rackin DP. 04:00 10:30 6.50 9,354 351 COMPZ RPEQPI TRIP T POOH slowly, observing free movement, no overpull. Pull to top of hook hanger at 9094'. Contiue POOH racking back 5" DP. Observed hole takin dis lacement lus. 10:30 12:00 1.50 351 0 COMPZ RPEQPI PULD T Lay down BHA #3 recovered small amount of metal fines 12:00 13:00 1.00 0 0 COMPZ RPEQPI OTHR T Clean out boot baskets and bend 'oint of 3 1/2 8rd to 15°. Page 7 of 19 n Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 13:00 13:30 0.50 0 0 COMPZ RPEQPI SFTY T Held PJSM on making up BHA. 13:30 15:00 1.50 0 202 COMPZ RPEQPI PULD T Make up BHA #4 15:00 19:30 4.50 202 9,008 COMPZ RPEQPI TRIP T RIH f/ 202' to 9008' -DPM. Observed well takin all dis lacement lus. 19:30 00:00 4.50 9,008 9,142 COMPZ RPEQPI WASH T MU Top drive. Obtain parameters. UP WT = 157K, SO WT = 76K. Pumps at 5 BPM - 540 PSI. Slack off to wash through Hook Hanger with no issues. Tag up at 9137 DPM. Repeat tag. Continued with repeated attempts to verify wellbore, and wash down, we reverse circulated ,and pumped a high visc sweep down the drill string utilizing max rates with success only to 9142' (5'). Reverse circulated 50 BBLS before POOH. 1 /29/2010 POOH from 9142' to 5885'. At 0230 HRS, Security announced Phase 3 Conditions. Stabbed valve in drill string. Shut down, wait on weather. Load 280 jts of 2 7/8 DP in pipe shed. RU, pull wear bushing, set test plug. and perform scheduled BOP test. Witness of test waived bu AOGCC rep Bob Noble. Fluid loss today = 349 BBLS 00:00 02:30 2.50 9,142 5,885 COMPZ RPEQPI TRIP T POOH from 9142' - 5885' DPM. Observed hole taking all dis lacement lus. 02:30 23:30 .21.00 5,885 5,885 COMPZ RPEQPI OTHR T Security announced Phase 3 conditions field wide. Shut down. Secure well. Wait on weather. Fill hole with 20 BBLS 6% KCL every hour, continuing to monitor well. Conserve Fuel & Water. Held PJSM with crew. Minimize all operations, and stop traffic movement on pad except to clear a path from rig to rig camp. Load 280 jts of 2 7/8 DP in pipe shed while waitng for weather to clear.Held PJSM. SDiscuss safety & hazard recognition issues. Discuss procedure to test BOP's. Rig up and pull Wear bushiing, Install Test plug. Test BOP's. 23:30 00:00 0.50 5,885 5,885 COMPZ RPEQPI BOPE T Security lifted the Phase 3 conditions. Continue test BOP's. choke manifold, HCR valves and all rig floor safety valves. Fluid loss toda =349 BBLS 1 /30/2010 Complete BOP Test. Witness of test waived by AOGCC rep Bob Noble. Complete loading 280 jnts of 2 7/8" PAC DP. Phase 3 conditions lifted. Install wear bushing. Continue POOH with BHA #4. lay down washng tools. MU 2 7/8" Mule shoe assembly. TIH. To work through Hook hanger and MLZXP packer in B Lat with no isssues. Continue wash 5 1/2" slotted liner to 9463' DPM. Total fluid losses toda = 1146 BBLS. Page 8 of 19 ~ ~ ?':Time Lo s ":Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 02:30 2.50 5,885 5,585 COMPZ RPEQPI BOPE T Continue test BOP's. choke manifold, HCR valves and all rig floor safety valves. Perform Koomey test with 200 PSI increase in 16 seconds, and full 3000 PSI in 2 min - 28 seconds. 02:30 04:00 1.50 5,585 5,585 COMPZ RPEQPI BOPE T Rig down test equipment. Blow donw lines, choke & degasser. Pull test plug, install wear bushing. Install mouse hole., Prep floor for POOH. Held PJSM, discussing safety & hazard reco nition issues. 04:00 08:00 4.00 5,585 0 COMPZ RPEQPI TRIP T POOH with BHA #4 from 5585' to surface. Breakout & lay down snozzilator wash tool assembly. Observed hole taking displacement plus. Fill backside with 20 BBLS eve hour. 08:00 11:00 3.00 0 0 COMPZ RPEQPI PULD T Break out & lay down BHA. Inspect wash tools and stop sub. Wear marks on stop sub indicated Hook Hanger may have been repositioned, or turned some. Recovered approximately 10# of fne iron on the string magnets. Decision to makeup 2 7/8" Mule shoe assembl . 11:00 12:00 1.00 0 0 COMPZ RPEQPI OTHR P Clean & clear rig floor area. Prep tools for next BHA. Held PJSM with crew & BOT rep. Discuss safety & hazard recognition issues. Discuss procedure to pick up DP from the i e shed. 12:00 21:00 9.00 0 8,884 COMPZ RPEQPI PULD P Make up 2 7/8" Mule shoe on PAC ' DP. Continue trip in hole picking up a total of 280 jnts of PAC DP. BHA lenagth = 8883.88'. Observed hole taking displacement plus. Fill backside with 20 BBLS eve hour. 21:00 21:30 0.50 8,884 8,884 COMPZ RPEQPI PULD P Change out DP running equipment, and RU for 5" DP. 21:30 22:30 1.00 8,884 8,884 GOMPZ RPEQPI PULD P Make up Crossovers and remaining BHA including BJ, OJ and P.O. Sub. Run 3 stands of 5" DP. Page 9 of 19 • `''Time Lo s 'Date From To Dur S. De th E. De th Phase Gode Subcode T Comment 22:30 .00:00 1.50 8,884 9,463 COMPZ RPEQPI WASH P Make up Top Drive. Obtain parameters. UP WT = 95K, SO WT _ 63, ROT WT = 73K, with 14 RPM's and 2K TO. Pumps on at 3 BPM - 800 PSI. work through Hook Hanger area at 9094 with no issues, and down to-top of MLZXP at 9167. Tag up verify depth. Repeat tag. Pull up and begin slowly rotating down through MLZXP with no issues. Continue washing down each stand at 10-12 Ft/Min, with 3 BPM, and pumping tubed fluid in annulus to aid in friction reduction. No tag up or torque issues observed. Midnight dpth = 9463' DPM -Total fluid lost toda = 1146 BBLS 1 /31/2010 Continue wash 5 1/2" slotted liner to 13824' DPM. Pump sweeps as need in order to clean hole, Observed no sand returns at surface. Avg pump rate @ 6 BPM - 900-2600 PSI. Observed possible rubber plug being pushed into the hole as pump pressure increase to 3000 PSI when on bottom. Mix & pump a HiVisc Lube sweep, reverse circulating entire 672 BBL annulus volume, while working drill string up through closed annular. Fluid loss for the da = 2161 BBLS. 00:00 10:30 10.50 9,463 12,487 COMPZ RPEQPI WASH P Continue wash 5 1/2" slotted liner from 9463' - 11,266' DPM. Obtain parameters. UP WT = 115K, SO WT = 71, ROT WT = 75K, with 14 RPM's and 2K TQ. Pumps on at 3 BPM - 800 PSI, washing down each stand at 10-12 FUMin, with 3 BPM, and pumping tubed fluid in annulus to aid in friction reduction. No tag up or for ue issues observed. 10:30 14:00 3.50 12,487 12,487 COMPZ RPEQPI CIRC P Circulate 40 bbl Lube pill surface to surface @ 5 bpm @ 1,650 psig while reciprocating in 90' intervals. Increase PR to 6 bpm @ 3,000 psig ICP and 2,600 si FCP at BU. 14:00 15:30 1.50 12,487 12,847 COMPZ RPEQPI WASH P Continue wash 5 1/2" slotted liner from 12,487' - 12,847' DPM. Obtain parameters. UP WT = 115K, SO WT = 85, ROT WT = 80K, with 14 RPM's and 2K TO. Pumps on at 6 BPM - 3,000 PSI, washing down each stand at 10-12 Ft/Min, @ 6 BPM, and pumping tubed fluid in annulus_to aid in friction reduction. Acts as if fighting rubber ahead, but no torque issues observed. Page 10 of 19 Time Lo s Date -From To Dur S. De th E. De th Phase Code Subcode T Comment 15:30 17:30 2.00 12,847 12,942 COMPZ RPEQPI WASH P Circulate 40 bbl Lube pill @ 6 bpm @ 3,200 psig continue to wash down from 12,847 to 12,942' @ 14 rpms @ 3K torque @ 6 bpm @ 3,000 psig w/ 115k up wt while rot, and 85k do wt while rot. Lost 438 bbls while circulating since 12:00 hrs - equivilant to 80 retumsWash from 12847' - 12942'. DPM 14 RPM's 6 BPM - 3000 PSI. 17:30 18:30 1.00 12,942 12,942 COMPZ RPEQPI CIRC P Pump a 30 BBL sweep at 6 BPM. 18:30 21:30 3.00 12,942 13,727 COMPZ RPEQPI WASH P Continue wash 5 1/2" slotted liner from 12,942' - 13727' DPM. UP WT = 115K, SO WT = 85, ROT WT = 80K, with 14 RPM's and 4K TQ. Pumps on at 6 BPM - 3,000 PSI, washing down each stand at 10-12 FtlMin, @ 6 BPM. 21:30 00:00 2.50 13,727 13,727 COMPZ RPEQPI CIRC P Discussion with Rig engineer. Mix up total of 150 BBLS of 3 PPB Flo-Visc, 3 %Lube 776. Rig up, Close annular bag with drill string on bottom. Pump 50 BBLS of the sweep, chasing with 6% KCL, reverse circulating @ 6 BPM - 120 PSI, while slowly pulling the string up 1 stand. When full stand pulled. Stop pumping, open annular. Rotate drill string and pump at 2 BPM to get back to bottom. Close annular and repeat operation as above, until pumped and entire 672 BBLS annulus volume. Observed no sand returns at surface, with fluid losses at 240 BPH. Total fluid losses for the da = 2161 BBLS. 2/01 /2010 Continue wash 5 1/2" slotted liner from 13824' - 17507' DPM. Pump sweeps as need in order to clean hole. Stop at depths of 15618, 16094, 17034, and 17507, closing annular and Reverse circulating 2 DP volumes, while working drill string up through annular. Avg pump rate @ 5-6 BPM 2600-3300 PSI. Fluid loss for the da = 2043 BBLS. 00:00 08:00 8.00 13,727 15,618 COMPZ RPEQPI WASH P Continue wash 5 1/2" slotted liner from 13,727' - 15,618 DPM. UP WT = 115K, SO WT = 85, ROT WT = 80K, with 14 RPM's and 4K TQ. Pumps on at 6 BPM - 3,000 PSI, washing down each stand at 10-12 FUMin, @ 6 BPM. Observed initial pump pressure up to 3400 PSI indicating we may have loaded the drill string up with sand debris. Observed pressure steadily come back down to 2700 PSI 6 BPM. 0800 10:30 2.50 15,618 15,618 COMPZ RPEQPI CIRC P Pump 40 BBL Lube pill surface to surface 6 BPM 2,800 si . Page 11 of 19 • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 10:30 13:00 2.50 15,618 16,094 COMPZ RPEQPI WASH P Continue to Clean out f/ 15,618' t/ 16,094'. 140k up wt w/ no rot. 115k up wt and 90k w/ rot. Circ @ 6 BPM @ 2,670 psig @ 14 rpms @ 5k for ue. 13:00 14:30 1.50 16,094 16,094 COMPZ RPEQPI CIRC P Reverse Circulate 2 DP Vol. (320 BBLS) @ 6 BPM @ 250 psig w/ 240 bbl losses Burin circ. 14:30 16:00 1.50 16,094 16,565 COMPZ RPEQPI WASH P Continue to Clean out f/ 16,094' t/ 16,565'. 140k up wt w! no rot. 125k up wt and 85k w/ rot. Circ @ 6 BPM @ 2,700 psig @ 14 rpms @ 6k for ue. 16:00 17:30 1.50 16,565 16,565 COMPZ RPEQPI CIRC P Reverse Circulate 2 DP Vol. (320 BBLS) @ 6 BPM @ 250 psig w/ 240 bbl losses Burin circ. 17:30 00:00 6.50 16,565 17,507 COMPZ RPEQPI WASH P Continnue wash 5 1/2" B Lat liner from 16565' - 17507' DPM. 140k up wt w/ no rot. 115k up wt and 90k w/ rot. Circ @ 6 BPM @ 3050 psig @ 14 rpms @ 7k torque. Stop and. reverse circulate at depth of 17034' and 17507', while stripping drill string up through the annular to keep pipe moving. Fluid loss for the day = 2043 BBLS. 2/02/2010 Continue wash 5 1/2" slotted liner from 17507' - 17717' DPM.We stayed 5' off of bottom. Pump sweeps as need in order to clean hole. Close annular and pump 2 DP volumes down drill string, while working drill string up through annular. Avg pump rate @ 5-6 BPM 3300 PSI. Observed formation charged up. Allow fluid to bleed back to pits, gaining 114 BBLS. Monitor welll, Circulate bottoms up to ensure well dead. POOH Laying down 5" DP f/ 17,717' t/ 16,092'. Standby for Phase 3 Conditions, maintaining circulation and rotation. Fluid loss to formation for the da = 871 BBLS. 12,862 bbls total. 00:00 01:00 1.00 17,507 17,717 COMPZ RPEQPI WASH P Continue wash 5 1/2" B Lat liner from 17507 - 17717 DPM. 145k up wtw/ no rot. 125k up wt and 100k w/ rot. Circ @ 6 BPM @ 3260 psig @ 14 r ms 7k for ue. 01:00 02:30 1.50 17,717 17,717 COMPZ RPEQPI CIRC P Rig up, close annular, and pump down drill string at 5 BPM, 3000 PSI for 2 drill string volumes. Stop pumps. Observe formation charged u ,with 28% flow. 02:30 04:30 2.00 17,717 17,317 COMPZ RPEQPI OWFF P Blow down Top Drive. Monitor well, observing 137 bbls flowed back. Watch well until small trickle of flow, slowly pulling 4 stands, no swasbbing, but fluid did not fall and 2.5 BBLS gained. Decision to circulate bottoms u . 04:30 06:30 2.00 17,317 17,317 COMPZ RPEQPI CIRC P Circulate bottoms up @ 5 bpm - 2430 psi. Periodically work drill string to observe free movement. 06:30 07:00 0.50 17,317 17,317 COMPZ RPEQPI OWFF P BDTD and monitor well 07:00 09:00 2.00 17,317 16,092 COMPZ RPEQPI PULD P POOH laying down 5" DP f/ 17,317' t/ 16,092' Page 12 of 19 • lJ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 09:00 17:30 8.50 16,092 16,092 COMPZ RPEQPI CIRC T Field went to Phase 3 weather conditions -Screwed in TD and Circulated @ 2 bpm @ 420 psig - took 10 bbls to fill hole -maintaining 40 bbl / hr losses. 17:30 22:00 4.50 16,092 16,092 COMPZ RPEQPI CIRC T Field went to Phase 3 weather conditions -Screwed in with TD and Circulating @ 2 bpm @ 420 psig - Pumped 10 bbl tube pill @ 17:30 hrs and continue to circulate - maintaining 40 bbl / hr losses. Have 300 bbls in pits and 290 bbls on truck that is un accessable at this time. 22:00 00:00 2.00 16,092 16,092 COMPZ RPEQPI CIRC T Blow down Top drive. Begin filling hole every hour with 20 bbls and reciprocating drill string for 90' periodically. Fluid loss to formation for the day = 681 BBLS. Total Fluid Losses to formation = 12,862 BBLS 2/03/2010 Continue to standby for phase 3 conditions, filling hole every hr w/ 20 bbls and reciprocating drill string.Phase 3 lifted at 0300 HRS. Plow snow & clean rig area. RU to thaw out & unpack snow from elevators for laying down DP. Continue POOH laying down 5" DP, stopping to unload pipe shed as needed. Observed hole taking 2 x dis lacement lus 20 BBLS / HR. Fluid loss for the da = 688 BBLS. Total losses = 13617 BBLS. 00:00 06:00 6.00 16,092 16,092 COMPZ RPEQPI CIRC T Blow down Top drive. Begin filling hole every hour with 20 bbls and reciprocating drill string for 90' periodically. Went to Phase 2 @ 03:00 hrs -Waiting on rig loader to clear pad area around rig to resume operations. Continue to fill hole every hour w/ 20 bbls and reciprocate drill string for 90'. Ri .went off Phase 3 as of 06:00 hrs 06:00 06:30 0.50 16,092 16,092 COMPZ RPEQPI SFTY P Held PJSM on POOH and Laying down 5" Drill Pi e. 06:30 07:00 0.50 16,092 16,092 COMPZ RPEQPI OTHR P Fill pits. Blow down Top Drive. 07:00 08:00 1.00 16,092 15,143 COMPZ RPEQPI PULD P POOH laying down 5" DP f/ 16,092' U 15,143', double displacing the hole fill. @ 07:15 hrs employee smashed left pinky tip while releasing tongs - taken to Medic - recieved wound care and splint for finger -Employee returned to work. 08:00 11:00 3.00 15,143 15,143 COMPZ RPEQPI OTHR T Elevator on the drillers side of the rig was snow packed and had to to be thawed before off loading 5" Drill pipe from i e shed. Page 13 of 19 • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 11:00 12:00 1.00 15,143 15,143 COMPZ RPEQPI OTHR P Offload pipe shed of 5"drill pipe. 12:00 00:00 .12.00 15,143 8,893 COMPZ RPEQPI PULD P POOH laying down 5" drill pipe and ofFloading the same f/ 15,143' U 8893' -double displacing the hole fill. Total fluid loss for the day = 688 BBLS. Total for well = 13617 BBLS 2/04/2010 Slip & Cut Drilling line. Inspect & Service Top Drive. Wash down through hook hanger assembly down to MLZXP in B lat, and to 9303' DPM. Observed auger line & trough packed off while taking returns. Clean crude from shaker area and pit room. POOH lay down 5" DP .Continue thaw out kill line. Rev. Circulate 20 BBLS tube sweep, taking crude returns form DP until clean. Lay down all DC"s , 5" DP, and 4 3/4" BHA. prep rig floor for 2 7/8" DP. Rig crews held Safety Stand up meetings with management. Fluid loss for the day = 764 BBLS. Total = 13281 BBLS 00:00 02:30 2.50 8,893 8,893 COMPZ RPEQPI SLPC P Held PJSM. Discuss safety & Hazard recognition issues. Discuss procedure to slip & cut drilling line. Hand Blocks and Top Drive. RU & slip & cut 120' of drilling line. Inspect & Service to drive. 02:30 04:00 1.50 8,893 8,893 COMPZ RPEQPI RGRP T Service Top drive and change out rabber dies 04:00 04:30 0.50 8,893 -9,183 COMPZ RPEQPI WASH P Make up top drive, wash into hole through the Hook hanger @ 9094', continuing down through the MLZXP @ 9067' to 9,183'. Pump Pressure at 540 PSI - 2 BPM. Pull back throu h washin same. 04:30 06:00 1.50 9,183 9,183 COMPZ RPEQPI OTHR T The chute below the auger in the shaker room had plugged off during the blizzard and extreme cold temperatures. As oil was returned over the shakers and backed up causing an estimated 2 gal. oil spill on the snow, that was immediatly cleaned up. PIR was filed and securi was notified. 06:00 08:30 2.50 9,183 9,183 COMPZ RPEQPI WASH P Wash up f/ 9,183' U 9,088' and back down @ 2 bpm @540 psig increasing pump rate to 4 bpm @ 880 psig. Locate the top of the MLZXP 9,167'. 08:30 10:00 1.50 9,183 9,303 COMPZ RPEQPI WASH P Make connection and began to wash f/ 9,183' to 9,303', circulating @ 3 bpm @ 1,100 psig, returning oil. Stop operation to send oil returns to kill tank -found reverse line had an ice blocks e. 10:00 12:00 2.00 9,303 9,303 COMPZ RPEQPI WASH T Offload 5" DP and Load Completion quipment into pipe shed while thawin -out line. 12:00 14:30 2.50 9,303 9,303 COMPZ RPEQPI CIRC P Reverse circulate 20 bbl Lube PiII @ 6 bpm @ 150 psig ICP with minimal to no returns. 250 psig FCP. Recovered 128 bbls in kill tank during reverse o erations. 14:30 15:00 0.50 9,303 9,303 COMPZ RPEQPI OTHR P Blow down Top drive, hard line and kill line. Page 14 of 19 • Time Lo s Date - .From To _ Dur S. De th E. De th Phase Code Subcode T Comment 15:00 16:00 1.00 9,303 9,847 COMPZ RPEQPI TRIP P RIH w/ remaining 2 stds of drill pipe from derrick and 4 stds ush i e. 16:00 19:00_ 3.00 9,847 8,900 COMPZ RPEQPI PULD P POOH laying down Push pipe and 5" DP 19:00 19:30 0.50 8,900 8,900 COMPZ RPEQPI SFTY P Crew Change out. Pre-Tour Meeting afrer Safte Stand u at KOC. 19:30 20:30 1.00 8,900 8,900 COMPZ RPEQPI RGRP P Observed break in Breakout Line. Change out same installing new one. Pull test same on the stum . 20:30 21:30 1.00 8,900 8,856 COMPZ RPEQPI PULD P Lay down pump out sub, fishing jars, LBS, X-O, X-O, X-O 21:30 00:00 2.50 8,856 8,856 COMPZ RPEQPI RURD P Change over to 2 7/8 equipment. Clear rig floor of 5" DP equipment. Unload shed. Begin POOH with 2 7/8" DP. Fluid loss for the day = 764 BBLS. Total = 13281 BBLS 2/05/2010 Held PJSM. POOH Lay down 2 7/8" DP & Mule shoe. ND & install shooting flange. RU HES wireline crew. MU Tools WLIH to 1400', observed short in cable head. WLOH repair same. MU Tools WLIH. Fluid loss for toda = 401 BBLS. Total for well) = 13482 BBLS 00:00 00:30 0.50 8,856 8,856 COMPZ RPEQPI SFTY P Held PJSM with crew. Discuss safety & Hazard recognition issues. Discuss la in down 2 7/8" DP. 00:30 06:00 5.50 8,856 4,746 COMPZ RPEQPI PULD P POOH lay down DP f/ 8,856' t/ 4,746' installing thread protectors and unloadin shed when needed. 06:00 12:00 6.00 4,746 0 COMPZ RPEQPI PULD P Continue to POOH lay down DP f/ 4,746' installing thread protectors and unloadin shed when needed. 12:00 14:00 2.00 0 0 COMPZ RPEQPI OTHR P RD and offload 5" and 2 7/8" Rental e ui ment 14:00 17:00 3.00 0 0 COMPZ RPEQPI ELOG P ND flow riser and NU 13 5/8 5m x 7" Otis shootin flan e. 17:00 17:30 0.50 0 0 COMPZ RPEQPI SFTY P Held PJSM with crew, HES reps. Discuss safety & hazard recogniiton issues. Discuss RU & Run wireline tali er assembl . 17:30 19:00 1.50 0 0 COMPZ RPEQPI ELOG P Pull sheaves and tools to rig floor. MU tools. Function test same. MU Lubricator on shootin flan e. 19:00 20:00 1.00 0 0 COMPZ RPEQPI ELOG P WLIH to 1400' WLM. Observed "short" in assembly. Trouble shoot same. Fillin hole with 20 BBLS / HR 20:00 23:30 3.50 0 0 COMPZ RPEQPI ELOG T WLOH. Breakout and lay down assembly. Inspect & repair cable head. Observed short in the cable head. MU tools, function test assembly. OK at surface. MU Lubricator on shooting flange. Filling hole with 20 BBLS / HR 23:30 00:00 0.50 0 0 COMPZ RPEQPI ELOG T WLIH with second run to 1400'. Observed repeat in short. Filling hole with 20 BBLS / HR Fluid loss for today = 401 BBLS. Total for well = 13482 BBLS Page 15 of 19 • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 2/06/2010 24 hr summary Continue WLIH to 1400' WLM, and observed repeat failure in cable head. WLOH. Trouble shoot & repair cable head. WLIH to 1400', observed repeat short in line. WLOH. Repair smae. MU tools, WLIH to 2400' WLM, Observed surge in unit generator, causing anothe short in the system. After troubleshooting, fated to regain sufficient power. RD HES wireline crew and shooting flange. RU & test BOP's. Witness of test waived by AOGCC rep John Crisp. Note: While ND shooting flange, dropped a cotton glove down the hole. Fishing will commence after BOP test. Fluid loss for the da = 405 BBLS, total for well = 13887 BBLS 00:00 00:30 0.50 0 0 COMPZ RPEQPI ELOG T WLOH with assembly to surface. Filliin hole with 20 BBLS / HR 00:30 03:00 2.50 0 0 COMPZ RPEQPI ELOG T Troubleshoot cable head verify short. Repar cable head. MU tool string with Caliper assembly. Function test same on ri floor. OK 03:00 04:00 1.00 0 0 COMPZ RPEQPI ELOG T WLIH to 1400'. All is good again. 04:00 05:30 1.50 0 0 COMPZ RPEQPI ELOG T Power up Tractor, experiencing power surges, short at surface. Trouble shoot down to slip ring assembly on drum. Repaired. Re-established communication with tools down hole @ 2450'. Ex eriencin same ower sur es. 05:30 09:00 3.50 0 0 COMPZ RPEQPI ELOG T Ordered out new power supply from Deadhorse. 09:00 11:00 2.00 0 0 COMPZ RPEQPI ELOG T Same problems with new power supply. Replace Umbellical cable from power supply to wire line, this did not remed the roblem. 11:00 14:00 3.00 0 0 COMPZ RPEQPI ELOG T POOH from +/- 2500'. RD e-line e ui ment. 14:00 17:00 3.00 0 0 COMPZ RPEQPI NUND P ND 13 5/8" x 7" 5M Otis Shooting flange. NU Flow Riser. While nippling down flange, accidently dropped orange cotton glove down hole. Continued to NU flow riser and will attempt to circulate glove out after BOPE test. 17:00 22:00 5.00 0 0 COMPZ RPEQPI BOPE P Funtion test and PT ROPE and choke manifold to 250/2500 psi. Test all floor valves. Perform Koomey test with the first 200 PSI gained in 22 secs, with full 3000 PSI in 1 min 57 secs. 22:00 00:00 2.00 0 0 COMPZ RPEQPI RURD P RD test equipment. reposition completion equipment in the pipe shed. Install wear bushing. RILDS. Pull fishing tools to rig floor. Fluid loss for the day = 405 BBLS, total for well = 13887 BBLS 2/07/2010 Continue RU to run 3 112" TBG. MU Crankshaft Rope Spear assy with drain sub. TIH picking up 31/2" tbg from shed to 1400' MD, Took weight. POOH, check spear, no fish. MU Reverse basket assmy. TIH to 3214'. Calculated top with volume added. POOH, breakout & lay down reverse basket with recovered fish. Clean floor MU Weatherford A-well gauge, observed fault when tested. Troubleshoot ESP completion RU to run area . . . same. Call for Schlumberger Phoenix gauges with backup. Weatherford rep inspected and repaired gauge. Decision to run Weatherford. Fluid loss for the da =448 BBLS. Total for well = 14120 BBLS. 00:00 01:00 1.00 0 0 COMPZ RPEQPI RURD P Continue rig up floor & equipment to run 3 1/2" TBG. Page 16 of 19 Time Lo s .Date From To Dur S. De th E. De th Phase Code Subcode T Comment d BOT 01:00 01:30 0.50 0 0 COMPZ RPEQPI SFTY P Held PJSM with crew an fishing rep. Discuss safety & hazard recognition issues. Discuss procedure to MU Rope spear assmy, and pick up tubing from the pipe shed. ear S ft R 01:30 02:00 0.50 0 18 COMPZ RPEQPI PULD T ope p Make up Cranksha assembly with drain sub crossed over to 3 1/2" 8rnd EUE. 02:00 03:30 1.50 18 1,410 COMPZ RPEQPI TRIP T TIH picking up 3 1/2" 8rnd EUE tubing to 1410". Calculated hole fill since glove dropped at 177 BBLS = 2335'. Planned depth. Observed takin wei ht at 1410' 03:30 05:30 2.00 1,410 0 COMPZ RPEQPI TRIP T POOH racking back 14 stands of 3 1/2" tbg from 1410'. Inspect rope spear for fish (empty). Broke down ro e s ear and LD. 05:30 10:30 5.00 0 3,116 COMPZ RPEQPI TRIP T Clean rig floor and tools. PU Reverse Circulating Junk basket w/8 1/2' shoe MU and RIH on 3 1/2" 8rd EUE tubin to 3116'. 10:30 11:30 1.00 3,116 3,116 COMPZ RPEQPI RURD T Change Saver Sub on Top Drive from 5" to 3 1 /2". 11:30 12:00 0.50 3,116 3,214 COMPZ RPEQPI FISH T MU 3 1/2" drillpipe, Washdown 4 BPM w/210 psi to 3214'. No returns until we washed down to 3214'. 12:00 14:30 2.50 3,214 0 COMPZ RPEQPI TRIP T POOH laying down 3 jts of 3 1/2" drillpipe, standing back 98 jts of 3 1/2" tubin . 14:30 17:00 2.50 0 0 COMPZ RPEQPI NUND T Broke down reverse basket and cleaned out. Recovered one "Orange Pinch Point Glove". LD fishing tools and break down load out. Clean rig floor and RU running equipment for ESP corn letion run. well d A f h 17:00 18:30 1.50 0 0 COMPZ RPEQPI RCST P or - er .Install & test Weat gauge. Observed fault. repeat test. Intermittent faults. Remove for ins ection. ineer on next Ri 18:30 00:00 5.50 0 0 COMPZ RPEQP I EQRP T g eng Discussion with step. Called for Sclumberger Phoenix gauge and back up. Obtain test box from Milne Point Centrilift. During standby, Weatherford repaired cracked insulator on A-Well gauge, function tested same.Good test. Decision to run Weatherford A-well gauge. Held Safety Meeting on Hand Awareness with ri crew. 2/08!2010 MU ESP Completion assembly with Y-Block.. Continue RIH with 31/2" Completion string installing 224 jnts as per plan. Megger & communication tests line very 1000'. Install hanger and landing joint. MU penetrator and tail. RU, and begin ESP cable splice as per Centrilift reps. Fluid loss for the day = 344 BBLS. Total Losses for well = 14464 BBLS Page 17 of 19 • 'T'ime Lo s -Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 06:00 6.00 0 0 COMPZ RPEQPI PULD P Make up ESP completion with Weatherford A-well gauge and Y-Block with 2 7/8" spacer pipe assembly as per Centrilift and Weatherford reps. Observed sheared thread on pump installation. Had to to out the bolt holes. 06:00 10:00 4.00 0 COMPZ RPCOM RCST P Continued making up pump, motor and seal section and servicing. Connected A-well Sensor. Ran cable over sheave, connected motor lead and tested same. Continue in hole and MU Unique discharge pressure sub, retest, ok. 10:00 15:00 5.00 0 3,247 COMPZ RPCOM RCST P MU CMU sliding sleeve (closed), MU 2.813"'DS Nipple, start running in hole on tubing from derrick, performing electrical inspection/tests on ESP power cable every 1000', insatlling Cannon crosscoupling clamps on 1st 6 connections and eve other one thereafter. 15:00 22:30 7.50 3,247 7,300 COMPZ RPCOM RCST P Continue RIH with ESP completion PU 3 1/2' tubing from pipe shed, performing electrical inspection/tests on ESP power cable every 1000', insatlling Cannon crosscoupling clamps on 1st 6 connections and everyother one thereafter. Fill hole eve hour with 20 BBLS. 22:30 00:00 1.50 7,300 7,300 COMPZ RPCOM RCST P Make up Vetco Gray hanger with 3 1/2" x 4 1/2" crossover to tubing string. Make up landing joint. Position hanger at floor. UP WT = 80K, SO WT = 55K. Measure ESP cable. RU and perform ESP cable splice as per Centrilift reps. Fluid loss for the day =344 BBLS. Total losses for the well = 14464 BBLS 2/09/2010 Continue Splice ESP cable. Land tubing hanger. RILDS. ND BOP's. NU Tree. Freeze protect Well. Secure Cellar. 00:00 03:30 3.50 7,300 7,300 COMPZ RPCOM RCST P Continue Splice ESP cable as per Centrilift reps. Inspect & perform electrical inspection/tests on ESP power cable. Fill hole with 20 BBLS eve hour. 03:30 04:30 1.00 7,341 7,341 COMPZ RPCOM RCST P Ensure stack drained. Land Tubing hanger. UP WT = 80K, SO WT = 55K. RILDS, Back out & lay down landing joint. Install two- way check as er Vetco Gra re . 04:30 12:00 7.50 0 0 COMPZ RPCOM NUND T ND riser, attempt to change out element in annularprreventor could not get top ring off. Broke threads loose and abandoned task. Will chap a out element in DTH later. Page 18 of 19 • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 12:00 13:30 1.50 0 COMPZ RPCOM NUND P Continue on with ND of BOP stack, choke & Kill Lines. Cleanin its. 13:30 14:30 1.00 COMPZ RPCOM NUND P NU tubing head adapter and.tree. PT the tree and hanger void/packoff to 5000 psi. Check the ESP cable/motor electrical integrity and record phase-to-phase and phase-to ground resistivity for all three phases at the hanger penetrator. Pressure sensor readings also good. Pressure test tree to 5000 si. 14:30 16:00 1.50 COMPZ WELCTL OTHR P RU lubricator, pulled two-way check. 16:00 19:30 3.50 COMPZ RPCOM FRZP P RU Little Red Hot Oil. Pumped 30 bbls of Diesel down the Tubing at 1.0 bpm/1,300 psi. Pumped 200 bbls of Diesel down the IA at 2.0 bpm/400 si. Ri down Little Red. 19:30 21:00 1.50 COMPZ RPCOM OTHR P Monitor WHP at 175 psi. Pick up Lubricator and install BPV. Lay down Lubricator. 21:00 00:00 3.00 COMPZ RPCOM OTHR P Clean Pits. Secure Cellar. Final pressures, Tbg = 175 psi, IA = 25 psi, OA = 400 psi. Prep to Move off Well Slot. Released Nordic Rig 3 at 24:00 hrs, 02/09/2010. Page 19 of 19 ~ ~~ Page 1 of 1 Schwartz, Guy L (DOA) _ ~(~ ~~' "~7-. ~3 ~ From: NSK Prod Engr Specialist [n1139@conocophillips.com] Sent: Monday, October 19, 2009 3:24 PM To: Schwartz, Guy L (DOA) Cc: CPF1 Prod Engr Subject; 1.~-135 Guy- in response toyouur question regarding the summary sheet information on this we{I; TESTED TBG @ 6226',2503',2411',1006' 8~ 509' SLM. ***FAILED***. LOST FLUID RAPIDLY Ei 10/05/09 UNSEATING HOLEFINDER . TBG NOT NOLDING FLUID. IN PROGRESS. To summarize: The ESP was pulted and an Gt~ was set 2453` RK$. Inatia! at#empts to britag the wela or~ witl~ gas lift were unsuccessful so troubleshooting efforts were undertaken. The Wells Group was unable to set the hole finder tool after several attempts and the process was stopped. The Slickline Wells Group Supervisor attributed the unsuccessful hole finder troubleshooting attempts to the high angle o# tl~e weAbore. A fluid level was obtained on 10/7/09. The well was placed on lift gas again a after 2 days it unloaded and is now operating properly. The well was retamed ta servi~ 1 Q/8>(79 10-0~-09 TBG & IA FL. T/I/O = 30/450/419. Well is shut in. TBG FL @ 888 ft(600 fps). IA FL @ 3986 ft. Ho~e tl~is answers your c}uestions. 8ob Christensen / Darrell Humphrey ConocoPhillips Alaska, Inc. Production Engineering Specialist C?ffice (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) ~,~~~~ N ~ ~ ~ ~ 20~~ 10120120fl9 ' • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug PeAorations ~ Stimulate ~ Other ~ Failed ESP to Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Time Extension ^ Gasiift Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter S spended Well ^ 2. Operator Name: 4. Current Well Status: Permit to Drill Number: ConocoPhillips Aiaska, InC. Development ^~ Exploratory ^ 207-039 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23349-60 KB Elevation (ft): ~Well Name and Number: RKB 123' 1J-135L1 8. Property De ' nation: 10. Field/Pool(s): ADL 25662, 380058 Kuparuk River Field/West Sak Oil Pool 11. Present Well Condition Summary: ~ Total Depth measured 17935' feet true vertical ~ 3420' feet Plugs (measured) Effective Depth measured 17921' feet Junk (measured) true vertical 3420' feet Casing Length Size MD ND Burst Collapse CONDUCTOR 80' 20" ~2~' 121' SURFACE 3421' 13-3/8" 3462' 2215' INTERMEDIATE 9778' 9-5/8" 9819' 3604' D SLOTTED LINE 3576' 4-1/2" 17923' 3420' Perforation depth: Measured depth: 9375'-12949'; 12951'-17878' true vertical depth: 3549'-3495 ; 3495'-3420' Tubing (size, grade, and measured depth) 4-1/2", L-80, 7548' MD. Packers & SSSV (type & measured depth) D sand Baker ECP 9218' None 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 410 221 38 207 412 Subsequent to operation 396 238 43 894 230 14. Attachments Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 6. Well Status after proposed work: Oii^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. exempt: N/A contact B. Christensen/ D. Humphrey Printed Name ob D. hr' tensen Title Production Engineering Specialist Signature -A-_ Phone:659-7535 Date Av ~~ ~ F ,~ - - - v.. • `~'` ~ P~1J?~1`~ i~ ~ ~ !v~ ~L ' ~9 Form 10-404 Revised 04/2004 Submit Original Only • . 1J-135L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/27/09 09/28/09 10/04/09 10/05/09 PULLED 45.7' ESP FROM DEPLOYMENT SUB, LAY ON GROUND FOR CENTRALIFT,GAUGE TBG TO 3.80" STALLED OUT @ 3200' SLM DUE TO DEVIATION, ATTEMPT TO PULL STA# 1@ 2472' RKB, IN PROGRESS. PULLED 1"SOV( VALVE HAD SEVERE FLOW CUT HOLE IN SIDE OF IT) @ 2453' RKB, SET NEW GLV @ 2453' RKB, COMPLETE. ATTEMPT TO TEST TBG @ 2500' SLM. PULLED GLV @ 2453' RKB. SANDS IN NOSE CONE & MINOR FLOW CUT BELOW LOWER PACKING. SET EXT PACKING DMY @ 2453' RKB. IN PROGRESS. TESTED TBG @ 6226',2503',2411',1006' & 509' SLM. ***FAILED***. LOST FLUID RAPIDLY EACH TIME AFTER UNSEATING HOLEFINDER . TBG NOT HOLDING FLUID. IN PROGRESS. J Cor~ocoPhilli ~ Ak~v-.a.l~ I/ NaIICOnRU:MUITIPIEUTERAIS-1J-135Lt iJ~1J200935]26i Schematie - PcNal HANGER, 18---~- '~'~ CONDUCTOR, I 44-172 ESP MANOREL, 2,453 SURFACE, 94-3,463 ESP MANDREL, I,362 DISCHARGE, ~,eio XOINTAKE, . KUP all AttNbut es IDoraAPl/UWI 50029233496 FIeldName 0 WESTSAK ment iV: NONE H YS (ppm) 0 Date 12126/2007 o~atlon d Tag: DepN (ftKB) Entl ~a0e Mnohtlon Rev Reason: ~ain Strin s ~~a oes~r!pnoo 'VGER D-SAND Slring O._ 6.03 Slring ID ... 4.950 Top ((tNB) 9,093.7 ~~a oes~~~Pno~ INER String 0... 5 S[dnp ID ._ 4.000 Top (HNB) 9,308.8 ier Details rop oepm (TVD) ToPlncl Incl 1J-135L1 Incl (°) MO (ttl(e) Pct Btm (ftNB) 93.65 13,201.90 17,935.0 ale KBl'irA (fl) Rig Release Data 4/9I2008 44.00 5~23/2007 Lasl MoC ... EnE ~ate Imos bor 10l10/2009 ~m jrvo~ ... so-~~9 we_. st.~~a ... seri~a roP rnm ,548.7 15.50 L-80 BTC-mod am ~rvo~ ... so-m9 wt... stri~a ... so-~~g rop rnm .420.2 11.60 L-80 BTC Run ITOO IftK81 IBtm IttNBI l T(RK ~o) I etIRK ~o) I Zone I Date I ~ ~~s I Tvoa I Comment I icial rows/ft, 3" centers, 18 deg. .125" wide, 4 icial rows/R, 3" centers, 18 dep. Valw ~ LaOC~ ~ Size ~TRO Run SLOTS, 9,37512.9a9 SLOTS, 12.~1-1],B]B SHOE, 77,927 D LINER, 9,309-17 923 TDI1J-135L1). _~ 17 935 Insulated Conduaor, 20" 9M~ KSS x 34" 0.3~2 VJT */- 80' ~ Wellhead / Tubing I Tree: 133/8" x 41/2", 5,000 psi ConocoPhi I I i ps West Sak Hybrid Producer ,o ~~~~ Casing, 73.~, ~.~o, 1 J-135 BTCM ~ 1533' MD Dual Lateral Completion 2194' MD~ GLM, Camco, ht/2" x 1" KBMG, ~870' ND (66 day) ~ S / Completed 13-3/8" Casing Shoe, 68#, L-80, BTC set ~ 3462' MD, 2213' ND 7548' MD -Bottom of Motor Centnlizer Centralift 418 HP KMHFER with FC6000 Pump Tubing String 41/7' 12.60, L-80, IBT-M 3.958" ID, 3.890" Drift D-sand Window at 9097' MD (80 deg) ~D' Sand Lateral avz° ~~.cte, Hydrii aod src, L-BO Slotted and Blank Liner 9218' MD - 5-112" Baker ECP 41/2" Eeeentrie ~ Guide Shoe 9093' MD - 7" x 9-5/8" Model B HOOK Hanger 9188' MD - 7" X 9S/8" MLZXP Liner Top Paekar with integrated RS profik and Fle~dock slips ~ aapa. Huynu ~om. mma ao<~~m m+r ~a n..w~~+=b o~ a„n~em.a. ~n wnw. or m wn. in a~r rorm oi ny anr mnns decvonic w mecnanicai, inuuai~q pholowpyl~p, recordinp, or Ey any infomwtpn atonps aM rNnevd sy~tam rww Mown or M1xaaflar inhrRaE, witM1O~rt vwiM~n permission hom BaWr Hup~n Inc MKYG i[s Baker Oil Tools E~uinment Soecifications 7"" X 9~/8" HOOK Hanger Mainboro Drik: 7.00" Mainbon Drift, with div~rt~r. 6.26" Labral Drift, no diwrtor or LEM: 6.16" Labral DrifS, w/ diwMr. no LEM: 6.13•• LatanllMainbon Diwrtar OD: 8.60" 4-1/2" Casing Shoe, 11.6#, L-80 BTCM sssrMO-soecomoravz^be~c~o~~e Set@ 17923' MD, 3420' TVD 9308' MD - 7" Tieback Sleeve 9195'MD-CasingSealbore 'B' Sand Lateral ReeepWek 4.75" ID f S7/2" 15.5 Y, Hydril and BTC, L~0 Slotted and Blank Liner 5-1/2" Eccentric ~ Guide Shoe _'_ ~ '-_ '~~ 5-1/2" Casing Shoe, 15.5 #, L-80 BTCM 9-5/8" Casing Shoe, Set @ 17722' MD, 3512' ND 40.0#, L-80 BTC @ 9819' MD, 3604' ND (90 deg inc) ~n..: a.. • • u' ~ ~' DATA SUBMITTAL COMPLIANCE REPORT 6/2/2009 Permit to Drill 2070390 Well Name/No. KUPARUK RIV U WSAK 1J-135L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23349-60-00 MD 17935 TVD 3420 Completion Date 5/22/2007 Completion. Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION ~--,,~, Mud Log No Sampies No Directional Survey ( Ye~ DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~D D Asc Directional Survey 10734 17904 Open 8/2/2007 ~~ D Asc Directional Survey 9086 11190 Open 8/2/2007 PB 1 D C Lis 15312 Gamma Ray 3438 17935 Open 8!3/2007 LIS Veri, GR, ROP, FET w/Graphics pt 15312 LIS Verification 3438 .17935 Open 8/3/2007 LIS Veri, GR, ROP, FET ~ C Lis 15313 Gamma Ray 3438 11190 Open 8/3/2007 PB1 LIS Veri, GR, ROP, FET w/Graphics pt 15313 LIS Verification 3438 11190 Open 8/3/2007 PB1 LIS Veri, GR, ROP, FET D C 18061 See Notes 0 0 5/21/2009 EWR logs in PDS, EMF and CGM graphics C 18062 See Notes 0 0 5/21/2009 P61 EWR logs in PDS, EMF and CGM graphics G o Induction/Resistivity 2 Col 121 3420 C,~ae~ 5/21/2009 TVD EWR, DGR d og InductionlResistivity 2 Col 121 11190 asEe 5/21/2009 MD ROP, EWR, DGR Induction/Resistivity 2 Col 121 3497 c~, 5/21!2009 P61 TVD EWR, DGR og Induction/Resistivity 2 Col 121 17935 pefse 5/21/2009 P61 MD ROP, EWR, DGR Well Cores/Samples Information: Interval Name Start Stop Sample Set Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 6/2/2009 Permit to Drill 2070390 Well Name/No. KUPARUK RIV U WSAK 1J-135L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23349-60-00 MD 17935 TVD 3420 Completion Date 5/22/2007 Completion Status 1-OIL Current Status 1-OIL UIC N ADDITIONAL INFORMATION Well Cored? Y(/ Itl, Chips Received? ~-`F-,F-PJ-` Analysis ~-hN-- Received? Daily History Received? '~~"' Formation Tops Y / N Comments: Compliance Reviewed By: ___..______. Date: _ ~- ~ ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-135+L1+L1PB1 May 7, 2009 AK-MW-4957664 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling, Arctic Blvd., Anchorage, AK 99518 1J-135+L1+L1PB1 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23 349-00,60,70 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23 349-00,60,70 Digital Log Images 2 CD Rom 50-029-23349-00,60,70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 BCvSn:B haliiburton.com .---_..~ Date: SAY 2 ~ LUu`' :~. BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: ~0~,o3~s /$O~C) ~o'~- _ O39 ~ ~b~a Ktt.:ClV~I~ i STATE OF ALASKA MAY 1 3 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION q~aska Dil & Gas Cons. Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage t. Operations Pertormed: Abandon ^ Repair Well ^~ Plug Pertorations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing Q Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhilllps Alaska, InC. Development ~ Exploratory ^ 207-039 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23349-60 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 41' ~ 1 J-135L1 8. Property Designation: 10. Field/Pool(s): ADL 25662; 380058 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 17935' ~ feet true vertical 3420' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 121' 121' SURFACE 3421' 13-3/8" 3462' 2215' INTERMEDIATE 9778' 9-5/8" 9819' 3546' D-SAND SLOTTE 8615' S-1/2" 17923' 3420' Perforation depth: Measured depth: 9375'-12949', 12951'-17878' true vertical depth: 3549'-3495', 3495'-3420' Tubing (size, grade, and measured depth) tubing in main wellbore, , MD. Packers &SSSV (type & measured depth) D-sand Baker ECP pkr @ 9218' no SSSV 12. Stimulation or cement squeeze summary: ~F ~~~y ~ ~ ~~~& I~ Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 968 411 52 -- 251 Subsequent to operation 518 131 157 -- 225 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oi10 Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-109 contact Brett Packer Printed Name Brett Packer Title Wells Group Engineer -/ Signature ~ Phone: 265-6845 S ~Z/~ ~ Date Pre aced b Karon Allsu -Drake 263-4612 ~'~' s~~ r''~ Form 10-404 Revised 04/2006 ~ "~ (", ~~'2r~ Submit ~;?ngin On ~~`\ }} ConacoPhittip~ ,etas ~r~c. ~1 SEALS (7514-7528, OD:5.13Q) M110TOR 17s2s•7ss2, OD:5.82f7j ;~s~ ~~>_. I~ i ~KRU 1J-135L1 '!1J_i35L1 API ;500292334960 Well T e: PROu An le a TS: ; de w SSSV T e: ;NONE Ori Com letion: 5/23/2007 An le TD: 90 d 17935 Annular Fluid: ; Last W/O: 4/9!2008 Rev Reason:.; ESP WORKOVER . ....... _Reference_Loq_41.4' RKB .............__. ..._..._.__ .__._Ref_Log Date..._ .........__..__---..__........._._..._ ..-._..___ .._Last Update __4/14/2008......_._..._...---__... Last Ta TD: ; 17935 ftKB ;._ Last Tag Date__ -. Max Hole Angle:: 94 dec7 CeW 13202 ', Casing Strrng -ALL STRINGS { D escriptwn maize 10 _ P t3ottom __ . _ f VD _..... Wt grade Thread _ _..._ __ _._... ---- _ - _ CONDUCTOR ..... _.. _ .. 20.000 0 _... . 118 118 94.00 H-40 WELDED __ SURFACE 13.375 0 $462 - 2215 68.00 L-80 BTC INTERMEDIATE 9.625 0 9819 3546 40.00 L-80 BTCM D-SAND SLOTTED LINER 5.500 9308 17923 3420 15.50 L-80 BTCM Tubing Strinc~TUBING _ Size fop _ - Bottom ~ __ TVD _ Nlt ~ Grade thread ~ 4.500 '- 0 - _ 7548 _ 3258 - Ie'f~1 2.60 '_L 80 _ Perforations 5ummar~ Interval TVD : _ Lone atus St ' Ft .SPF Date..._.._._ ..._f.YPe _.._......._......__Comment.....__.._.._........._...._ _ ....._............_ .__.... 9375 -12949 3549 -3495 .. _ - _ ..._.._ INS D _. 3574 ... 32 ........_ 5/i 7%2007 SLOTS 2.5" Long x .125" wide, 4 circumferencial rawstft, 3" centers sta ered 18 d 12951 -17878 3495 -3420 WS D 4927 32 5/17/2007 SLOTS 2.5" long x .125" wide, 4 circumferencial rows/ft, 3" - _ ___- centers. staggered, 18 deg. ''Gas Lift MandrelslValves St ; MU TVD Man rttr Man Type V Mir V t ype V OU Latch Port TRO ; Uate Kun Vlv } Cmnt 1 ~2472 960 ~ 1 1 CAMCO KBMG CAMCO ~ SOV ~.0 ~ ~._.. _ ~_ .... B~ 0_~ ~ ~ ~.... 4 R8_ ~_..........__....._...~ _ _ II 1 7380 I1 .... . 3._19 _ ... -- jCAMC01 ._.. ... ...._-_ -- KBMG CAMC . ff ....._ - DM _- .__. ......._ 0 ._ _ . ~ B 0 0 1 2~ Otherlugs; etc u~ etc.~_- COMPLETION _Depth_._. ..._T VU_... .........__TYpe._._._._~ --___..._......__...._....._ ................_Uescriptbn_._.._.._...... __ _ __ IU 36 36 HANGER VETCO GRAY TUBING HANGER 4.500 7428 _ 3230 Discharge __ _ _____ _ UNIQUE DISCHARGE SUB 3:950 Sub 7504 3248 XO Intake PERFORATED CROSSOVER INTAKE TTC ESPCP 0.000 7514 3250 SEALS UPPER/LOWER TANDEM SEAL GS83D8 FER HL SSCV H6 SB/SB PFSA 0.000 ODEL B 1' HOOK HANGER QNSIDE CSG)_ } 9097 ~ 3528 ~ VD ~AND ~ D-SAND WINDOW 0 00 ' - Other ' iu s, e~uip_, etc: . j - D-SAND LINER DETAIL __ Depth_ TVD Type- _ Descri_pt;!on _._-. _.. _-- .. iU___._. 9115 3531 HANGER (OUTSID E__CSG)_ _ D-SAND BAKER'B-1' HOOK HANGER - 3.688 - ____ 9218 3542 PACKER __ _ _ D-SAND BAKER PAYZONE ECP ~ 4.920 9278 3546 XO _ _ _ ___ D-SAND CROSSOVER 5.5 x 4.5" 4.500 9309 3548 SLEEVE D-SAND BAKER'HR' LINER SETTING SLEEVE 5.750 9352 3549 SHOE D-SAND MULE SHOE 3.958 9369 3549 XO D-SAND CROSSOVER 5.5" x 4.5" 3.940 17921 - 3420 SHOE D-SAND ROT SILVER BULLET GUIDE SHOE (NO FLOATI ___ 3.940 Ge~erai Note s __ _ _ Date _ 'Note 5/23120071 NOTE: MULTI-LATERAL WELL -1J-135 (B-5AND1. 1J-135L1 (D-SAND) ITERMEDIATE {0-9819, OD:9.625, W t:50.00) • • Cono~oPhillips Time Log Summary WelNlew Web ReFO+7Mg - --~ Well Name: 1 J-135 Job Type: RECOMPLETION Time Logs _ _ Date From To Dur S. De th E. De th Phase Code Subcode T COM 03/18/2008 00:00 08:00 8.00 COMPZ MOVE MOB _ P Move from 3M Pad to 1J Pad @ 3M x 3A intersection as of 04:30 hrs and 1 O Pad as of 08:00 hrs. 08:00 11:00 3.00 COMPZ MOVE WOCC NP Wait on ConocoPhillips Field crew chan e. 11:00 17:00 6.00 COMPZ MOVE MOB P Continue to move Rig Nordic 3 from 3M Pad to 1J Pad. 17:00 18:00 1.00 COMPZ MOVE PSIT P Move in and spot over well. Accept Nordic 3 ri 18:00 hrs. 18:00 23:30 5.50 COMPZ RPCO OTHR P Set down and install handi berm. RU Hardllines from cellar to well head and to tiger tank. Load lubricator and warm u. 23:30 00:00 0.50 COMPZ RPCOh OTHR P Lubricate out BPV and lay down lubricator. 0 Psi tbg, 850 psi IA, 400 si OA. 03/19/2008 00:00 01:30 1.50 COMPZ RPCO SFEQ P Blow thru lines and PT @ 1,000 psi, Pump hot fluid thru lines to thaw out artiall blocked lines. 01:30 03:30 2.00 COMPZ RPCO OTHR P Bleed off gas head on IA 850 psi initial ressure and bled down to 260 si. 03:30 04:00 0.50 COMPZ RPCOh CIRC P Bleed IA down from 260 psi to 180 psi. While pumping 50 bbls 6% sea water @ 2 bpm @ 0 psi down tbg to verify no blocka e. 04:00 09:00 5.00 COMPZ RPCOA CIRC P Reverse circulate @ 2 bpm w/ 170 psi ICP. No returns /press to tbg. Cont pump 425 bbls total do IA. No returns / press to tbg at any time. FCP 340 si. 09:00 10:00 1.00 COMPZ WELCT OWFF P Monitor well. IA build to 360 psi. Tbg "0" psi. Attempt bleed IA 30 min to 350 psi and stable. Will not bleed. Crude /sludge /gas returns. No chan a to tb while bleed. 10:00 18:30 8.50 COMPZ WELCT KLWL P PJSM, Plumb lines /test 2500 psi for pump do tbg. Commence well kill do tbg (KOBE knock out confirmed open) to kill tank. Hold 280 psi backpressure on choke, ICP 50 psi on tbg. Linear decrease at IA while kill surface to surface. Open choke. 0 psi tbg / IA. Large quantities crude /sludge /gas during kill. Plumb returns to rig pits, circ well clean. 3bpm / 400 psi. Condition fluids. 1~~~ 1 of 14 • Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 03/24/2008 05:00 07:30 2.50 8,394 7,169 COMPZ RPCOh TRIP T Pooh w! Test packer and RBP. PKR han u at 7169 ft. 07:30 08:30 1.00 7,169 7,169 COMPZ RPCOh TRIP T No upward movement possible at 7169 ft. Continued up / do movement. Work free. Re-ci 60 ft strokes, confirm free. 08:30 14:00 5.50 7,169 25 COMPZ RPCOh TRIP T Resume POH 3-1/2 Dp to PKR assy. Attempt test set RBP at 6500 ft. No test, will not set. Flow check. Resume POH. 14:00 15:00 1.00 25 0 COMPZ RPCO PULD T Inspect RBP /test PKR. Slight scarring at retainer ring RBP. No sanding at internals. LD PKR BHA, clear floor. Fill hole. 68 bbls. Flow check. Static losses 20-25 b h. 15:00 18:00 3.00 0 0 COMPZ RPCO WOEQ T WO arrival addtnl clean out tools. 18:00 18:30 0.50 0 COMPZ FISH OTHR T Bring toots to rig floor, warm and stra . 18:30 19:30 1.00 0 COMPZ RPCOh CIRC T Fill hole, Took 140 bbls to fill. 19:30 21:30 2.00 0 382 COMPZ RPCO PULD T Pu BHA #3 and Rih w/ 8.5" od Globe Basket, X-O, X-O, LBS, Fishing Jars, 11 - 4.75" OD DC's 21:30 00:00 2.50 382 3,281 COMPZ RPCO TRIP T Rih w/ DP from 382' t/3,281' 80 up wt. and 60 do wt. 03/25/2008 00:00 03:00 3.00 3,281 7,140 COMPZ RPCOh TRIP T Continue to Rih w/ C/O assy BHA# 3 f/ 3,281' to 7,140' 03:00 05:30 2.50 7,140 7,140 COMPZ FISH CIRC T Mix and Pump 82 bbl High visc pill to attempt in fluid losses and cleared DP w/ 53 bbls. ICP @2 bpm @ 125 psi. FCP @ 2 bpm @ 240 psi. Monitor well. DP on vacuum. Fill annulus w/40 bbls. Attempt to circulate. No returns. 05:30 07:00 1.50 7,140 8,611 COMPZ RPCO TRIP T RIH 3-1/2 DP 7140 - to tag fill at 8611 ft 07:00 08:30 1.50 8,611 8,740 COMPZ RPCO FCO T Wash do 8611 - 8740 ft. 4 bpm / 500 psi / 3K torque / 30 rpm. 50% returns. Trace sands to shaker. 08:30 09:30 1.00 8,740 8,740 COMPZ RPCO OTHR T Thaw shaker cuttings auger. 09:30 12:00 2.50 8,740 9,090 COMPZ RPCOti FCO T Resume wash 8740 - 9090 ft. 12:00 12:30 0.50 9,090 9,094 COMPZ RPC06 FCO T Wash (no rotation) to hgr at 9094 ft. 12:30 13:30 1.00 9,094 9,094 COMPZ RPCO CIRC T Reverse circ 4 bpm / 310 psi. No sand to shakers. 90% returns. 13:30 14:00 0.50 9,094 8,929 COMPZ RPCO TRIP T PJSM, flow check, static losses 25 b h. POH 3-1/2 DP to8929 ft. 14:00 16:00 2.00 8,929 8,929 COMPZ RIGMN RGRP T Repair rig wt indicator. 16:00 20:00 4.00 8,929 8,929 COMPZ RPCOh TRIP T Resume POH 3-1/2 DP for csg test tool run f/ 8929' - 90'. 20:00 22:00 2.00 8,929 8,929 COMP2 RPCO PULD T PJSM, Break out / LD BHA, inspect Basket, no junk, loaded w/ chi s coatin or aint? . ~~~~ 4 of 14 • Time Logs D to From To Dur S. D th E. De th Ph se Code Subcode T COM 03/25/2008 22:00 23:00 1.00 8,929 8,929 COMPZ RPCOA OTHR T Clean /Clear floor, bring RBP & runnin tools to floor. 23:00 00:00 1.00 8,929 8,929 COMPZ RIGMN SVRG T PJSM, Slip & Cut drill line. 03!26/2008 00:00 00:30 0.50 8,929 8,929 COMPZ RIGMN OTHR T Finish S&C Drill line. 00:30 01:30 1.00 8,929 8,929 COMPZ RPCOti PULD T PJSM, PU Halliburton RBP. 01:30 06:00 4.50 8,929 9,094 COMPZ RPCOh TRIP T TIH w/ RBP to tag hook hanger at 9094 ft. 06:00 07:00 1.00 9,094 9,094 COMPZ RPCOh PACK T PJSM, Set HOWCO RBP at 9075 ft. 07:00 09:00 2.00 9,094 7,045 COMPZ RPCOh TRIP T PJSM, flow check, POH 3-1/2 DP to 7045 ft. 09:00 09:30 0.50 7,045 7,045 COMPZ RPCO CIRC T Pump wt pill. 09:30 10:30 1.00 7,045 7,045 COMPZ RIGMN SVRG T Service rig. 10:30 14:00 3.50 7,045 0 COMPZ RPCO TRIP T PJSM, resume POH 3-1/2 DP for test PKR run. 14:00 15:00 1.00 0 0 COMPZ RPCO PULD T Inspect RBP run tool, LD same. Flow check. Clear floor. 15:00 15:30 0.50 0 0 COMPZ RPCO PULD T PJSM, MU Baker test PKR Retrievamatic. 15:30 18:00 2.50 0 2,000 COMPZ RPCOh TRIP T Flow check, follow PKR assy with 3-1/2 DP to 2000'. 18:00 23:30 5.50 2,000 7,450 COMPZ RPCO TRIP T PJSM, crew change. Continue RIH to 7450' w/ BOT Retreivamatic test acker usin d ca on DP. 23:30 00:00 0.50 7,450 7,450 COMPZ RPCO PACK T Fill Pipe, PU 95 klbs, SO 65 klbs. Set packer perform prelim csg p-test w/ TD hooked up to verify csg integrity, OK. Disconnect TD, Blow down same, RU lines for chart recorder, reset packer @ 7450' and start csg test over interval from 7450' - 9075'. Be in 2500 si test for 30 min. 03/27/2008 00:00 01:00 1.00 7,450 7,450 COMPZ RPCOti DHEQ T Test 9 5/8" csg from 7450' - 9094' to 2500 psi f/ 30 minutes, OK. Unseat acker, RD test lines. 01:00 01:30 0.50 7,450 7,450 COMPZ RPCO OTHR T PJSM, prepare floor f/ TOH w/ packer. 01:30 07:30 6.00 7,450 0 COMPZ RPCOh TRIP T TOH w/ test packer. 07:30 08:30 1.00 0 0 COMPZ RPCO PULD T LD test pkr, clear floor. 08:30 14:30 6.00 0 0 COMPZ WELCT BOPE P PJSM, Test BOPE / ali related equip 250 / 2500 psi. Perform time /volume /press test accumulator. All tests successful, no re-tests. 14:30 15:00 0.50 0 15 COMPZ CEME PULD T MU muleshoe BHA, RIH same. 15:00 19:00 4.00 15 9,075 COMPZ CEME TRIP T Follow BHA with 3-1l2 DP !Jars to tag RPB at 9075 ft. 19:00 20:00 1.00 9,075 9,075 COMPZ CEME OTHR T RU to pump sand. Page a of 14 I~ Time Logs Date From To Dur S De th E. Depth Phase Code Subcode T COM 03/27/2008 20:00 22:00 2.00 9,075 9,075 COMPZ CEME OTHR T PJSM, Start taking on fluid to pumps to blend polymer. Water cold, lines freezin . 22:00 00:00 2.00 9,075 9,075 COMPZ CEME OTHR T Thaw lines, wait on vac truck. Reroute lines to take warmer water off ri . 03/28/2008 00:00 01:45 1.75 9,075 9,075 COMPZ CEME OTHR T RU vac truck, bring fluid into pump van, vis-up, blend in sand and pump away. Start displacement using pump van. 01:45 02:00 0.25 9,075 9,075 COMPZ CEME OTHR T Had spill, blew fluid feed line from rig to pump van. Clean up same while reroute hoses to finish displacement usin ri um s. 02:00 02:30 0.50 9,075 9,000 COMPZ CEME OTHR T Displace sand into place using rig um s. 02:30 04:00 1.50 9,000 9,000 COMPZ CEME OTHR T Blend 114 bbls Hi-Vis pill, pump same and spot over top of sand plug. Pre are to POOH. 04:00 11:30 7.50 9,000 15 COMPZ CEME TRIP T TOH with drill pipe to PU Retainer. Flow check. Well static, no losses. 11:30 12:00 0.50 15 0 COMPZ CEME PULD T Inspect / LD muleshoe assy. 12:00 13:00 1.00 0 0 COMPZ RIGMN SVRG P Service rig. 13:00 13:30 0.50 0 15 COMPZ CEME PULD T MU cmt Baker Model K-1 cmt retainer, RIH same. 13:30 18:30 5.00 0 7,395 COMPZ CEMEt` TRIP T PJSM, flow check, well static, follow BHA with 3-1/2 DP to 7395' 18:30 19:30 1.00 7,395 7,395 COMPZ CEME CIRC T Break circulation, noted sudden pressure increase on DP at 210 strokes: 10 spm @ 850 psi. Shut down, RU to reverse, able to pump at 3 bpm, 550 psi. Pump 1.3 DP volumes to clear possible obstruction with full returns, RU to circulate long way, again, Press 850 psi @ 10 spm. Decision made to POOH to inspect retainer ass . 19:30 20:30 1.00 7,395 6,527 COMPZ CEME TRIP T BD lines, POOH 6 stands DP t/ 6527', prepare to circulate again, further dia nostics. 20:30 22:00 1.50 6,527 6,527 COMPZ CEME CIRC T Pump results similar, pumping down DP @ 11 spm, pressure 850 psi. Swap lines to reverse, reverse circ @ 3 bpm, 560 psi full returns. Decide to POOH to ins ect retainer ass . 22:00 00:00 2.00 6,527 4,590 COMPZ CEME TRIP T BD lines, TOH with Baker retainer and runnin ass . 03/29/2008 00:00 03:00 3.00 4,590 0 COMPZ CEME TRIP T POOH to inspect retainer. Break out retainer and running tool. Clean and inspect, no obvious obstruction. Unable to achieve full throughput with hose. Load and to ship to shop for tear-down & rebuild. 03:00 07:00 4.00 0 0 COMPZ CEME WOEO T Wait on replacement retainer. Pale 6 of 9d Time Logs Date From To Dur 5 De th E. De th Phase Code Subcode T COM 03/29/2008 07:00 07:30 0.50 0 0 COMPZ CEME RURD T PU / MU new Baker Model K-1 Cmt Retainer. 07:30 10:00 2.50 0 3,775 COMPZ CEME TRIP T TIH w/ retainer to 3775'. Stop to erform um -thru test on retainer. 10:00 10:30 0.50 3,775 3,775 COMPZ CEME CIRC T Break circulation, pump 2.6 bpm @ 220 si, OK. 10:30 13:30 3.00 3,775 7,390 COMPZ CEME TRIP T Continue TIH to 7390'. 13:30 14:00 0.50 7,390 7,390 COMPZ CEMEI~ CIRC T Break circulation, pump tbg volume, confirm clear, rate 3 b m 370 si. 14:00 15:00 1.00 7,390 7,390 COMPZ CEME PACK T Set Baker Model K-1 Mechanical set cement retainer @ 3790', Test IA 1000 psi, DP 3000 psi. Verify injection at 3 b m, 1050 si. 15:00 16:00 1.00 7,390 7,390 COMPZ CEME RURD T RU cementers, Space out DP. 16:00 18:00 2.00 7,390 7,390 COMPZ CEME DISP T Mix /Pump cement, displace to retainer. 18:00 19:30 1.50 7,390 7,390 COMPZ CEME SOEZ T Perform hesitation squeeze procedure. Squeeze #2: 4 bbls w/ DPi 19psi, DPs 192psi, DPf 207 psi, wait 10 min. Squeeze #3: 4 bbls w/ DPi 29psi, DPs 180psi, DPf 220psi, wait 10 min. Squeeze #4: 4 bbls w/ DPi 40 psi, DPs 228psi, DPf 238psi, wait 10 min. Squeeze #5: 6 bbls w/ DPi 74psi, DPs 258psi, DPf 267psi, wait 10 min. Final DP 80psi. Used 12 ppg DeepCRETE cmt system. Partial success, pressures increasing at end each squeeze, final displace 4 bbls behind cement below retainer to leave wet interval from retainer to csg hole. Order out additional cement. 19:30 20:30 1.00 7,390 7,390 COMPZ CEME CIRC T Unsting from retainer, reverse DP clean, had 10 bbls cement contaminate to surface on clean-up, circulate until clean, stab back into retainer and inject 4 bbls brine to insure wet, pump @ 19 spm & 210 si. 20:30 00:00 3.50 7,390 7,390 COMPZ CEME WOSP T Wait on additional cement. 03/30/2008 00:00 11:00 11.00 7,390 7,390 COMPZ CEME WOSP T Wait on cement for next squeeze rocedure. 11:00 13:00 2.00 7,390 7,390 COMPZ CEME RURD T Arrival new blend cmt. PJSM, RU Cementers, all related a ui . P~g~ ? gat 1 A~ C~ r~ Time Lomas Date From To Dur S. De th _E. De th Phase Code Subcode T CODA 03/30/2008 13:00 15:30 2.50 7,390 7,390 COMPZ CEME SQEZ T PJSM; commence cmt squeeze to csg hole at 7442 ft. Sting in retainer, re-establish injection rate 2 bpm / 240 psi. Sting out. Line up returns to choke. Pump 3 bbls H2o, test lines 4000 psi, mix /pump 50 bbls 12 ppg LiteCrete, follow with, 5 bbls H2o. Displace with rig pump. Cease pumping as cmt exits DP. Close choke, open annular, sting in retainer, begin squeeze resulting in final of 4 stages of 2000 psi bleeding to 1900 psi and stable. Total cmt to squeeze (Behind Csg) 22 bbls slurry. 4 bbls below retainer. Stage 1 (20.7 bbls 2000 psi, bleed to 1534) Stage 2 (.35 bbls 2000 psi, bleed to 1690 psi), Stage 3, (.17 bbls, 2000 psi, bleed to 1800 psi), Stage 3 (.058 bbls, 2000 psi, bleed to 1900 psi). Sting out leaving press below retainer. Flow check, no flowback. 15:30 17:00 1.50 7,390 7,390 COMPZ CEME CIRC T Girc out cmt to surface. 133 bbls contaminate with approx 25 bbls cmt. Cont reverse 65 bbls brine. Clean returns. Flow check, wellbore balanced. 17:00 18:30 1.50 7,390 7,390 COMPZ CEME RURD T RD Schlum, flush all flow lines /equip in cement return flow ath. 18:30 19:00 0.50 7,390 7,210 COMPZ CEME TRIP T TOH f/ 7390ft - 7270 ft. PU 120k1bs, SO 55klbs. Noted sudden overpull and i e stickin . 19:00 19:30 0.50 7,210 7,210 COMPZ CEME CIRC T MU Top Drive, Girc/ rot/ recip pipe @ 190 spm, 1800 psi. Noted cmt in returns. Circ and recip until pipe drag and torq clear up. BD TD and prepare to continue TOH. 19:30 23:00 3.50 7,210 0 COMPZ CEME TRIP T TOH f/ 7270' -surface. BO DL retainer runnin tool. 23:00 00:00 1.00 0 0 COMPZ CEME OTHR T Clear and clean floor, send out running tool and test acker for load-out. 03/31/2008 00:00 02:00 2.00 0 0 COMPZ CEME OTHR T Drain and wash stack and wellhead for install of wear bushin . 02:00 04:00 2.00 0 0 COMPZ RIGMN OTHR T Slip & cut drill-line. 04:00 04:30 0.50 0 0 COMPZ CEMEP TRIP T Shuffle DC's and MU BHA for drill-out. 04:30 08:30 4.00 0 1,200 COMPZ CEME TRIP T TIH with 8-1/2 drilling assy to 6730 ft. Take wt on cmt strin ers. 08:30 11:00 2.50 1,200 7,235 COMPZ CEME OTHR T Wash /drill cmt stringers to 7235 ft. 11:00 16:30 5.50 7,235 7,235 COMPZ CEME CIRC T Circ / cond fluids. Cmt contaminate to its. 16:30 18:00 1.50 7,235 7,385 COMPZ CEME CIRC T Precautionary wash /ream to tag retainer at 7385 ft. 18:00 00:00 6.00 7,385 7,385 COMPZ CEME DRLG T Drlg on cmt retainer at 7385 ft. Vary ammeters in attem t to drill out. ~~~e ~ 01'l~ n C~ Time Logs _ Date From To Dur 5. Depth E. Depth Phi e Code Subcode T COM 04!01/2008 00:00 08:00 8.00 7,385 7,385 COMPZ CEME DRLG T Drilling on retainer. Vary parameters w/ attempting drill out cmt retainer at 7385'. 08:00 08:30 0.50 7,385 7,529 COMPZ CEMEI~ DRLG T Drill out retainer, continue drill /clean out cmt from 7385' - 7529'. 08:30 09:30 1.00 7,529 7,529 COMPZ CEME CIRC T CBU @ 200 spm, 2050 psi w/ rotate at 50 r m to clean out cmt and debris. 09:30 10:00 0.50 7,529 7,430 COMPZ CASIN( DHEQ T RU and perform csg integrity test. Rack back (1) std. Achieved 680 psi w/ pumping @ 10 spm (.6 bpm). Total fluid pumped away 50 strokes (3 bbls). Call town and advise of test results. Pre are to POOH. 10:00 15:00 5.00 7,430 0 COMPZ CEME TRIP T TOH w/ bit f/ 7430' - surf. Pull wear rin ,break out bit. 15:00 18:30 3.50 0 7,450 COMPZ CEME TRIP T MU 8.50" bit, 9-5/8" 40# casing scraper, 2-7"junk baskets on 3-1/2" drillpipe and RIH to 7450' for cleanout run. 18:30 19:30 1.00 7,450 7,450 COMPZ CEME CIRC T CBU 11 bpm & 1910 psi. 19:30 20:00 0.50 7,450 7,450 COMPZ CEME OTHR T BD top drive. Monitor well, static. 20:00 00:00 4.00 7,450 97 COMPZ CEME TRIP T PJSM, POOH f/ 7450' - 97' 04/02/2008 00:00 02:00 2.00 97 0 COMPZ CEME PULD T BOLDS, Finish TOH, break out and LD junk baskets, jars. Clear and clean floor and prepare to TIH w/ New Cmt Retainer. C/O of boot baskets yielded handful) of metal from drilled retainer and (1) partial ss esp cable band clam . 02:00 05:00 3.00 0 0 COMPZ CEME WOEO T CIP. Decided to order out and run composite retainer in lieu of cast iron. Wait on new retainer. 05:00 09:30 4.50 0 7,397 COMPZ CEME PULD T PU / MU new retainer. Start RIH w/ Halliburton Composite Cmt Retainer on 3 1/2" DP Workstrin . 09:30 12:30 3.00 7,397 7,397 COMPZ CEME PACK T On depth with Halliburton Fas Drill cement retainer @ 7397'. Up wt 90K Dwn wt 60K. Pumped thru retainer @ 2 BPM w/250 psi. Attempted to set retainer several times by rotating with no luck. Spotted 30 bbls fresh water around retainer to clean off tube in mud system. Set retainer by rotating 30 turns to right, pick up and set with 50K over. Pulled up and sheared out at 150K. Lowered back down in test position and PT drillpipe to 3000 psi and annulus to 1000 psi. Set down opening sliding valve, pumped into hole to est. rate of .5 b m 800 si. P~sJ~ ~at'l~ Time Logs Date From To Dur S De th E. De th Phase Code Subcode T COM 04/02/2008 12:30 16:00 3.50 7,397 7,397 COMPZ CEME SQEZ T RU Schlumberger cement equip. PJSM. Test lines to 3000 psi. Mixed and pumped 76 bbls Class'G' + 0.5%S2 + 0.3% D167 + 0.3% D65 + 0.2% D46, 15.8 ppg cement 3.5 bpm @ 975 psi, putting 20 bbls cement behind pipe. Shut down, wait 10 min. to hesitate squeeze. Pump 5 bbls wait 10 min (two stages % bbls per stage) With 30 bbls cement behind pipe, switched from Schlumberger to rig pump. Continued to hesitate squeeze 5 bbls waiting 10 min each stage pressures continuing to climb. When press. was 1220 psi, broke down to 850 psi. Continue to squeeze with max pressure at 1200 psi. Slowly shut pump down and pressure stayed at 1130 psi. Total cement pumped 86 bbls. Total cement behind pipe 67 bbls. 16:00 17:30 1.50 7,367 7,367 COMPZ CEME CIRC T PU to sting out of retainer closing valve and trapped 1130 psi below retainer. LD single. RU and reverse circulate at 3 BPM 400 psi to clean up drill i e. RD and BD lines. 17:30 22:00 4.50 7,367 0 COMPZ CEME TRIP T POOH with drillpipe and setting tool f/ 7367' -surf. 22:00 23:00 1.00 0 0 COMPZ CEME PULD T BO and LD FAS Drill setting tool. Clear and clean floor. 23:00 00:00 1.00 0 0 COMPZ RIGMN RGRP T CO top drive saver sub. Svice top drive. 04/03/2008 00:00 01:00 1.00 0 0 COMPZ CEME PULD T Load additional drill collars in i eshed, stra and tall same. 01:00 01:30 0.50 0 0 COMPZ CEMEt` PULD T Install wear bushing in wellhead, RILD. 01:30 02:00 0.50 0 0 COMPZ RIGMN SVRG T Svice rig and repair MU tong. 02:00 03:30 1.50 0 217 COMPZ CEME PULD T PU and RIH w/drilling bha assy to drill out retainer and cmt. 03:30 06:00 2.50 217 4,000 COMPZ CEME TRIP T TIH f/ 217' - 4000'. 06:00 08:00 2.00 4,000 7,330 COMPZ CEME TRIP T Crew change. Continue to TIH f/4000' to 7330'. 08:00 12:00 4.00 7,330 7,330 COMPZ CEME WOC T Wait on cement. Perform monthly derrick inspection. Clean rig floor and re for drillout. 12:00 12:30 0.50 7,330 7,375 COMPZ CEME DRLG T RIH f/7330' to 7375', tag TOC . Up wt 100K Dwn wt 70K. 12:30 16:00 3.50 7,402 7,402 COMPZ CEME DRLG T Drill cement f/7375' (hard). Drill cement retainer from 7393' to 7398'. Hard cement again from 7398' to 7402'. 16:00 16:30 0.50 7,140 7,140 COMPZ CEME OTHR T Bit plugged. POOH from 7402' to 7140'. ~~ =F~age 1ft of 1~b Time Logs Da e From To Dur S. De th E. De th Ph e Code Subcode T COM 04/03/2008 16:30 17:30 1.00 7,140 7,140 COMPZ CEME OTHR T R/U and attempt to reverse circulate and uplug bit. Pressured up to 1000 psi held for 15 min. Pressured up to 1500 si but could not un lu bit. 17:30 00:00 6.50 7,140 0 COMPZ CEME TRIP T TOH f/ 7140' - 185'. Noted hard sheath inside last three jts of DP and top of 1st DC. Cmt was breaking up and lu ed bit. 04/04/2008 00:00 00:30 0.50 0 0 COMPZ CEMEC` PULD T Wash-out and clean out junk baskets. Cement and fiberglass debris f/ retainer in both. 00:30 01:00 0.50 0 0 COMPZ CEME OTHR T Clear /clean rig floor. 01:00 03:00 2.00 0 0 COMPZ WELCT OTHR T Pull wear bushing, RU and wash-out BOP stack. BD Top drive, drain stack. Set test lu for BOP test. 03:00 08:00 5.00 0 0 COMPZ WELCT BOPE T Testing ROPE 250/ 2500. AOGCC witness of test waived by Lou Grimaldi 3-Apr-08 and approving the waiting until drill out of squeeze complete and POH putting weekly BOP test starting 3 hrs into 4-April-08 (test date on inall 3-A ril-08 08:00 12:00 4.00 0 765 COMPZ CEME TRIP T Remove jets from bit. MU drillout BHA and start RIH cleaning out cement and debris from DCs and DP to 765'. 12:00 16:30 4.50 765 7,336 COMPZ CEME TRIP T Continue RIH drifting pipe from 765' to 7336'. 16:30 18:30 2.00 7,366 7,452 COMPZ CEME DRLG T MU TOP Drive, tag top of cement @ 7402'. Drill cement from 7402' to 7452'. Pump rate 10 bpm @ 1640 psi. Up wt 105K Down wt 70K Rot. wt 85K. Tor ue 5270 FUIb WOB 10K. 18:30 19:00 0.50 7,452 7,430 COMPZ CEME CIRC T Picked up to 7430'. Circulate bottoms u to clean u hole. 19:00 20:00 1.00 7,430 7,430 COMPZ CEME OTHR T Blow down top drive. RU for casing inte ri test. 20:00 23:00 3.00 7,430 7,430 COMPZ CASINC DHEO T Fluid pack lines for testing ops. Test casing at 1500 psi f/ 30 minutes on chart. Lost 50 psi / 30 min w/ final pressure 1450 psi. Reconfigure shut-in configuration, i.e. close rams instead of annular. Retest: Start pressure 1560 psi, @ 30 min 1510psi, @ 1 hr 1490 psi., @ 1hr 30 min 1490 psi. Discuss results w/ Lou Grimaldi AOGCC, casin inte ri OK'd. 23:00 00:00 1.00 7,430 7,530 COMPZ CEME DRLG T Drilg cmt & retainer remnants f/ 7452' - 7530'. PU 105 klbs, SO 70 klbs, RotWt 85klbs, ONBTorq 5.5kft-Ibs, OFBTorq 4.5kft-Ibs. WOB 8 - 10 klbs. Significant cmt chips and residue in returns. 04/05/2008 00:00 08:00 8.00 7,530 7,728 COMPZ CEME DRLG T Drilling cmt and cmt stringers out of 9 5/8" casin f/ 7530 - 7807'. Page 11 of 14 ~ i Time Logs D to From To Dur S De th E D th Ph se Code Subcode T COM 04/05!2008 08:00 11:00 3.00 7,728 8,884 COMPZ CEME DRLG T Drilled thru @ 7807'. Attempted to RIH without rotating, still stacking out. Pum and rotated down to 8884'. 11:00 12:00 1.00 8,884 8,884 COMPZ CEME CIRC T Circulate bottoms up to clean hole. 10 b m 2000 si 80 RPM 12:00 13:00 1.00 8,884 9,055 COMPZ CEME DRLG T RIH f/8884' to 9050' tagged up. Dry drill (/9050' to 9055'. Soft (possibly 'ust sand . U wt 120K Dwn wt. 55K. 13:00 18:00 5.00 9,055 0 COMPZ CEME OTHR T POOH with drill out assembly. Break out BHA. Empty boot baskets. Both baskets full of pieces of Baker cement retainer. Clean rig floor and prep for next run. 18:00 19:30 1.50 0 130 COMPZ CEME PULD T PJSM, PU & MU Rev Circ Junk Basket & BHA. 19:30 00:00 4.50 130 9,020 COMPZ CEME TRIP T TIH f/ 130' - 9020' w/ 3 1/2" DP workstrin PU 120k1bs, SO 58klbs. 04/06/2008 00:00 01:00 1.00 9,020 9,059 COMPZ CEME CIRC T Break circ, pump 30 bbls, drop ball, circulate @ 5 bpm - 1030 psi. Tag fill at 9050'. Circulate f/ 9050' - 9059' (suck 9ft fill). Circulating at 9 bpm - 2900 psi. PU 120k1bs, SO 58klbs, RotWt 85klbs. Torq 4.23kft-Ibs @ 20r m. 01:00 01:30 0.50 9,059 9,020 COMPZ CEME OTHR T PU t/ 9020'. BD top drive w/monitor well, static. 01:30 06:00 4.50 9,020 200 COMPZ CEME TRIP T TOH f/ 9020' - 200'. 06:00 07:30 1.50 200 COMPZ CEME TRIP T Break out BHA and clean out RCJB and 2 junk baskets. Recovered more feces of Baker cement retainer. 07:30 08:00 0.50 COMPZ CEME TRIP T MU BHA for another clean out run. 08:00 09:00 1.00 0 1,780 COMPZ CEME TRIP T RIH with DP to 1780'. 09:00 11:00 2.00 1,780 1,780 COMPZ RIGMN OTHR P Slip & Cut drill line. Service Blks, TD & Crown. 11:00 14:00 3.00 1,780 9,055 COMPZ CEME CIRC T Continue RIH to 9055'. Dropped ball and um ed down for RCJB. 14:00 17:30 3.50 9,055 9,068 COMPZ CEME CIRC T Washed down to top of RBP @ 9068'. Circulated clean. Pumped Hi Vis Sweep, 6 bpm @ 2900 psi. Pump dry 'ob. 17:30 22:00 4.50 9,068 103 COMPZ CEME TRIP T POOH f/9068' - 103' 22:00 23:00 1.00 103 0 COMPZ CEME PULD T BO & LD BHA. 23:00 00:00 1.00 0 0 COMPZ CEME PULD T Break out RCJB and boot baskets. Empty and clean same. Noted handful) of metal pieces. Clear /clean floor for tri in. 04/07/2008 00:00 00:30 0.50 0 0 COMPZ CEME PULD T PJSM, PU & MU HOWCO RTTS runnin /retrieval tool. 00:30 04:30 4.00 0 8,998 COMPZ CEME TRIP T TIH w/ RTTS Running/retrieval tool on 3.5" DP to 8998'. PU 135 klbs, SO 53 klbs. €~~~~ 1 ~ oaf 14 s ~~ Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T COM __ 04/07/2008 04:30 05:00 0.50 8,998 9,063 COMPZ CEME~ CIRC T MU TD, clean TJ and tube pipe OD. Line up manifold f/ rev circ. Break circulation, slowly ramp up rate to 7.5 b m 970 si. Work i e to 9063'. 05:00 08:00 3.00 9,063 9,063 COMPZ CEME~ CIRC T Continue Rev Circ w/working pipe, recip same at 7.5 bpm. Pump Hi Vis swee 6 BPM 1000 si. 08:00 09:00 1.00 9,063 9,063 COMPZ CEME~ CIRC T Pump down drill pipe @ 11 BPM, 2500 psi w/Hi Vis sweep. No visible sand or debris in returns, hole clean. 09:00 14:00 5.00 9,063 9,063 COMPZ CEME~ WOEQ T Slow pump down to 3 BPM, 325 psi. Wait on trucks for hole swa . 14:00 15:00 1.00 9,063 9,063 COMPZ CEME~ CIRC T Pumped 30 bbls Hi Vis Pill, switched to 8.6 ppg 6% KCL clean brine and swa ed out hole fluids. 15:00 16:00 1.00 9,068 8,984 COMPZ CEME~ PACK T Latched onto Haliburton RBP, opened bypass. Well went on vacumm. Let elements on BP relax. Blow down TD, monitor well. 16:00 20:30 4.50 8,984 2,815 COMPZ CEME~ TRIP T PJSM. POOH from 8984' - 2815 racking back 6000' of drillpipe for next job. Laying down 3000' of drillpipe. Clear i e-shed. 20:30 00:00 3.50 2,815 300 COMPZ CEME~ TRIP T Clear pipeshed, unload 4 3/4" DC's, cunt POOH f! 2815' - 300', LD 31l2" DP. 04/08/2008 00:00 01:00 1.00 300 0 COMPZ CEME PULD T Finish POOH w! laying DN DC's. Inspect RBP, Break out Ret tool, LD and remove both from floor. 01:00 02:00 1.00 0 0 COMPZ CEME~ OTHR T Clear, clean floor. Clear pipe-shed for cm Itn hase. 02:00 03:00 1.00 0 0 COMPZ RPCO RURD P RU equipment and prepare for running ESP com letion. 03:00 06:00 3.00 0 0 COMPZ RPCO PULD P PU / MU ESP, Motor, seal sections, etc... Hang ESP cable sheave. Checkin connections. Checkin oil. 06:00 10:00 4.00 0 220 COMPZ RPCO PULD P RIH with ESP completion to 220'. 10:00 13:30 3.50 220 220 COMPZ RPCO PULD P PJSM with rig and Halliburton crew. RU and run the ESP, pack off assembly and slipstop. PT to 850 psi for 15 min. Good test, confirmed pack off assembly is sealing. Pulled the SOV from mandrel to be set at _2500', will run it open to enable freeze protect after com letion is hun off. 13:30 00:00 10.50 220 5,594 COMPZ RPCO RCST P RIH with 4-1/2" completion string. Testing ESP cable every 1000'. from 220' to 5,594' 92k u wt; 55k do wt 04/09/2008 00:00 04:00 4.00 5,594 7,556 COMPZ RPCOti RCST P RIH with 4-1 /2" completion string. Testing ESP cable every 1000'. from 5,594' to 7,556'. Install hanger. Ran 128 cannon clamps, 3 protectolizers, 2 flatguards and 20 flat stainless steel bands. 04:00 11:00 7.00 7,556 7,556 COMPZ RPCO OTHR P Make cable splice, connect to enetrator, test cable. ® f~~c~~ 13 cif `Id ~ ~ Time Lomas _ Date From To Dur 5 De th E. Depth Phase Code Subcode T COM 04/09/2008 11:00 11:30 0.50 7,556 7,566 COMPZ RPCO HOSO P Land tuging hanger with BPV installed, lock down. PT tubing pack off to 5000 si. 11:30 15:00 3.50 7,566 7,566 COMPZ RPCOb NUND P Change upper rams to 3-1/2" and lower to 4-1/2", NP BOPE. 15:00 15:30 0.50 7,566 COMPZ RPCOh DHEQ P Test ESP connection. Test conducted: 2.4 Phase to Phase, 1 gig ohms Phase to Ground, 1,033# intake pressure, 1,035# discharge pressure, 71?F Intake tempeture, 72 motor motor wind. 15:30 18:00 2.50 COMPZ RPCO NUND P NU tree 18:00 19:00 1.00 COMPZ RPCO SFEO P Pressure test tree to 5,000 psi. 19:00 20:00 1.00 COMPZ RPCOh CIRC P Pump remaing pit vol of 93 bbls @ 4 b m 70 si down IA 20:00 21:00 1.00 COMPZ RPCOh OTHR P Move and equalize DP from side to side for ri move re aration. 21:00 21:30 0.50 COMPZ RPCO SFTY P Held PJSM w/ LRS on freeze protect. 21:30 23:30 2.00 COMPZ RPCO FRZP P Pressure test lines to 2,500 psi and pump 50 bbls @ 2 bpm and freeze protect tbg to 2,500'. Then pump 150 bbls @ 2 bpm down IA and freeze rotect to 2,500' on IA. 23:30 00:00 0.50 COMPZ RPCO OTHR P Set BPV and Release Rig @ 23:59 on 4-9-08 r'a~c 1A e~f 1~t Ng q ~ 6 (( # '*w~...r` g ~ }9,, { q f'~ p ia. .,k A~.t L<9 w..~7 p j -....,.J ~ f~ ~ yg j( ~ ,p-~1 f J t...~ L.~ 1~.! `~.-~ l ALASSA OIL AKD GA,S CO1~T5ERQATIOIQ COIri]•'II55IO1~T Brett Packer Wells Group Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-135L1 Sundry Number: 308-109 Dear Mr. Packer: SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well.. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend.. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Daniel T. Seamount, Jr. Chair DATED this 2nd day of April, 2008 • Encl. "' i~~ STATE OF ALASKA ~ ~ ~~ ALACSKA OIL AND GAS CONSERVATION COMMISSION ~~ ~A~ i V APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 .Alaska Oil & Gas Cons. Commissia~~i 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Wai ~~ Other ^ Alter casing ^ Repair well ^/ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^/ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 207-039 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23349-60 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? YeS ^ NO ~ ~ - 1J-135L1 9. Property Designation: ADL 25662; 380058 ' 10. KB Elevati (ft): RKB 41' ~~ C~ .I• i • 11. Field/Pool(s): ~ Kuparuk River Field /West Sak Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17935' 3420' ' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 20" 121' 121' SURFACE 3421' 13-3/8" 3462' 2215' INTERMEDIATE 9778' 9-5/8" g81g' 3546' SAND SLOTTED LIN 8615' S-1/2" 17923' 3420' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9375'-12949', 12951'-17878' 3549'-3495', 3495'-3420' tubing in main wellbore Packers and SSSV Type: Packers and SSSV MD (ft) D-sand Baker ECP pkr @ 9218' no SSSV no SSSV 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat March 28, 2008 Oil ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265-6845 Printed Name Brett Packer Title: Wells Group Engineer Signature i~~ Phone 265-6845 Date 3~2D~2 p' Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~ ~ i l1`~~ V~'tvv~vv`-L ~~ ~5 Subsequent Form Required: ~.p~4"ti APPROVED BY A roved by: COMMISSIONER THE COMMISSION Date: 3 R i. Q y' X -~~- G N A I ~~~Y~~ mi~ !D~ I$ to ..~. , i 1 J-135 West Sak Producer General Workover Procedure (Plan Forward) Cement Squeeze Casing Leak, Run ESP Completion 1. Spot 2500# sand on top of RBP set at 9075' MD. 2. Spot a 114 bbl (1500' MD) high-viscosity pill on top of sand plug. 3. RIH with a 95/8" cement retainer on 3%2" IF drillpipe and set at 7390' MD (approximately 50' above the casing leak at 7443'). 4. Close the annular and PT the backside to 1000 psi to verify retainer is set. Move stinger to test position and PT drillpipe to 3000 psi. Move stinger back down. 5. Check leak rates and pressures. 6. Mix and pump 50 bbls 12.0 ppg DeepCRETE cement and perform hesitation squeeze. 7. Leave 3.8 bbls cement in 95/8" casing below retainer (volume down to leak), sting out of cement retainer and dump remaining cement on top of retainer. 8. Pull up one stand, reverse circulate out at max rate. 9. POOH w/drillpipe and allow sufficient time for cement to cure. 10. RIH w/mill tooth bit assembly w/ large ports and while reverse circulating, slowly drill out cement and retainer down past casing leak to 7450' MD. 11. Pressure test casing to 1500 psi. 12. Continue to drillout contaminated cement stringers below the casing leak down to within one joint of the RBP. Reverse circulate while slowly rotating drillstring until returns are clean. 13. PT casing again to 1500 psi. 14. POOH and swap over to casing scraper with RBP retrieving head below. 15. RIH to RBP and reverse circulate out remaining sand above RBP. 16. Latch and release RBP, POOH laying down drillpipe. 17. Continue running ESP completion. i • KRU 1 J-135L1 ConocoPhillips Alaska, Inc. WELL LOG TRANSMITTAL To: State of Alaska July 6, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-135 L1 AK-MW-4957664 1 LDWG formatted CD Rom with verification listing. API#: 5 0-029-23 349-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ,,,; _~ Date: ~~ ~ ~a ~ ~ r ~ ~ , _, r Signed: ~o~--o~g ~ tS3ta • WELL LOG TRANSMITTAL To: State of Alaska July 6, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-135 L1 PB1 AK-MW-4957664 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23349-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 -~, ~ ~., w -~ , ~ !:~ Date: Signed: ~---~ rf~. U ~ ~ ~ 20Q? ~~~ ~ ; . -_ ~_a cN7'v~' ~ ~5~3 12-Jul-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-135 L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 10,734.91 ' MD Window /Kickoff Survey 10,825.00' MD (if applicable) Projected Survey: 17,904.53' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 ,, Date ~~7 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) a,0?- oZ~ i • 12-Jul-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-135 L1 pg ~ Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 9,086.87' MD Window /Kickoff Survey 9,097.00' MD (if applicable) Projected Survey: 11,190.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 ---~ Date Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) alt7'~3 l ConocoPhillips July 2, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1J-135, 1J-135L1 Dear Commissioner: Randy Thomas Kuparuk Drilling Team Leader Dritling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ConocoPhillips Alaska, lnc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak wells 1J-135 and 1J-135L1. - If you have any questions regarding this matter, please contact me at 265-6830 or Dennis Hartwig at 265-6862. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad __ dVE~ STATE OF ALASKA JUI. 0 5 Z~lCll ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT~~~fl~'~ ~~~ons. Commissnr~ 1a. Well Status: Oil ^/ Gas Plugged Abandoned ^ Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development Q Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., oraband.: May 22, 2007 ~ 12. Permit to Drill Number: 207-039 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: May 1, 2007 13. API Number: 50-029-23349-60 4a. Location of Well (Governmental Section): Surface: 1583' FSL, 2287' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: May 6, 2007 14. Well Name and Number: 1J-135L1 At Top Productive Horizon: 46' FSL, 805' FWL, Sec. 1, T10N, R10E, UM 8. KB (ft above MSL): Ground (ft MSL): 121' MSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 1757' FSL, 776' FWL, Sec. 13, T10N, R10E, UM 9. Plug Back Depth (MD + ND): 17921' MD / 3420' ND West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 558926 y- 5945397 Zone- 4 10. Total Depth (MD + ND): . 17935' MD /3420' ND *" 16. Property Designation: ADL 25662, 380058 TPI: x- 562078 y- 5938606 Zone- 4 Total Depth: x- 562127 ' - 5929758 - Zone- 4 11. SSSV Depth (MD + ND): none 17. Land Use Permit: 2177, 4604 18. Directional Survey: Yes Q No^ (Submit electronic and printed. information per 20 AAC 15.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): 1523' TVD (estimated) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): top of window @ 9097' MD / 3528' TVD GR/Res 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE TIN AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMEN G RECORD PULLED 20" x 34" 94# H-40 41' 121' 41' 121' 42" 280 sx AS 1 13.375" 68# L-80 41' 3463' 41' 2213' 16" 650 sx AS Lite, 220 sx DeepCRETE 9-5/8" 40# L-80 41' 9819' 41' 3604' 12.25" 720 sx DeepCRETE 5.5" x 4.5" 15.5# / 11.6# L-80 9093' 17923' 3528' 3420' 8.5" slotted liner 23. Open to production or injection? Yes 0 No ^ If Yes, list each 24. TUBING RECORD Interval open (MD + ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore slotted liner from 9375'-12951' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production June 10, 2007 Method of Operation (Flowing, gas lift, etc.) shares production with 1J-135 Date of Test 6/13/2007 Hours Tested 14 hours Production for Test Period --> OIL-BBL 1222 GAS-MCF 142 WATER-BBL 0 CHOKE SIZE 24% GAS-OIL RATIO 149 Flow Tubing press. 268 psi Casing Press: not available Calculated 24-Hour Rate -> OIL-BBL 1981 GAS-MCF 296 WATER-BBL 1 OIL GRAVITY -API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes No / Sidewall Cores Acquired? Yes No / If Yes to either question, list formations and intervals cored (MD + ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. COI~,iPL~T10"~ NONE SATE I •22•D i~ jFlED Form 10-407 Revised 2/2007 ORIGINAL CONTINUED ON REVERSE SIDE 7~EJ ~~ ~~IV~ Ed U ~OQ/ ~ l~ `isi~~~G ~/ ~''~~ r~ 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and PerrTlafroSt -Top surface surface attach detailed supporting data as necessary. If no tests were Permafrost -Bottom 1619' (est) 1523' (est) conducted, state "None". T3 n/a n/a K15 n/a n/a Ugnu C 6287' 2940' Ugnu B 7193' 3174' Ugnu A 7557 3260' K13 8i 57' 3379' West Sak D 9065' 3524' N/A 1 J-135L1 P61 TD 11190' 3497' Formation at total depth: West Sak D 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dennis Hartwig @ 265-6862 Printed N Ra Tho s Title: GKA Drillino Team Lead Signature ~ ~ -~ ne Date 71L.f6 INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 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 elevation in feet abour mean low low water. 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: True vertical thickness. 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, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2007 '" Slotted and Blank Liner Detail Well: 1J-135 L1 t,. t CQCIOCOP~1~~lj]~ Slotted and Blank Liner . Dafe: .5117107 a3~sKa. !~~. Supervisors: Fred Herhert/ Granville Rizek Rig: Doyon 15 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 LENGTH TOPS Plop 8~ Drop 9300.23 „~ .:._ .., : , ''B" Lateral MLZXP @ 9,167.28' MD / 3,538.85' TVD 9300.23 "D" lateral window top @ 9,09T/ 3,528.25' TVD 9300.23 - "D" lateral window bttm @ 9,114'/ 3,530.95' TVD 9300'.23 ' -- Window @ $1 deg 9300.23 TOL 194.82' out in open hole @ 9,308.82'/ 3,548' TVD 9300.23 TOL @ 88.21 deg. 9300.23 9300.23 5" DP to Surface =_> 9300.23 Cross over 4-112" IF Box x 3-112" IF Pin 1.98- 9300.23 Liner Runnin Tool 3-1/2" Does not sta in hole 6.61 9302.21 5 112" Baker "HR" Liner Setting Sleeve (6.43" O.D. x 5.75" LD.) 1.2.69 9308.82 5 1/2", 15.5 ppf, L-80, Hydril 521 Pup joint 7.37 9321.51 5 1/2", 15.5 ppf, L-80, Hydril 521 41.02 .9328.88 5 1/2" Hydril 521 Box X 4 1/2" Hydril 521 Pin X/O (3.94" LD.) 1:.43 9369.90 4-1/2", 12.6 ppf, L-80, Hydril 521 PUP Jt. 3.62 9371.33 Jts 116 to 20 s7 Jts 4-1/2",11.6 ppf, L-80, Hydril 521 Slotted Casing 3574.12 9374.95 4 1/2" Hydril 521 Box X 4 1/2" BTC Pin X/O (3.94" LD.) 1.65 12949.07 Jts 1 to 115 115 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 4927.23 12950.72 4-1/2", 14.6 ppf, L-80, BTC Blank (Bent} Joint 43.42 17877.95 4-1/2", ROT Silver Bullet Guide Shoe (No Float) 1.67 17921.37 17923.04 17923.04 TD 8 /2"hole @ 17,935' MD / 3,420' TVD 17923.04 4-1/2" Shoe @ 17,923.04' MD / 3,424.20' TVD (89.91 deg) 17923.04 (Rathole 11.96') 17923.04 17923.04 Total Parts used: 202 HydroFORM centralizers 17923.04 4-1/2"x 6.13" HydroFORM (#80549- 2 ribs) Cent.. 17923.04 4-1/2"x 6.13" HydroFORM (#80590- 3 ribs} Cent.. 17923.04 17923.04 Run 1 HydroFORM every jt. Floating on each joint 17923.04 JTS #1 - #202 17923.04 17923.04 17923.04 Run torque rings from joint # 56 thru # 115 17923.04 Total of 60-4-1/2" BTC torque rings. 17923.04 17923.04 4-1/2": Ran total of 1 Jt Blank = 43.42' and 202 Jts Slotted = 8501.35'. Up Wt 250K Slots are w/ (32) 2.5" long x .125" @ 4 Circumferential adjacent rows, Dn Wt none 3" Centers Staggered 18 deg., 3 ft. non-slotted ends. Block 1/Ut 70K Used Run-NSeal thread compound on all connections. Rot Wt 452K Drifted 4-1/2" to 3.833 w/ teflon rabbit. Halliburton Company Survey Report ' Company: ConocoPhillips Alaska Inc. llate: 6/13/2007 'fimc 14:54:18 __ Page: t Field: Kuparuk River Unit Co -ordinate(NE) Reference: Well: 1 J-135, Tru e North Site: Kuparuk 1J Pad Vertical (TVD)Re ference: 1J-135L1: 122.5 Nell: 1J-135 Section (VS) Kefer ence: Well (O.OON,O.OO E,180.OOAzi) Wellpath: 1J-135L1 ___ Survey Calculatio _ n 11ethod: Minimum Curvature Db: Oracle __ __ __ Field: Kuparuk River Unit __ North Slope Alaska United States ' Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Coordinate System: Weii Centre Geomagnetic Model: bggm2006 ~ Well: 1J-135 Slot Name: Well Position: +N/-S -523.65 ft Northing: 594539 7.09 ft Latitude: 70 15 41.108 N +E/-W 132.13 ft Easti ng : 558926.15 ft Longitude: 149 31 25.162 W Position Uncertainty: 0.00 ft Wellpath: 1J-135L1 Drilled From: 1J-135L1PB1 500292334960 Current Datum: 1J-135L1: Height 12 2.50 ft Tie-on Depth: Above System 10734.91 ft Datum: Mean Sea Level Magnetic Data: 4/7/2007 ~ Declination: 23.56 deg Field Strength: 57621 nT Mag Dip Angle: 80.82 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg i 41.40 _ 0.00 0.00 180.00 Survey Program for Definitive Wellpath 'I Date: 6/13/2007 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 104.00 836.00 1J-135 gyro (104.00-836.00) (2 CB-GYRO-SS Camera based gyro single shot 877.39 9086.87 1J-135 (877.39-17706.10) (2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9086.87 10734.91 1J-135L1 PB1 (9086 .87-11159.42) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 110825.00 17904.53 1J-135L1 (10825.00-17904.53) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey __ __- MD Incl Arim TVD Sys TVD N/S E/W '11apN DIapE Tool '~ ft deg deg ft ft ft ft ft ft j 41.40 0.00 0.00 41.40 -81.10 0.00 0.00 5945397.09 558926.15 TIE LINE 104,00 0.15 49.37 104.00 -18.50 0.05 0.06 5945397.14 558926.21 CB-GYRO-SS ~ 204.00 0.27 345.24 204.00 81.50 0.37 0.10 5945397.46 558926.25 CB-GYRO-SS 304,00 0.97 8.61 303.99 181.49 1.43 0.17 5945398.52 558926.31 CB-GYRO-SS 404,00 0.48 14.03. 403.98 281.48 2.67 0.40 5945399.77 558926.53 CB-GYRO-SS !~ 490.00 0.62 128.00 489.98 367.48 2.74 0.85 5945399.83 558926.98 CB-GYRO-SS 590.00 3.21 167.67 589.92 467.42 -0.33 1.87 5945396.77 558928.03 CB-GYRO-SS 660.00 6.04 179.53 659.69 537.19 -5.93 2.32 5945391.18 558928.52 CB-GYRO-SS , 'I 750.00 10.35 190.39 748.75 626.25 -18.62 0.90 5945378.48 558927.20 CB-GYRO-SS 836.00 13.54 192.07 832.88 710.38 -36.07 -2.60 5945361.00 558923.84 CB-GYRO-SS 877.39 14.06 186.38 873.08 750.58 -45.81 -4.17 5945351.26 558922.34 MWD+IFR-AK-CAZ-SC 972.10 17.03 178.69 964.32 841.82 -71.11 -5.13 5945325.95 558921.58 MWD+IFR-AK-CAZ-SC 1066.14 22.67 174.48 1052.74 930.24 -102.95 -3.07 5945294.13 558923.89 MWD+IFR-AK-CAZ-SC I; 1161.80 24.65 168.79 1140.37 1017.87 -140.87 2.58 5945256.26 558929.84 MWD+IFR-AK-CAZ-SC 1256.42 27.32 165.35 1225.42 1102.92 -181.25 11.91 5945215.96 558939.48 MWD+IFR-AK-CAZ-SC 1353.43 30.42 156.52 1310.40 1187.90 -225.34 27.34 5945171.99 558955.25 MWD+IFR-AK-CAZ-SC 1449.50 34.95 151.63 1391.25 1268.75 -271.89 50.12 5945125.62 558978.39 MWD+IFR-AK-CAZ-SC 1544.36 39.40 150.90 1466.82 1344.32 -322.13 77.69 5945075.61 559006.35 MWD+IFR-AK-CAZ-SC 1639.12 42.27 149.15 1538.51 1416.01 -375.78 108.66 5945022.21 559037.74 MWD+IFR-AK-CAZ-SC 1731.22 46.22 148.58 1604.47 1481.97 -430.77 141.89 5944967.49 559071.39 MWD+IFR-AK-CAZ-SC I ~ 1829.23 48.60 148.84 1670.80 1548.30 -492.43 179.36 5944906.13 559109.34 MWD+IFR-AK-CAZ-SC 1924.09 51.44 149.71 1731.74 1609.24 -554.91 216.49 5944843.94 559146.95 MWD+IFR-AK-CAZ-SC 2019.30 56.06 149.30 1788.02 1665.52 -621.05 255.45 5944778.12 559186.42 MWD+IFR-AK-CAZ-SC 2112.70 63.18 154.09 1835.25 1712.75 -691.97 293.50 5944707.50 559225.03 MWD+IFR-AK-CAZ-SC 2207.28 66.41 156.23 1875.53 1753.03 -769.62 329.42 5944630.14 559261.55 MWD+IFR-AK-CAZ-SC 2304.78 71.28 156.77 1910.70 1788.20 -852.99 365.66 5944547.07 559298.44 MWD+IFR-AK-CAZ-SC 2399.24 73.90 157.30 1938.96 1816.46 -935.97 400.83 5944464.38 559334.25 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 6/13/2007 Time: 14:54:18 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1 J-135, True North Site: Kuparuk 1J Pad Vcrtical(TVD)Refcrence: 1J-135L1: 122.5 1'Vell: 1J-135 Section (VS)Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-1351.1 Suncy Calculation Method: Minimum Curvature Db: Oracle Sung bID Iucl Azim TVD Sys TVD N/S E/W b1apN MapE Tool ft deg deg ft ft ft ft ft ft 2493.74 73.23 157.95 1965.70 1843.20 -1019.78 435.33 5944380.84 559369.40 MWD+IFR-AK-CAZ-SC 2589.04 73.02 155.79 1993.37 1870.87 -1103.64 471.15 5944297.27 559405.88 MWD+IFR-AK-CAZ-SC 2684.10 75.92 154.75 2018.82 1896.32 -1186.82 509.47 5944214.41 559444.84 MWD+IFR-AK-CAZ-SC j 2779.50 76.26 154.79 2041.75 1919.25 -1270.59 548.94 5944130.96 559484.96 MWD+IFR-AK-CAZ-SC 2874.33 76.89 155.81 2063.77 1941.27 -1354.39 587.48 5944047.47 559524.15 MWD+IFR-AK-CAZ-SC 2969.94 75.61 153.53 2086.50 1964.00 -1438.32 627.20 5943963.86 559564.53 MWD+IFR-AK-CAZ-SC 3063.12 75.51 152.63 2109.73 1987.23 -1518.78 668.06 5943883.73 559606.01 MWD+IFR-AK-CAZ-SC 3158.23 75.53 152.86 2133.51 2011.01 -1600.65 710.23 5943802.21 559648.81 MWD+IFR-AK-CAZ-SC i 3253.33 73.01 152.92 2159.29 2036.79 -1682.12 751.94 5943721.07 559691.16 MWD+IFR-AK-CAZ-SC 3349.13 75.81 153.50 2185.04 2062.54 -1764.48 793.52 5943639.04 559733.38 MWD+IFR-AK-CAZ-SC 3430.38 73.89 153.16 2206.27 2083.77 -1834.56 828.72 5943569.24 559769.12 MWD+IFR-AK-CAZ-SC 3476.12 73.42 151.99 2219.14 2096.64 -1873.52 848.94 5943530.45 559789.64 MWD+IFR-AK-CAZ-SC 3571.21 76.13 152.53 2244.11 2121.61 -1954.72 891.64 5943449.59 559832.97 MWD+IFR-AK-CAZ-SC 3665.99 74.72 152.44 2267.96 2145.46 -2036.07 934.01 5943368.58 559875.98 MWD+IFR-AK-CAZ-SC 3760.70 74.65 153.47 2292.98 2170.48 -2117.43 975.55 5943287.56 559918.14 MWD+IFR-AK-CAZ-SC 3854.86 74.28 154.06 2318.20 2195.70 -2198.80 1015.65 5943206.51 559958.88 MWD+IFR-AK-CAZ-SC 3950.50 75.24 154.47 2343.34 2220.84 -2281.93 1055.72 5943123.71 559999.59 MWD+IFR-AK-CAZ-SC 4045.69 74.27 154.76 2368.37 2245.87 -2364.90 1095.09 5943041.06 560039.61 MWD+IFR-AK-CAZ-SC 4140.32 74.66 156.13 2393.71 2271.21 -2447.82 1132.98 5942958.44 560078.14 MWD+IFR-AK-CAZ-SC 4235.60 75.86 158.41 2417.96 2295.46 -2532.81 1168.57 5942873.75 560114.39 MWD+IFR-AK-CAZ-SC 4330.90 75.22 158.17 2441.75 2319.25 -2618.54 1202.71 5942788.29 560149.19 MWD+IFR-AK-CAZ-SC 4426.87 74.84 157.06 2466.55 2344.05 -2704.27 1238.01 5942702.85 560185.17 MWD+IFR-AK-CAZ-SC 4522.05 74.90 156.35 2491.39 2368.89 -2788.66 1274.35 5942618.76 560222.16 MWD+IFR-AK-CAZ-SC i 4615.70 75.87 155.26 2515.02 2392.52 -2871.31 1311.49 5942536.40 560259.94 MWD+IFR-AK-CAZ-SC 4711.45 74.66 153.98 2539.37 2416.87 -2954.97 1351.18 5942453.06 560300.28 MWD+IFR-AK-CAZ-SC 4807.09 75.88 153.98 2563.69 2441.19 -3038.09 1391.75 5942370.27 560341.50 MWD+IFR-AK-CAZ-SC 4901.25 76.38 153.38 2586.26 2463.76 -3120.03 1432.28 5942288.66 560382.67 MWD+IFR-AK-CAZ-SC ! 4996.87 76.11 152.76 2609.00 2486.50 -3202.84 1474.35 5942206.20 560425.37 MWD+IFR-AK-CAZ-SC 5092.56 75.67 153.45 2632.33 2509.83 -3285.60 1516.33 5942123.77 560467.99 MWD+IFR-AK-CAZ-SC 5187.78 74.47 153.42 2656.86 2534.36 -3367.89 1557.47 5942041.81 560509.78 MWD+IFR-AK-CAZ-SC 5282.86 74.22 154.26 2682.52 2560.02 -3450.07 1597.84 5941959.96 560550.78 MWD+IFR-AK-CAZ-SC 5377.84 74.34 155.17 2708.25 2585.75 -3532.73 1636.89 5941877.61 560590.47 MWD+IFR-AK-CAZ-SC 5472.88 74.78 155.11 2733.55 2611.05 -3615.85 1675.40 5941794.80 560629.63 MWD+IFR-AK-CAZ-SC 5568.00 75.81 155.35 2757.70 2635.20 -3699.39 1713.95 5941711.58 560668.83 MWD+IFR-AK-CAZ-SC 5663.14 76.25 154.98 2780.67 2658.17 -3783.18 1752,72 5941628.10 560708.25 MWD+IFR-AK-CAZ-SC 5762.04 75.53 154.23 2804.78 2682.28 -3869.83 1793.86 5941541.79 560750.06 MWD+IFR-AK-CAZ-SC 5853.10 75.16 154.41 2827.81 2705.31 -3949.22 1832.03 5941462.70 560788.85 MWD+IFR-AK-CAZ-SC Ij 5941.89 74.91 154.95 2850.74 2728.24 -4026.76 1868.72 5941385.46 560826.14 MWD+IFR-AK-CAZ-SC 6045.41 75.36 154.21 2877.30 2754.80 -4117.13 1911.67 5941295.44 560869.79 MWD+IFR-AK-CAZ-SC 6139.32 74.98 154.62 2901.34 2778.84 -4199.01 1950.87 5941213.88 560909.63 MWD+IFR-AK-CAZ-SC 6233.85 74.79 154.91 2925.99 2803.49 -4281.56 1989.78 5941131.64 560949.18 MWD+IFR-AK-CAZ-SC 6328.51 74.61 154.62 2950.96 2828.46 -4364.15 2028.71 5941049.37 560988.75 MWD+IFR-AK-CAZ-SC 6422.91 74.79 155.42 2975.87 2853.37 -4446.69 2067.16 5940967.14 561027.84 MWD+IFR-AK-CAZ-SC i 6517.50 75.05 155.07 3000.48 2877.98 -4529.62 2105.40 5940884.51 561066.73 MWD+IFR-AK-CAZ-SC 6613.03 75.24 155.23 3024.97 2902.47 -4613.41 2144.21 5940801.04 561106.18 MWD+IFR-AK-CAZ-SC 6708.50 75.36 156.01 3049.20 2926.70 -4697.52 2182.32 5940717.24 561144.95 MWD+IFR-AK-CAZ-SC 6802.49 75.56 155.28 3072.80 2950.30 -4780.40 2219.84 5940634.66 561183.12 MWD+IFR-AK-CAZ-SC 6897.56 74.91 154.43 3097.03 2974.53 -4863.62 2258.90 5940551.76 561222.82 MWD+IFR-AK-CAZ-SC 6992.34 74.54 153.53 3122.00 2999.50 -4945.79 2299.01 5940469.92 561263.57 MWD+IFR-AK-CAZ-SC 7087.72 74.60 154.99 3147.38 3024.88 -5028.60 2338:94 5940387.43 561304.14 MWD+IFR-AK-CAZ-SC 'I 7182.84 75.94 156.22 3171.56 3049.06 -5112.38 2376.93 5940303.96 561342.78 MWD+IFR-AK-CAZ-SC 7278.62 76.05 156.44 3194.74 3072.24 -5197.50 2414.24 5940219.14 561380.75 MWD+IFR-AK-CAZ-SC 7373.83 76.36 155.99 3217.44 3094.94 -5282.11 2451.53 5940134.84 561418.70 MWD+IFR-AK-CAZ-SC ! Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 6/13/2007 Time: 14:54:16 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1 J-135, True North Site: Kuparuk 1J Pad Vertical CCVD) Reference: 1J-135L1: 122.5 Nell: 1J-135 Section (VS) Reference: Well (O.OON,O.OOE,180:OOAzi) ', Wellpath: 1J-135t_1 Survey Calculation method: Minimum Curvature Db: Oracle Survcv 1~iD Incl Azim TVD Sys TVD N/S E/1V 1fap~ ~IapE Tool ft deg deg ft ft ft ft ft` ft i i 7468.42 76.51 155.66 3239.63 3117.13 -5365.99 2489.19 5940051.25 561457.01 MWD+IFR-AK-CAZ-SC 7563.85 76.83 155.13 3261.63 3139.13 -5450.42 2527.85 5939967.14 561496.33 MWD+IFR-AK-CAZ-SC 7658.87 78.28 152.78 3282.11 3159.61 -5533.77 2568.59 5939884.12 561537.72 MWD+IFR-AK-CAZ-SC 7753.94 76.58 153.44 3302.80 3180.30 -5616.53 2610.56 5939801.70 561580.33 MWD+IFR-AK-CAZ-SC 7848.52 78.54 154.50 3323.18 3200.68 -5699.51 2651.09 5939719.04 561621.50 MWD+IFR-AK-CAZ-SC 7944.52 80.41 155.00 3340.71 3218.21 -5784.88 2691.34 5939634.00 561662.42 MWD+IFR-AK-CAZ-SC 8039.59 79.41 154.78 3357.37 3234.87 -5869.63 2731.06 5939549.57 561702.79 MWD+IFR-AK-CAZ-SC 8135.58 79.22 155.38 3375.16 3252.66 -5955.17 2770.81 5939464.35 561743.20 MWb+IFR-AK-CAZ-SC 8230.04 81.79 156.36 3390.75 3268.25 -6040.19 2808.89 5939379.64 561781.94 MWD+IFR-AK-CAZ-SC 8324.93 81.35 154.46 3404.66 3282.16 -6125.54 2847.94 5939294.61 561821.66 MWD+IFR-AK-CAZ-SC 8420.20 80.91 153.81 3419.35 3296.85 -6210.24 2889.01 5939210.24 561863.39 MWD+IFR-AK-CAZ-SC 8515.46 80.72 154.49 3434.55 3312.05 -6294.87 2930.01 5939125.95 561905.04 MWD+IFR-AK-CAZ-SC I 8610.32 80.96 158.30 3449.66 3327.16 -6380.67 2967.50 5939040.45 561943.20 MWD+IFR-AK-CAZ-SC 8705.63 80.84 161.67 3464.74 3342.24 -6469.08 2999.71 5938952.30 561976.10 MWD+IFR-AK-CAZ-SC 8800.15 80.59 162.91 3479.99 3357.49 -6557.94 3028.09 5938863.68 562005.17 MWD+IFR-AK-CAZ-SC 8895.48 80.79 163.69 3495.41 3372.91 -6648.04 3055.12 5938773.79 562032.90 MWD+IFR-AK-CAZ-SC 8990.86 80.60 164.92 3510.83 3388.33 -6738.66 3080.58 5938683.39 562059.07 MWD+IFR-AK-CAZ-SC ~ 9086.87 80.53 169.44 3526.58 3404.08 -6830.98 3101.59 5938591.24 562080.80 MWD+iFR-AK-CAZ-SC 9097.00 80.71 169.78 3528.23 3405.73 -6840.81 3103.39 5938581.43 562082.68 MWD+IFR-AK-CAZ-SC 9149.61 83.49 170.81 3535.46 3412.96 -6892.17 3112.17 5938530.14 562091.86 MWD+IFR-AK-CAZ-SC 9212.09 84.64 172.02 3541.92 3419.42 -6953.62 3121.45 5938468.78 562101.61 MWD+IFR-AK-CAZ-SC 9307.23 88.15 173.84 3547.90 3425.40 -7047.83 3133.13 5938374.67 562114.03 MWD+IFR-AK-CAZ-SC 9400.62 89.82 172.56 3549.56 3427.06 -7140.54 3144.19 5938282.05 562125.81 MWD+IFR-AK-CAZ-SC 9500.86 91.48 172.69 3548.42 3425.92 -7239.94 3157.05 5938182.77 562139.45 MWD+IFR-AK-CAZ-SC 9591.06 90.53 174.68 3546.84 3424.34 -7329.58 3166.97 5938093.22 562150.07 MWD+IFR-AK-CAZ-SC !~ 9686.52 89.85 176.20 3546.52 3424.02 -7424.73 3174.56 5937998.14 562158.41 MWD+IFR-AK-CAZ-SC 9781.31 89.60 178.77 3546.98 3424.48 -7519.42 3178.72 5937903.49 562163.30 MWD+IFR-AK-CAZ-SC 9878.04 92.32 182.40 3545.36 3422.86 -7616.11 3177.73 5937806.81 562163.08 MWD+IFR-AK-CAZ-SC 9972.54 92.32 184.49 3541.53 3419.03 -7710.35 3172.06 5937712.53 562158.14 MWD+IFR-AK-CAZ-SC ~ 10068.28 90.40 184.80 3539.26 3416.76 -7805.75 3164.31 5937617.09 562151.14 MWD+IFR-AK-CAZ-SC 10163.15 90.96 184.65 3538.13 3415.63 -7900.29 3156.50 5937522.50 562144.06 MWD+IFR-AK-CAZ-SC 10258.41 90.77 185.00 3536.69 3414.19 -7995.20 3148.48 5937427.54 562136.80 MWD+IFR-AK-CAZ-SC 10352.03 90.84 184.16 3535.38 3412.88 -8088.51 3141.01 5937334.18 562130.05 MWD+IFR-AK-CAZ-SC 10447.19 90.47 179.38 3534.29 3411.79 -8183.59 3138.07 5937239.09 562127.86 MWD+IFR-AK-CAZ-SC ~ it 10544.37 91.81 179.77 3532.36 3409.86 -8280.75 3138.79 5937141.95 562129.34 MWD+IFR-AK-CAZ-SC i 10639.60 92.07 178.79 3529.13 3406.63 -8375.91 3139.99 5937046.81 562131.28 MWD+IFR-AK-CAZ-SC 10734.91 91.82 179.98 3525,90 3403.40 -8471.16 3141.01 5936951.58 562133.05 MWD+IFR-AK-CAZ-SC ~' 10825.00 93.45 179.80 3521.76 3399.26 -8561.15 3141.18 5936861.60 562133.92 MWD+IFR-AK-CAZ-SC 10920.45 89.72 180.17 3519.12 3396.62 -8656.55 3141.21 5936766.22 562134.69 MWD+IFR-AK-CAZ-SC 11019.16 91.19 180.88 3518.33 3395.83 -8755.25 3140.30 5936667.52 562134.56 MWD+IFR-AK-CAZ-SC i I 11113.51 89.23 179.34 3517.99 3395.49 -8849.59 3140.12 5936573.19 562135.12 MWD+IFR-AK-CAZ-SC ~ 11208.46 91.65 179.59 3517.26 3394.76 -8944.53 3141.01 5936478.27 562136.75 MWD+IFR-AK-CAZ-SC 11303.10 91.33 178.53 3514.80 3392.30 -9039.12 3142.56 5936383.70 562139.04 MWD+IFR-AK-CAZ-SC 11396.73 90.65 178.07 3513.18 3390.68 -9132.70 3145.34 5936290.16 562142.55 MWD+IFR-AK-CAZ-SC 11493.22 90.59 179.33 3512.14 3389.64 -9229.15 3147.53 5936193.73 562145.49 MWD+IFR-AK-CAZ-SC j i 11588.66 92.05 181.82 3509.94 3387.44 -9324.55 3146.57 5936098.34 562145.28 MWD+IFR-AK-CAZ-SC 11683.77 92.07 184.25 3506.52 3384.02 -9419.46 3141.54 5936003.40 562140.99 MWD+IFR-AK-CAZ-SC ~ 11778.82 89.10 184.96 3505.55 3383.05 -9514.19 3133.91 5935908.63 562134.11 MWD+IFR-AK-CAZ-SC 11873.47 87.56 184.36 3508.31 3385.81 -9608.48 3126.22 5935814.29 562127.16 MWD+IFR-AK-CAZ-SC 11969.51 88.18 183.85 3511.88 3389.38 -9704.21 3119.35 5935718.52 562121.04 MWD+IFR-AK-CAZ-SC it 12064.46 88.80 182.67 3514.38 3391.88 -9798.97 3113.96 5935623.73 562116.38 MWD+IFR-AK-CAZ-SC 12159.90 91.99 181.48 3513.72 3391.22 -9894.33 3110.50 5935528.35 562113.68 MWD+IFR-AK-CAZ-SC li • Halliburton Company Survey Report Cv~upxny: ConocoPhillips Alaska Inc. Date: 6/13/2007 Time: 14:54:18 Page: 4 Eield: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1 J-135, True North Site: KuparuklJPad Vertical(TVD)Reference: 1J-135L1:122.5 Well: 1J-135 Section (~'S) Reference: Well (O.OON,O.OOE,180.OOAzi) ~~'ellpath: 1J-135L1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey IVID [ncl Azim TVD ft deg deg ft 12255.18 91.33 177.72 3510.96 12350.77 91.88 177.88 3508.28 12445.50 90.71 178.42 3506.14 12540.99 91.09 179.72 3504.64 , 12635.80 91.45 177.58 3502.54 12730.37 91.83 176.49 3499.83 12825.44 90.83 177.35 3497.63 12919.75 91.52 177.65 3495.69 13015.47 91.46 178.44 3493.20 13108.76 91.95 178.89 3490.43 13201.90 93.65 180.97 3485.88 13300.18 92.63 180.44 3480.49 13395.57 92.87 181.51 3475.92 13489.60 92.44 182.45 3471.56 13586.77 91.27 183.09 3468.42 13682.44 91.02 182.64 3466.50 13765.93 89.35 183.07 3466.23 13871.97 90.76 182.68 3466.13 13966.48 91.88 183.00 3463.95 14059.42 92.01 182.59 3460.80 14156.43 90.59 180.12 3458.60 14251.51 90.84 178.79 3457.41 i 14345.98 90.03 176.93 3456.70 14441.72 90.10 176.07 3456.59 14536.85 92.03 176.10 3454.82 14632.82 91.14 176.80 3452.16 li 14725.25 90.84 175.94 3450.57 i 14821.61 89.17 176.64 3450.56 14915.75 90.45 179.35 3450.87 15012.52 90.03 182.90 3450.47 15107.60 90.41 182.17 3450.10 j 15202.58 89.85 181.99 3449.88 15298.06 90.71 183.27 3449.42 15391.54 90.22 183.23 3448.66 15488.70 89.60 182.87 3448.81 15583.55 91.18 184.90 3448.17 15678.24 90.46 184.38 3446.81 15773.64 91.21 183.11 3445.42 '~ 15868.85 90.65 179.94 3443.88 15963.78 90.03 178.23 3443.31 16058.95 90.71 179.73 3442.70 16154.16 90.53 179.56 3441.67 16249.25 91.57 180.43 3439.92 16343.65 90.34 179.59 3438.35 i 16438.37 90.53 180.10 3437.63 !~ 16534.11 89.66 181.04 3437.47 16628.70 90.22 180.80 3437.57 16724.47 90.90 183.15 3436.64 16819.50 91.27 182.41 3434.84 16914.06 91.15 180.31 3432.84 17008.93 90.46 179.89 3431.51 17104,09 90.78 179.56 3430.48 17199.06 89.41 179.73 3430.32 3388.46 -9989.55 3385.78 -10085.03 3383.64 -10179.69 3382.14 -10275.15 3380.04 -10369.90 3377.33 -10464.31 3375.13 -10559.21 3373.19 -10653.41 3370.70 -10749.04 3367.93 -10842.27 3363.38 -10935.29 3357.99 -11033.41 3353.42 -11128.68 3349.06 -11222.55 3345.92 -11319.55 3344.00 -11415.08 3343.73 -11498.46 3343.63 -11604.37 3341.45 -11698.73 3338.30 -11791.51 3336.10 -11888.46 3334.91 -11983.52 3334.20 -12077.92 3334.09 -12173.48 3332.32 -12268.37 3329.66 -12364.12 3328.07 -12456.35 3328.06 -12552.50 3328.37 -12646.57 3327.97 -12743.31 3327.60 -12838.29 3327.38 -12933.21 3326.92 -13028.58 3326.16 -13121.91 3326.31 -13218.93 3325.67 -13313.55 3324.31 -13407.92 3322.92 -13503.11 3321.38 -13598.26 3320.81 -13693.17 3320.20 -13788.32 3319.17 -13883.52 3317.42 -13978.59 3315.85 -14072.98 3315.13 -14167.69 3314.97 -14263.43 3315.07 -14358.00 3314.14 -14453.71 3312.34 -14548.61 3310.34 -14643.11 3309.01 -14737.97 3307.98 -14833.13 3307.82 -14928.09 3111.17 3114.83 3117.89 3119.44 3121.67 3126.56 3131.67 3135.78 3139.05 3141.22 3141.33 3140.13 3138.51 3135.26 3130.57 3125.79 3121.63 3116.31 3111.63 3107.10 3104.81 3105.71 3109.24 3115.08 3121.58 3127.52 3133.37 3139.60 3142.89 3140.99 3136.79 3133.34 3128.96 3123.66 3118.49 3112.07 3104.41 3098.18 3095.64 3097.16 3098.85 3099.44 3099.45 3099.44 3099.69 3098.74 3097.22 3093.92 3089.31 3087.07 3086.90 3087.36 3087.95 5935433.15 5935337.71 5935243.09 5935147.65 5935052.92 5934958.57 5934863.72 5934769.56 5934673.97 5934580.78 5934487.77 5934389.65 5934294.38 5934200.50 5934103.47 5934007.91 5933924.51 5933818.58 5933724.18 5933631.38 5933534.43 5933439.38 5933345.03 5933249.52 5933154.70 5933059.01 5932966.84 5932870.75 5932776.71 5932679.98 5932584.97 5932490.04 5932394.64 5932301.28 5932204.23 5932109.57 5932015.16 5931919.94 5931824.78 5931729.89 5931634.76 5931539.58 5931444.52 5931350.15 5931255.44 5931159.72 5931065.14 5930969.42 5930874.50 5930779.99 5930685.14 5930590.00 5930495.05 ivlapE Tool ft 562115.09 MWD+IFR-AK-CAZ-SC 562119.50 MWD+IFR-AK-CAZ-SC 562123.30 MWD+IFR-AK-CAZ-SC 562125.59 MWD+IFR-AK-CAZ-SC 562128.57 MWD+IFR-AK-CAZ-SC 562134.20 MWD+IFR-AK-CAZ-SC 562140.04 MWD+IFR-AK-CAZ-SC 562144.89 MWD+IFR-AK-CAZ-SC 562148.91 MWD+IFR-AK-CAZ-SC 562151.81 MWD+IFR-AK-CAZ-SC 562152.65 MWD+IFR-AK-CAZ-SC 562152.21 MWD+IFR-AK-CAZ-SC 562151.34 MWD+IFR-AK-CAZ-SC 562148.82 MWD+IFR-AK-CAZ-SC 562144.89 MWD+IFR-AK-CAZ-SC 562140.86 MWD+IFR-AK-CAZ-SC 562137.35 MWD+IFR-AK-CAZ-SC 562132.86 MWD+IFR-AK-CAZ-SC 562128.92 MWD+IFR-AK-CAZ-SC 562125.12 MWD+IFR-AK-CAZ-SC 562123.58 MWD+IFR-AK-CAZ-SC 562125.23 MWD+IFR-AK-CAZ-SC 562129.50 MWD+IFR-AK-CAZ-SC 562136.09 MWD+IFR-AK-CAZ-SC 562143.33 MWD+IFR-AK-CAZ-SC 562150.01 MWD+IFR-AK-CAZ-SC 562156.59 MWD+IFR-AK-CAZ-SC 562163.57 MWD+IFR-AK-CAZ-SC 562167.60 MWD+IFR-AK-CAZ-SC 562166.46 MWD+IFR-AK-CAZ-SC 562163.00 MWD+IFR-AK-CAZ-SC 562160.29 MWD+IFR-AK-CAZ-SC 562156.66 MWD+IFR-AK-CAZ-SC 562152.09 MWD+IFR-AK-CAZ-SC 562147.68 MWD+IFR-AK-CAZ-SC 562142.00 MWD+IFR-AK-CAZ-SC 562135.08 MWD+IFR-AK-CAZ-SC 562129.59 MWD+IFR-AK-CAZ-SC 562127.80 MWD+IFR-AK-CAZ-SC 562130.06 MWD+IFR-AK-CAZ-SC 562132.50 MWD+IFR-AK-CAZ-SC 562133.83 MWD+IFR-AK-CAZ-SC 562134.59 MWD+IFR-AK-CAZ-SC 562135.31 MWD+IFR-AK-CAZ-SC 562136.31 MWD+IFR-AK-CAZ-SC 562136.10 MWD+IFR-AK-CAZ-SC 562135.32 MWD+IFR-AK-CAZ-SC 562132.77 MWD+IFR-AK-CAZ-SC 562128.91 MWD+IFR-AK-CAZ-SC 562127.41 MWD+IFR-AK-CAZ-SC 562127.98 MWD+IFR-AK-CAZ-SC 562129.18 MWD+IFR-AK-CAZ-SC 562130.51 MWD+IFR-AK-CAZ-SC Sys T1'D N/S E/y~' MapN ft ft ft ft • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 6/13/2007 Time: 14;54:18 Page: 5 Field: Kuparuk River Unit Co-or dinate(NE) Reference: Well: 1 J-135, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-135L1: 122.5 Nell: 1J-135 Sectio n (VS)Reference: Well (O.OON,O.OOE,180AOAzi) ~'1'ellpath: 1J-135L1 Sun~e y Cakufation 1lethod: __ Minimum Curvature Db: Oracle tiurvc~ __ __ 11D Iucl Aim TVD Sys TVD Lv/S @/~V AIapN ivtapE Tool ft deg dw3 ft ft ft ft ft ft 17293.27 90.58 179.76 3430.33 3307.83 -15022.30 3088.37 5930400.86 562131.67 MWD+IFR-AK-CAZ-SC 17388.13 92.94 179.13 3427.41 3304.91 -15117.10 3089.29 5930306.07 562133.33 MWD+IFR-AK-CAZ-SC I. 17483.34 89.84 178.98 3425.11 3302.61 -15212.26 3090.86 5930210.94 562135.64 MWD+IFR-AK-CAZ-SC ~ 17575.82 91.43 182.36 3424.08 3301.58 -15304.71 3089.78 5930118.49 562135.29 MWD+IFR-AK-CAZ-SC 17671.37 91.14 181.70 3421.94 3299.44 -15400.18 3086.39 5930023.01 562132.65 MWD+IFR-AK-CAZ-SC 17769.46 90.65 181.74 3420.41 3297.91 -15498.21 3083.45 5929924.97 562130.47 MWD+IFR-AK-CAZ-SC 17864.50 89.79 181.41 3420.04 3297.54 -15593.21 3080.84 5929829.96 562128.61 MWD+IFR-AK-CAZ-SC 17904.53 89.91 182.01 3420.15 3297.65 -15633.23 3079.64 5929789.94 562127.72 MWD+IFR-AK-CAZ-SC ,, 17935.00 89.91 182.01 3420.19 F 3297.69 -15663.68 3078.57 5929759.49 °' 562126.89 ~ PROJECTED to TD • Halliburton Company Survey Report __ ' Company: ConoCDPhillips Alaska Inc. __ - Date: 6/13!2007 _ Time: 14:33:49 Page: 1 Field: Kuparuk River Unit Co-ordinate(t\'E) Reference: Well: 1J-135, Tr ue North Site: Kuparuk 1J Pad Vertical (CV U) Reference: 1J-135L1P81: 1 22.5 Well: 1 J-135 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1 J-135L1 PB1 Survey. Calenlation Method: Minimum Curva ture Ub: Oracle Field: Ku aruk River Unit P I North Slope Alaska I ~ United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1 J-135 Slot Name: ell Position: +N/-S -523.65 ft Northing: 5945397.09 ft Latitude: 70 15 41.108 N +E/-W 132.13 ft Easting : 558926.15 ft Longitude: 149 31 25.162 W Position Uncertainty: 0.00 ft ~ellpath: 1J-135L1P61 Drilled From: 1J-135 ! 500292334970 Tie-on Depth: 9086.87 ft Current Datum: 1 J-135L1 PB1: Height 122.50 ft Above System Datum: Mean Sea Level Magnetic Data: 4/7/2007 Declination: 23.56 deg Field Strength: 57621 nT Mag Dip Angle: 80.82 deg I Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft 41.40 ft 0.00 ft 0.00 deg 180.00 j Survey Program for Definitive Wellpath Date: 6/13/2007 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft 104.00 836.00 1J-135 gyro (104.00-836.00) (2 CB-GYRO-SS` Camera based gyro single shot 877.39 9086.87 1J-135 (877.39-17706.10) (2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 9086.87 11159.42 1J-135L1 P61 (9086. 87-11159.42) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey ... . NID incl Aciw TVU Stis"1'VD ~~/S E/W IVfapN MapE loo{ ft deg deg ft ft ft ft ft ft 41.40 0.00 0.00 41.40 -81.10 0.00 0.00 5945397.09 558926.15 TIE LINE 1 104.00 0.15 49.37 104.00 -18.50 0.05 0.06 5945397.14 558926.21 CB-GYRO-SS '' 204.00 0.27 345.24 204.00 81.50 0.37 0.10 5945397.46 558926.25 CB-GYRO-SS 304.00 0.97 8.61 303.99 181.49 1.43 0.17 5945398.52 558926.31 CB-GYRO-SS i 404.00 0.48 14.03 403.98 281.48 2.67 0.40 5945399.77 558926.53 CB-GYRO-SS 490.00 0.62 128.00 489.98 367.48 2.74 0.85 5945399.83 558926.98 CB-GYRO-SS 590.00 3.21 167.67 589.92 467.42 -0.33 1.87 5945396.77 558928.03 CB-GYRO-SS 660.00 6.04 179.53 659.69 537.19 -5.93 2.32 5945391.18 558928.52 CB-GYRO-SS 750.00 10.35 190.39 748.75 626.25 -18.62 0.90 5945378.48 558927.20 CB-GYRO-SS 836.00 13.54 192.07 832.88 710.38 -36.07 -2.60 5945361.00 558923.84 CB-GYRO-SS 877.39 14.06 186.38 873.08 750.58 -45.81 -4.17 5945351.26 558922.34 MWD+IFR-AK-CAZ-SC 972.10 17.03 178.69 964.32 841.82 -71.11 -5.13 5945325.95 558921.58 MWD+IFR-AK-CAZ-SC 1066.14 22.67 174.48 1052.74 930.24 -102.95 -3.07 5945294.13 558923.89 MWD+IFR-AK-CAZ-SC 1161.80 24.65 168.79 1140.37 1017.87 -140.87 2.58 5945256.26 558929.84 MWD+IFR-AK-CAZ-SC 1256.42 27.32 165.35 1225.42 1102.92 -181.25 11.91 5945215.96 558939.48 MWD+IFR-AK-CAZ-SC 1353.43 30.42 156.52 1310.40 1187.90 -225.34 27.34 5945171.99 558955.25 MWD+IFR-AK-CAZ-SC 1449.50 34.95 151.63 1391.25 1268.75 -271.89 50.12 5945125.62 558978.39 MWD+IFR-AK-CAZ-SC 1544.36 39.40 150.90 1466.82 1344.32 -322.13 77.69 5945075.61 559006.35 MWD+IFR-AK-CAZ-SC 1639.12 42.27 149.15 1538.51 1416.01 -375.78 108.66 5945022.21 559037.74 MWD+IFR-AK-CAZ-SC 1731.22 46.22 148.58 1604.47 1481.97 -430.77 141.89 5944967.49 559071.39 MWD+IFR-AK-CAZ-SC i 1829.23 48.60 148.84 1670.80 1548.30 -492.43 179.36 5944906.13 559109.34 MWD+IFR-AK-CAZ-SC 1924.09 51.44 149.71 1731.74 1609.24 -554.91 216.49 5944843.94 559146.95 MWD+IFR-AK-CAZ-SC 2019.30 56.06 149.30 1788.02 1665.52 -621.05 255.45 5944778.12 559186.42 MWD+IFR-AK-CAZ-SC 2112.70 63.18 154.09 1835.25 1712.75 -691.97 293.50 5944707.50 559225.03 MWD+IFR-AK-CAZ-SC 2207.28 66.41 156.23 1875.53 1753.03 -769.62 329.42 5944630.14 559261.55 MWD+IFR-AK-CAZ-SC 2304.78 71.28 156.77 1910.70 1788.20 -852.99 365.66 5944547.07 559298.44 MWD+IFR-AK-CAZ-SC I ' 2399.24 73.90 157.30 1938.96 1816.46 -935.97 400.83 5944464.38 559334.25 MWD+IFR-AK-CAZ-SC 2493.74 73.23 157.95 1965.70 1843.20 -1019.78 435.33 5944380.84 559369.40 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report ('ompany: ConocoPhillips Alaska Inc. llate: 6/13/2007 Time: 14:33:49 Pale: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-135, True North Site: KuparuklJPad Vertical (TVD)Reference: 1J-135LiPB1: 122.5 Nell: 1J-135 Section (~'S) Keference: Well (O.OON,O.OOE,180.OOAzi) W'ellpath: 1J-135L1 PB1 Survey Calculation Method: Minimum Curvature Dh: Oracle Survev 1fiD Incl Azim TVD Sys TVD N/S E/~V MapN ~1apF Tool 1 ft deg deg ft ft f[ ff ft ft ~! 2589.04 73.02 155.79 1993.37 1870.87 -1103.64 471.15 5944297.27 559405.88 MWD+IFR-AK-CAZ-SC 2684.10 75.92 154.75 2018.82 1896.32 -1186.82 509.47 5944214.41 559444.84 MWD+IFR-AK-CAZ-SC 2779.50 76.26 154.79 2041.75 1919.25 -1270.59 548.94 5944130.96 559484.96 MWD+IFR-AK-CAZ-SC ~~ 2874.33 76.89 155.81 2063.77 1941.27 -1354.39 587.48 5944047.47 559524.15 MWD+IFR-AK-CAZ-SC 2969.94 75.61 153.53 2086.50 1964.00 -1438.32 627.20 5943963.86 559564.53 MWD+IFR-AK-CAZ-SC 3063.12 75.51 152.63 2109.73 1987.23 -1518.78 668.06 5943883.73 559606.01 MWD+IFR-AK-CAZ-SC 3158.23 75.53 152.86 2133.51 2011.01 -1600.65 710.23 5943802.21 559648.81 MWD+IFR-AK-CAZ-SC 3253.33 73.01 152.92 2159.29 2036.79 -1682.12 751.94 5943721.07 559691.16 MWD+IFR-AK-CAZ-SC 3349.13 75.81 153.50 2185.04 2062.54 -1764.48 793.52 5943639.04 559733.38 MWD+IFR-AK-CAZ-SC 3430.38 73.89 153.16 2206.27 2083.77 -1834.56 828.72 5943569.24 559769.12 MWD+IFR-AK-CAZ-SC 3476.12 73.42 151.99 2219.14 2096.64 -1873.52 848.94 5943530.45 559789.64 MWD+IFR-AK-CAZ-SC 3571.21 76.13 152.53 2244.11 2121.61 -1954.72 891.64 5943449.59 559832.97 MWD+IFR-AK-CAZ-SC 3665.99 74.72 152.44 2267.96 2145.46 -2036.07 934.01 5943368.58 559875.98 MWD+IFR-AK-CAZ-SC 3760.70 74.65 153.47 2292.98 2170.48 -2117.43 975.55 5943287.56 559918.14 MWD+IFR-AK-CAZ-SC 3854.86 74.28 154.06 2318.20 2195.70 -2198.80 1015.65 5943206.51 559958.88 MWD+IFR-AK-CAZ-SC 3950.50 75.24 154.47 2343.34 2220.84 -2281.93 1055.72 5943123.71 559999.59 MWD+IFR-AK-CAZ-SC 4045.69 74.27 154.76 2368.37 2245.87 -2364.90 1095.09 5943041.06 560039.61 MWD+IFR-AK-CAZ-SC i I 4140.32 74.66 156.13 2393.71 2271.21 -2447.82 1132.98 5942958.44 560078.14 MWD+IFR-AK-CAZ-SC '~ 4235.60 75.86 158.41 2417.96 2295.46 -2532.81 1168.57 5942873.75 560114.39 MWD+IFR-AK-CAZ-SC 4330.90 75.22 158.17 2441.75 2319.25 -2618.54 1202.71 5942788.29 560149.19 MWD+IFR-AK-CAZ-SC 4426.87 74.84 157.06 2466.55 2344.05 -2704.27 1238.01 5942702.85 560185.17 MWD+IFR-AK-CAZ-SC 4522.05 74.90 156.35 2491.39 2368.89 -2788.66 1274.35 5942618.76 560222.16 MWD+IFR-AK-CAZ-SC ~ 4615.70 75.87 155.26 2515.02 2392.52 -2871.31 1311.49 5942536.40 560259.94 MWD+IFR-AK-CAZ-SC 4711.45 74.66 153.98 2539.37 2416.87 -2954.97 1351.18 5942453.06 560300.28 MWD+IFR-AK-CAZ-SC II 4807.09 75.88 153.98 2563.69 2441.19 -3038.09 1391.75 5942370.27 560341.50 MWD+IFR-AK-CAZ-SC 4901.2 7 153.38 .2 2463.76 - 14 2.2 4 560382.7 MWD+IFR-AK-CAZ-SC 5 6 38 2586 6 3120.03 3 8 59 2288.66 6 4996.87 76.11 152.76 2609.00 2486.50 -3202.84 1474.35 5942206.20 560425.37 MWD+IFR-AK-CAZ-SC 5092.56 75.67 153.45 2632.33 2509.83 -3285.60 1516.33 5942123.77 560467.99 MWD+IFR-AK-CAZ-SC 5187.78 74.47 153.42 2656.86 2534.36 -3367.89 1557.47 5942041.81 560509.78 MWD+IFR-AK-CAZ-SC 5282.86 74.22 154.26 2682.52 2560.02 -3450.07 1597.84 5941959.96 560550.78 MWD+IFR-AK-CAZ-SC 5377.84 74.34 155.17 2708.25 2585.75 -3532.73 1636.89 5941877.61 560590.47 MWD+IFR-AK-CAZ-SC 47 .11 1 - 6 MWD+IFR-AK-CAZ- 5 2.88 74.78 155 2733.55 261 .05 3615.85 1675.40 5941794.80 560 29.63 SC 5568.00 75.81 155.35 2757.70 2635.20 -3699.39 1713.95 5941711.58 560668.83 MWD+IFR-AK-CAZ-SC I 5663.14 76.25 154.98 2780.67 2658.17 -3783.18 1752.72 5941628.10 560708.25 MWD+IFR-AK-CAZ-SC 5762.04 75.53 154.23 2804.78 2682.28 -3869.83 1793.86 5941541.79 560750.06 MWD+IFR-AK-CAZ-SC 5853.10 75.16 154.41 2827.81 2705.31 -3949.22 1832.03 5941462.70 560788.85 MWD+IFR-AK-CAZ-SC 5941.89 74.91 154.95 2850.74 2728.24 -4026.76 1868.72 5941385.46 560826.14 MWD+IFR-AK-CAZ-SC 6045.41 75.36 154.21 2877.30 2754.80 -4117.13 1911.67 5941295.44 560869.79 MWD+IFR-AK-CAZ-SC 6139.32 74.98 154.62 2901.34 2778.84 -4199.01 1950.87 5941213.88 560909.63 MWD+IFR-AK-CAZ-SC 6233.85 74.79 154.91 2925.99 2803.49 -4281.56 1989.78 5941131.64 560949.18 MWD+IFR-AK-CAZ-SC ~ 6328.51 74.61 154.62 2950.96 2828.46 -4364.15 2028.71 5941049.37 560988.75 MWD+IFR-AK-CAZ-SC 6422.91 74.79 155.42 2975.87 2853.37 -4446.69 2067.16 5940967.14 561027.84 MWD+IFR-AK-CAZ-SC 6517.50 75.05 155.07 3000.48 2877.98 -4529.62 2105.40 5940884.51 561066.73 MWD+IFR-AK-CAZ-SC 6613.03 75.24 155.23 3024.97 2902.47 -4613.41 2144.21 5940801.04 561106.18 MWD+IFR-AK-CAZ-SC 670.0 75.36 156.01 9.20 2926.70 -4 7. 2 2182.32 40717.24 561144.95 MWD IFR-AK-CAZ-SC 8 5 304 69 5 59 0 7 1 .2 2 .30 1 4 5611 12 MWD IFR-AK-CAZ SC 68 2.49 5.56 55 8 3072.80 950 4780.40 22 9.8 5940634.66 83. - - 6897.56 74.91 154.43 3097.03 2974.53 -4863.62 2258.90 5940551.76 561222.82 MWD+IFR-AK-CAZ-SC 6992.34 74.54 153.53 3122.00 2999.50 -4945.79 2299.01 5940469.92 561263.57 MWD+IFR-AK-CAZ-SC 7087.72 74.60 154.99 3147.38 3024.88 -5028.60 2338.94 5940387.43 561304.14 MWD+IFR-AK-CAZ-SC 7182.84 75.94 156.22 3171.56 3049.06 -5112.38 2376.93 5940303.96 561342.78 MWD+IFR-AK-CAZ-SC 7278.62 76.05 156.44 3194.74 3072.24 -5197.50 2414.24 5940219.14 561380.75 MWD+IFR-AK-CAZ-SC 7373.83 76.36 155.99 3217.44 3094.94 -5282.11 2451.53 5940134.84 561418.70 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Ina Date: 6/13/2007 Time: 14:33:49 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-135, True North Site: Kuparuk 1J Pad Vertical (TVD)Reference: 1J-135L1PB1:122.5 Well: 1J-135 Section (VS) Reference: Well (O.OON,O.OOE,180AOAzi) ~4'ellpath: 1 J-135L1 PB1 Survey Calculation 'Method: Minimum Curvature Db: Oracle __ ___ Survey __ ', MD Incl Azim TVD Sys T~'D ~/S E/V1' D1apY MapE Tool ft deg deg ft ft ft ft ft ft 7468.42 76.51 155.66 3239.63 3117.13 -5365.99 2489.19 5940051.25 561457.01 MWD+IFR-AK-CAZ-SC 7563.85 76.83 155.13 3261.63 3139.13 -5450.42 2527.85 5939967.14 561496.33 MWD+IFR-AK-CAZ-SC 7658.87 78.28 152.78 3282.11 3159.61 -5533.77 2568.59 5939884.12 561537.72 MWD+IFR-AK-CAZ-SC 7753.94 76.58 153.44 3302.80 3180.30 -5616.53 2610.56 5939801,70 561580.33 MWD+IFR-AK-CAZ-SC 7848.52 78.54 154.50 3323.18 3200.68 -5699.51 2651.09 5939719.04 561621.50 MWD+IFR-AK-CAZ-SC 7944.52 80.41 155.00 3340.71 3218.21 -5784.88 2691.34 5939634.00 561662.42 MWD+IFR-AK-CAZ-SC ', j 8039.59 79.41 154.78 3357.37 3234.87 -5869.63 2731.06 5939549.57 561702.79 MWD+IFR-AK-CAZ-SC 8135.58 79.22 155.38 3375.16 3252.66 -5955.17 2770.81 5939464.35 561743.20 MWD+IFR-AK-CAZ-SC 8230.04 81.79 156.36 3390.75 3268.25 -6040.19 2808.89 5939379.64 561781.94 MWD+IFR-AK-CAZ-SC 8324.93 81.35 154.46 3404.66 3282.16 -6125.54 2847.94 5939294.61 561821.66 MWD+IFR-AK-CAZ-SC 8420.20 80.91 153.81 3419.35 3296.85 -6210.24 2889.01 5939210.24 561863.39 MWD+IFR-AK-CAZ-SC 8515.46 80.72 154.49 3434.55 3312.05 -6294.87 2930.01 5939125.95 561905.04 MWD+IFR-AK-CAZ-SC 8610.32 80.96 158.30 3449.66 3327.16 -6380.67 2967.50 5939040.45 561943.20 MWD+IFR-AK-CAZ-SC 8705.63 80.84 161.67 3464.74 3342.24 -6469.08 2999.71 5938952.30 561976.10 MWD+IFR-AK-CAZ-SC ~j 8800.15 80.59 162.91 3479.99 3357.49 -6557.94 3028.09 5938863.68 562005.17 MWD+IFR-AK-CAZ-SC 8895.48 80.79 163.69 3495.41 3372.91 -6648.04 3055.12 5938773.79 562032.90 MWD+IFR-AK-CAZ-SC 8990.86 80.60 164.92 3510.83 3388.33 -6738.66 3080.58 5938683.39 562059.07 MWD+IFR-AK-CAZ-SC i 9086.87 80.53 169.44 3526.58 3404.08 -6830.98 3101.59 5938591.24 562080.80 MWD+IFR-AK-CAZ-SC 9097.00 80.71 169.78 3528.23 3405.73 -6840.81 3103.39 5938581.43 562082.68 MWD+IFR-AK-CAZ-SC 9149.61 83.49 170.81 3535.46 3412.96 -6892.17 3112.17 5938530.14 562091.86 MWD+IFR-AK-CAZ-SC 9212.09 84.64 172.02 3541.92 3419.42 -6953.62 3121.45 5938468.78 562101.61 MWD+IFR-AK-CAZ-SC 9307.23 88.15 173.84 3547.90 3425.40 -7047.83 3133.13 5938374.67 562114.03 MWD+IFR-AK-CAZ-SC 9400.62 89.82 172.56 3549.56 3427.06 -7140.54 3144.19 5938282.05 562125.81 MWD+IFR-AK-CAZ-SC 9500.86 91.48 172.69 3548.42 3425.92 -7239.94 3157.05 5938182.77 562139.45 MWD+IFR-AK-CAZ-SC 9591.06 90.53 174.68 3546.84 3424.34 -7329.58 3166.97 5938093.22 562150.07 MWD+IFR-AK-CAZ-SC 9686.52 89.85 176.20 3546.52 3424.02 -7424.73 3174.56 5937998.14 562158.41 MWD+IFR-AK-CAZ-SC 9781.31 89.60 178.77 3546.98 3424.48 -7519.42 3178.72 5937903.49 562163.30 MWD+IFR-AK-CAZ-SC 9878.04 92.32 182.40 3545.36 3422.86 -7616.11 3177.73 5937806.81 562163.08 MWD+IFR-AK-CAZ-SC i 9972.54 92.32 184.49 3541.53 3419.03 -7710.35 3172.06 5937712.53 562158.14 MWD+IFR-AK-CAZ-SC i 10068.28 90.40 184.80 3539.26 3416.76 -7805.75 3164.31 5937617.09 562151.14 MWD+IFR-AK-CAZ-SC 10163.15 90.96 184.65 3538.13 3415.63 -7900.29 3156.50 5937522.50 562144.06 MWD+IFR-AK-CAZ-SC 10258.41 90.77 185.00 3536.69 3414.19 -7995.20 3148.48 5937427.54 562136.80 MWD+IFR-AK-CAZ-SC 10352.03 90.84 184.16 3535.38 3412.88 -8088.51 3141.01 5937334.18 562130.05 MWD+IFR-AK-CAZ-SC 10447.19 90.47 179.38 3534.29 3411.79 -8183.59 3138.07 5937239.09 562127.86 MWD+IFR-AK-CAZ-SC 10544.37 91.81 179.77 3532.36 3409.86 -8280.75 3138.79 5937141.95 562129.34 MWD+IFR-AK-CAZ-SC 10639.60 92.07 178.79 3529.13 3406.63 -8375.91 3139.99 5937046.81 562131.28 MWD+IFR-AK-CAZ-SC 10734.91 91.82 179.98 3525.90 3403.40 -8471.16 3141.01 5936951.58 562133.05 MWD+IFR-AK-CAZ-SC 10829.27 93.53 179.79 3521.49 3398.99 -8565.42 3141.20 5936857.34 562133.97 MWD+IFR-AK-CAZ-SC 10923.76 93.93 179.19 3515.35 3392.85 -8659.70 3142.04 5936763.07 562135.55 MWD+IFR-AK-CAZ-SC 11019.53 92.87 179.82 3509.67 3387.17 -8755.30 3142.86 5936667.49 562137.12 MWD+IFR-AK-CAZ-SC !~ 11114.69 94.27 179.42 3503.74 3381.24 -8850.27 3143.49 5936572.54 562138.50 MWD+IFR-AK-CAZ-SC 11159.42 95.13 178.84 3500.08 3377.58 -8894.84 3144.17 5936527.98 562139.52 MWD+IFR-AK-CAZ-SC 11190.00 95.13 178.84 3497.34 3374.84 -8925.29 3144.79 5936497.53 562140.38 PROJECTED to TD • • Time Lo s Date From To Dur S: De th E. De th° Phase Code ` Subcode T COM 04!29/2007 01:30 03:00 1.50 92 92 PROD1 DRILL PULD P Plug in and download MWD assembl . 03:00 04:00 1.00 92 0 PROD1 DRILL PULD P Continue breakout & lay down BHA. Ins ect & rade bit to 04:00 05:00 1.00 0 0 COMPZ DRILL PULD P Clear & clean rig floor area of tools and OBM. Held PJSM with crew, & GBR reps. Discuss safety & hazard recognition issues. Discuss procedure to run 5 1/2" slotted liner. Rig up GBR casing equipment for running 5 1/2" slotted liner. Double check liner e uipment & runnin order. 05:00 06:00 1.00 0 1,323 COMPZ CASINC RURD P Make up Silver bullet guide shoe & joint. Continue R!H with 5 1/2" Slotted BTC liner to 1323'. Make up torque = 5k Ft/Lbs. Crew Chan e 06:00 13:30 7.50 1,323 8,455 COMPZ CASINC RNCS P Continue RIH with 5 1/2" Slotted BTC liner from 1323' - 8455'. Make up torque = 5k Ft/Lbs. BTC with torque rings = 6K ft/Ibs. UP WT = 140K, SO WT - 100K. 13:30 14:30 1.00 8,455 8,455 COMPZ CASINC RNCS P Rig up smaller tools to make up inner strip .Monitor well -static. 14:30 15:30 1.00 8,455 8,500 COMPZ CASINC RNCS P Make up liner running & setting tools as per BOT rep & Sperry sun reps. Orient MWD to liner hap er. 15:30 15:45 0.25 8,500 8,500 COMPZ CASINC RURD P Rig down GBR casing running equipment. Clear & clean rig floor of tools and OBM. 15:45 18:00 2.25 8,500 9,803 COMPZ CASINC RUNL P Continue RIH with 5 1/2" slotted liner form 8500' - 9803'. perform shallow pulse test. Good @ 2.7 BPM - 350 GPM's. Obtain T&D parameters as per rig engineer every 5 stands. Crew Chan e 18:00 22:30 4.50 9,803 13,767 COMPZ CASINC RUNL P Continue RIH with 5 1/2" slotyted liner form 9803' -13767'. Ran out of down weight. Obtain T&D parameters as per rig engineer every 10 stands. Observed proper hole fill. Running speed with DP = 90 seconds /stand as er BOT re . 22:30 00:00 1.50 13,767 14,740 COMPZ CASINC RUNL P Make top drive connection & begin rotating 5 112" slotted liner in the hole from 13767' - 14740'. Continue obtain T&D parameters as per rig engineer every 10 stands.`Observed correct hole fill. 04/30/2007 00:00 04:30 4.50 14,740 17,722 COMPZ CASINC RUNL P Continue rotating 5 1/2" slotted liner in the hole from 14740' to tag bottom at 17741'. Continue obtain T&D parameters as per rig engineer every 10 stands. Observed correct hole fill. Pull up to set liner top on depth as per detail with liner to 9167'. page 76 of 41 , • • Time Logs. , Date' From To Dur S. De th E. De th Phase Code ' Subcode - T COM 04/30/2007 04:30 05:00 0.50 17,722 17,722 COMPZ CASINC CIRC P Work torque out of drill string to observe oriented Liner hanger to 1 degree left. Pumps @ 3 BPM - 650 PSI. UP WT = 235K, SO wt = O. ROT WT = 130K. 05:00 06:00 1.00 17,722 17,722 COMPZ CASINC CIRC P Break connection & drop 1 3/4" ball down drill string. Pump down at 3 BPM - 650 PSI. Crew Chan e 06:00 07:30 1.50 17,722 8,830 COMPZ CASINC CIRC P Continue pump 1 3/4" Ball down drill string to observe ball landed in 1270 stks. Slack off weoight to 72K. Pressure to 3000 PSI. Pressure to 3430 PSI observing pressure fall off suddenly with flow in the stack. Close pipe rams. Pump down kill line to obtain a test on the MLZXP to 2500 PSI for 5 minutes. NOTE. Pump strokes indicated pressuring the DP a!so through the setting tools. ~Iled pressures. open rams. Pull up to attempt to pull free. No Go. Pull up to 100K over rested times. Work left hand torque down to tool to safety off of assembly. Pull 5 stands. Monitor well -static. 07:30 07:45 0.25 8,830 8,830 COMPZ RIGMN SFTY P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure for slip,& cut drillin line. 07:45 09:15 1.50 8,830 8,830 COMPZ RIGMN SVRG P Slip & cut 131' of drilling line. Inspect & adjust brakes on draw works. Service auto driller & crown o matic. 09:15 10:15 1.00 8,830 8,830 COMPZ RIGMN SVRG P Inspect & service Top Drive & travelling equipment. SIMOPS: Pump 160 BBLS of Freeze protect diesel down OA with Little Red services @ 2 BPM - 775 PSI. Final shut in pressure = 320 PSI. 10:15 10:30 0.25 8,830 8,830 COMPZ RIGMN SVRG P Replace 1 1/4" Oil hose on Top drive for the oil um . 10:30 12:00 1.50 8,830 5,597 COMPZ CASINC RUNL P POOH on elevators from 8830' - 5597. Observed correct hole fill. 12:00 14:30 2.50 5,597 0 COMPZ CASINC RUNL P Continue POOH on elevators from 5597 -running & setting tools. Observed correct hole fill. 14:30 15:15 0.75 0 0 COMPZ CASINC RURD P Inspect, breakout & lay down setting & runnin tools. 15:15 16:00 0.75 0 0 COMPZ CASINC OTHR P Clear & clean floor area from tools & OBM. Change out air boot in Bell ni le for SPCC control. 16:00 16:15 0.25 0 0 PROD2 STK OTHR P Held PJSM with crew, BOT & Sperry Sun reps. Discuss safety & hazard recognition issues. Discuss procedure to make up & run New whipstock assembly with ML Anchor assembly & orientation of same to MWD. Page 17 of 41 • Time Logs .Date From To Dur S. De th E. De th Phase Code Subcode T COM 04/30/2007 16:15 18:00 1.75 0 0 PROD2 STK PULD P Make up ML Whipstock assembly with new ML anchor & seals. Orient whipstock face with ML anchor latch. Crew Chan e 18:00 20:30 2.50 0 0 PROD2 STK PULD P Continue make up whipstock assembly as per BOT reps. Make up mills with a 8 1/2" Pathmaker starting mill. orient MWD to whipstock slide as per Sper Sun re s. 20:30 21:00 0.50 0 0 PROD2 STK PULD P Plug in and upload MWD assembly. 21:00 21:45 0.75 0 290 PROD2 STK PULD P Continue make up remaining BHA with bumperjar, and drill collars. Total BHA len th = 290.39'. 21:45 22:00 0.25 290 290 PROD2 STK TRIP P TIH with 1 stand of DP. perform shallow pulse test on MWD tools with 490 GPM"S - 850 PSI. Good test. 22:00 00:00 2.00 290 3,621 PROD2 STK _ TRIP P Trip in hole with whipstock assembly fi um 290' - 3621' at 90 seconds i stand as per BOT rep. Observe proper hole fill. Fill drill string every 25 stands. 05/01/2007 00:00 03:00 3.00 3,621 8,039 PROD2 STK TRIP P Continue trip in hole with whipstock assembly from 3621' - 8039 at 90 seconds /stand as per BOT rep. Observe proper hole fill. Fill drill string eve 25 stands. 03:00 04:15 1.25 8,039 8,164 PROD2 STK OTHR P Perform MAD PASS from 8039' - 8164' DPM @ 180 ft/min. Perform test on tools with circulation rates, obsrerving low rate at 440 GPMs- 1530 PSI. 04:15 04:30 0.25 8,164 8,661 PROD2 STK TRIP P Continue trip in hole with whipstock assembly from 8164' - 8661 at 90 seconds /stand as per BOT rep. Observe roper hole fill. 04:30 05:30 1.00 8,661 9,120 PROD2 STK WPST P Single in hole with 15 joints of 5" HWDP for extra down weight as per BOT rep from 8661' - 9120'. 05:30 06:00 0.50 9,120 9,180 PROD2 STK WPST P Pick up 1 more stand of DP & circulate @ 9120' to observe orientation of whipstock face to 44 deg right of high side. Slack off to tag & latch up into MLZXP packer @ 9180' DPM.Pumps @ 430 GPM's - 1650 PSI. UP WT = 220K, SO WT = 108K. Attempt to latch up into profile, and pick up several times to verify latch. Observed seals "hydraulically" preventing a good latch up. Crew Chan e Page ~8 of 41' • ~~~ ~C~ ®~ ~~ `~L Time Logs Date From To Dur S. De th E be th Phase Code `' Subcode T COM 05/01/2007 06:00 07:00 1.00 9,180 9,180 PROD2 STK WPST P Continue attempt to snap into profile, setting up to 28K downweight to observe snapped in and MWD orientation moving from 44 deg Right back to 33 Deg left. Pull up to 20K over to verify good latch up & orientation of whipstock. SIMOPS: Held PJSM with crew for OBM dis lacement. ~ 07:00 08:00 1.00 9,180 9,180 PROD2 STK CIRC P Displace well with 8.5 PPG OBM at ~ `~`~ 600 GPM's - 2000 PSI. NO movement ~ in drill string as we are still bolted up to whi stock. 08:00 08:30 0.50 9,180 9,180 PROD2 STK WPST P Shear 45K bolt with 3 attempts "slapping" the bolt with the bumper jar. Up movement indicated sheared off and free movement. UP WT = 205K, SO WT = 105, ROT WT = 155K with 1 Kt 08:30 12:00 3.50 9,097 9,104 PROD2 STK MILL P MITI window in 9 5/8" casing from 9097' - 9104'. WOB = 4K, RPM's = 120, Pum sat 450 GPM's - 1700 PSI. 12:00 15:15 3.25 9,104 9,137 PROD2 STK MILL P Continue mlll window in 9 5/8" casing from 9104' - 9113'. Mill in open hole from 9113' - 9137'.Total milling time = 6.12 HRS. WOB = 4K, RPM's = 120, Pumps at 450 GPM's - 1700 PSI. 15:15 16:00 0.75 9,137 9,137 PROD2 STK CIRC P Circulate out sweep in hole, while reciprocate & rotate drill string with mills to clean u window area. 16:00 16:45 0.75 9,137 8,947 PROD2 STK TRIP P Pull & rack back 1 stand of DP. Lay down sin le to shed. 16:45 18:00 1.25 8,947 8,947 PROD2 WELCT OTHR P Make up BOT 9 5/8" storm packer. RIH to set packer @ 68'. Release from packer. POOH. Close blind rams. Test packer to 500 PSI - 5 minutes. Good test. Crew than e 18:00 19:45 1.75 8,947 8,947 PROD2 WELCT OTHR P Rig up tools & BOLDS to pull wear bushing. Make up stack washing tool. RIH, flush BOP stack & lines of iron cuttin s. 19:45 00:00 4.25 8,947 8,947 PROD2 WELCT BOPE P Install test plug. Rig up test equipment & lines. Test BOP's & choke manifold. perform Koomey draw down test. 200 PSI increase in 54 seconds, with full pressure in 3 min, 18 seconds. 5 Nitrogen bottles with avg PSI of 2300 PSI. 05/02/2007 00:00 00:45 0.75 8,947 8,947 PROD2 WELCT BOPE P Pull test plug. Install wear bushing - RILDS. Blow down Choke & kill lines, and manifold. Witness of BOP test waived b AOGCC re -Jeff Jones. Page 19 of 41 ..f i Time Logs Date' From To Dur S. De th E. De th Phase Cade ` Subcode T COM 05/02/2007 00:45 02:00 1.25 8,947 8,930 PROD2 WELCT OTHR P Held PJSM with crew & BOT rep. Discuss safety & hazard recognition issues. Discuss procedure to retrieve storm packer & well control issues. Make up retrieving tool. RIH to 66', and screw into storm packer. Pull bypass open to verify no pressure. Release packe with 1 RH turn, pull to rig floor. Breakout & lay down storm packer assembl . 02:00 02:45 0.75 8,930 8,930 PROD2 STK OTHR P Make top drive connection. Pump down drill string to verify minimal flow test for MWD. pumps at 300 GPM's indicated too much noise & little detection. Pumps at 325 GPM's - indicated good pulses & detection but questionable. MWD rep recomends minimal rate @ 350 GPM's with good oulses & detection. 02:45 03:15 0.50 8,930 8,930 PROD2 STK OWFF P Monitor well -static. Pump dry job. 03:15 06:00 2.75 8,930 207 PROD2 STK TRIP P Trip out of hole with milling assembly from 8930' - 207'. Observed proper hole fill. Crew Chan e 06:00 08:30 2.50 207 0 PROD2 STK TRIP P Continue trip out of hole .Breakout, inspect & lay down milling assembly.Grade pathmaker mill to 010/NOlA/X/I/NO/TD. Send tools outside. 08:30 11:00 2.50 0 0 PROD2 RPCOti OTHR P Make up Baker FJD tool with tailpipe to the MWD. Perform test on FJD tool with 2 x 18's & 1 x 16"jets. pumps @ 350 GPM's - 850 PSI Good MWD Signal. Observed partial actuation of FJD tool @ 425 GPM @ 1240 PSI and Full actuation of tool w/ 450 GPM's - 1400 PSI. Shut down, Change out jets to 2 x 20's & 1 x 16. partial actuation @ 400 GPM @ 1100 PSI and Full actuation w/ 450 GPM's -1400 PSI. Test questionalble. Breakout & lay down FJD tools & tail i e. 11:00 11:45 0.75 0 0 PROD2 STK PULD P Plug in and download MWD assembl . 11:45 12:45 1.00 0 0 PROD2 DRILL PULD P Lay down DM asssembly from MWD. Make up new DM assembly. Make up GeoPilot & bit. Breakout & lay down Pulsar. Install new Pulsar assembly, and make u to BHA. 12:45 13:30 0.75 0 0 PROD2 DRILL PULD P Plug in and Upload MWD assembly. 13:30 14:00 0.50 0 0 PROD2 DRILL PULD P Make up ARD resisitivity & float sub to BHA. 14:00 14:45 0.75 0 0 PROD2 DRILL PULD P Plug in and Upload ARD assembly. Page 2Q of 41' ! ! Time Lo s Date - From To Dur S: De th E. De th Phase Code Subcode -T COM 05/02/2007 14:45 15:00 0.25 0 398 PROD2 DRILL PULD P Perform shallow [pulse test on MWD assembly. Good test. Total BHA = 398.28' 15:00 18:00 3.00 398 5,155 PROD2 DRILL TRIP P Trip in hole from 398' - 5155'. Fill drill string every 25 stands. Observed ro er hole fill. Crew Chan e 18:00 19:45 1.75 5,155 8,559 PROD2 DRILL TRIP P Continue trip in hole from 5155' - 8559'. Observed proper hole fill. Fill DP eve 25 stands. 19:45 20:15 0.50 8,559 8,559 PROD2 RIGMN' SVRG P Service Top Drive, Blocks & draw works. 20:15 21:00 0.75 8,559 9,137 PROD2 DRILL TRIP P Continue trip in hole from 8559' - 9137'. observed no issues with assembly through the whipstock. Pumps on at 2 BBLS minute. Pull back above window. Pumps @ 600 GPM's - 2650 PSI. Slack off through window verifying ABI inclination readin s. 21:00 21:30 0.50 9,137 9,137 PROD2 DRILL CIRC T Trouble shoot MWD problems. Observed poor detection. Gained detection b mode switchin . 21:30 22:00 0.50 9,137 9,165 PROD2 DRILL DDRL P Directional drill in the D lateral from 9137' - 9165'. ADT = .33 HRS. Observed poor detection again. Lost ABI surve s. 22:00 00:00 2.00 9,165 9,165 PROD2 DRILL CIRC T Pull drill string back into casing above window. Trouble shoot MWD and ABI problems. Continue with mode switching. Observed good ABI surveysahd good detection. Decision to continue drillin . 05/03/2007 00:00 00:45 0.75 9,165 9,165 PROD2 DRILL CIRC T Continue trouble shoot MWD assembl . 00:45 02:30 1.75 9,165 9,240 PROD2 DRILL DDRL P Continue directional drilling from 9165' - 9240'. observed questionable detection. ADT = .33 HRS. 02:30 03:15 0.75 9,240 9,054 PROD2 DRILL TRIP T POOH from 9240' - 9054'. Trouble shoot MWD. Lost ABI, gained it back, then bad detection. Got it back. 03:15 04:15 1.00 9,054 9,054 PROD2 DRILL OTHR T Check all surface equipment. Pull screens on pumps, check valves & seats. Check all manifold valves and perform a 3000 PSI surface test on all lines & e ui ment. 04:15 04:30 0.25 9,054 9,240 PROD2 DRILL TRIP T Trip in hole from 9054' - 9240'. 04:30 05:00 0.50 9,240 9,432 PROD2 DRILL DDRL P Continue drilling D lateral from 9240' - 9432'. Total ADT = 1.27 HRS. ECD = 9.78 PPG. Detection roblems a ain. 05:00 06:00 1.00 9,432 9,179 PROD2 DRILL TRiP T POOH from 9432' - 9179'. Take checkshots at 9336', 9241' and 9179'. Obtained ood surve s. Crew than e 06:00 06:15 0.25 9,179 9,432 PROD2 DRILL TRIP T TIH once again with good detection to 9432'. Page 21 of 41 • Time Logs I Date _ From _ To Dur S D~th E. Depth Phase Code Subcode T COM ___ 05/03/2007 06:15 06:45 0.50 9,432 9,539 PROD2 DRILL DDRL P Continue driectional drill in the D lateral from 9432' - 9539'. ADT = .34 HRS. Observed trouble with detection. Decision to POOH. 06:45 07:30 0.75 9,539 9,539 PROD2 DRILL CIRC T Retake check shot surveys for verification. Obtain survey @ 9527'. MD. 07:30 08:00 0.50 9,539 9,539 PROD2 DRILL OWFF T Monitor well -static. pump dry job. POOH from 9539' - 9097'. 08:00 08:15 0.25 9,539 9,539 PROD2 DRILL TRIP T Blow down Top drive & lines. Install stri in rubbers & air sli s. 08:15 11:00 2.75 9,539 410 PROD2 DRILL TRIP T POOH from 9097' - 410'. Observed correct hole fill. 11:00 11:30 0.50 410 398 PROD2 DRILL PULD T Breakout & lay down BHA to MWD. 11:30 12:00 0.50 398 398 PROD2 DRILL PULD T Plug in and download MWD &ARD tools. 12:00 13:00 1.00 398 398 PROD2 DRILL PULD T Breakout & lay down pulsar. Change out internal components, and make up same. 13:00 14:15 1.25 398 398 PROD2 DRILL PULD T Plug in and Upload MWD and ARD assemblies. Pull to bit. Inspect & rade same to 1/1MIT/GT/X/I/NO/DTF 14:15 14:45 0.50 398 398 PROD2 DRILL PULD T Make Top Drive connection. Perform shallow ulse test. Good test. 14:45 15:00 0.25 398 398 PROD2 DRILL PULD T Make up remaining BHA.FIex DC's & 'ars. 15:00 18:00 3.00 398 8,007 PROD2 DRILL TRIP T Trip in hole from 398' - 8007'. Observed correct hole fill, and fill drill string every 25 stands. Crew Chan e 18:00 18:45 0.75 8,007 9,539 PROD2 DRILL TRIP T Continue trip in hole from 8007' - 9539': Observed clean hole and no issues when assembly going through whi stock area. 18:45 19:00 0.25 9,539 9,539 PROD2 DRILL CIRC T Obtain drilling parameters as per DD. Get ood PWD baseline readin s. 19:00 00:00 5.00 9,539 10,222 PROD2 DRILL DDRL P Continue driectional drill 8 1/2" hole in the D lateral from 9539' - 10222' MD. TVD = 3537'. ADT = 2.81 HRS. ECD = 10.28 PPG. 05/04/2007 00:00 04:30 4.50 10,222 10,825 PROD2 DRILL DDRL P Continue directional drill 8 1/2" hole in the D lateral from 10222' - 10825' MD. ADT = 2.58 HRS. ECD = 10.40 PPG. 04:30 06:00 1.50 10,825 11,050 PROD2 DRILL DDRL P Continue directional drill 8 1/2" hole in the D lateral from 10825' - 11050' MD. TVD = 3506'. ADT = 1.25 HRS. ECD = 10.40 PPG. e _ _. l~~€1e 22 of ~1 i i Time__Logs ___ ___ _ -,Date From To Dur S. nth E. De th Phase Code Subcode T COM ___ _._ 05/06/2007 06:00 07:45 1.75 17,406 17,609 PROD2 DRILL DDRL P Continue directional drill 8 1/2" hole in the D lateral from 17406' - 17609' MD. ND =3423'. ADT = .89 HRS. ECD = 11.26 PPG. 07:45 09:00 1.25 17,609 17,609 PROD2 DRILL CIRC T Circulate & reciprocate drill string while repair Mud Pump # 2. Washed out liner seal. 09:00 12:00 3.00 17,609 17,935 PROD2 DRILL DDRL P Continue directional drill 8 1/2" hole in the D lateral from 17609' - 17935' MD. ND = 3420'. ADT = 1.86 HRS. ECD = 11.27 PPG. 12:00 16:30 4.50 17,935 17,935 PROD2 DRILL CIRC P Circulate Hi Visc sweep + 4 bottoms up. Reciprocate & rotate drill string while circulating. Pumps @ 620 GPM's - 3850 PSI. 16:30 17:15 0.75 17,935 17,470 PROD2 DRILL TRIP P POOH on elevators form 17935' - 17470'. Hole fill not correct. 17:15 18:00 0.75 17,470 16,912 PROD2 DRILL TRIP P Continue pump out of hole from 17470' - 16912'. Crew Chan e 18:00 00:00 6.00 16,912 12,858 PRODZ DRILL REAM P Attempt to POOH on elevators. Observed improper hole fill, and fluid running over DP in stump, and as we pulled. Continue BROOH to 12858'. Observed good hole conditions with increased cuttings, slowing speed to allow cuttin s to clean u . 05/07/2007 00:00 03:00 3.00 12,858 10,577 PROD2 DRILL REAM P Continue BROOH from 12858' - 10577'. Observed good hole conditions. 03:00 06:00 3.00 10,577 10,577 PROD2 RIGMN RGRP T While lowering Top drive to rig floor, the bales were being floated to center position, driller observed bales continued to extend in reverse sending drill pipe elevators and bales out the back side of the derrick. Rig team notified. No injuries, or spills. Invetigation underway. Pull Top drive up and retract bales and elevators into center "float" position. Remove damaged parts. Send for inspection & repair. Prepare Top drive to use without link tilt. Inspect derrick. tnspect switch on Top drive panel. Crew than e 06:00 09:45 3.75 10,577 9,054 PROD2 DRILL REAM P Continue BROOH slow from 10577' - 9054'. Observed ood hole conditions. 09:45 10:15 0.50 9,054 9,054 PROD2 DRILL CIRC P Circulate and reciprocate drill string from 9054' - 8961'. Clean & clear rig floor area. 10:15 11:00 0.75 9,054 9,054 PROD2 RIGMN SVRG P Blow down & service Top Drive. grease crown section & sheaves. Service travelling block. Inspect derrick. Continue work on #2 mud pump dischar a screen flan es. 11:00 12:30 1.50 9,054 9,054 PROD2 RIGMN SVRG P Slip & cut 119' of drilling line. Install Floor safe valve. ~__. ~~c~~ 24r~t ~1 Time Lo s Date From To Dur S. De th E Depth Phase Code Subcode T COM _ 05/07/2007 12:30 15:30 3.00 9,054 9,054 PROD2 DRILL OTHR P Rig up handling equipment. pick up and rack back 9 stands of 5" HWDP planned for future run, while waiting on To drive arts. 15:30 18:00 2.50 9,054 9,054 PROD2 RIGMN SVRG P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss and change out 4 1/2" IF saver sub on To Drive. Crew chan e 18:00 21:30 3.50 9,054 9,054 PROD2 RIGMN SVRG P Continue change out saver sub with new crew. Complete repair of discharge screen flanges on mud um #2. 21:30 23:30 2.00 9,054 9,054 PROD2 DRILL CIRC P Test mud pump & lines. Establish circulation. Pump 35 BBL Hi Visc sweep @ 620 GPM - 2950 PSI. Reciprocate & rotate drill string @ 120 RPM's. Observe minimal increase in cuttings when sweep returned. Continue pump 1 more bottoms up to veri hole clean. 23:30 00:00 0.50 9,054 9,054 PROD2 RIGMN RGRP T Install floor safety valve. Continue assemble parts on Top Drive. Monitor well through trip tank. Observed 4 BBL loss. 05/08/2007 00:00 04:00 4.00 9,054 9,054 PROD2 RIGMN RGRP T Continue assemble parts on Top Drive. Attach hydraulic lines and adjust link tilt assembly. Test run link tilt assembly. Continue Monitor well throu h tri tank. 04:00 06:00 2.00 9,054 10,930 PROD2 DRILL TRIP P Trip back in hole Fill every 20 stands. PU wt 205k, SO wt 80k. 06:00 07:45 1.75 10,930 12,383 PROD2 DRILL TRIP P Continue trip back in hole. Fill every 10 stands. Obtain PU and SO wt's. 07:45 14:15 6.50 12,383 17,935 PROD2 DRILL REAM P Ream in the hole (no down wt). 14:15 17:00 2.75 17,935 17,935 PROD2 DRILL CIRC P Circ and condition hole. Circulated 2211 bbls and 45 bbl weighted sweep (10.2 ppg, 185 vis). Total of 2256 bbls pumped. Slight increase in cuttings from sweep. Rotate 150 rpm w! 18-20k ft Ibs for ue. 17:00 19:15 2.25 17,935 17,935 PROD2 DRILL CIRC P Displace well to Solids free oil base mud. Rotate 150 rpm w/ 20-21 k ft Ibs for ue. 19:15 19:30 0.25 17,935 17,935 PROD2 DRILL OWFF P Monitor well. 19:30 21:15 1.75 17,935 16,566 PROD2 DRILL TRIP P POOH on the trip tank. Hole not taking proper fill. Record PU and SO wYs eve 10 stands. SLM. 21:15 00:00 2.75 16,566 14,665 PROD2 DRILL TRIP P Pump out of the hole. Pulling 45'/min. pumping 180 gpm. PU wt 270k, no down wt. record PU and So wt's every 10 stands. SLM. 05/09/2007 00:00 01:00 1.00 14,665 14,189 PROD2 DRILL TRIP P Pump out of the hole. Pulling 45'/min. pumping 180 gpm, 500 psi. PU wt 270k, no down wt. record PU and So wt's eve 10 stands. SLM. Pa€~~ ~5 of 41 Time Logs Date From To Dur S Depth E. De>th Phase Code Subcode T COM___ __ _ 05/09/2007 01:00 03:30 2.50 14,189 11,716 PROD2 DRILL TRIP P Pump out of the hole every other one. Pulling 45'/min. pumping 180 gpm, 460 psi. PU wt 270k, no down wt. record PU and So wt's every 10 stands. SLM. 03:30 06:00 2.50 11,716 10,101 PROD2 DRILL TRIP P Pump out of the hole every 3rd one. Pulling 45'/min. pumping 180 gpm, 460 psi. PU wt 270k, no down wt. record PU and So wt's every 10 stands. SLM. 06:00 07:30 1.50 10,101 9,054 PROD2 DRILL TRIP P Pump out of the hole every 4th one. Pulling 45'/min. pumping 180 gpm, 460 psi. PU wt 270k, no down wt. record PU and So wt's every 10 stands. SLM. 07:30 08:15 0.75 9,054 9,054 PROD2 DRILL CIRC P Circulate bottom's up. Rotate 120 rpm w! 13k ft Ibs for ue. 08:15 08:30 0.25 9,054 9,054 PROD2 DRILL CIRC P Perform minimal flow test w/ Sperry MWD. 300 gpm was determined with ood detection. 08:30 08:45 0.25 9,054 9,054 PROD2 DRILL OWFF P Monitor well. Static. 08:45 09:15 0.50 9,054 8,198 PROD2 DRILL TRIP P Pull out of the hole. Hole not taking ro er fill. 09:15 09:45 0.50 8,198 8,388 PROD2 DRILL TRIP P RIH 09:45 10:30 0.75 8,388 8,388 PROD2 DRILL CIRC P Circulate bottom's up. Rotate 120 rpm w/ 13k ft Ibs for ue. 10:30 12:00 1.50 8,388 7,057 PROD2 DRILL TRIP P Pump out of the hole every 3rd one. Pulling 45'/min. pumping 180 gpm, 460 psi. PU wt 270k, no down wt. record PU and So wt's every 10 stands. SLM. 12:00. 13:00 1.00 7,057 6,201 PROD2 DRILL TRIP P POOH. Hole started taking proper fill. 13:00 13:15 0.25 6,201 6,201 PROD2 DRILL OWFF P Monitor well. Static. 13:15 13:30 0.25 6,201 6,201 PROD2 DRILL CIRC P Pump dry job. Blow down top drive. 13:30 17:45 4.25 6,201 398 PROD2 DRILL PULD P Insert Haggard ID mud wiper. Pull out and la down drill i e. 17:45 18:30 0.75 398 247 PROD2 DRILL TRIP P Stand back HWDP, lay down jars, PU a sin le HWDP. 18:30 18:45 0.25 247 247 PROD2 DRILL OTHR P Clear and clean rig floor. 18:45 19:00 0.25 247 247 PROD2 DRILL SFTY P PJSM on laying down BHA # 6 19:00 19:30 0.50 247 125 PROD2 DRILL PULD P UD 3 jts of NM flex collars. 19:30 20:00 0.50 125 125 PROD2 DRILL OTHR P Download Sperry Sun MWD. 20:00 20:30 0.50 125 77 PROD2 DRILL PULD P UD MWD 20:30 21:00 0.50 77 77 PROD2 DRILL OTHR P Download Sperry Sun MWD. I _ _ _._® rage 26 of ~1 Time Logs I __ - -~ Date From To Dur S. De th E. Depth Phase Code S_ubcode T COM __ 05/09/2007 24:00 23:00 2.00 77 0 PROD2 DRILL TRIP P PU single dp, stand back MWD. Break bit, lay down geopilot. Note: Calculated fill for trip 160 bbls, actual 213 bbls. Total of 53 bbls over calculated. 23:00 23:15 0.25 0 0 COMPZ FISH SFTY P PJSM on PU BHA #7. 23:15 00:00 0.75 0 63 COMPZ FISH .PULD P PU/MU BHA # 7 to retrive whipstock assembl 05/10/2007 00:00 00:30 0.50 63 154 COMPZ FISH PULD P Continue to PU/MU BHA # 7 to retrive whi stock assembl 00:30 01:30 1.00 154 2,532 COMPZ FISH TRIP P RIH w/ whipstock retrieval assembly (BHA #7). Fill every 25 stands. Record PU and SO wt's every 5 stands. PU wt 115, SO wt 108k. 01:30 01:45 0.25 2,532 2,532 COMPZ FISH CIRC P Fill pipe, circ 50 bbls. 01:45 02:45 1.00 2,532 4,909 COMPZ FISH TRIP. P RIH w/ whipstock retrieval assembly (BHA #7). Fill every 25 stands. Record PU and SO wt's every 5 stands. PU wt 140, SO wt 108k. 02:45 03:00 0.25 4,909 4,909 COMPZ FISH CIRC P Fill pipe, circ 50 bbls. 03:00 04:00 1.00 4,909 7,285 COMPZ FISH TRIP P RIH w/ whipstock retrieval assembly (BHA #7). Fill every 25 stands. Record PU and SO wt's every 5 stands. PU wt 180, SO wt 95k. 04:00 04:15 0.25 7,285 7,285 COMPZ FISH CIRC P Fill pipe, circ 50 bbls. 04:15 05:15 1.00 7,285 9,061 COMPZ FISH TRIP P RIH w/ whipstock retrieval assembly (BHA #7). Fill every 25 stands. Record PU and SO wt's every 5 stands. PU wt 220, SO wt 110k. 05:15 05:30 0.25 9,061 9,061 COMPZ FISH SFTY P PJSM on displacing well to MOBM. 05:30 06:45 1.25 9,061 9,061 COMPZ FISH CIRC P Displace from SFOBM to MOBM.PU wt prior todisplacement =220k, SO 110k. 06:45 09:00 2.25 9,061 9,061 COMPZ FISH CIRC P Circulate 5 BU at a high rate to clean casing.PU wt after circuiting and displacement = 210k, SO wt 140k. Gained 30k down wt. 09:00 09:30 0.50 9,061 9,101 COMPZ FISH FISH P Make up stand 96, RIH, engage hook into whipstock. Pull 25k over. Jar, then pull to 285k. Unlatched anchor and ulled u 30'. 09:30 10:00 0.50 9,071 9,071 COMPZ FISH CIRC P Circulate bottom's up. 10:00 10:15 0.25 9,071 9,071 COMPZ FISH OTHR P Observe well for flow. Static. 10:15 10:30 0.25 9,071 9,071 COMPZ FISH CIRC P Pump dry job. Blow down top drive. 10:30 14:45 4.25 9,071 154 COMPZ FISH TRIP P POOH with whipstock assembly. Hole took ro er dis lacment. 14:45 16:30 1.75 154 0 COMPZ FISH PULD P Stand back a stand of HWDP. Lay down whipstock retrieval assembly and whi stock assembl . ~~~~ gage 2P ~sf 41 Time Lags __ __ _ _ Date From To Dur S Depth E Depth Phase Code Subcode TCOM 05/10/2007 16:30 17:00 0.50 0 0 COMPZ FISH PULD P Clean tools. UD Baker tools from the floor. 17:00 17:30 0.50 0 0 COMPZ FISH OTHR P Clean and clear rig floor. 17:30 17:45 0.25 0 0 COMPZ RPCO SFTY P PJSM on picking up Baker RAM diverter assembl . 17:45 20:15 2.50 0 125 COMPZ RPCOb PULD P PU/MU RAM diverter assembly, orient same to index opening with window and lu . 20:15 21:00 0.75 125 174 COMPZ RPCOh PULD P PU/MU Sperry MWD and make top drive connection. U load MWD. 21:00 21:30 0.50 174 174 COMPZ RPCOh OTHR P Set Seal bore diverter in the rotary table. Manually release FJD running tool. PU and disengage the running tool. Test volume and pressure for release. Results: @ 275 gpm w/ 550 psi- detection but not real good, 300 gpm w/ 640 psi- good detection w/ MWD, 325 gpm w/ 740 psi- tool still not released, 350 psi w/ 850 psi- still not releassed, 375 gpm w/ 980 psi, @ 400 m w/ 1100 si tool released. 21:30 00:00 2.50 174 4,240 COMPZ RPCO TRIP P PJSM, RIH w/diverter assembly on 5" drill pipe. Good hole displacement. Runnin seed 80-90' er min. 05/11/2007 00:00 03:00 3.00 4,240 9,173 COMPZ RPCO TRIP P Continue to RIH w/diverter assembly on 5"drill pipe. Good hole displacement. Running speed 80-90' per min. PU wt 210k, SO wt 130k @ 9173'. 03:00 03:30 0.50 9,173 9,205 COMPZ RPCOh OTHR P MU top drive on stand 96, break circulation, establish circulation and good detection w/ 275 gpm w! 830 psi. PU wt 210k, SO wt 135k. Initial survey w/MWD showed 130 right. Work pipe to a final of 83 Right and torque worked down hole. Slack off until) latched in w/mule shoe @ 9205.43'. Surve indicatin 8 de left. 03:30 04:00 0.50 9,205 9,205 COMPZ RPCO OTHR P Pull testing to see required overpull to snap out. Snapped out w/ weight indicator reading 320k (110k overpull). Confirm PU wt 210k and SO 130k. 04:00 04:15 0.25 9,205 9,075 COMPZ RPC011 OTHR P Set back down to weight indicator reading of 80k. Increase pumps f/ 275 gpm w/ 830 psi to 500 gpm w/ 2380 psi. Pickup and free of diverter assembl . PU wt is now 205k. 04:15 04:30 0.25 9,075 9,075 COMPZ RPCOb SFTY P PJSM on displacing well f/ 8.4 ppg MOBM to NEW 8.5 ppg Solids free oil base mud. 04:30 06:00 1.50 9,075 8,999 COMPZ RPCO CIRC P Set back stand #96. Displace well from 8.4 ppg MOBM to 8.5 ppg Solids free Oil Base mud, pumping 570 gpm w/ 3280 psi. Reciprocate pipe 65' stroke. Take SPR's. Record PU and SO wt. PU 220k, 135k SO wt. ~'~~~ ~~ ~f 41 ~ J lime Logs _ _ _ Date _ From To __ Dur 5. De th E Depth Phase Code Subcode T COM ____ __ 05!11/2007 06:00 06:15 0.25 8,999 8,999 COMPZ RPCOb OTHR P Monitor well. Static. 06:15 06:30 0.25 8,999 8,999 COMPZ RPCOh OTHR P Blow down top drive. 06:30 11:30 5.00 8,999 50 COMPZ RPCO TRIP P POOH w/diverter running tools. 11:30 12:00 0.50 50 50 COMPZ RPCOR OTHR P Download MWD. 12:00 12:45 0.75 50 0 COMPZ RPCOh PULD P Lay down BHA: MWD and Baker runnin tools. 12:45 13:15 0.50 0 0 COMPZ RPC06 OTHR P Clean and clear rig floor. Function pipe rams, blind rams, kill and choke HCR valves and the annular. 13:15 13:45 0.50 0 0 COMPZ CASIN RURD P Rig up GBR equipment to run "D" lateral 4-1/2" 11.6 f 13:45 14:00 0.25 0 0 COMPZ CASINC SFTY P Pre job safety meeting on running "D" lateral slot balnk 4-1 /2" liner w/ Baker RAM liner han er. 14:00 18:06 4.00 0 6,240 COMPZ CASIN PUTS P Run 4-1/2", 11.6 ppf, slotted liner f/ "D" lateral. 18:00 20:30 2.50 6,240 8,763 COMPZ CASINC PUTB P Continue to run 4-1/2", 11.6 ppf, slotted liner f! "D" lateral. Record PU and SO wt's every 10 jts. PU wt 120k, SO wt 95k. Calculated displacement 37 bbls, actual dis lacement 29 bbls. 20:30 21:00 0.50 8,763 8,763 COMPZ CASINC PUTS P PU/MU crossover to 7" Hydril 563. Monitor well on tri tank. 21:00 22:15 1.25 8,763 8,763 COMPZ CASIN WOEO NP Load pipe shed w/ 96 joints of 4-1/2" 12.6 ppf L-80 IBT-m tubing for the completion run, while trying to locate a ~t of 3-112" STL for the inner strin . 22:15 00:00 1.75 8,763 8,763 COMPZ DRILL PULD P Lay down 5" extra drill pipe from driller's side of derrick while waiting on a joint of 3-1/2" STL inner string for the liner run. 05/12/2007 00:00 00:15 0.25 8.,763 8,763 COMPZ DRILL PULD P Lay down 5" extra drill pipe from driller's side of derrick while waiting on a joint of 3-1/2" STL inner string for the liner run. Layed down total of 7 stands esterda and toda . 00:15 00:45 0.50 8,763 8,828 COMPZ CASIN PUTB P PU Ram hanger, MU inner string, MU to liner. PU wt 100k, SO wt 125k. 00:45 01:30 0.75 8,828 9,200 COMPZ CASINC RUNL P Run 4-1/2" "D" lateral liner on 5"drill pipe. Note: with stand # 2 picked up(prior to exit diverter): PU wt 130k, SO wt 100k, rot @ 35 rpm w/ 4000 ft Ib torque, rot @ 45 rpm w! 4000 ft Ib torque, 110k rot wt. Note: with stand # 4 picked up(in open hole 9200'): PU wt 130k, SO wt 100k, rot @ 35 rpm w/ 4000 ft ib torque, rot @ 45 rpm w/ 4000 ft Ib torque, 112k rot wt. . ~ __. ~ _ _ ~ ._~~. (y~ge__ n Trine Low i _ Date From To Dur S Depth E_._De th Phase Code Subcode T COM_____ _ __ 05/12/2007 01:30 06:00 4.50 9,200 14,058 COMPZ CASIN( RUNL P Continue to run in hole w/ 4-1/2" slotted liner on 5"drill pipe. Record PU and SO wt's every 5 stands, record torque every 10 stands.. Fill pipe every 25 stands or 10 stands to maintain weight. @ 14058': PU wt 180k, So wt 80K, rot wt 125k. No rotation required to this point, with 55 stands of 5"drill i e. 06:00 11:00 5.00 14,058 17,868 COMPZ CASIN RUNL P Rotate 4-1/2" slot/blank "D" lateral liner in the hole. Record PU and SO wt's every 10 stands. Record torque. Ran in hole stand # 95 and 41' in on #96. Note: Torque was 17k prior to reaching this oint, for ued u to 23k ft lbs. 11:00 12:00 1.00 17,868 17,868 COMPZ CASIN OTHR P Obtain PU and SO wt's prior to attempting to run through diverter and land. PU wt 242k, SO wt 85k, Rot wt 169k. Rotating up 195k, Rotating down 165k. Made several attempts to land. Decision made to POOH and look at tool for any indications why it would not. Suspicion of 7" x 4.5" crossover assembly hanging up on diverter. 12:00 14:15 2.25 17,868 17,868 COMPZ CASIN CIRC T Circulate bottom's up. (top slot @ 9202'). After CBU a small amount of gas back to surface. Circulated until well was static before tripping out of hole. Could not get liner hanger to final osition sh b 38.32' . 14:15 14:30 0.25 17,868 17,868 COMPZ CASIN OTHR T Monitor well. Static. 14:30 18:00 3.50 17,868 13,963 COMPZ CASIN( OTHR T POOH w/ 4-1/2" slotted/ blank 11.6 ppf liner with Baker RAM liner hanger. Hole took ro er dis lacment. 18:00 20:15 2.25 13,963 8,828 COMPZ CASIN OTHR T Continue to POOH w/ 4-1 /2" slotted/ blank 11.6 ppf liner with Baker RAM liner hanger. Calculated displacment 86.4, actual 92.5 bbls. 20:15 20:45 0.50 8,828 8,765 COMPZ CASIN( OTHR T Look at Baker RAM hanger and crossover under same. Analyze scarrin and re-veri dimensions. 20:45 22:45 2.00 8,765 8,765 COMPZ CASIN WOOR T Waiting on decision. While waiting: service top drive, crown, and drawworks. Clean out drip pan under drawworks and rig floor. Check h draulic lines under ri floor for leaks. 22:45 23:45 1.00 8,765 8,827 COMPZ CASIN OTHR T Lay down and change 7" Hydril pup and 7" x 4-1/2" hydril crossover under hanger. Install 7" crossover to 5-1/2" hydril, then 5-1/2" Hydril pup, then crossover to 4-1/2" h dril. ~~€~ 3C3 ~# ~'I Time Logs ---- - -- ---- - Date From To Dur _S Depth E. De th Phase Code Subcode T COM __ 05/12/2007 23:45 00:00 0.25 8,827 9,018 COMPZ CASIN( RUNL T RIH w/ liner on 2 stands of 5" drill pipe. Obtain PU, SO wt's. PU 135k, SO 90k, Rotate @ 30 rpm w/ 5000 ft Ib torque (Torque limit set at 5000 ft Ib ,with rotatin wei ht of 112k. 05/13/2007 00:00 00:30 0.50 9,018 9,102 COMPZ CASIN( RUNL T Trip in hole w/ "D"lateral liner on 5" dp. Tag up on diverter of seal bore diverter @ 9102'. Set down 10k f/ 90k to 80k, PU w/ 5k overpull f/ 135k to 140k. RiH and tag again with same 10k down wei ht loss and 5k over ull. 00:30 00:45 0.25 9,102 9,018 COMPZ CASIN OTHR T POOH one stand of 5"drill pipe. Decision made to POOH w/ 4-1 /2" "D" lateral liner assembly, then more than likely run the plop and drop liner s stem. 00:45 02:15 1.50 9,018 9,018 COMPZ RIGMN SVRG T Slip and cut 119' of 1-3/8"drilling line. 02:15 02:30 0.25 9,018 8,827 COMPZ CASIN( OTHR T POOH 5"drill pipe to Baker RAM liner han er f/ the "D" lateral. 02:30 03:45 1.25 8,827 8,780 COMPZ CASIN OTHR T Lay down Baker RAM liner hanger. La down 4-1/2" inner strin . 03:45 04:30 0.75 8,780 8,780 COMPZ CASIN RURD T Change out GBR tongs, rig up to lay down 4-1/2" 11.6 ppf slot and blank, h dril 521 and BTC liner f/ "D"lateral. 04:30 04:45 0.25 8,780 8,780 COMPZ CASIN SFTY T Pre job safety meeting on laying down 4-1 /2" liner. 04:45 06:00 1.25 8,780 8,320 COMPZ CASINC OTHR T Rig up to lay down and lay down 10 jts of 4-1/2" 11.6 ppf L-80 Hydril 521" liner to the i e shed. 06:00 18:00 12.00 8,320 0 COMPZ CASINC OTHR T Continue to lay down 4-1/2" 11.6 ppf L-80 Hydril 521" liner to the pipe shed. Note: A total of 7 stop rings for the 4-1 /2" were not accounted for while ullin out of the hole with the liner. 18:00 18:30 0.50 0 0 COMPZ CASINC OTHR T Clear and clean rig floor. 18:30 19:00 0.50 0 0 COMPZ CASIN OTHR T Continue to clean rig floor. Retrieve Haggard ID wiper f/ inside of 4-1/2" liner shoe ~oint. 19:00 19:15 0.25 0 0 COMPZ FISH SFTY T Pre job safety meeting on running in the hole w/ Baker retrieving toot for the seal bore diverter. 19:15 19:45 0.50 0 22 COMPZ FISH PULD T PU/MU Baker FJD running tool for the seal bore diverter, install float sub on to w/ orted float. 19:45 00:00 4.25 22 7,819 COMPZ FISH TRIP T RiH w/ Baker running tool on 5" drill pipe. Record PU and SO wt's every 10 stands. Fill i e eve 25 stands. 05/14/2007 00:00 01:00 1.00 7,819 9,020 COMPZ FISH TRIP T Continue RIH w/ FJD diverter running tool to pull the diverter. Record PU and SO wt's every 10 stands. Fill pipe every 25 stands. PU wt 235k, SO wt 100k. 01:00 01:45 0.75 9,020 9,020 COMPZ FISH CIRC T CBU while reciprocate 65'. Circulate total of 475 PacJ~ 31 a~ 41~ Time Logs _ _ ~' __ __ _ _ _ Date From To Dur 5. De th E. De th Phase Code Subcode T CONI 05/14/2007 01:45 02:30 0.75 9,020 9,088 COMPZ FISH CIRC T Continue circ while 5' in to 9088'. Circ another 250 bbls. Recip pipe 65' to just above the diverter to . 02:30 04:45 2.25 9,088 9,103 COMPZ FISH FISH T PU wt 235k, SO wt 110k. Attempt to latch into the top of the diverter assembly with the running tool. Slack off 40k to 70k, Pull up to 235 and over pull to 280-290k and weight dropped off to 235-150k. Wash slot with up to 500 m w/ 2070 si um ressure. 04:45 06:00 1.25 9,103 7,914 COMPZ FISH TRIP T POOH with running tool. 06:00 08:45 2.75 7,914 0 COMPZ FISH TRIP T Continue to POOH w/ Baker runnin /retievin tool for the diverter. 08:45 09:15 0.50 0 0 COMPZ FISH OTHR T Clean and inspect running tool. Found (1) stop ring wedged in the retieving tool fin er. UD retrievin tool. 09:15 09:45 0.50 0 0 COMPZ FISH OTHR T Clean and clear rig floor. 09:45 10:15 0.50 0 0 COMPZ RIGMN SVRG T Service rig. 10:15 10:45 0.50 0 0 COMPZ FISH PULD T Bring Baker oil tools fishing tools to the rig floor. Stap and obtain OD,ID len the and fishin neck of tools. 10:45 11:30 0.75 0 0 COMPZ FISH PULD T MU fishing tools (magnets) per Baker Oil Tools re . 11:30 17:00 5.50 0 9,032 COMPZ FISH TRIP T Trip in the hole w/the magnets. Fill pipe every 25 stands, record PU and SO wt's every 10 stands. Depth 9032': PU wt 150k, SO wt 95k. 17:00 18:00 1.00 9,032 9,082 COMPZ FISH CIRC T Establish circulation then 5 foot in the hole. Circulate bottom's up+ (503 bbls). Rotate 110 rpm w/ 11-13k ft Ib for ue. Rot wt 160k. 18:00 19:30 1.50 9,082 9,082 COMPZ FISH CIRC T Continue to rotate and recip 60' the magnets, while pumping a 50 bbl sweep (9.5 ppg, 100 vis) around and to surface. Pumping 600 gpm w/ 2170 psi. No increase in cutttings. Rotate 110 rpm w/ 9-10k ft Ib torque. With um son: PU wt 205k, SO wt 120k. 19:30 20:30 1.00 9,102 9,116 COMPZ FISH OTHR T PU wt 218k, SO wt 130k, Rot wt 170k rotating 30 rpm w/ 10k ft Ibs of torque. Work down 70' in on stand # 96 to 9102' (Ramp of diverter) without pumps on. Took weight. Rotate 30 rpm w/ torque limit set @ 12k ft Ib (normal torque 10k). Worked down to 9105', then free @ 9105'. Shut off rotary. Continue to slack off to 9116', (83' in on stand # 96) (2' below bottom of the window @ 9114'). PU with no restriction or extra dra . ~~ t Page ~2 of 4~ • Time L_o_gs _ __ _ _ _ _ Date From To Dur S. De th E. De th Ph~e _ Code Subcode T _COM 05/14/2007 20:30 00:00 3.50 9,116 4,310 COMPZ FISH TRIP T PU to 9032'. POOH with magnet assembly. Perform ROPE test of choke manifold while POOH. Witness of ROPE test waived by AOGCC ins ector John Cris . 05/15/2007 00:00 02:30 2.50 4,310 76 COMPZ FISH TRIP T PU to 9032'. POOH with magnet assembly. Perform BOPE test of choke manifold while POOH. Witness of BOPE test waived by AOGCC ins ector John Cris . 02:30 03:30 1.00 76 0 COMPZ FISH PULD T Pull magnets to the floor. Clean magnets. Recovered 4 halves of stop rin s. La down ma nets. 03:30 04:00 0.50 0 0 COMPZ WELCT OTHR P Clean and clear rig floor.. Rig up to ull wear bushin .Pull wear bushin . 04:00 04:30 0.50 0 0 COMPZ WELC OTHR P Rig up to test BOPE. 04:30 07:45 325 0 0 COMPZ WELC BOPE P Two week BOPE test (witness of test waived by AOGCC inspector John Crisp). Test upper pipe rams (variable 3-1/2" x 6") and annular to 250 psi and 3000 psi with a 4-1/2" test joint. Test upper rams w/ 5" test joint. Test floor safety valves and top drive valves, kill and choke. Accumulator test. 07:45 08:45 1.00 0 0 COMPZ WELCT OTHR P Rig down test equipment. Blow down choke and kill lines and top drive. Install Vetco Gray Wear bushing 3.17' long, 9" ID, 13-3/8" OD. Hold wear bushin w/ 2 lockdown screws. 08:45 09:15 0.50 0 0 COMPZ RIGMN SVRG P Service drawworks ,top drive and crown 09:15 09:45 0.50 0 0 COMPZ FISH PULD T Clear rig floor of fishing tools not needed. 09:45 10:30 0.75 0 138 COMPZ FISH PULD T PU/MU Baker FJD running/retrieving tool, make up float sub, 1 joint of 5" drill pipe. Make up top drive and pump. Tool released @ 450 gpm w/ 102 psi. PU/MU Bum er sub and 'ars. 10:30 16:00 5.50 138 9,072 COMPZ FISH TRIP T RIH w! retrieving tool on 5"drill pipe. Record PU and SO wt's every 10 stands. Fill pipe every 25 stands.PU wt 200k, SO wt 110k. Calculated displacement 86.3 bbls, actual dis lacement 79 bbls. 16:00 17:15 1.25 9,072 9,072 COMPZ FISH CIRC T Circulate bottom's up. Reciprocate 30'. Monitor well, bubbling, continue to circualte. Circulate a total of 735 bbls. 17:15 17:30 0.25 9,072 9,102 COMPZ FISH FISH T Five foot in the hole. Attempt to engage diverter running/retieving tool into the diverter. PU wt 218k, SO wt 138k. Slack off and set down to 100k, PU to 340k (120k overpull to pull diverter free). Gained string pu wt now 225k 7k wei ht increase . 17:30 18:00 0.50 9,072 9,072 COMPZ WELCT OWFF T Monitor well, static. • I Time Logs _ _ _ Date From To Dur S. Depth E. Depth Phase Code Subcode T GOM ____ ____ 1 05/15/2007 18:00 00:00 6.00 9,072 123 COMPZ FISH TRIP T POOH w/diverter retrieving tool and diverter assembly. Last stand of drill i e out of the hole midni ht. 05/16/2007 00:00 00:30 0.50 123 123 COMPZ FISH RURD T RU GBR to break and lay down Baker RAM assembl . 00:30 02:15 1.75 123 0 COMPZ FISH PULD T Break and lay down messed up Baker RAM diverter and running tool. Retrieved a total of 2 stop rings in pieces. Also recovered some formation in the diverter below the opening. Note: Two stop rings still unaccounted for. 02:15 02:45 0.50 0 0 COMPZ FISH OTHR T Rig down GBR tongs. Clear and clean ri floor. 02:45 03:15 0.50 0 0 COMPZ FISH PULD T PU tools for cleanout run to the rig floor. 03:15 04:30 1.25 0 50 COMPZ FISH PULD T MU BHA for reverse circ basket and magnets and junk baskets to clean out to packer f/the "B" lateral. Packer 9167.28'. 04:30 08:45 4.25 50 9,090 COMPZ FISH TRIP T Trip in the hole w/ 5"drill pipe and BHA to clean out to the top of the "B" lateral packer. Calculated siplacment 85 bbls, actual 78.5 bbls. Aty 9090' PU wt 215k, So wt 135k 08:45 10:00 1.25 9,090 9,090 COMPZ FISH CIRC T Circulate bottom's up (the window is @ 9097'-9114') while recip 90' .Pump total of 704 bbls. 10:00 11:45 1.75 9,090 9,090 COMPZ FISH CIRC T Drop a 1" ball and pump bpm w/ 630 psi. Ball on seat @ 1250 strokes. Now with reverse cirulation @ the basket, pump with 2700 psi. Five foot in to final depth of 9175' with this tally (Liner tally depth is 9167.28'). Set down 5k on liner top. Continue to reverse circ at the basket and POOH to 9090'. Shut down um s. 11:45 12:00 0.25 9,090 9,090 COMPZ FISH OTHR T Monitor well. Static. 12:00 16:30 4.50 9,090 50 COMPZ FISH TRIP T Pull out of the hole to Baker fishing assembly. Calculated fill 86 bbls, actua! fill 97 bbls. 16:30 16:45 0.25 50 50 COMPZ FISH OTHR T Inspect reverse junk basket and the junk baskets for recovery. Found 2 halves and a hinge of stop rings, also pieces (large) of formation. Reverse basket was full. Emptied contents into a halve of a 5 gal bucket. Pictures were taken. Note: Alt except one 4-1/2" stop ring has been recovered and accounted for from the initial RAM liner run. 16:45 18:00 1.25 50 0 COMPZ FISH PULD T Lay down BHA and clear floor of Baker fishin tools. 18:00 18:30 0.50 0 0 COMPZ CASIN RURD T Lay Baker fishing tools off the floor. _ ~ gaar~~ 3~ ref ~1 • • Time Lomas _ _ ____ :Date From To Dur S De th E. Depth Phase Code:! Subcode T COM _ _ 05/17/2007 12:00 16:30 4.50 14,146 17,906 COMPZ CASIN RUNE T Continue RIH by rotating 4-1/2" Plop and Drop liner on 5" drill pipe. Fill pipe every 20 stands pumping 210 gpm w/ 450 psi. Record PU and SO wt's every 5 stands. Rotating 45 rpm w/ 10-11 k ft Ib torque to final torque on bottom of 19k. . Rotating wt 130k to final of 152k, PU wt 190k to final of 250k. 16:30 18:00 1.50 17,906 17,923 COMPZ CASIN RUNL T Continue RIH by rotating 4-1/2" Plop and Drop liner on 5"drill pipe. Pumping 210 gpm w/ 450 psi. Rotating 45 rpm w/ 19k ft Ib torque. Rotating wt 152k, PU wt 250k. Five foot in to tag bottom @ 17935', PU to set liner top @ 9308'. Drop and pump 29/32" ball @ 4bpm w/ 480 psi. Ball on seat w/ 1825 strokes. Pressure to 3500 psi, then slack off to 100k, PU to 235k (3 times) running tool is free from liner. PU 5' and pressure to 4000 spi to blow ball seat. OK. Monitor well. 18:00 18:45 0.75 17,923 8,900 COMPZ CASINC OTHR T POOH to 8900' 18:45 20:30 1.75 8,900 8,900 COMPZ CASINC CIRC T Circulate bottom's up. Pumping 370 gpm w/ 870 psi. Circulate a total of 722 bbls. 20:30 21:00 0.50 8,900 8,900 COMPZ CASINC OTHR T Monitor well. OK. Blow down top drive. 21:00 00:00 3.00 8,900 3,518 COMPZ CASINC OTHR T Pull out of the hole with Baker liner running toot f/ the Plop and drop "D" lateral liner. 05/18/2007 00:00 01:45 1.75 3,518 30 COMPZ CASINC OTHR T Continue to pull out of the hole with Baker liner running tool f/the Plop and dro "D" lateral liner. 01:45 02:00 0.25 30 0 COMPZ CASIN OTHR T Lay down Baker running tools. 02:00 02:15 0.25 0 0 COMPZ CASINC OTHR T Clear and clean rig floor. 02:15 03:30 1.25 0 0 COMPZ CASINC OTHR T Rig up to run Hook Hanger assembly tri #2. 03:30 04:30 1.00 0 226 COMPZ CASIN OTHR T MU Hook hanger assembly till ready for the inner strin 04:30 06:30 2.00 226 226 COMPZ CASINC OTHR T PU/Run inside of Hook Hanger assembly the Sperry Sun MWD, make up cup and 2-3/8" 4.6 ppf, hydril 511,E-80s aceouttubin 06:30 06:45 0.25 226 226 COMPZ CASINC OTHR T PU Baker B-1 Hook Hanger, MU inner strin to the hook han er. . 06:45 07:00 0.25 226 226 COMPZ CASINC OTHR T Make hook hanger up to assembly below. Check MWD orientation to the Baker hook han er. 07:00 08:00 1.00 226 360 COMPZ CASINC RUNE T Run in the hole one stand, make a top drive connection. Record PU wt of 85k, SO wt 85k. ~~ ~'aq~ ~ti cf ~~ ' Time Logs. - _- __-- I Date From To _Dur S. Depth _E De th Phase Code Subcode T COM _ 05/18/2007 08:00 08:30 0.50 360 360 COMPZ CASIN( CIRC T Pump to shallow test Sperry MWD. Pumping 130 gpm w/ 660 psi. Good detection. 08:30 14:00 5.50 360 9,267 COMPZ CASIN( RUNL T RIH w/ Baker Hook hanger (Trip #2) assembl on 5"drill i e. 14:00 16:15 2.25 9,267 9,352 COMPZ CASIN RUNL T Five foot in to 9352. Pickup 10'. Break circulation to see what Sperry MWD indicates. Hook Baker B-1 9-5/8" x 7" hook hanger on the bottom of the window (hooked @ 9114.84')with the mule shoe 9352.43'. 16:15 18:30 2.25 9,352 9,352 COMPZ CASIN OTHR T Drop the 29/32" ball, circ @ 3bpm w/ 920 psi, after 120 bbls slow to 2bpm w/ 490 psi. Ball was on seat after pumping 198 bbls. Increase pressure f/ 1000 psi in stages to 1500, 2000, 2200, 2400, 2600 psi. No Shear @ 2600 psi. Increase to 2700 psi, shear valve and inflate ECP w/ 2 strokes, pressure bled back to 2300 psi. Pressure back up to 2700 psi w/ 2 strokes, bled back to 1500 psi, increase to 2600 psi w/ 3 strokes. Pressure bled backto 1500 psi. Pressure back up to 2600 psi w/ 3 strokes and not hoding pressure after pumping a total of 10 strokes (1 bbl). Attempt to blow ball seat w/ 4200 psi. Stop pumping, bleed off all pressure with the tool released from the hook hanger. PU wt 230k, no drag or indication of moving the hook assembl . SO wt 115k. 18:30 23:15 4.75 9,352 174 COMPZ CASIN OTHR T POOH with the Hook Hanger running tools and inner strip . 23:15 23:45 0.50 174 174 COMPZ CASIN OTHR T Rig up and lay down running tools and inner strip . 23:45 00:00 0.25 174 60 COMPZ CASIN OTHR T Lay down running tools f/the hook hap er. 05/19/2007 00:00 00:45 0.75 60 0 COMPZ CASINC OTHR T Finish Laying down running tools for the hook hap er. 00:45 01:15 0.50 0 0 COMPZ CASIN OTHR T Remove hook hanger handling tools and inner strip tools from the floor. 01:15 02:30 1.25 0 7 COMPZ DRILL PULD T Rig up floor to MU BHA. MU 8-1/2" reverse circulating basket, bit sub with a float. 02:30 06:45 4.25 7 9,093 COMPZ DRILL TRIP T Trip in the hole with the BHA on 5"drill pipe. Fill pipe every 20 stands. Tag the top of the hook hanger @ 9093', set 12k on the to . 06:45 08:45 2.00 9,092 9,063 COMPZ DRILL CIRC T Pick up, make a top drive connection, PU 30 'above hook hanger top and circulate. Circulate a total of 730 bbls. 08:45 09:00 0.25 9,063 9,063 COMPZ DRILL OWFF P Monitor well. Install stripping rubbers. °age 3~ of ~1 Time_Logs _ _ Date From To Dur S De th E Depth Phase __Code Subcode T _ COM ____ 05/19/2007 09:00 09:30 0.50 9,063 9,063 COMPZ DRILL CIRC P Pump a 20 bbls dry job (9.5 ppg), break connection and drop the Haggard tD wiper (Mud dog). Blow down the to drive. 09:30 12:00 2.50 9,063 6,940 COMPZ DRILL PULD P Pull out of the hole laying down 5"drill pipe. A total of 33 joints of 5" HWDP and 33 joints of 5" drill pipe. Monitor well on the tri tank. 12:00 13:15 1.25 6,940 5,135 COMPZ DRILL PULD P Pull out of the hole laying down 5" drill pipe. A total of 57 joints of 5"drill pipe altogether. Monitor well on the trip tank. 13:15 14:15 1.00 5,135 8,082 COMPZ DRILL TRIP P Run in hole with 31 stands of 5"drill i e from the derrick. 14:15 17:00 2.75 8,082 5,023 COMPZ DRILL PULD P Pull out of the hole laying down 5" drill pipe. A total of 195 joints of 5" drill pipe altogether. Monitor well on the tri tank. 17:00 18:30 1.50 5,023 5,023 COMPZ RIGMN SVRG P Slip and cut 18 wraps of 1-3/8"drilling line. 18:30 19:30 1.00 5,023 5,023 COMPZ RIGMN' SVRG P Service drawworks, topdrive and blocks. 19:30 22:00 2.50 5,023 5,023 COMPZ RIGMN RGRP T Locate and repair a Glycol leak on the drawworks. 22:00 22:30 0.50 5,023 5,023 COMPZ DRILL SFTY P Pre job safety meeting on pulling out of the hole and laying down the 5" dritl i e. 22:30 00:00 1.50 5,023 3,225 COMPZ DRILL PULD P Continue pulling out of the hole laying down 5"drill i e. 05/20/2007 00:00 03:00 3.00 3,225 682 COMPZ DRILL PULD P Continue pulling out of the hole laying down 5"drill i e. 03:00 04:15 1.25 682 682 COMPZ RIGMN RGRP T Repair link tilt "U" bolt clamp attatched to the bales. 04:15 06:30 2.25 682 682 COMPZ DRILL OTHR P Remove 41 joints of 4-1/2" completion tubing from the pipe shed. Re strap 168 joints on bottom row. Monitor well on tri tank. 06:30 08:30 2.00 682 7 COMPZ DRILL PULD P Continue pulling out of the hole laying down 5"drill i e. 08:30 08:45 0.25 7 0 COMPZ DRILL PULD P Lay down BHA. Clear floor of BHA Reverse basket w/ 8-1/2" OD shoe. 08:45 09:15 0.50 0 0 COMPZ DRILL OTHR P Clear floor of BHA (Reverse basket w/ 8-1/2" OD shoe. 09:15 09:45 0.50 0 0 COMPZ RPCOh RURD P Rig up 4-1 /2" Tubing equipment. 09:45 10:15 0.50 0 0 COMPZ RPCOh SFTY P Pre job safety meeting on Picking up/making up/ RIH w/ 4-1/2" 12.6 ppf, L80, IBT-m tubin . 10:15 18:00 7.75 0 7,200 COMPZ RPCO PULD P PU/MU/RIH w/ 4-1/2" completion tubing w/mule shoe on the bottom to 7200'. Total of 234 'ts 18:00 23:00 5.00 7,200 0 COMPZ RPCOh TRIP P Pull out and stand back the 4-1 /2" comp-etion tubing. Install new seal rin s in the boxes of'oints broke out. P~ijE ~a$ raf x't1 • • Time Logs --- ---- - ------ -- -- .Date _ From 7o Dur 5 De th E. Depth Phase Code Subcode T COM _ _ 05/20/2007 23:00 23:30 0.50 0 0 COMPZ RPCOh OTHR P UD mule shoe, clean and clear rig floor. Shut blind rams. Calculated fill 33 bbls, actual 42 bbls. 23:30 00:00 0.50 0 0 COMPZ RPCO OTHR P Drain stack, pull Vetco Gray wear bushin . 05/21/2007 00:00 00:30 0.50 0 0 COMPZ RPCO RURD P Rig up tools f! completion. 00:30 00:45 0.25 0 0 COMPZ RPCO SFTY P Pre job safety meeting on Picking up perforated pump intake w/ pup, 2 joints of 4-1/2" 12.6 ppf IBT tubing, 4-1 /2" pup jt, discharge sub, 4-1/2" pup jt. Picking up and installing pump w/wireline. Testin . 00:45 01:30 0.75 0 91 COMPZ RPCO PULD P Pick up perforated pump intake w/ pup, MU 2 joints of 4-1/2" 12.6 ppf i8T tubing, 4-1/2" pup jt, discharge sub, 4-1/2" u ~t. 01:30 01:45 0.25 91 91 COMPZ RPCOh PULD P Set Pump eye, gas seperator and FC 6000 um inside of tubin . 01:45 03:30 1.75 91 91 COMPZ RPCO SLKL P RU HOWCO slickline. MU crossover, 2-7/8" spacer pup, bow spring and hanger receptical to lower section, RIH and set. POOH, RIH w/ D & D packoff, Kobe knockout, and check valve. Distance f/ FN to Kobe knock out is 36", Distance f! FN to check valve is 86". Overall of packoff is 100.5". Set on to of um .POOH. 03:30 03:45 0.25 91 91 COMPZ RPCOh RURD P RU to test with water and rig test um . 03:45 04:15 0.50 91 91 COMPZ RPCOR DHEO P Test to 1000 psi. lost 100 psi in 15 min. Decision to make test tool run. Ri down test a ui ment. 04:15 05:00 0.75 91 91 COMPZ RPCOh SLKL P HOWCO slickline RIH w/ D&D test tool. POOH. RU test equipment. test to 1000 psi f/ 15 min. Lost 50 psi. Rig down test a ui ment. 05:00 05:15 0.25 91 91 COMPZ RPCOh SLKL P HOWCO slickline RIH w/ 4-1/2 GS, latch tool, POOH. RIH w/ tubing slip sto and set. POOH wireline. 05:15 05:30 0.25 91 91 COMPZ RPCOh RURD P Rig down HOWCO slickline. 05:30 05:45 0.25 91 0 COMPZ RPCOh TRIP P POOH w/ stand, check rotation of um . OK. 05:45 08:00 2.25 0 0 COMPZ RPCO RURD P RU ESP sheave, stage tools and clam son ri floor. 08:00 08:30 0.50 0 0 COMPZ RPCOh SFTY P Pre job safety meeting on running com letion. 08:30 11:00 2.50 0 51 COMPZ RPCOh PULD P PU motor, fill with oil, install capillary tube f/ A-well senost ti dischar a sub. 11:00 11:30 0.50 51 51 COMPZ RPCO OTHR P Test ESP cable at the reel in spooling unit. Good. 11:30 13:45 2.25 51 143 COMPZ RPCOh PULD P MU pump assembly to motor. Install bands and clam s. £'~~;c 3~ a~f ~1 .« ! • Time Logs Date From To Dur S De th E. Depth Phase Code Subcode T ____ COM 05/22/2007 18:00 23:15 _ 5.25 _ A , 0 COMPZ RPCO FRZP P Continue displace well with freeze protect diesel at 1 BPM - 550 PSI. Increase rate gradually up to 2 BPM - 575 PSI when diesel in the tubing, with 100% returns. Total pumped = 600 BBLS with FCP @ 510 PSI. Total losses while pumping = 25 BBLS. Shut in valves on tree. 23:15 00:00 0.75 0 0 COMPZ RPCOh FRZP P Vac out all lines and rig down Little Red services. Blow down all lines including choke manifold and degasser. Rig down all lines including choke line. 05/23/2007 00:00 02:30 2.50 0 0 COMPZ MOVE DMOB P Continue cleaning pits. Demob rig for move. Move change house. Remove Rockwasher. Rig Released @ 0400 HRS 02:30 04:00 1.50 0 0 COMPZ RPCO OTHR P Continue install BPV with Lubricator as per Vetco Gray reps. Rig down Lubricator. Shut in pressures = OA - 250PSI, IA - 490 PSI, Tubing - 490 PSI. { E~~~~ ~1 0# 41 Page 1 of 1 • Maunder, Thomas E (DOA} From: Thomas Maunder [tom_maunder@admin.state.ak.us] Sent: Wednesday, April 11, 2007 4:16 PM To: Hartwig, Dennis D Cc: Thomas, Randy L Subject: Re: 1 J-135 L1 (207-039) Hole Size Change Dennis, This note is sufficient. Tom Maunder, PE AOGCC Hartwig, Dennis D wrote, On 4/11/2007 4:05 PM: Tom, Doyon 15 is currently moving to drill the 1J-135 Dual Lat Producer. The well was permitted to Drill the lower B-Sand as an 8 '/z" hole with a 5 '/" slotted liner and the upper sand as a 6 ~l." with 4 '/" slotted liner. We have changed the plan to drill both laterals (B & D) as 8 "/2" hole sizes, however the liner sizes will remain as originally planned. Please contact me if further documentation is required for compliance. Best Regards... Dennis Dennis Hartwig Drilling Engineer ConocoPhillips Alaska, Inc. Oifi~ce :907-265-6862 Cell :907-980-1433 Fax :907-265-1535 ~~ ~~~ ~~ 5/22/2008 • C0IQSER~A'1`l[®1~T C®M1~i15SI®1~T Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 1J-135L1 ConocoPhillips Alaska, Inc. Permit No: 207-039 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Surface Location: 1583' FSL, 2287' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 1759' FSL, 766' FWL, SEC. 13, T10N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. I The permit is for a new wellbore segment of existing well KRU 1J-135, Permit No. 207- 038, API No. 50-029-23349-00. Production should continue to be reported as a function of the original API number stated above. 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 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 intor at (907) 659-3607 (pager). DATED this day of March, 2007 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION (~c,, R~ ~® MAR Y ~4 f~~1(~7 PERMIT TO DRILL Alaska 0~ & Gay Ivt)ia:p. C~~t 20 AAC 25.005 1a. Type of Work: Drill 0 Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil Q - Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^ 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-135L1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 17903' TVD: 3469' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1583' FSL, 2287' FEL, Sec. 35, T11 N, R10E, UM 7. Property Designation: ADL 25662 & 380058 West Sak Oil Pool Top of Productive Horizon: 223' FNL, 832' FWL, Sec. 12, T10N, R10E, UM 8. Land Use Permit: ALK 2177 & 4604 13. Approximate Spud Date: 4/12/2007 Total Depth: 1759' FSL, 766' FWL, Sec. 13, T10N, R10E, UM - 9. Acres in Property: 2560 14. Distance to Nearest Property: > 1 mile ` 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558926 ~ y- 5945397 Zone- 4 10. KB Elevation /Dp ~~L (Height above GL): 28' RKB ee~`• 1eb'. Distance to Nearest Well within Pool: 1J-103L2 , 147' @ 1381 16. Deviated wells: Kickoff depth: 9328 ~ ft. Maximum Hole Angle: 92° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.oa5) Downhole: 1539 psig - Surface: 1145 psig i 18. Casing Program if ti S Setting Depth Quantity of Cement Size ica ons pec Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 40" 20" 62.5# H-40 Welded 80' 28' 28' 80' 80' 260 cf ArcticCRETE 16" 13.375" 68# L-80 BTC 3511' 28' 28' 3511' ° 2221' ~ 670 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 10200' 28' 28' 10200' 3639' 840 sx DeepCRETE 8.5" 5.5" 15.5# L-80 BTCM 8578' 9328' - 3564' - 17906" 3469' ~ slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing ' Length Size Cement Volume MD TVD Conductor/St r u ct u ra I Surface Intermediate Production Liner Perforation Depth MD (ft): ~ ~O - Perforation Depth TVD (ft): 20. Attachments: Filing Fee L BOP Sketch Drilling Program ~ Time v. Depth Plot ^ Shallow Hazard Analysis 0 Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements ^~ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ; ~ J 1 Phone ~ ~(~~ 3 v Date Tj ~~ G'' ` \ P ed 11 Drake Commission Use Only Permit to Drill /~ Number: ~?"~3 { API Number: ,\ 50-~?i9 ~~ ~ ~ ~'- w Permit Approval Date: ~• ` ~ U See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed mQthane, gas hydrates, or gas contained in shales: Samples req'd: Yes ^ No rL•~1( ud log req'd: Yes ^ No [t/r Other: "~~f ~ ,,.~, ~\ '~~'~ ~~,~,,. H2S measures: Yes ^ i al svy req'd: Yes Q~ No ^ _ ~ ~ APPROVED BY THE COMMISSION DATE:` /~ O~ ,COMMISSIONER Form 10-401 Revised 12/2005 Submit in Duplicate 7 J ~~ ~6b 3~ lG_t~7 1 Applicfor Permit to Drill, Well 1 J-135 L1 Revision No.O Saved: 14-Mar-07 Permit It -West Sak Well #1J-135L1 ' Application for Permit to Drill Document r.~ -~~ qx mizi~ w~ii yv~uo Table of Contents 1. Well Name .................................................................................................................. 2 q .f ~ ............................................................................................................. Re uirements o 20 AAC 25.005 2 2. Location Summary ..................................................................................................... 2 Requirements of 20 AAC 25.OOS(c)(2) ......................................................................................................... 2 q f ~) ............................................................................................................. Re uirements o 20 AAC 25.050 2 3. Blowout Prevention Equipment Information ............................................................... 3 Requirements of 20 AAC 25.005(c)(3) ......................................................................................................... 3 4. Drilling Hazards Information ..................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ........................................................................................................ 3 5. Procedure for Conducting Formation Integrity Tests .................................................. 3 Requirements of 20 AAC 25.005 (c)(S) ........................................................................................................ 3 6. Casing and Cementing Program ................................................................................. 3 Requirements of 20 AAC 25.OOS(c)(6) ......................................................................................................... 3 7. Diverter System Information ...................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ......................................................................................................... 4 8. Drilling Fluid Program ............................................................................................... 4 Requirements of 20 AAC 2S.OOS(c)(8) ......................................................................................................... 4 Lateral Mud Pro am MI VersaPro Mineral Oil Base 4 9. Abnormally Pressured Formation Information ........................................................... 4 Requirements of 20 AAC 25.005 (c)(9) ........................................................................................................ 4 10. Seismic Analysis ......................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ...................................................................................................... 5 11. Seabed Condition Analysis .......................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ...................................................................................................... 5 12. Evidence of Bonding ................................................................................................... ~ 1J-135 L1 PERMIT IT Page 1 of 6 Printed: 14-Mar-07 • Appli~for Permit to Drill, Well 1J-135 L1 Revision No.O Saved: 14-Mar-07 Requirements of 20 AAC 25.005 (c)(12) ...................................................................................................... 5 13. Proposed Drilling Program ......................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ...................................................................................................... 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .................................. 6 Requirements of 20 AAC 25.005 (c)(14) ...................................................................................................... 6 15. Attachments ............................................................................................................... 6 Attachment 2 Directional Plan (6 pages) .................................................................................................... 6 Attachment 3 Drilling Hazards Summary (1 page) ...................................................................................... 6 (P g) ....................................................................................................... Attachment 4 Well Schematic t a e 6 1. Well Name Requirements of 20 AAC 25.005 (fl Each well must be identifted by a unique name designated by the operator and a unigaEe API number assig~aed by the commission under 20 AAC 2~.040(b). For a well isith multiple Nell branches, each branch must similm•ly be identifred by a unique name and API number by adding a suffix to the name designated for the well by tlae operator and to the number assigned to the Nell by the commission. The well for which this Application is submitted will be designated as 1J-135 L1. 2. Location Summary Requirements of 20 AAC 2S.OOS(c)(2) An application for a Permit to Drill must be accompanied by each of the folloia ing items, except for an item already on file Nith the commission and identified in the application: (2) a plat identifying the property and the property's oisners and shown~g (A)the coordinates of the proposed location of the ~+~ell at the surface, at the top of each objective formation, and at total depth, referenced to gm~ernmenfal section lines. (BJ the coordinates of the proposed location of the Nell at the sup face, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Ab~tospheric Administration; (C) the proposed depth of the well at the top of each objective formation mzd at total depth; Location at Surface 1,584' FSL, 2,287' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 109' AMSL Northings: 5,945,397 Eastings: 558,926 Pad Elevation 81' AMSL Location at Top of Productive Interval (West 223' FNL, 832' FWL, Section 12, TlON, R10E Sak "D" Sand) ASP Zone 4 NAD 27 Coordinates Northings: 5,938,336 Eastings: 562,106 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, SS: Location at Total De th 1,759' FSL, 766' FWL, Section 13, T10N, R10E ~ ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 17,903 ~ Northings: 5,929,759 Eastings: 562,116 Total Vertical Depth, RKB: 3,469 Total Vertical De th, SS: 3,348 and (D) other information required by 20 AAC 25.OS0(b); Requirements of 20 AAC 25.050(b) If a Nell is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (IJ inch~de a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent u~ellbores within 200 feet of any portion of the proposed i~~ell; 1J-135 L1 PERMIT IT Page 2 of 6 Printed: 14-Mar-07 • Please see Attachment 1: Directional Plan Appli~ for Permit to Drill, Well 1 J-135 L1 Revision No.O Saved: 14-Mar-07 and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and shrnv that each named operator has been furnished a copy of the application by certified mail; or (B) state that d2e applicmat is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following Items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as reguired by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-135 Ll. Please see information on the Doyon Rig 15 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and ident~ed in the application: (4J information on drilling ha=ards, including (A) the nurximum drnvnhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a nzefhane gradient; The expected reservoir pressure in the West Sak sands in the 1J-135 L1 is 0.43 psi/ft, or 8.3 ppg EMW (equivalent , mud weight). The maximum potential surface pressure (MPSP) is 1,145 psi. Based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak D sand formation is 3,578'. The MPSP is: MPSP = (3,578 ft)(0.43 - 0.11 psi/ft) =1,145 psi (Bf data on potential gas=ones; The well bore is not expected to penetrate any gas zones. And (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation pones, and cones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(S) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission aiad identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(fl; No formation integrity test will be performed in the drilling of 1J-135 L1 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for ara item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre perforated liner, or screen to be installed,' 1J-135 L1 PERMIT IT Page 3 of 6 Printed: 14-Mar-07 Casing and Cementing Program See also Attachment 3: Cement Summary Appli~ for Permit to Drill, Well 1 J-135 L1 Revision No.O Saved: 14-Mar-07 Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (lb/ft) Grade Connection t) (ft) t) Cement Program 20" 40" 62.5 H-40 Welded 80 28' / 28' 80' / 80' Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 13-3/8" 16" 68 L-80 BTC 3,511 28' / 28' 3,511' / 2,221' 670 sx ArcticSet Lite Lead, 220 sx Dee CRETE Tail Cement Top planned @ 5,496' 9-5/8" 12-1/4" 40 L-80 BTCM 10,200 28' / 28' 10,200' / 3,639' IviD / 2,736' TVD. Cemented w/ 840 sx DeepCRETE 5-1/2 8-1/2" B Sand Lateral 15.5 L-80 BTCM 8,481 9,428' / 3,570' 17,909' / 3,532' Slotted-no cement loft 1 - °~°- 4-1/2 6-3/4" D Sand Lateral 11.6 L-80 BTCM 8,578 9,328' / 3,564' 17,906' / 3,469' Slotted-no cement slotted (1J-180 Ll) _....- ~~ -~-~s,.~, ---~ 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the follox~ing items, except for an item already on file with the commission and identified in the application: (7) a diagram mid description of the diverter system as required by 20 fL9C 25.035, unless this requirenvent is waived by the commission under 20 AAC 25.035 (h) (2); No diverter system will be used during operations on 1J-135 L1 8. Drilling Fluid Program Requirements of 20 AAC 2S.OOS(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro Mineral Oil Base) Value Density (pp~ 8.4 - 8.6 Plastic Visconti (lb/100 s 15-25 Yield Point (cP) 18-28 HTHP Fluid loss (ml/30 min 200psi & 1 SO° <4.0 Oil /Water Ratio 80:20 Electrical Stability >600 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormrzllygeo~ressured strata as required by 20 AAC 25.0330; 1J-135 L1 PERMIT /T Page 4 of 6 Printed: 14-Mar-07 Appli~ for Permit to Drill, Well 1 J-135 L1 Revision No.O Saved: 14-Mar-07 Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be acconepmaied by each of the follrnving items, except for an item already on file with the commission and identifred in the applicatio~7: (10J for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(aJ; Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(I1) An application for a Permit to Drill must be accompanied by each of the follorooing items, except for an item already on file with the commission and ident~ed in the application: (11) for a well drilled from an offshore platform, mobile bottom foundzd structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(6); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) fln application for a Permit to Drill must be accompanied by each of the following items, ez:ceptfor an item already on file with the commission and identified in the applicatioi~• (12) evidence shoia-ing that the reguiren:ents of 20 ~.4C 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the follrnving items, except for an item already on file with dze commission and identifred in the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 1J-135 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 9,328' MD / 3,564' TVD, the top of the "D" sand. 2. Mi118-1/2" window. POOH. 3. Pick up 4-3/4" drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of "D" sand lateral at 17,906' MD / 3,469' TVD, as per directional plan. 5. POOH, back reaming out of lateral. POOH. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4-1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH, laying down drill pipe as required. 10. PU ESP completion as required and RIH to depth. Land tubing. Set BPV. 11. Nipple down BOPE, nipple up tree and test. Pull BPV. 12. Freeze protect well with diesel by pumping into 4-1/2" x 9-5/8" annulus, taking returns from tubing and allowing to equalize. 13. Set BPV and move rig off. 14. Rig up wire line unit. Pull BPV. 15. Set gas lift valves in mandrels. Operate well on ESP until well cleanup is finished. 1J-135 L1 PERMIT IT Page 5 of 6 Printed: 14-Mar-07 • 16. Place well on production. Applir~ for Permit to Drill, Well 1J-135 L1 Revision No.O Saved: 14-Mar-07 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by earls of the follo~~ing items, except for ara item already on file with the commission and identfed in the application: (14) a general description of hrnv the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorisation under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on lE Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 1J-135 L1 PERMIT IT Page 6 of 6 Printed: 14-Mar-07 • ConocoPhillips Alaska Plan: 1J-135 L1 (wp07) Sperry Drilling Services Proposal Report -Geographic 13 March, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-135 Plan 1J-135 L1 Local Coordinate Origin: Viewing Datum: TVDs to System: North Reference: Unit System: Centered on Well Plan 1J-135 D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) N ~` True ,; API - US Survey Feet IH,A I..~ IL.I IE3 t..! IF'~"T C711V 9p®rry Drilling ServicQsi HALLIBURTOIV WELL DETAIIS Plan IJ-135 Ground Level: 81.10 Sp®rry Drilling Services +N/-S +E/-W Northing Easting Latittude Longitude Slot 0.00 0.00 5945397.09 558926.15 70°IS'4LIOSN 149°31'25.162W FORMATION TOP DETAILS No.TVDPath TVDSS MDPath Formation 1 1523.45 1402.35 1619.42 Pfrost 2 1663.46 1542.36 1811.35 T3 3 1989.76 1868.68 2615.87 K15 4 2207,16 2086.06 3455.76 Casing Pt 5 2869.53 2748.43 6014.96 Ugnu C 6 3129.13 3008.03 7017.98 Ugnu B 7 3193.59 3072.49 7267.03 Ugnu A 8 3374.78 3253.68 8210.15 K 13 9 3544.80 3423.70 9322.72 W Sak D CASING DETAILS ~ 11 j No MD T'A'D TVDss Name Size 1 3455.76 220216 2086.06 13 3/8" 13-3/ j~~r J/~ 2 9322.74 3544.80 3423.70 9 5/8" TOW 9-5/8 3 17903.09 3469.20 3348.1 41/2" 4-1/2 J _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ - L1: 9 5/8" TOW @ 9323' MD, 3545' ND - 223' FNL, 832' FWL - Sec12-T10N-R10E L1: BHL @ 17903' MD, 3469' ND - 1759' FSL, 766' FWL - Sec13-T10N-R10E .\ 250C 0 3000 o ___ __ _ o ------------/--- ------------------------------------------ _n=---O-- -Q-----0---- a-4J-135-i'•-(?vP67j .... O ~ O O O V7 fD O n r O ° ' O ~ ~ ,., __~----~----o__--O--a-~---------------------------------------_ __---_-____-_-------------~-X41/2"-__ n ~ ~ rn N 3500 -~ _. _. _ - -- --_- - --_---- --_---- -:- ---. c - - - - - _N - / ~ i ~ p - - - - O c- o o - - = o \\ °o ° °o ' °o °o i / , °j 1J-135 (wp _ O o ~ ~ i i i ~ t \~~ ~ i i ~ ~ ~ ~ 4000 ~~ ~ ~ i t ,~ i ~ t ~ i ~ ~ t t t i ~ ~` ~ ~` t t i t i i 4500 1J-135 MB_D Heel (01/31/2007) ~~\ 1J-135 MB_D CP2 (01/31/2007) `~ 1J-135 MB_D CP4 (01/31/2007) ~~ 1J-135 MB_D CP6 (01/31/2007) j 1J-135 MB_D CP8 (01/31/2007) ~ 1J-135 MB_D Toe (01/31/2007) `~ ~ 1J-135 MB D CP1 (01/31/2007) 1J-135 MB_D CP3 (01/31/2007) 1J-135 MB_D CPS (01/18/2007) 1J-135 MB_D CP7 (01!31/2007) 1J-135 MB_D CP9 (01/31/2007) 5000 6500 7000 7500 8000 8500 9000 9500 10000 IJ`r~0 11000 11500 12000 12500 13000 13500 14000 14500 15000 15500 16000 Vertical Section at 180.00° (1000 ft/in) Conoco`Phillips H/3-LL IBURTON Project: Kuparuk River Unit WELL DETAIIS: Plan IJ-135 Site: Kuparuk 1J Pad Ground Level: 81.10 Sperry O riliing Services Well: Plan 1J-135 +N/-S +E/-W Northing Easting Latittude Longitude Slot ° ' ° ' W 25.162W 41.108N 149 31 15 ellbore: Plan 1J-135 L1 0.00 0.00 5945397.09 558926.15 70 Plan: 1J-135 L1 (wp07) REFERENCE INFORMATION Co-ortiinate (NIE) Reference: Well Plan iJ-135, True North -6000 Vertical (ND) Reference: D15 (40+81.1) (~+ 121.10ft (D15 (40+81.1)) Measuretl Depth Reference: D15 (40+81.1) (d 121.1 Ofl (D15 (40+81.1)) ,S 5° Calculation Methotl: Minimum Curvature -6500 X65° CASING DETAILS 3500 No MD TVD TVDss Name Size -7000 1 3455.76 2207.16 2086.06 13 3/8" 13-3/8 " LI-i3s ti1L~ D ]feel of/sv2oo7 _ _ _ _ _ _ _ ( TOW 9-5/8 J3Q 2 9322.74 3544.80 3423.70 9 5/8 3 17903.09 3469.20 3348.1 4 1/2" 4-1/2 - - - IJ-13, \113 UCPI (0131_007 --_____ _ -'' -7500 Ll: 9 5/8" TOW @ 9323' MD, 3545' TVD - 223' FNL, 832' FWL - Secl2-TI ON-R' "" ~,~~ 180° \ / -8000 -8500 180° n-13~au3 Dc]'3(o131,007 ____-- -9000 1 go° -9500 IJ-135 V113 DCI'-1(0131 =(r07 -_____ -10000 180° -10500 c IJ-I?i V13 DCPZ f0118'u07 ----_-_ _ c -11000 3500 N + -11$00 180° .L O -12000 IJ-13S V16 DCP((0131^007 _______ 'J 7 O -12500 1R0° -13000 I1-I ;; A113 D('1'7101317iA)", _______ -13500 180° -14000 I1-135 \16 D CP8 (01 31:'_007 _ _ _ _ _ _ _ -14500 180° -15000 II-135 MB DCP9 (0131?007 _______ -15500 I I- l i ~ 1111 r1 Toc Ui l '31 '(~'~7 _ _ _ _ _ _ _ q 1/2„ ~ _ _ _ _ _ _ _ _ LI: BHL @ 17903' MD, 3469' TVD - 1759' FSL, 766' FWL- Sec13-TI ON-R10E '~ i ~ T M Azimuths to True North -16000 I Magnetic North: 23.77° 1J-135 LI (wp07) Magnetic Field Slrength:57609.7nT -16500 Dip AngIe:80.80° Date: 10/5/2006 Model: BGGM2006 -17000 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 ~ West(-)/East(+) (1250 ft/in) ColnocoPhillips ~-'' Halliburton Company CO~CG~t~~ Planning Report -Geographic E"~>~L~~~IV~~O Sperry ONliing ~~rvlaas Database: Compass 2003.11 ' Local Co-ordinate Reference: Well Plan 1J-135 Company: ConocoPhillips Alaska, Inc. ND Reference: ! D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Project: Kuparuk River Unit MD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Site: Kuparuk 1J Pad ' North Reference: True - Well: Plan 1J-135 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-135 L1 Design: 1J-135 L1 (v/p07) Project Kuparuk River Unit. North Slope Alaska, U nlted States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1J-135 _ Well Position +N/-S 0.00 ft Northing: 5,945,397.09 ft ~ Latitude: 70° 15' 41.108" N +E/-W 0.00 ft Easting: 558,926.15 ft - Longitude: 149° 31' 25.162" W Position Uncerta inty 0.00 ft Wellhead Elevation: ft Ground Level: 81.10ft Wellbore Plan 1J-135 L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2006 10/5/2006 23. 80.20 57.610 Design 1J-135 L1 (wp07J Audit Notes: Version: Phase: PLAN Tie On Depth: 9,322.72 Vertical Section: Depth From (ND) +NI-S +E/-W Direction (ft) (ft) (ft1 (°) 40.00 0.00 0.00 180.00 3/13/2007 7:00:46PM Page 2 of 8 COMPASS 2003.11 Build 48 • Caioca~~'hitlips Alaska Halliburton Company Planning Report -Geographic • ~"'~14~.~~BVRT~N Sperry Qriilin® Ssrvic~es Database: Compass 2003.11 Local Co-ordinate Reference: `Well Plan 1J-135 Company: ConocoPhillips Alaska, Inc. TVD Reference: G15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Project: Kuparuk River Unit MD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-135 Survey Calculation Method: 'Minimum Curvature Wellbore: Plan 1J-135 L1 Design: iJ-135 L1 (wp07) Plan Summary Measured Depth Inclination Azimuth lft) l°) (°1 9,322.72 82.00 180.00 9,339.22 84.24 180.00 9,369.22 84.24 180.00 9,494.34 90.49 180.38 9,551.97 90.49 180.38 9,565.27 89.96 180.45 10,440.27 89.96 180.45 10,452.47 89.84 180.45 11,081.31 89.84 180.45 11,182.81 90.85 180.44 11,981.46 90.85 180.44 12,111.98 92.16 180.40 13,139.32 92.16 180.40 13,209.40 91.46 180.40 14,239.77 91.46 180.40 14,380.90 90.05 180.35 15,438.86 90.05 180.35 15,457.34 89.86 180.39 16,338.94 89.86 180.39 16,351.20 89.96 180.31 17,539.02 89.96 180.31 17,645.37 91.02 180.29 17,903.09 91.02 180.29 Vertical Dogleg Build Turn Depth +N/-S +E/-W Rate Rate Rate TFO (ft) (ft) (ft) (°1100ft) (°I100ft) (°/100ft) (~) 3,544.80 -7,085.47 3,125.74 0.00 0.00 0.00 0.00 3,546.78 -7,101.85 3,125.74 13.60 13.60 0.00 0.00 3, 549.78 -7,131.70 3,125.74 0.00 0.00 0.00 0.00 3,555.53 -7,256.62 3,125.32 5.00 4.99 0.31 3.53 3,555.04 -7,314.25 3,124.93 0.00 0.00 0.00 0.00 3,554.99 -7,327.55 3,124.84 4.00 -3.97 0.48 173.14 3,555.60 -8,202.52 3,117.99 0.00 0.00 0.00 0.00 3,555.62 -8,214.73 3,117.89 1.00 -1.00 0.00 -180.00 3,557.40 -8,843.55 3,112.97 0.00 0.00 0.00 0.00 3,556.79 -8,945.03 3,112.18 1.00 1.00 -0.01 -0.34 3,544.90 -9,743.58 3,106.02 0.00 0.00 0.00 0.00 3,541.47 -9,874.04 3,105.06 1.00 1.00 -0.03 -2.00 3,502.80 -10,900.63 3,097.96 0.00 0.00 0.00 0.00 3,500.59 -10,970.67 3,097.47 1.00 -1.00 0.00 180.00 3,474.40 -12,000.68 3,090.34 0.00 0.00 0.00 0.00 3,472.55 -12,141.80 3,089.42 1.00 -1.00 -0.03 -178..12 3,471.70 -13,199.74 3,082.94 0.00 0.00 0.00 0.00 3,471.71 -13,218.22 3,082.83 1.00 -0.98 0.19 169.24 3,473.80 -14,099.79 3,076.90 0.00 0.00 0.00 0.00 3,473.82 -14,112.05 3,076.83 1.00 0.76 -0.65 -40.64 3,474.70 -15,299.85 3,070.50 0.00 0.00 0.00 0.00 3,473.79 -15,406.20 3,069.95 1.00 1.00 -0.02 -0.90 3,469.20 -15,663.88 3,068.65 0.00 0.00 0.00 0.00 3/13/2007 7:0046PM r Page 3 of 8 - COMPASS 2003.11 Build 48 • Conacc~hillips Alaska Halliburton Company Planning Report -Geographic • HA1_l.1BURTf~R1 Sperry ~rilling Serviae>s Database: Compass 2003.11 Local Co-ordinate Reference: Well Plan 1J-135 Company: <_:onocoPhillips Alaska, Inc. TVD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Project: k;uparuk River Unit MD Reference: < D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Site: K.uparuk 1J Pad North Reference: 'True Well: Plan 1J-135 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-135 L1 Design: 1J-135 L1 (wp07) Planned Survey 1.1-135 L 1 (wp07) Map Map MD Inclination Azimuth ND SSTVD +N/-S +E!-W Northing Easting DLSEV Vert Section (ft) l°) (°) (ft) (ftl (ft) lft) (ft) lft) 1°I100ft) (ftl 9,322.72 82.00 180.00 3,544.80 3,423.70 -7,085.47 3,125.74 5,938,336.99 562,106.93 0.00 7,085.47 L1: 9 5/8" TOW @ 9323' MD, 3545' TVD - 223' FNL, 832' FWL - Sec12-T1 ~ 0N-R10E - W Sak D - 9 518" TOW ~ 9,339.22 84.24 180.00 3,546.78 3,425.68 -7,101.85 3,125.74 5,938,320.61 562,107.06 13.60 7,101.85 9,369.22 84.24 180.00 3,549.78 3,428.68 -7,131.70 3,125.74 5,938,290.76 562,107.29 0.00 7,131.70 9,400.00 85.78 180.10 3,552.46 3,431.36 -7,162.36 3,125.72 5,938,260.11 562,107.51 5.00 7,162.36 9,494.34 90.49 180.38 3,555.53 3,434.43 -7,256.62 3,125.32 5,938,165.85 562,107.85 5.00 7,256.62 9,500.00 90.49 180.38 3,555.48 3,434.38 -7,262.29 3,125.28 5,938,160.19 562,107.85 0.00 7,262.29 9,551.97 90.49 180.38 3,555.04 3,433.94 -7,314.25 3,124.93 5,938,108.23 562,107.91 0.00 7,314.25 9,565.27 89.96 180.45 3,554.99 3,433.89 -7,327.55 3,124.84 5,938,094.93 562,107.92 4.00 7,327.55 9,600.00 89.96 180.45 3,555.01 3,433.91 -7,362.28 3,124.57 5,938,060.20 562,107.92 0.00 7,362.28 9,700.00 89.96 180.45 3,555.08 3,433.98 -7,462.28 3,123.78 5,937,960.21 562,107.92 0.00 7,462.28 9,800.00 89.96 180.45 3,555.15 3,434.05 -7,562.27 3,123.00 5,937,860.22 562,107.92 0.00 7,562.27 9,900.00 89.96 180.45 3,555.22 3,434.12 -7,662.27 3,122.22 5,937,760.23 562,107.92 0:00 7,662.27 10,000.00 89.96 180.45 3,555.29 3,434.19 -7,762.27 3,121.44 5,937,660.24 562,107.92 0.00 7,762.27 10,100.00 89.96 180.45 3,555.36 3,434.26 -7,862.27 3,120.65 5,937,560.25 562,107.92 0.00 7,862.27 10,200.00 89.96 180.45 3,555.43 3,434.33 -7,962.26 3,119.87 5,937,460.26 562,107.92 0.00 7,962.26 10,300.00 89.96 180.45 3,555.50 3,434.40 -8,062.26 3,119.09 5,937,360.27 562,107.92 0.00 8,062.26 10,400.00 89.96 180.45 3,555.57 3,434.47 -8,162.26 3,118.30 5,937,260.28 562,107.92 0.00 8,162.26 10,440.27 89.96 180.45 3,555.60 3,434.50 -8,202.52 3,117.99 5,937,220.02 562,107.92 0.00 8,202.52 1J-135 MB_D CP2 (01 131/2007) 10,452.47 89.84 180.45 3,555.62 3,434.52 -8,214.73 3,117.89 5,937,207.82 562,107.92 1.00 8,214.73 10,500.00 89.84 180.45 3,555.76 3,434.66 -8,262.25 3,117.52 5,937,160.29 562,107.92 0.00 8,262.25 10,600.00 89.84 180.45 3,556.04 3,434.94 -8,362.25 3,116.74 5,937,060.30 562,107.92 0.00 8,362.25 10,700.00 .89.84 180.45 3,556.32 3,435.22 -8,462.25 3,115.96 5,936,960.31 562,107.92 0.00 8,462.25 10,800.00 89.84 180.45 3,556.60 3,435.50 -8,562.24 3,115.17 5,936,860.32 562,107.92 0.00 8,562.24 10,900.00 89.84 180.45 3,556.89 3,435.79 -8,662.24 3,114.39 5,936,760.33 562,107.92 0.00 8,662.24 11,000.00 89.84 180.45 3,557.17 3,436.07 -8,762.24 3,113.61 5,936,660.34 562,107.92 0.00 8,762.24 11,081.31 89.84 180.45 3,557.40 3,436.30 -8,843.55 3,112.97 5,936,579.04 562,107.92 0.00 8,843.55 1J-135 MB_D CP3 (01 /3112007) 11,100.00 90.02 180.45 3,557.42 3,436.32 -8,862.23 3,112.83 5,936,560.35 562,107.92 1.00 8,862.23 11,182.81 90.85 180.44 3,556.79 3,435.69 -8,945.03 3,112.18 5,936,477.56 562,107.93 1.00 8,945.03 11,200.00 90.85 180.44 3,556.53 3,435.43 -8,962.22 3,112.05 5,936,460.37 562,107.93 0.00 8,962.22 11,300.00 90.85 180.44 3,555.04 3,433.94 -9,062.21 3,111.28 5,936,360.39 562,107.94 0.00 9,062.21 11,400.00 90.85 180.44 3,553.55 3,432.45 -9,162.20 3,110.51 5,936,260.41 562,107.95 0.00 9,162.20 11,500.00 90.85 180.44 3,552.07 3,430.97 -9,262.18 3,109.74 5,936,160.43 562,107.96 0.00 9,262.18 11,600.00 90.85 180.44 3,550.58 3,429.48 -9,362.17 3,108.96 5,936,060.45 562,107.97 0.00 9,362.17 11,700.00 90.85 180.44 3,549.09 3,427.99 -9,462.15 3,108.19 5,935,960.47 562,107.98 0.00 9,462.15 11,800.00 90.85 180.44 3,547.60 3,426.50 -9,562.14 3,107.42 5,935,860.49 562,107.99 0.00 9,562.14 11,900.00 90.85 180.44 3,546.11 3,425.01 -9,662.13 3,106.65 5,935,760.52 562,108.00 0.00 9,662.13 11,981.46 90.85 180.44 3,544.90 3,423.80 -9,743.58 3,106.02 5,935,679.07 562,108.01 0.00 9,743.58 1J-135 MB_D CP4 (01 /31/2007) 12,000.00 91.04 180.44 3,544.59 3,423.49 -9,762.11 3,105.88 5,935,660.54 562,108.01 1.00 9,762.11 12,100.00 92.04 180.40 3,541.91 3,420.81 -9,862.07 3,105.15 5,935,560.58. 562,108.07 1.00 9,862.07 12,111.98 92.16 180.40 3,541.47 3,420.37 -9,874.04 3,105.06 5,935,548.61 562,108.08 1.00 9,874.04 12,200.00 92.16 180.40 3,538.16 3,417.06 -9,962.00 3,104.46 5,935,460.66 562,108.15 0.00 9,962.00 12,300.00 92.16 180.40 3,534.39 3,413.29 -10,061.93 3,103.76 5,935,360.75 562,108.24 0.00 10,061.93 3/13/2007 7:00:4SPM Page 4 of 8 COMPASS 2003.11 Build 48 • CUt'lOC4~11~~1~t5 Alaiska Halliburton Company Planning Report -Geographic ~"~AI~L~$ V ~~0 Sperry Qritiing ~srvicss Database: Compass 2003.11 Local Co-ordinate Reference: 'Well Plan 1J-135 Company: ConocoPhillips Alaska, Inc. ND Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Project: k:uparuk River Unit MD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+g1.1)) Site: l~:uparuk 1J Pad North Reference: 'True Well: Wellbore: Plan 1J-135 Flan 1J-135 L1 Survey Calculation Method: Minimum Curvature Design: 1J-135 L1 (wp07j Planned Survey 1J-135 L1 (wp07j Map Map MD Inclination Azimuth ND SSND +NI-S +E!-W Northing Easting DLSEV Vert Section (ft) (~) (') (ft) (ft) (ft) (ft) (ft) lft) (°I100ft) Iftl 12,400.00 92.16 180.40 3,530.63 3,409.53 -10,161.85 3,103.07 5,935,260.83 562,108.33 0.00 10,161.85 12,500.00 92.16 180.40 3,526.87 3,405.77 -10,261.78 3,102.38 5,935,160.91 562,108.42 0.00 10,261.78 12,600.00 92.16 180.40 3,523.10 3,402.00 -10,361.71 3,101.69 5,935,060.99 562,108.51 0.00 10,361.71 12,700.00 92.16 180.40 3,519.34 3,398.24 -10,461.63 3,101.00 5,934,961.07 562,108.60 0.00 10,461.63 12,800.00 92.16 180.40 3,515.57 3,394.47 -10,561.56 3,100.30 5,934,861.15 562,108.69 0.00 10,561.56 12,900.00 92.16 180.40 3,511.81 3,390.71 -10,661.49 3,099.61 5,934,761.23 562,108.78 0.00 10,661.49 13,000.00 92.16 180.40 3,508.04 3,386.94 -10,761.41 3,098.92 5,934,661.31 562,108.87 0.00 10,761.41 13,100.00 92.16 180.40 3,504.28 3,383.18 -10,861.34 3,098.23 5,934,561.39 562,108.96 0.00 10,861.34 13,139.32 92.16 180.40 3,502.80 3,381.70 -10,900.63 3,097.96 5,934,522.10 562,109.00 0.00 10,900.63 1J-135 MB_D CP5 (01 /1 812 0 0 7) 13,200.00 91.55 180.40 3,500.84 3,379.74 -10,961.28 3,097.54 5,934,461.46 562,109.05 1.00 10,961.28 13,209.40 91.46 180.40 3,500.59 3,379.49 -10,970.67 3,097.47 5,934,452.07 562,109.06 1.00 10,970.67 13,300.00 91.46 180.40 3,498.29 3,377.19 -11,061.24 3,096.84 5,934,361.50 562,109.14 0.00 11,061.24 13,400.00 91.46 180.40 3,495.75 3,374.65 -11,161.21 3,096.15 5,934,261.55 562,109.23 0.00 11,161.21 13,500.00 91.46 180.40 3,493.20 3,372.10 -11,261.17 3,095.46 5,934,161.59 562,109.32 0.00 11,261.17 13,600.00 91.46 180.40 3,490.66 3,369.56 -11,361.14 3,094.77 5,934,061.63 562,109.41 0.00 11,361.14 13,700.00 91.46 180.40 3,488.12 3,367.02 -11,461.10 3,094.07 5,933,961.67 562,109.50 0.00 11,461.10 13,800.00 91.46 180.40 3,485.58 3,364.48 -11,561.07 3,093.38 5,933,861.71 562,109.59 0.00 11,561.07 13,900.00 91.46 180.40 3,483.04 3,361.94 -11,661.03 3,092.69 5,933,761.76 562,109.68 0.00 11,661.03 14,000.00 91.46 180.40 3,480.49 3,359.39 -11,761.00 3,092.00 5,933,661.80 562,109.77 0.00 11,761.00 14,100.00 91.46 180.40 3,477.95 3,356.85 -11,860.96 3,091.30 5,933,561.84 562,109.86 0.00 11,860.96 14,200.00 91.46 180.40 3,475.41 3,354.31 -11,960.93 3,090.61 5,933,461.88 562,109.95 0.00 11,960.93 14,239.77 91.46 180.40 3,474.40 3,353.30 -12,000.68 3,090.34 5,933,422.13 562,109.99 0.00 12,000.68 1J-135 MB_D CP6 (01 !31/2007) 14,300.00 90.85 180.38 3,473.19 3,352.09 -12,060.90 3,089.93 5,933,361.92 562,110.05 1.00 12,060.90 14,380.90 90.05 180.35 3,472.55 3,351.45 -12,141.80 3,089.42 5,933,281.03 562,110.17 1.00 12,141.80 14,400.00 90.05 180.35 3,472.53 3,351.43 -12,160.90 3,089.30 5,933,261.93 562,110.21 0.00 12,160.90 14,500.00 90.05 180.35 3,472.45 3,351.35 -12,260.89 3,088.69 5,933,161.94 562,110.38 0.00 12,260.89 14,600.00 90.05 180.35 3,472.37 3,351.27 -12,360.89 3,088.08 5,933,061.95 562,110.55 0.00 12,360.89 14,700.00 90.05 180.35 3,472.29 3,351.19 -12,460.89 3,087.46 5,932,961.96 562,110.72 0.00 12,460.89 14,800.00 90.05 180.35 3,472.21 3,351.11 -12,560.89 3,086.85 5,932,861.97 562,110.89 0.00 12,560.89 14,900.00 90.05 180.35 3,472.13 3,351.03 -12,660.89 3,086.24 5,932,761.98 562,111.06 0.00 12,660.89 15,000.00 90.05 180.35 3,472.05 3,350.95 -12,760.89 3,085.63 5,932,661.99 562,111.23 0.00 12,760.89 15,100.00 90.05 180.35 3,471.97 3,350.87 -12,860.88 3,085.02 5,932,562.00 562,111.40 0.00 12,860.88 15,200.00 90.05 180.35 3,471.89 3,350.79 -12,960.88 3,084.41 5,932,462.01 562,111.57 0.00 12,960.88 15,300.00 90.05 180.35 3,471.81 3,350.71 -13,060.88 3,083.79 5,932,362.02 562,111.74 0.00 13,060.88 15,400.00 90.05 180.35 3,471.73 3,350.63 -13,160.88 3,083.18 5,932,262.03 562,111.91 0.00 13,160.88 15,438.86 90.05 180.35 3,471.70 3,350.60 -13,199.74 3,082.94 5,932,223.17 562,111.98 0.00 13,199.74 1J-135 MB_D CP7 (01 131/2007) 15,457.34 89.86 180.39 3,471.71 3,350.61 -13,218.22 3,082.83 5,932,204.69 562,112.01 1.00 13,218.22 15,500.00 89.86 180.39 3,471.82 3,350.72 -13,260.88 3,082.54 5,932,162.04 562,112.05 0.00 13,260.88 15,600.00 89.86 180.39 3,472.05 3,350.95 -13,360.87 3,081.87 5,932,062.05 562,112.16 0.00 13,360.87 15,700.00 89.86 180.39 3,472.29 3,351.19 -13,460.87 3,081.19 5,931,962.06 562,112.27 0.00 13,460.87 15,800.00 89.86 180.39 3,472.52 3,351.42 -13,560.87 3,080.52 5,931,862.07 562,112.38 .0.00 13,560.87 15,900.00 89.86 180.39 3,472.76 3,351.66 -13,660.87 3,079.85 5,931,762.08 562,112.50 0.00 13,660.87 16,000.00 89.86 180.39 3,473.00 3,351.90 -13,760.86 3,079.18 5,931,662.09 562,112.61 .0.00 .13,760.86 16,100.00 89.86 180.39 3,473.23 3,352.13 -13,860.86 3,078.51 5,931,562.10 562,112.72 0.00 13,860.86 3/13/2007 7:00:46PM Page 5 of 8 COMPASS 2003.11 Build 48 • ~011t?C4~"tl~~I~S Alaska Halliburton Company Planning Report -Geographic • H~1LFt_IBt.~RTCitV Sperry QrittMEg Setwicas Database: Compass 2003.11 Local Co-ordinate Reference: Well Plan 1J-135 Company: ConocoPhillips Alaska, Inc. ND Reference: D15 (40+g1.1) @ 121.10ft (D15 (40+81.1)) Project: K.uparuk River Unit MD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Site: K:uparuk 1J Pad North Reference: True Well: Plan 1J-135 Survey Calculation Method: Minimum Curvature Wellbore: Flan 1J-135 L1 Design: 1J-135 L1 (wp07) Planned Survey 1J-135 L1 nvp07) Map Map MD Inclination Azimuth ND SSND +N/-S +E/-W Northing Easting fftl (°) (°) (ft) (ftl lft) (ft) lft) (ft) 16,200.00 89.86 180.39 3,473.47 3,352.37 -13,960.86 3,077.83 5,931,462.11 562,112.83 16,300.00 89.86 180.39 3,473.71 3,352.61 -14,060.85 3,077.16 5,931,362.12 562,112.94 16,338.94 89.86 180.39 3,473.80 3,352.70 -14,099.79 3,076.90 5,931,323.19 562,112.98 1J-135 MB_D CP8 (01 !31/2007) 16,351.20 89.96 180.31 3,473.82 3,352.72 -14,112.05 3,076.83 5,931,310.93 562,113.00 16,400.00 89.96 180.31 3,473.86 3,352.76 -14,160.85 3,076.57 5,931,262.13 562,113.12 16,500.00 89.96 180.31 3,473.93 3,352.83 -14,260.85 3,076.03 5,931,162.14 562,113.37 16,600.00 89.96 180.31 3,474.00 3,352.90 -14,360.85 .3,075.50 5,931,062.15 562,113.62 16,700.00 89.96 180.31 3,474.08 3,352.98 -14,460.85 3,074.97 5,930,962.16 562,113.87 16,800.00 89.96 180.31 3,474.15 3,353.05 -14,560.85 3,074.44 5,930,862.17 562,114.12 16,900.00 89.96 180.31 3,474.23 3,353.13 -14,660.85 3,073.90 5,930,762.18 562,114.37 17,000.00 89.96 180.31 3,474.30 3,353.20 -14,760.84 3,073.37 5,930,662.19 562,114.62 17,100.00 89.96 180.31 3,474.37 3,353.27 -14,860.84 3,072.84 5,930,562.20 562,114.87 17,200.00 89.96 180.31 3,474.45 3,353.35 -14,960.84 3,072.31 5,930,462.21 562,115.12 17,300.00 89.96 180.31 3,474.52 3,353.42 -15,060.84 3,071.77 5,930,362.22 562,115.37 17,400.00 89.96 180.31 3,474.60 3,353.50 -15,160.84 3,071.24 5,930,262.23 562,115.62 17,500.00 89.96 180.31 3,474.67 3,353.57 -15,260.84 3,070.71 5,930,162.24 562,115.87 17,539.02 89.96 180.31 3,474.70 3,353.60 -15,299.85 3,070.50 5,930,123.23 562,115.97 1J-135 MB_D CP9 (01 /31/2007) 17,600.00 90.57 180.30 3,474.42 3,353.32 -15,360.83 3,070.18 5,930,062.25 562,116.13 17,645.37 91.02 180.29 3,473.79 3,352.69 -15,406.20 3,069.95 5,930,016.89 562,116.25 17,700.00 91.02 180.29 3,472.82 3,351.72 -15,460.82 3,069.67 5,929,962.28 562,116.40 17,800.00 91.02 180.29 3,471.04 3,349.94 -15,560.80 3,069.17 5,929,862.30 562,116.68 17,900.00 91.02 180.29 3,469.25 3,348.15 -15,660.79 3,068.67 5,929,762.33 562,116.96 17,903.09 91.02 180.29 3,469.20 3,348.10 -15,663.88 3,068.65 5,929,759.24 562,116.97 L1: BHL @ 17903' MD, 3469' ND - 1759' FSL, 766' FWL - Sec13-T10N-R10E - 4 1/2" - 1J-135 MB_D Toe (0113112007) DLSEV Vert Section (°/100ft) (ft) 0.00 13,960.86 0.00 14,060.85 0.00 14,099.79 1.00 14,112.05 0.00 14,160.85 0.00 14,260.85 0.00 14,360.85 0.00 14,460.85 0.00 14,560.85 0.00 14,660.85 0.00 14,760.84 0.00 14,860.84 0.00 14,960.84 0.00 15,060.84 0.00 15,160.84 0.00 15,260.84 0.00 15,299.85 1.00 15,360.83 1.00 15,406.20 0.00 15,460.82 0.00 15,560.80 0.00 15,660.79 0.00 15,663.88 3/132007 7:00:46PM Page 6 of 8 COMPASS 2003.11 Build 48 Y Halliburton Company [~-1~1L.t.,1E~U't"'Qh CO~OC4~~ti~l1 Planning Report -Geographic Sperry ~riilMg ~srvic+ss Database: i:ompass 2003.11 Local Co-ordinate Reference: 'Well Plan 1J-135 Company: ConocoPhillips Alaska, Inc. ND Reference: D15 (40+g1.1) @ 121.10ft (D15 (40+81.1)) Project: Kuparuk River Unit MD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Site: Kuparuk 1J Pad North Reference: :True Well: Plan 1J-135 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-135 L1 Design: 1J-135 L1 (wp07) Geologic Targets Plan 1J-135 L1 ND Target Name +N/-S +E/-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,544.90 1J-135 MB_D CP4 (01/3112007) -9,743.58 3,106.02 5,935,679.07 562,108.01 - Polygon Point 1 0.00 0.00 5,935,679.07 562,108.01 Point 2 -1,157.80 -7.08 5,934,522.13 562,109.99 3,555.60 1J-135 MB_D CP2 (01/31/2007) -8,202.52 3,117.99 5,937,220.02 562,107.92 - Polygon Point 1 0.00 0.00 5,937,220.02 562,107.92 Point 2 -641.02 -5.02 5,936,579.04 562,107.92 3,474.40 1J-135 MB_D CP6 (01/31/2007) -12,000.68 3,090.34 5,933,422.13 562,109.99 - Polygon Point 1 0.00 0.00 5,933,422.13 562,109.99 Point 2 -1,199.06 -7.39 5,932,223.17 562,111.98 3,473.80 1J-135 MB_D CP8 (01/31/2007) -14,099.79 3,076.90 5,931,323.19 562,112.98 - Polygon Point 1 0.00 0.00 5,931,323.19 562,1.12.98 Point 2 -1,200.06 -6.40 5,930,123.23 562,115.97 3,469.20 1J-135 MB_D Toe (01/31/2007) -15,663.88 3,068.65 5,929,759.24 562,116.97 - Point 3,502.80 1J-135 MB_D CP5 (01/18/2007) -10,900.63 3,097.96 5,934,522.10 562,109.00 - Polygon Point 1 0.00 0.00 5,934,522.10 562,109.00 Point2 -1,100.26 -7.62 5,933,422.14 562,109.99 3,559.80 1J-135 MB_D Heel (01/31/2007) -7,085.47 3,125.74 5,938,336.99 562,106.93 - Polygon Point 1 0.00 0.00 5,938,336.99 562,106.93 Point 2 -217.01 -1.70 5,938,120.00 562,106.93 3,559.40 1J-135 MB_D CP1 (01/31/2007) -7,302.47 3,124.04 5,938,120.00 562,106.93 - Polygon Point 1 0.00 0.00 5,938,120.00 562,106.93 Point 2 -900.06 -6.05 5,937,220.02 562,107.92 3,471.70 1J-135 MB_D CP7 (01/31/2007) -13,199.74 3,082.94 5,932,223.17 562,111.98 - Polygon Point 1 0.00 0.00 5,932,223.17 562,111.98 Point 2 -900.05 -6.04 5,931,323.19 562,112.98 3,474.70 1J-135 MB_D CP9 (01131/2007) -15,299.85 3,070.50 5,930,123.23 562,115.97 - Polygon Point 1 0.00 0.00 5,930,123.23 562,115.97 Point 2 -364.06 -1.85 5,929,759.24 562,116.97 3,557.40 1J-135 MB_D CP3 (01/31/2007) -8,843.55 3,112.97 5,936,579.04 562,107.92 - Polygon Point 1 0.00 0.00 5,936,579.04 562,107.92 Point 2 -900.10 -6.95 5,935,679.07 562,108.01 3/13/2007 7:00:46PM Page 7 of 8 COMPASS 2003.11 Build 48 • Conotitlips Alaska Halliburton Company Planning Report -Geographic • HLILIBt.~R"TC~N Spisrry Drilling B®rvices Database: Compass 2003.11 Local Co-ordinate Reference: 'Well Plan 1J-135 Company: GonocoPhillips Alaska, Inc. ' TVD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Project: Kuparuk River Unit MD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-135 Survey Calculation Method: Minimum Curvature Wellbore: Flan 1J-135 L1 Design: 1J-135 Li (vrp07) Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) ("} 1") 3,455.76 2,207.16 13-3/8 16 9,322.74 3,544.80 9-5/8 12-114 17,903.09 3,469.20 4-112 6-314 Prognosed Form ation Intersecti on Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +EI-W Name (ft) (~) (°) (ft) (ft) (ft) 1,619.42 38.36 148.34 1,523.45 -380.63 124.00 Pfrost 1,811.35 47.82 150.68 1,663.46 -493.58 190.24 T3 2,615.87 75.00 154.83 1,989.78 -1,142.50 511.78 K15 3,455.76 75.00 154.83 2,207.16 -1,876.71 856.87 Casing Pt 6,014.96 75.00 154.83 2,869.53 -4,113.92 1,908.39 Ugnu C 7,017.98 75.00 154.83 3,129.13 -4,990.74 2,320.50 Ugnu B 7,267.03 75.00 154.83 3,193.59 -5,208.46 2,422.83 Ugnu A 8,210.15 80.90 153.82 3,374.78 -6,040.54 2,825.90 K 13 9,322.72 82.00 180.00 3,544.80 -7,085.47 3,125.74 W Sak D Plan Annotations 1 Measured Vertical Local Coor dinates De th P De th P +NI-S +E/-W Comment (ft) (ft) (ft) (ft) 9,322.74 3,544.80 -7,085.49 3,125.74 L1: 9 5/8" TOW @ 9323' MD, 3545' ND - 223' FNL, 832' FWL - Sec12-T10N- 17,903.09 3,469.20 -15,663.88 3,068.65 L1: BHL @ 17903' MD, 3469' TVD - 1759' FSL, 766' FWL - Sec13-T10N-R10E 3/13/2007 7:00;46PM Page 8 of 8 COMPASS 2003.11 Build 48 Conac PPhillips ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan: 1J-135 L1 (wp07) 1/4 Mile Pool Scan Sperry Drilling Services March 13, 2007 1~/ na._ J/~ C] HALLIBURTON Drilling and Formation Evaluation Clesest in POOL Closest A roa ch: Referen ce Well: 1J-135 L1 w 07 Plan Offset W ell: 1J-103 L2 Coords. - Coords. - ASP ASP 3-D ctr-ctr ' ' Meas Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. . De th Incl. An le TRUE Azi. TVD E + /W - 180° Comments De th Incl. An le TRUE Azi. TVD E + /W - 1 SO° Comments P L Min istance POOL Min Distance (146.63 ft) in POOL (146.63 ft) in POOL (9323 - 17903.09 MD) (9323 - 17903.09 MD) to 1J-135 L1 (wp07) to 1 J-103 L2 (5990 - Plan (5990 - 13866 146.63 9325 82.31 180 3424.057 5938334 562107.1 7087.872 13866 MD) 13811.75 70.99 176.08 3535.26 5938367 562017.5 7695.89 MD) Closest A roach: Reference Well: 1J-135 L1 w 07 Plan Offset Well: 1J-136 L1 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas Subsea N(+)/S(-) View VS Meas. Subsea N(+)IS(-) View VS Min. Dist. . De th Incl. An le TRUE Azi. TVD E + /W - 180° Comments De th Incl. An le TRUE Azi. TVD E + /W - 180° Comments P L in Distance POOL Min Distance (982.64 ft) in POOL (982.64 ft) in POOL (9323 - 17903.09 M (9323- 17903.09 MD) to 1J-135 L1 (wp07 to 1J-136 L1 (9081 - Plan (9081 - 982.64 ~ [ ' °~~ 3.'>~a2~s 16075 89.86 180.39 3352.014 5931585.7 562112.9 13836 17233.03 MD) 15698.15 91.19 180.8 3312.45 5931580.9 561131.1 13813.6 17233.03 MD) Closest A roach: Reference Well: 1J-135 L1 w 07 Plan Offset Well: 1J-133 Int. Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS ° Min. Dist. De th Incl. An le TRUE Azi. TVD E + /W - 180° Comments De th Comments Incl. An le TRUE Azi. TVD E + /W - 180 POOL Min Distance POOL Min Distance (1386.88 ft) in POOL (1386.88 ft) in POOL (9323 - 17903.09 MD) (9323 - 17903.09 MD) to 1J-135 L1 (wp07) to 1J-133 Int. (9880 - Plan (9880 - 1386.88 9325 82.31 180 3424.057 5938334 562107.1 7087.872 10878.02 MD) 9802.42 78.89 167.86 3486.69 5938518.4 563480.3 6953.12 10878.02 MD) Closes t A roach: Reference Well: 1J-13 5 L1 w 07 Plan Offset Well: 1J-102 L2 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS ° Min. Dist De th Incl. An le TRUE Azi. TVD E + /W - 180° Comments De th Comments Incl. An le TRUE Azi. TVD E + /W - 180 POOL Min Distance POOL Min Distance (1494.54 ft) in PO (1494.54 ft) in POOL (9323 - 17903.09 (9323 - 17903.09 MD) to 1J-135 L1 (wp0 to 1J-102 L2 (4730 - Plan (4730 - 9325 31 82 180 3424 057 5938334 562107.1 7087.872 12060.83 MD) 12060.83 90.9 178.05 3380.307 5938522.2 560625.1 6888.013 12060.83 MD) 1494.54 . . POOL Summary Template.xls 3113/2007 7:53 PM 1 O O M ~ N O ~ ~ ~ 0 ~ ~ V ~ ~~ / M I.,d' O \~ O 0 ~ ~ ~ 0 n ~~ ~ OD N N M ~ ~ N~~d' ~ ap _ _ ~MapN ~ M ~ ~ ~ Z~rncY J N(001 to yO Vtf> W 0 (O M ~ O ~~ ~ ~ M M Z ~ fD ~ CO Q U N M M ~(006~ ~ O O M O ~ I I O Z'-NM m '~ ~ ~ n `m a ~ °- o i r`~i a~i d o YY~~ 3 ~` L L r t p~ ~ !Y ac.c c~ 7 7 ~ R7 >mo~ YYaa~ d} J Q ~ ~ }' d . N C C cc`~ ~~ff p~~Qa ~o~uNi a ~ m>x ~ N N Q Q mrn c C L N Z W ~~ Q.c~ ~ 4 a ~W ~0 m O J ~ U ~ ~ ~~ i ~ M ~q ~ N M ~/ M c ~ 1, 1 ;] ~ 00 .' i O M i ~ i '7 J ` M ,i '., '~. `. N .... ..... .. .. _. ~ O ., ~ ~~ ~ OD J ~ N p O ~ i ._.......... _. ~ c i 1 ~ p •• ~ ~ O •`: J (O N r M O ~ ~ 3 ~. _, ~. ~. G~ ~0 ~~~I I _,, \ ' ~ n ~ N ` ~ p, 3 v ~ J N ~ ._-, r M _.__. ~ r ...._._ ~ • • ConocoPhillips Alaska Plan: 1J-135 L1 (wp07) Sperry Drilling Services Anticollision Summary 13 March, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-135 Plan 1J-135 L1 Local Coordinate Origin: Centered on Well Plan 1J-135 Viewing Datum: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet ~Ai.asB'~~T~~Y Spst~y Drilfing 8ervic®s SURVEI' PROGRAM ConocoPhillips Alaska, Inc. ANTI-COLLISION SETTINGS Date: 2007-03-13'1'00:00:00 VaGda[ed: Yes Version: Depth FromDepth To Survey/Plan Tool 40.011 1400.10 CB-GYRO-SS 1400.10 9322.72 MWD+IFR-AK-CAUSC 9322.72 17903.08 1J-135 Ll (wp07) MWD+IFR-AK-CAZrSC 0 270 180 90 Travelling Cylinder Azimuth (TFO+AZI) (°~ vs Centre to Centre Separation X150 ft/ink NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1J-135 Ground Level: 81.10 +NI-S+EI-W Northing Easting Latittude Longitude Slot 0.00 0.00 5945197.09 558926.15 70°15'41.108N 149°31'25.162W REFERENCE INFORMATION Co-ordinate (NIE) Reference: Well Plan 1J-115, True North Vertical (ND) Reference: D15 (40+g1.1) @ 121.108 (D15 (40+81.1)) Section (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: D15 (40+g1.1) ~ 121.108 (D75 (40+81.1)) Calculation Method: Minimum Curvature Colour To 0 9000 9000 9250 9250 9500 9500 - 9750 9750 10000 10000 - 10250 10250 10500 10500 10750 10750 11000 11000 11250 11250 - - - 11500 11500 11750 11750 12000 12000 12250 12250 _ 12500 12500 12750 12750 13000 13000 13250 13250 13500 13500 13750 13750 14000 14000 14250 14250 14500 14500 14750 14750 -- 15000 15000 15250 15250 15500 15500 15750 15750 16000 16000 16250 16250 16500 16500 16750 16750 17000 Interpolation Method: MD Interval: SOStations Depth Range From: 9322.72 To 17903.9107181 Maximum Range:1986.39107180364 Reference: Plan: 1J-135 L1 (wp07) 0 secnorl DETRIL6 Sec MD IM A:1 ND ~WS ~El-W DLp TFec° VSx Target 1 9322.71 82.00 180.00 3541.80 -]0&5.4] 3125.]0 0.00 2 9319.22 e0.20 180.00 3516.]8 -]101.85 3125.]4 13.60 0.00 ]%S.d] 0.00 ]101.85 3 9389.22 80.20 180.00 3549.]8 -]131.]0 3125.]4 0.00 d 9090.31 90.49 180.38 %55.53 -]25fi.62 3125.32 5.00 0.00 ]131.]0 J.53 J256.fi2 5 9%1.8] %A9 180.38 3555.01 -]31d.I5 3124.93 0.00 8 9505.27 89.% 180.6 3554.% -]32].55 3124.84 4.00 0.00 ]31 d.25 1]J.1d ]32].55 ] 1pM0.2] 89.% 180.6 3555.60 -0202.32 311].% 0.00 8 10152.4] eH.e4 180.6 %55.62 -0211.]3 311].89 1.00 0.% 8202.52 1}135 Ma_DCY2 (O1I31rz00'~ -180.00 8214.]3 9 IIOBI.J1 89.BC 180.6 J55].d0 384].55 3112.9] 0.00 10 11182.81 %.85 180.M 3556.]9 39603 3112.18 1.00 0.00 88/3.55 i}1%Me DCPJ (011312007) -0.3a 89°5.03 11 11%1.6 %.85 180.N 3511.90 -9)0.1.58 3106.02 0.00 O.OD 9]43.58 1}135 M8 DDF4 (011312007) 12 12111.% 92.16 190.00 3511 I7 -%]1.04 3105.06 1.00 13 13139.33 H2.16 180.40 3501.80-109W.63 309].% 0.00 -2.00 %]4.00 0.00 10900.63 1}135 MB OCPS (01/182007) 1413209.40 9/A6 180.40 3500.59-109]06] 309].4] 100 15 14239 T7 91.16 180.6 34]d.d0 -12000.68 3090.34 0.00 18000 109]0.6] 0.00 12000.68 11135 MB DCP6 /011312 0 01) 1614360.% %.OS 180.35 3472.55-12141.80 3089 d2 1.00 t] 1543e.86 %OS 180.35 3171 i0-13199.]4 308294 0.00 -1]8.1112101.80 0.00 13198.]1 1}135 Me DCP](01131rzW7) 18 156).34 e9.% 160.39 31]1.]1 -13218.22 3082.83 1.00 19 16338.94 89.86 160.J9 34)3.80-14099.]9 30]6.90 0.00 169.21 1]216.22 0.00 140%.]9 1}135 M8 DCPe (011318007) 2016351 ZO e9.% 180.31 317382-14112.05 30]6.83 f.00 21 1]539.02 e9.% 180.31 3474.70-15299.85 30]0.50 0.00 J0.6a 14112.05 0.00 15199A5 1}135 MB OCP9 (O1I31rz007) 22 t]645.J) 91.02 180.29 31]3.)9-1510G.20 3069.95 1.00 23 1)903.08 81.02 160.29 3469.20-15663.88 3068.65 0.00 0.90 1510610 0.00 15663.86 1}135 M6 DT9a (01/31/100]) Engineering Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surtace: Elliptical Conic Warning Method: Rules Based 90 Travelling Cylinder Azimuth (TFO+AZI) i°i vs Centre to Centre Separation X50 ft/in( 180 i J-103 L2 Tool Name Description ~-~'` ' Halliburton Company HA-LL.IC-3t.lR"~"'CtN- COt1000P~ 1~IIl~~ 1~5 Anticollision Report Sperry Drifliln® Services Company; ConocoPhillips Alaska, Inc. Local Co-ordinate Reference: Well Plan 1J-135 Project: Kuparuk River Unit ND Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Reference Site: Kuparuk 1J Pad MD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Site Error. ~ OOft North Reference: True Reference Well: Fian 1J-135 Survey Calculation Method: Minimum Curvature Well Error: ` O.OOft Output errors are at 2.00 sigma Reference Wellbore Plan 1J-135 L1 Database: Compass 2003.11 Reference Design: 1J-135 L1 (wp07) Offset ND Reference: Offset Datum Reference 1J-135 L1 i~~/i~07 Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: 9,322.72 to 17,903.91ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,986.39ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 3/1312007 From To (ft) (ft) Survey (Wellbore) 40.00 1,400.10 1J-135 (wp07) tPlan 1J-135) 1,400.10 9,322.72 1 J-135 (wp07) (Plan 1 J-135) 9,322.72 17,903.08 1J-135 L1 (wp07) (Plan 1J-135 L1) • CB-GYRO-SS Camera based gyro single shot MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Reference Measured Site Name Depth Offset Well -Wellbore -Design !ff1 Kuparuk 1J Pad iJ-127 - iJ-i27 L2 - 1J-127 L2 Rig Surveys 1J-14 - 1J-14 - 1J-14 1J-182 - 1J-182 - 1J-182 1J-182 - 1J-182 L1 - 1J-182 L1 1J-182 - 1J-182 L1 PB1 - 1J-182 L1 P61 1J-184 - 1J-184 - 1J-184 1J-184 - 1J-184 L1 - 1J-184 L1 Plan 1J-130 -Plan 1J-130 - 1J-130 (wp02) Plan 1J-133 - 1J-133 - 1J-133 Intermediate Plan 1 J-135 -Plan 1 J-135 - 1J-135 (wp07) Plan 1J-174 (Q1 Phase 2) - 1J-174 - 1J-174 (wp0! Plan 1J-174 (01 Phase 2) - 1J-174 L1 - 1J-174 L1 Plan 1J-176 (02 Phase 2) - 1J-176 - 1J-176 (wp0: Plan 1J-176 (02 Phase 2) - 1J-176 L1 - 1J-176 L1 Plan 1J-178 (Q3 Phase 2) - 1J-178 - 1J-178 (wp0: Plan 1J-178 (03 Phase 2) - 1J-178 L1 - 1J-178 L1 Rig: 1J-103 - 1J-103 L2 - 1J-103 L2 Rig: 1J-136 - 1J-136 - 1J-136 Rig: 1J-136 - 1J-136 L1 - 1J-136 L1 Rig: 1J-136 - 1J-136 L1 P61 - 1J-136 L1 PB1 Rig: 1J-136 - 1J-136 L1 P62 - 1J-136 L1 P62 Rig: 1J-137 - 1J-137 - 1J-137 Rig Rig: 1J-137 - 1J-137 L1 - 1J-137 L1 Rig: 1J-137 - 1J-137 L1 PB1 - 1J-137 L1 PB1 Rig: 1J-137 - 1J-137 L1 P62 - 1J-137 L1 PB2 Rig: 1J-180 - 1J-180 - 1J-180 Rig: 1J-180 - 1J-180 - 1J-180 (wp10) Rig: 1J-180 - 1J-180 L1 - 1J-180 L1 Rig: 1J-180 - 1J-180 L1 P61 - 1J-180 L1 (wp10) Rig: 1J-180 - 1J-180 L1 PB1 - 1J-180 L1 P61 Offset Centre to Measured Centre Depth Distance (ffl (ff) No-Go Allowable Distance Deviation (ft) from Plan (ff) Warning Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Pass -Major Risk FAIL - No Errors Out of range Out of range Out of range Out of range Out of range Out of range FAIL -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 10,204.97 10,878.02 1,413.15 268.81 1,144.35 9,325.00 9,325.00 0.00 0.68 -0.68 9,339.79 13,850.00 150.64 207.29 -56.65 17,895.57 17,507.04 1,217.72 467.00 750.72 16,105.56 15,725.00 983.73 412.14 571.59 13,698.31 13,300.00 1,200.23 348.65 851.58 15,094.20 14,704.51 1,089.06 384.90 704.16 CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 3/13/2007 2:13:37PM Page 2 of 2 COMPASS 2003.11 Build 48 1~-135Li~rilling Hazards~umm (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) Production Hole Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs, decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo , LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out, backreamin 1J-135 L1 Drilling Hazards Summary 3/1/2007 2:38 PM Re: 1J-]35 Subject: Re: 1J-135 ~' ~._.,rL„ From: Thomas Maunder <tom maunderwadmin.state.ak.us> Date: Fri, 16 Mar ?007 15:01:40 -0800 ~~~ To "1-Hartwig, .Dennis D" <Dennis.D.I1~u h~ i~, ~i ~c~n~~c«phillips.con~. Thanks Dennis, As I got to reviewing 1J-135L1, I was able to look at the plan and 3D views of the trajectories. Was it intended to include similar plots in 1J-135. It does not appear that any were included. Those plots make the complicated geometries much easier to understand. I will plan to make additional copies so both applications have this information. My question is answered. Tom Maunder, PE AOGCC Hartwig, Dennis D wrote, On 3/16/2007 2:47 PM: Tom, You are correct, the Anti-collision violation occurs while the 1J-135 is drilling the 12 1/4" hole with the toe (6 3/4") of 1J-103. The 1J-103, over the interval in question, is in the D-Sand while the 1J-135 is in the K-13 shale. The risk is null because of geologic control as we drill the interval. In essence the error ellipses of both wells overlap but because of geologic control we know that one well is in the D-sand while the other is in the K-13. The issue is highlighted to the rig-site team for heightened awareness as we drill over the interval in question. Regards. .'. Dennis ', Dennis Hartwig ', Drilling Engineer ConocoPhillips Alaska, Inc. Office 907-265-6862 Cell 907-980-1433 Fax 907-265-1535 -----Original Message----- From: Thomas Maunder [mailt::c:to^~ ?nayaRcier~?.~adrr:i~:..-:tate.ak.xs] Sent: Friday, March 16, 2007 2:18 PM - - To: Hartwig, Dennis D Cc: Greener, Mike R. Subject: 1J-135 Dennis, I am reviewing the 1J-135 permit application. All appears to be in order. I have 1 question regarding the anticollision report. It is indicated that proximity with 1J-103 fails the major risk criteria at 13475'. Could you provide a little more information on this? It appears from the relative depths/lengths that 1J-135 is still drilling in the 12-1/4" hole and 1J-103 is "in the laterals". I look forward to your reply. Tom Maunder, PE AOGCC l of 1 3/16/2007 3:02 PM • • `VEL,L NAME /~~~ ~.T ~3SL.. ®evelopment Service Exploratory Stratigraphic Pest Yon-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ~ ADD-ONS TEXT FOR APPROVAL LETTER WHAT ~ (OPTIONS) aPPL[ES ~ MliLTI LATERAL I The permit is for a new wellbore se meet of existing ~ ~ we f 1 M~-~vl ~ a~ " 1.3~ j ~ (If last two digits in I permit No. ~?• ~ 3 , AP[ No. 30-~~~ -~ I i API number are I between 60-69) 'Production should continue to be reported as a function of the original API number stated above. i PILOT HOLE ; In accordance with 20 A.AC 25.005(f), all records, data and. logs i j ;acquired for the pilot hole must be clearly differentiated in both i ;well name ( PH) and API number I i ' (50- - -~ from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION ~ 2~.0». Approval to perforate and produce /infect is contingent ~ upon issuance of a conservation order approving a spacing j i i' exception. assumes the ' liability of any protest to the spacing exception that may occur. ' DRY D[TCH ~ All dry ditch sample sets submitted to the Commission must be in i i SA!~IPLE i no greater than 30' sample intervals from below the permafrost or i ! I from where samples are first caught and !0' sample intervals j ,' ~ through target cones. Please note the following, special condition of this permit: Non-Conventional i production or production testing of coa! bed methane is not allowed i I Well ~ for (name of well) until after (Com~anv Name) has designed and implemented a water well testing program to provide baseline data j ,' on water quality and quantity. (Company Name) must contact the ~ ~ Commission to obtain advance approval of such water well testing program. i Rev: 12~i06 C:' jody~transmittal_checklist ~~7 ^ N ~ a N ,N N ~ O ~ .n - ~ N C ¢ I I c O ° o W' ~ of O E O f`6 01 0 d 0 I, J !~ M C ~_ Y ~> Y Q M a ~ ~ ~ Y ~ a~ o f6 Z Z W a_ w 0 m .~ O O d a a~ i.~ J U Y >, U ~ W a N' , U. 3 , , ,c. , , -o' , , a~ N , , ~ o, , , Q rn , , o. c , , o ~, , , ~ v. , , o: , ~ ~, p. ~ N~ N o. >, m: , m c QN. ~ m. O' ~, , v' c Q ° ~ a , O' w o o, M C: T N O. O' L• N. O, O. C O- N• m. Q, O. ~ iu o m .c ~ ~ ~ ° , a~ w ~~ c, `~' -o' , U > m. ~ , 7, ~, w, O o co U ~ o. ° ,rn , °. m. v. , y. C.. __~ ~ Y. U ~. ~ , ¢; aNi, aNi, aNi, aNi; aNi, aNi, aNi, aNi, aNi; aNi, aNi, aNi Q, ¢; ¢, ¢; ; ~° _~ N. ~ C O' E. 3 E, m. o ~, , ~ ~Z ~ ~ ~, p. ~: , o. , ~, ~ ~ a O. a~, M' U C' _ O, ~, ~~ ~~ t6. N. N~ a ~ ~ ~ ~ ~~ ~~ o c~i' O fl: L: a O. 3' ai ~ c v' -~ o. ~, ~ N o co' f6. c. ~~ .O„ .p.. f6. ~; OL N a m, f9 a, (6. N a a O O O. O N ~ N ~ O O O Q a' ~.. ~~ ~ ,p. 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N ~~ o. °~ m i c; aci, c; o ` ~ ~ o. o; 3 rn ~ - o; ~, ~ ~ v% or ~; N ~ i ~ n .~ ~ t ~ ~ ~' ~' o U, U, U U, U; U; ¢, ~; ¢, ~; ; m, m, U, ; ; a, , U, U, ~ ~ ON N N N N N N N N N OM M M M M M M ~ M U O _..._______ __. __.___ ______. _.. ___-_, _. __._-___- _- ___ _____ _____-- H U p I o O C ~ N ~ ~ ~ ON I ~ ~ r M II i M J ° !~ i y C o C ' W E a ~ ~ a~ a w ~ a ¢ ¢ ~ w ~ ¢t- I 0 =' J t6 \' T ° a~ O p_ m ¢ c~ U C (6 .`o 3 m N a fCi Y f6 U a~ a~ m ~ M` V m U O U ~ ~\ (6 ~ ~M t rn° C C 0 .~ N N .N •~ ~ O WU ~i m a~ U C O O N 0 U O M • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify minding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically . organize this category of information. 1]135L1P61o05042007SSN.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon 7ul 02 15:02:59 2007 Reel Header Service name...... ... .LISTPE Date. ..................07/07/02 0ri9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN COmments .................STS LIS Writing Library. scientific Technical services Tape Header Service name .............LISTPE Date . ...................07/07/02 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical Services Physical EOF comment Record TAPE HEADER Kuparuk River unit west sak MWD/MAD LOGS WELL NAME: 1]-135 L1P61 API NUMBER: 500292334970 OPERATOR: conocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 02-JUL-07 ]OB DATA MWD RUN 2 MWD RUN 5 MWD RUN 6 JOB NUMBER: w-0004957664 w-0004957664 w-0004957664 LOGGING ENGINEER: B. HENNINGSE B. HENNINGSE R. FRENCH OPERATOR WITNESS: M. THORNTON F. HERBERT M. THORNTON MWD RUN 7 JOB NUMBER: w-0004957664 LOGGING ENGINEER: R. FRENCH OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 1583 FEL: 2287 FWL: Page 1 a~~._p3°j ~15~13 • i 17135L1P61o05042007SSN.txt ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 122.50 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 3462.0 2ND STRING 8.500 9.625 9097.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 9097' MD/3528'TVD, WITHIN THE RUN 2 INTERVAL OF THE 17-135 WELLBORE. THE WHIP- STOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 5. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,3,6,7 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP). MWD RUNS 3,6,7 ALSO INCLUDED AT-BIT GAMMA (ABG) . 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1,2,5-7 REPRESENT WELL 17-135 L1PB1 WITH API#: 50-029-23349-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11190'MD/3497'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). Page 2 • 17135L1PB1o05042007SSN.txt File Header Service name... .......sTSLI6.001 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/07/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPM RPS RPD RPX ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 3438.5 3450.0 3450.0 3450.0 3450.0 3450.0 3473.5 STOP DEPTH 11153.0 11145.0 11145.0 11145.0 11145.0 11145.0 11190.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE .PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 3438.5 9097.0 5 9097.5 9137.0 6 9137.0 9539.0 7 9539.0 11190.5 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 Page 3 • 1.7135L1P61o050420075SN.txt FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce unit Min Max Mean Nsam Reading Reading DEPT FT 3438.5 11190.5 7314.5 15505 3438.5 11190.5 RPD MWD OHMM 3.34 2000 25.5307 15391 3450 11145 RPM MWD OHMM 0.44 1554.71 23.7185 15391 3450 11145 RPS MWD OHMM 2.37 1042.57 21.1083 15391 3450 11145 RPX MWD OHMM 3.85 1864.6 20.9433 15391 3450 11145 FET MWD HOUR 0.13 302.97 1.43123 15391 3450 11145 GR MWD API 9.8 117.18 66.7151 15430 3438.5 11153 ROP MWD FT/H 0.15 912 245.957 15435 3473.5 11190.5 First Reading For Entire File..........3438.5 Last Reading For Entire File...........11190.5 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/07/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header service name... .......STSLIB.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/07/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3438.5 9097.0 RPD 3450.0 9097.0 RPx 3450.0 9097.0 RPM 3450.0 9097.0 FET 3450.0 9097.0 RPS 3450.0 9097.0 ROP 3473.5 9097.0 Page 4 17135L1P61o0504200755N.txt LOG HEADER DATA DATE LOGGED: 20-APR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9097.0 TOP LOG INTERVAL (FT): 3473.0 BOTTOM LOG INTERVAL (FT): 9097.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 73.4 MAXIMUM ANGLE: 84.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 230192 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 3462.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (5): 56.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3): 4.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.400 92.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.930 116.0 MUD FILTRATE AT MT: 2.300 85.0 MUD CAKE AT MT: 2.800 85.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 Page 5 • 1~135L1PB1o05042007s5N.txt RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MwD020 HOUR 4 1 68 20 6 GR MwD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3438.5 9097 6267.75 11318 3438.5 9097 RPD MWD020 OHMM 3.34 2000 13.0466 11295 3450 9097 RPM MWD020 OHMM 0.44 1554.71 12.0921 11295 3450 9097 RPS MWD020 OHMM 2.37 50.26 11.2148 11295 3450 9097 RPX MWD020 OHMM 3.85 35.66 9.61519 11295 3450 9097 FET MwD020 HOUR 0.13 170.44 1.17487 11295 3450 9097 GR MwD020 API 9.8 117.18 67.0392 11318 3438.5 9097 ROP MWD020 FT/H 2.85 912 239.879 11248 3473.5 9097 First Reading For Entire File..........3438.5 Last Reading For Entire File...........9097 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/07/02 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF File Header Service name... ....STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/07/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH $oP 9097.5 9137.0 LOG HEADER DATA DATE LOGGED: 02-MAY-07 SOFTWARE Page 6 i • 1~135L1P61o05042007SSN.txt SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9137.0 TOP LOG INTERVAL (FT): 9097.0 BOTTOM LOG INTERVAL (FT): 9137.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Di rection .................DOwn optical log depth units...........Feet Data Reference. Point ..............undefined Frame Spacing....... ............60 .liN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 TOOL NUMBER 8.500 9097.0 Mineral Oil Base Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading Page 7 17135L1P61o05042007SSN.txt DEPT FT 9097.5 9137 9117.25 80 9097.5 ROP MWD050 FT/H 0.15 17.96 9.26487 80 9097.5 First Reading For Entire File..........9097.5 Last Reading For Entire File...........9137 File Trailer service name... .......STSLI6.003 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/07/02 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/07/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9097.5 9502.0 FET 9097.5 9494.0 RPX 9097.5 9494.0 RPM 9097.5 9494.0 RPD 9097.5 9494.0 RPS 9097.5 9494.0 OP 9137.5 9539.0 $ LOG HEADER DATA DATE LOGGED: 03-MAY-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9539.0 TOP LOG INTERVAL (FT): 9137.0 BOTTOM LOG INTERVAL (FT): 9539.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 80.7 MAXIMUM ANGLE: 89.8 Page 8 9137 9137 C~ • 17135L1P61o05042007SSN.txt TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 076571 EWR4 ELECTROMAG. RESIS. 4 145654 ABG AT-BIT GAMMA 143793 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 9097.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 62.0 MUD PH: ,0 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3): 7.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 100.1 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MwD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 9097.5 9539 9318.25 884 9097.5 RPD MWD060 OHMM 6.68 1496.94 55.7944 794 9097.5 Page 9 Last Reading 9539 9494 • 17135L1P6100504200755N.txt RPM MWD060 OHMM 8.17 1518.05 55.1148 794 9097.5 9494 RPS MWD060 OHMM 9.3 1042.57 48.8026 794 9097.5 9494 RPX MWD060 OHMM 9.74 1864.6 58.1258 794 9097.5 9494 FET MwD060 HOUR 0.14 302.97 8.21937 794 9097.5 9494 GR MWD060 API 48 100.67 64.6178 810 9097.5 9502 ROP MWD060 FT/H 20.6 514.9 274.813 804 9137.5 9539. First Reading For Entire File..........9097 Last Reading For Entire File..... .......9539 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/07/02 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......07/07/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE. START DEPTH STOP DEPTH RPX 9494.5 11145.0 RPD 9494.5 11145.0 FET 9494.5 11145.0 RPM 9494.5 11145.0 RPS 9494.5 11145.0 GR 9502.5 11153.0 OP 9539.5 11190.5 $ LOG HEADER DATA DATE LOGGED: 04-MAY-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11190.0 TOP LOG INTERVAL (FT): 9539.0 BOTTOM LOG INTERVAL (FT): 11190.0 BIT ROTATING SPEED (RPM): Page 10 • • 17135L1PB1o050420075SN.txt HOLE INCLINATION (DEG MINIMUM ANGLE: $9,6 MAXIMUM ANGLE: 95.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE -TOOL NUMBER DGR DUAL GAMMA RAY 076571 EWR4 ELECTROMAG. RESIS. 4 145654 ABG AT-BIT GAMMA 143793 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 9097.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (5): 60.0 MUD PH: ,0 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3): 7.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 .O MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN 'Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units Size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD070 oHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 FET MWD070 HOUR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 ROP MWD070 FT/H 4 1 68 28 8 Page 11 • 17135L1PB1o05042007SSN.txt First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9494.5 11190.5 10342.5 3393 9494.5 11190.5 RPD MwD070 OHMM 11.09 109.2 60.9573 3302 9494.5 11145 RPM MWD070 OHMM 10.35 95.46 55.9392 3302 9494.5 11145 RPS MWD070 OHMM 9.72 96.73 48.2912 3302 9494.5 11145 RPX MWD070 OHMM 9.52 130.83 50.7517 3302 9494.5 11145 FET MwD070 HOUR 0.15 12.45 0.67586 3302 9494.5 11145 GR MwD070 API 44.33 104.99 66.1185 3302 9502.5 11153 ROP MWD070 FT/H 20.6 660.64 265.363 3303 9539.5 11190.5 First Reading For Entire File..........9494.5 Last Reading For Entire File...........11190.5 File Trailer Service name... .......STSLIB.005 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/07/02 Maximum Physical Record..65535 File TyPe ................L0 Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/07/02 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. scientific Technical Services Reel Trailer Service name .............LISTPE Date . ...................07/07/02 Ori yin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Physical EOF Physical EOF End Of LIS File Scientific Technical services Page 12 i ~ 1J135L1o05062007SSN.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Jul 02 13:46:14 2007 Reel Header Service name .............LISTPE Date . ...................07/07/02 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Tape Header Service name .............LISTPE Date . ...................07/07/02 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .............. .STS LIS Writing Library. scientific Technical services Library. scientific Technical services Physical EOF Comment Record TAPE HEADER Kuparuk River unit west Sak MWD/MAD LOGS WELL NAME: 1J-135 L1 API NUMBER: 500292334960 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 02-JUL-07 JOB DATA MWD RUN 2 MWD RUN 5 MWD RUN 6 JOB NUMBER: w-0004957664 w-0004957664 w-0004957664 LOGGING ENGINEER: B. HENNINGSE B. HENNINGSE R. FRENCH OPERATOR WITNESS: M. THORNTON F. HERBERT M. THORNTON MWD RUN 7 MWD RUN 8 JOB NUMBER: w-0004957664 w-0004957664 LOGGING ENGINEER: R. FRENCH R. FRENCH OPERATOR WITNESS: M. THORNTON M. THORNTON SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 1583 FEL: 2287 FWL: Page 1 0~0"~-(~t ~ fi5~~a • ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1]135L1o05062007SSN.txt 122.50 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 3462.0 2ND STRING 8.500 9.625 9097.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE IS AN OPENHOLE SIDETRACK, EXITING THE 1]-13.5 L1PB1 WELLBORE AT 10825'MD/3521'TVD, WITHIN THE MWD RUN 7 INTERVAL. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,3,6-8 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP). MWD RUNS 3,6-8 ALSO INCLUDED AT-BIT GAMMA (ABG). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1,2,5-8 REPRESENT WELL 1]-135 Ll WITH API#: 50-029-23349-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 17935'MD/3420'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). File Header Service name... .......STSLIB.001 service sub Level Name... Page 2 17135L1o05062007SSN.txt version Number. ........1.0.0 Date of Generation.......07/07/02 Maximum Physical Record..65535 File Type.. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD RPS RPM FET RPX ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 3438.5 3450.0 3450.0 3450.0 3450.0 3450.0 3473.5 STOP DEPTH 17897.5 17890.0 17890.0 17890.0 17890.0 17890.0 17935.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 5 MWD 6 MWD 7 MWD 8 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 3438.5 9097.0 9097.5 9137.0 9137.0 9539.0 9539.0 10825.0 10825.5 17935.0 Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units Size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 Page 3 1)135L1o05062007SSN.txt First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 3438.5 17935 10686.8 28994 3438.5 17935 RPD MWD OHMM 3.34 2000 43.9641 28881 3450 17890 RPM MWD OHMM 0.44 2000 46.3217 28881 3450 17890 RPS MWD OHMM 2.37 2000 40.8584 28881 3450 17890 RPX MWD OHMM 3.85 2000 36.5941 28881 3450 17890 FET MWD HOUR 0.12 302.97 0.914761 28881 3450 17890 GR MWD API 9.8 117.18 65.2783 28919 3438.5 17897.5 RoP MWD FT/H 0.15 4992.88 272.296 28924 3473.5 17935 First Reading For Entire File..........3438.5 Last Reading For Entire File...........17935 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/07/02 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSL26.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/07/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3438.5 9097.0 RPD 3450.0 9097.0 RPM 3450.0 9097.0 RPx 3450.0 9097.0 RPS 3450.0 9097.0 FET 3450.0 9097.0 ROP 3473.5 9097.0 LOG HEADER DATA DATE LOGGED: 20-APR-07 SOFTWARE Page 4 ~ r 17135L1o05062007SSN.txt SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9097.0 TOP LOG INTERVAL (FT): 3473.0 BOTTOM LOG INTERVAL (FT): 9097.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Log~iny Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 73.4 84.9 TOOL NUMBER 216265 230192 12.250 3462.0 Fresh water Gel 9.20 56.0 9.3 800 4.4 2.400 92.0 1.930 116.0 2.300 85.0 2.800 85.0 Name Service order units Size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 Page 5 ~ ~ 17135L10050620075SN.txt FET MWD020 HOUR 4 1 68 20 6 GR MwD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 3438.5 9097 6267.75 11318 3438.5 9097 RPD MWD020 OHMM 3.34 2000 13.0466 11295 3450 9097 RPM MWD020 OHMM 0.44 1554.71 12.0921 11295 3450 9097 RPS MWD020 OHMM 2.37 50.26 11.2148 11295 3450 9097 RPX MWD020 OHMM 3.85 35.66 9.61519 11295 3450 9097 FET MWD020 HOUR 0.13 170.44 1.17487 11295 3450 9097 GR MWD020 API 9.8 117.18 67.0392 11318 3438.5 9097 ROP MWD020 FT/H 2.85 912 239.879 11248 3473.5 9097 First Reading For Entire File..........3438.5 Last Reading For Entire File...........9097 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1..0.0 Date of Generation.......07/07/02 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF File Header service name... .......STSLI6.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/07/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH $OP 9097.5 9137.0 LOG HEADER DATA DATE LOGGED: 02-MAY-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory Page 6 1)135L1o05062007SSN.txt TD DRILLER (FT): 9137.0 TOP LOG INTERVAL (FT): 9097.0 BOTTOM LOG INTERVAL (FT): 9137.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 9097.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~iny Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name Service Order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MwD050 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9097.5 9137 9117.25 80 9097.5 9137 ROP MWD050 FT/H 0.15 17.96 9.26487 80 9097.5 9137 Page 7 17135L100506200755N.txt First Reading For Entire File..........9097.5 Last Reading For Entire File...........9137 File Trailer service name... .......STSLIB.003 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/07/02 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......07/07/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 9097.5 9494.0 FET 9097.5 9494.0 GR 9097.5 9502.0 RPM 9097.5 9494.0 RPD 9097.5 9494.0 RP5 9097.5 9494.0 OP 9137.5 9539.0 $ LOG HEADER DATA DATE LOGGED: 03-MAY-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9539.0 TOP LOG INTERVAL (FT): 9137.0 BOTTOM LOG INTERVAL (FT): 9539.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 80.7 MAXIMUM ANGLE: 89.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 076571 Page 8 EWR4 ABG BOREHOLE AND CASING OPEN HOLE BIT SI; DRILLER'S CASING 17135L1005062007SSN.txt ELECTROMAG. RESIS. 4 145654 AT-BIT GAMMA 143793 DATA ?E (IN): 8.500 DEPTH (FT): 9097.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Mineral 8.40 62.0 .0 23000 7.0 .000 .000 .000 .000 Name service order units size Nsam Rep code offset channel ~~ ~..J oil Base .0 100.1 .0 .0 DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MwD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9097.5 9539 9318.25 884 9097.5 9539 RPD MWD060 OHMM 6.68 1496.94 55.7944 794 9097.5 9494 RPM MWD060 OHMM 8.17 1518.05 55.1148 794 9097.5 9494 RPS MWD060 OHMM 9.3 1042.57 48.8026 794 9097.5 9494 RPX MWD060 OHMM 9.74 1864.6 58.1258 794 9097.5 9494 Page 9 17135L1o05062007SSN.txt FET MWD060 HOUR 0.14 302.97 8.21937 794 9097.5 9494 GR MWD060 API 48 100.67 64.6178 810 9097.5 9502 ROP MWD060 FT/H 20.6 514.9 274.813 804 9137.5 9539 First Reading For Entire File ..........9097.5 Last Reading For Entire File. ..........9539 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/07/02 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLI6.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/07/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 9494.5 10825.0 FET 9494.5 10825.0 RPM 9494.5 10825.0 RPx 9494.5 10825.0 RPD 9494.5 10825.0 GR 9502.5 10825.0 ROP 9539.5 10825.0 LOG HEADER DATA DATE LOGGED: 04-MAY-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10825.0 TOP LOG INTERVAL (FT): 9539.0 BOTTOM LOG INTERVAL (FT): 10825.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 89.6 MAXIMUM ANGLE: 95.1 Page 10 1~135L1o05062007SSN.txt TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 076571 EWR4 ELECTROMAG. RESIS. 4 145654 ABG AT-BIT GAMMA 143793 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 9097.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 60.0 MUD PH: .O MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3): 7.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 133.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 FET MWD070 HOUR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 ROP MWD070 FT/H 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 9494.5 10825 10159.8 2662 9494.5 10825 Page 11 1.7135L1o05062007SSN.txt RPD MWD070 OHMM 30.56 109.2 69.8927 2662 9494.5 10825 RPM MWD070 OHMM 25.92 95.46 64.1048 2662 9494.5 10825 RPS MWD070 OHMM 25.23 96.73 54.965 2662 9494.5 10825 RPX MWD070 OHMM 25.42 130.83 57.8353 2662 9494.5 10825 FET MWD070 HOUR 0.15 12.45 0.736589 2662 9494.5 10825 GR MWD070 API 44.33 87.39 62.9297 2646 9502.5 10825 ROP MWD070 FT/H 20.6 660.64 276.945 2572 9539.5 10825 First Reading For Entire File..........9494.5 Last Reading For Entire File...........10825 File Trailer service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/07/02 Maximum Physical Record..65535 File TyC~e ................L0 Next File Name...........STSLIB.006 Physical EOF File Header service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/07/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 10825.5 17890.0 ROP 10825.5 17935.0 RPx 10825.5 17890.0 RPS 10825.5 17890.0 RPD 10825.5 17890.0 GR 10825.5 17897.5 ET 10825.5 17890.0 $ LOG HEADER DATA DATE LOGGED: 06-MAY-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 17935.0 TOP LOG INTERVAL (FT): 10825.0 BOTTOM LOG INTERVAL (FT): 17935.0 Page 12 1~135L1o050620075SN.txt BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.6 MAXIMUM ANGLE: 93.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA-RAY 076571 EWR4 ELECTROMAG. RESIS. 4 145654 ABG AT-BIT GAMMA 143793 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 9097.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 55.0 MUD PH: .0 MUD CHLORIDES (PPM): 14000 FLUID LOSS (C3): 8.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 133.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD080 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 RPS MWD080 OHMM 4 1 68 12 4 RPX MWD080 OHMM 4 1 68 16 5 FET MWD080 HOUR 4 1 68 20 6 GR MWD080 API 4 1 68 24 7 ROP MWD080 FT/H 4 1 68 28 8 Page 13 17135L10050620075SN.txt First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 10825.5 17935 14380.3 14220 10825.5 17935 RPD MWD080 OHMM 13.36 2000 63.1289 14130 10825.5 17890 RPM MWD080 OHMM 17.7 2000 69.8392 14130 10825.5 17890 RPS MWD080 OHMM 16.3 2000 61.4505 14130 10825.5 17890 RPX MWD080 OHMM 15.6 .2000 52.9485 14130 10825.5 17890 FET MWD080 HOUR 0.12 5.09 0.329938 14130 10825.5 17890 GR MWD080 API 41.89 94.16 64.3464 14145 10825.5 17897.5 ROP MWD080 FT/H 5.14 4992.88 298.434 14220 10825.5 17935 First Reading For Entire File..........10825.5 Last Reading For Entire File...........17935 File Trailer Service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/07/02 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/07/02 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date . ...................07/07/02 Ori9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EoF Physical EOF End Of LIS File writing Library. 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