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O O o O O N N ,..7.. vtQ IN G N N N N N N N N n Q O) O) O) co 0) O) 0) to E -LE p_ p - -....• N N N N N N N N 01 , O 0 0 0 0 0 0 0 0 u = `� O O O O O o O O fp O L lil 14) in in in In In in y�02 cc 11 Cc cia w i+ Y (Y N tO OL 1 e ti o 0 0 0 0 0 0) a .+ w K n 2 S 2 2 W LL _ _ �= ro v+ LL m 2 �� d Q N M E Z GJ -O w y1 'i .' liECEIVED • STATE OF ALASKA MAR 2 5 2015 AL, :A OIL AND GAS CONSERVATION COM.. _SION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Performed: Abandon r Repair w ell I✓ Rug Perforations r Perforate r Other r Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number. ConocoPhillips Alaska, Inc. Development p Exploratory r 185-244 3.Address: 6.API Number: Stratigraphic r Service r- P. O. Box 100360,Anchorage,Alaska 99510 50-029-21462-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25643,25632 KRU 3F-06 9.Logs(List logs and submit electronic and printed data per 20AAC25.071). 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7721 feet Plugs(measured) none true vertical 6316 feet Junk(measured) none Effective Depth measured 7611 feet Packer(measured) 6920, 7043, 7235 true vertical 6227 feet (true vertical) 5687,5781, 5930 Casing Length Size MD ND Burst Collapse CONDUCTOR 78 16 115 115 SURFACE 3347 9.625 3384 3047 PRODUCTION 7666 7 7701 6300' SIU Perforation depth: Measured depth: 7090-7160,7289-7326, 7344-7384 + True Vertical Depth: 5818-5872, 5972-6001,6015-6046 Tubing(size,grade,MD,and ND) 3.5, L-80, 7257 MD, 5947 TVD ' Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL PACKER @ 6920 MD and 5687 TVD PACKER-BAKER FHL PACKER @ 7043 MD and 5781 TVD PACKER-BAKER FB-1 PACKER @ 7235 MD and 5930 TVD no SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation 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 shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development Service r Stratigraphic r 16.Well Status after work: Oil P Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt 314-625 Contact Janelle Nesvold t' ,263-4641 Email Janelle.R.Nesvold(cr�cop.com Printed Name Janelle Nesvold Title Wells Engineer Signature � Phone:263-4641 Date 3/L4.1// i � t, ' L- 4)/6//3___.- ___ RBDMSd APR - 6 2015 Form 10-404 Revised 10/2012 0/o Submit Original Only gyp. 1 KUP PROD 3F-06 ConocoPhillips $ Well Attributes Max Angle&MD TD Alaska,Inck' - Wellbore APIIUWI Fold Name Wellborn Status ncl(') MD(ftKB) Act Ben(ftKB) conocoPrselps 500292146200 KUPARUK RIVER UNIT PROD 44.41 6,200.00 7,721.0 --• Comment H25(ppm) Date Annotation End Date KB-God(ft) Rig Release Date 3F-06,3/1700153:31:13 PM SSSV:NONE 200 11/18/2013 Last WO: 2/8/2015 41.00 10/28/1985 Verecal schemanc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER a2.i I'r';J.F,`.,;I Last Tag:SLM 7,372.0 8/3/2013 Rev Reason:WORKOVER smsmith 6/23/2014 Casing Strings x,a;11. Casing Description OD(in) ID(in) Top(MB) Set Depth(ftKB) Bet Depth(TVD)...Wt/Len(I...Grade Top Thread rCONDUCTOR 16 15.062 37.0 115.0 115.0 62.50 H-40 WELDED u ,. nmm�, runnnn,.,nn , .m,Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(1...Grade Top Thread `II SURFACE 95/8 8.921 37.0 3,384.4 3,0472 36.00 J-55 BTC Casing Description •OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ,TIEBACK 7 6.276 35.0 2,052.8 2,027.5 26.00 L-80 Hyd563 CONDUCTOR;37.0-115.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 2,052.8 7,700.8 6,299.5 26.00 J-55 BTC Tubing Strings Tubing Description 'String Ma...110(in) 'Top(ftKB) I Set Depth(It i Set Depth(TVD)(...I Wt(Iblft) (Grade 'Top Connection II TUBING-WO 2015 3 1/2 2.992 33 1 7,004 0 5,751 6 9.30 L-80 EUE8rd mod TIEBACK;35.0-2,052.8 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 33.1 33.1 0.04 HANGER FMC TUBING HANGER 2.992 GAS LIFT;2,644.2 6,889.5 5,664.2 40.66 LOCATOR LOCATOR 2.980 6,890.5 5,665.0 40.65 SEAL ASSY BAKER PBR SEAL ASSEMBLY 2.980 , 6,896.9 5,689.8 40.59 PBR BAKER 80/40 PBR 4.000 6,920.0 5,687.4 4042 PACKER BAKER FHL RETRIEVALBE PACKER 2.920 SURFACE;37.0-3,384.4- 6,974.7 5,729.1 40.05 NIPPLE CAMCO DS NIPPLE W/RHC PLUG 2.812 6,996.3 5,745.7 39.91 OVERSHOT BAKER POOR BOY OVERSHOT 3.610 -� Tubing Description 'String Ma...IID(in) 'Top(ftKB) 'Set Depth(ft..1Set Depth(TVD)(...'Wt(lb/ft) 'Grade 'Top Connection GAS LIFT;4,206.9 TUBING-ORIGINAL 41/2 3.000 6997.8 7,25721 , 5,947.4 9.30 J-55 EUE8r4MOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 7,029.0 5,770.8 39.72 PBR BAKER PBR 3.000 7,042.7 5,781.3 39.65 PACKER BAKER FHL PACKER 3.000 7,118.4 5,839.8 39.31 BLAST JT RICKERT BLAST JOINTS(3) 3.000 7,219.6 5,918.2 39.15 NIPPLE AVA BPL LANDING NIPPLE w/XO TO 2.875" 2.750 GAS LIFT;5,400.0 fl 7,233.3 5,928.8 39.09 LOCATOR BAKER LOCATOR 3.000 7,235.1 5,930.2 39.09 PACKER BAKER FE-1 PACKER 3.000 7,238.5 5,932.8 39.07 SBE XO BAKER SEAL BORE EXTENSION 2.875 3.5x2.875 7,250.0 5,941.8 39.02 NIPPLE CAMCO D NIPPLE NO GO 2.250 GAS LIFT;6,257.1--11 'ii(. 7,256.5 5,946.8 38.99 SOS CAMCO SHEAR OUT SUB 2.438 -- Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(TIKB) (ftKB) ("1 Des Com Run Date 11,)(in) _ 7,062.0 5,796.2 39.54 CATCHER CATCHER ON TOP OF WRP OAL 6' 6/20/2014 GAS LIFT;6,832.5 7,068.0 5,800.9 39.51 PLUG 2.69"Weatherford WRP mid element 7070' 6/19/2014 7,219.6 5,918.2 39.15 SLEEVE 2.75"BPI SLEEVE 7/27/2010 2.310 / `7 7,500.0 6,138.1 36.75 FISH Capillary Tube 48'CAPILLARY TUBING,INJ. 905/2004 0.000 LOCATOR;6,869.5 I" VALVE,KNUCKLE JOINT,PANEX BATTERY SEAL Asst;6,890.5 ikeli PACK,PANEX GAUGE 9/15/2004 PER;6,896.9 PACKER;6,920.0 _ Perforations&Slots Shot Dens (shotslf NIPPLE;8,974.8 Top(ftKB) BM,(MB) Top(TtrD) �m(TVD) (ftKB) MB) ZonaDate t) Type Corn 7,090.0 7,160.0 5,817.8 5,872.0 C-4,C-3,C-1, 12/6/1985 12.0 IPERF 90 deg.ph;5"HJ II Csg UNIT B,3F-06 Gun 7.289.0 7,326.0 5,972.1 6,001.0 A-4,A-3,3F- 12/6/1985 4.0 IPERF 90 deg.ph;4"HJ II Csg OVERSHOT;6,996.3 06 Gun 7,344.0 7,384.0 6,015.0 6,046.3 A-2,3F-O6 12/6/1985 4.0 (PERF 90 deg.ph;4"HJ II Csg Gun PBR;7,029.0 �S PACKER;7,042.7 _ Mandrel Inserts ', St I CATCHER;7,062.0 y//�(�(�/ ati PLUG;7,088.0 y N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Seri Type Type (in) (psi) Run Date Com PRODUCTION;7,080.7 1 2,644.2 2,506.2 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 2/24/2015 2 4,206.9 3,652.4 CAMCO MMG 1 1/2 GAS LIFT SOV RKP 0.000 2/24/2015 OCR- 1 (PERF;7,090.0-7,180.0- 3 5,400.1 4,556.1 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 2/24/2015 4 6,257.1 5,199.2 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/24/2015 NIPPLE;7,219.6, 5 6,832.5 5,621.1 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/24/2015 SLEEVE;7,219.6 y1.-I 6 7,080.7 5,810.7 CAMCO KBUG 1 PROD DMY MBK 0.000 0.0 1/15/1988 Notes:General&Safety PACKER;7,235.1 - End Date I Annotation SBE TO 3.5x2.875;7,238.5 2/2/1998 NOTE TRASH BESIDE DMY VALVE @ 7081'-7082' II 1/17/1999 NOTE:Loaded 7"casing w/185 bbls of diesel ni NIPPLE;7,250.0 - 9/15/2004 NOTE:PULLED PART OF.25"CAPILLARY TUBE,LEFT APPROX 58'OF FISH IN WELL a. SOS;7,256.5 11/2/2004 NOTE:WAIVERED WELL:OA x ATMOSPHERE COMMUNICATION-SURFACE CSG LEAK a 11/2/2004 NOTE:WAIVERED WELL:IA x OA x OOA COMMUNICATION 6/20/2014 NOTE:AS TUBING TALLY FROM 12/6/85 STATES (PERF;7,289.0-7,326.0 T 6/20/2014 NOTE:BETWEEN GLM#8 AND GLM#9 THERE ARE 336'OF 3.5 FULL JTS OF TUBING NOT 366' (PERF;7,344.0-7,384.0- . }lT FISH;7,500.0 II PRODUCTION;2,052.8-7,700.0 4• 4- ConocoPhillips Time Log & Summary Wel!view Web Reporting Report Well Name: 3F-06 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 2/9/2015 3:00:00 PM Rig Release: 2/25/2015 9:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/08/2015 24 hr summary RDMO 3Q-09. Prep rig and bridle up. Lower derrick. Remove berming around rig. Move sattelite camp and pit module to 3F. Move rig from 3Q to Y at 3B. 01:00 09:00 8.00 MIRU MOVE RURD P Secure rig floor. Bridle up. Take down berming around rig and camp. Lower Derrick. Jack up and prep sattelite camp for move. 09:00 20:00 11.00 MIRU MOVE MOB P Pull pits away from camp. Move satellite camp and pits to 3R and stage. Move rig from 3Q pad to 30 pad. Wait on change out. 20:00 00:00 4.00 MIRU MOVE MOB P Move rig from 30 pad to Y towards 3J 02/09/2015 Move rig onto 3F pad. MIRU over 3F-06. Spot pit module, raise derrick. Spot auxiliary equipment. Observe power tripping to pit module. Rig repair, change out breaker for pit module. Blow down lines to kill tank. R/U hoses to kill well. 00:00 02:30 2.50 MIRU MOVE MOB P Continue moving rig to 3F pad. Rig on location at 02:30. 02:30 06:30 4.00 MIRU MOVE MOB P Load tree in cellar. Set mats around rig. Stage wellhead equipment behind well. Spot sub base over 3F-06. 06:30 09:00 2.50 MIRU MOVE MOB P Back pit module into place, set mats underneath pit module. 09:00 15:00 6.00 MIRU MOVE RURD P Spot auxiliary equipment. Raise derrick and cattle chute, brudle down. 15:00 16:30 1.50 MIRU WELCTL RURD P Rig accepted at 15:00. Take on 9.6 ppg Brine. R/U hardline and kill tank. 16:30 18:00 1.50 MIRU WELCTL RGRP T Observe pit module power is tripping. Troubleshoot 18:00 23:00 5.00 MIRU WELCTL RGRP T Breaker for pit module bad. Blowdown steam lines, S/D power. C/O breaker. Turn power on and test breaker with charge pumps-good. Turn steam on. 23:00 00:00 1.00 MIRU WELCTL RURD P Blow down lines to kill tank. Continue taking on fluid in the pits. Install secondary annular valve. 02/10/2015 Continue to R/U to kill well. Lubricate out BPV. Initial pressures T/IA/OA=500/20/70; bleed gas caps T/IA= 180/0. Attempt to kill well with 9.6 ppg brine. Circulate 292 bbls around holding 150-200 psi back pressure, 9.6 ppg returned. Shut in and monitor. Pressure building T/IA=80/60 in 30 minutes. R/U and circulate hole volume through degasser holding 160 psi back pressure. Shut in and monitor;T/IA building to 80/in three hours. Calculate new kill weight fluid+125 psi= 10.3 ppg. Blend fluid in pits with 11.7 on location; call out for additional fluid. SITP 80 psi, SICP 40 psi. Line up hoses and begin well kill at 2 bpm 380 psi pump pressure, holding casing pressure constant until up to rate. Page 1 of 22 • Time Logs Date _From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:30 0.50 MIRU WELCTL RURD P Continue installing secondary annular valve and blowing down kill line. 00:30 02:30 2.00 MIRU WELCTL MPSP P R/U Lubricator and test to 1000 psi. _ Lubricate out BPV. 02:30 04:00 1.50 MIRU WELCTL RURD P Install tree cap. R/U hose to tubing. Initial tubing pressure 500 psi, Initial IA 20 psi, initial OA 70 psi. Blend pits. 04:00 07:30 3.50 MIRU WELCTL KLWL P PJSM kill well. Bleed off pressure. Tubing bled to 180 psi, IA bled to 0 psi. Circulate 9.6 ppg brine holding 150-200 psi back pressure. Pump 292 bbls, 272 bbls returned. Shut down pumps. Initial shut in pressure T/IA=0/0 5 minutes IA=25 20 minutes T/IA= 100/50 35 minutes T/IA=80/60 _ 07:30 11:00 3.50 MIRU WELCTL KLWL T BD Kill Line. R/U to circulate through gas buster. Circulate hole volume at 2.5 bpm 400 psi holding 160 psi back pressure. Shut in well and monitor. Fluid weight in and out _ 9.6 throughout circulation. 11:00 14:00 3.00 MIRU WELCTL OWFF T Monitor the shut-in tubing pressure build up after the second well kill circulation. SITP gradually built up to 80 psi in 3 hours(assume that formation pressure is slowly leaking by the WRP set in the tubing at 7,086-ft). Continue to monitor for an additional 1 hour to verify stabilization. Recalculate the new KWF with safety factor(125 psi)at 10.25 lb/gal. Initial shut in pressure T/IA=0/0 15 minutes T/IA=30/10 30 minutes T/IA=40/20 1 hour T/IA=50/70 2 Hours T/IA =70/50 _ 3 Hours T/IA=80/60 14:00 22:30 8.50 MIRU WELCTL WAIT T Blend 11.8 ppg brine from well with 9.6 ppg fluid in pits. Send trucks to 1B to pick up re-used 10.7 ppg Brine and water back. Wait on fluid. 22:30 00:00 1.50 MIRU WELCTL KLWL T PJSM Kill well with 10.3 ppg brine at 2bpm ICP 380 FCP 340 psi, holding back pressure. 02/11/2015 Continue to kill well with 10.3 ppg brine. Monitor well, static. Set BPV. N/D tree, N/U BOPE. Test E3OPE"s; right to witness waived by AOGCC Field Inspector. Attempt to pull decompletion, unable to. Call out E-Line. Spot E-Line unit and rig up. Page 2 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:15 2.25 MIRU WELCTI KLWL T Continue with well kill at 2 bpm following pressure schedule. Pump 290 bbls with 290 returned. Shut well in. Blow down hardline to kill tank. Monitor pressure at tree, no build up. 02:15 02:45 0.50 MIRU WELCTI.OWFF P Monitor well,static. 02:45 03:30 0.75 MIRU WHDBO MPSP P PJSM R/U and set BPV,test to 1000 psi-good. 03:30 09:00 5.50 MIRU WHDBO NUND P N/D tree, inspect hanger threads, Install the Blanking Plug(9 turns). Function lock down screws. Bleed to OA to"0"psi. 09:00 13:00 4.00 MIRU WHDBO NUND P Nipple up the BOP Stack. Install 7" Pipe Rams in the bottom gate. Install Riser. 13:00 19:30 6.50 MIRU WHDBO BOPE P Perform the initial BOPE test as per ConocoPhillips/AOGCC requirements at 250/3,000 psi with a 3 1/2"and 7"Test Joint. Test gas alarms. Perform the Koomey drawn test. Record all pressure tests on a chart. The State's right to witness the test was waived by AOGCC Field Inspector,J. Jones. 19:30 20:00 0.50 COMPZ WHDBO MPSP P Pull Blanking plug and BPV 20:00 20:30 0.50 COMPZ RPCOM PULL P M/U landing joint BOLDS 20:30 22:00 1.50 COMPZ RPCOM PULL P Attempt to pull 3-1/2"decompletion. Pull to max of 144K(114 plus blocks). Unable to pull seals free. 22:00 23:00 1.00 COMPZ RPCOM ELNE T Call out E-Line. Continue to work pipe, establish circulation 5 bpm 805 psi. Circulate hole volume while working pipe. 23:00 00:00 1.00 COMPZ RPCOM ELNE T Spot in E-Line and rig up. 02/12/2015 RIH with E-Line,fire string shot middle of first joint above PBR(6996'). POOH. M/U RCT. RIH and attempt to cut tubing at 6,996'. RCT anchors won't hold. P/U to 6,982'; able to get anchors to set. Fire RCT. POOH. Attempt to pull tubing, unsuccessfull. M/U string shot. RIH, unable to get past 6,940'. Fire string shot at 6,898'. POOH. M/U RCT. RIH to 6,996';attempt to set anchors, unsuccessful. P/U to 6,982'and attempt to set anchors, unable to. Make multiple attempt while consulting with town. Call out Jet cutter. POOH with RCT. 00:00 02:30 2.50 COMPZ RPCOM ELNE P Continue to rig up E-Line. 02:30 04:00 1.50 COMPZ RPCOM ELNE T E-Line unable to RIH,trouble shoot. Pack-off full of ice. R/D pack-off and thaw out. 04:00 07:00 3.00 COMPZ RPCOM ELNE T RIH on E-Line with string shot.. Record a tie-in pass to the Completion Jewelry. Position the Center of the String Shot in the middle of the first fill joint above the Seal Assembly at 6,996-ft.elmd. Fire String Shot. Good. Pull out. Page 3 of 22 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 07:00 10:45 3.75 COMPZ RPCOM ELNE T Lay down spent String Shot. Make-up the Radical Cutting Torch Cutter. Run in. Had to work Cutter Tool String through the bottom GLM (possibly String Shot debris). After several attempts Tool String fell through. Attempted to record a tie-in pass. However,the Tool String hung up in the GLM. Un-load Jar and "popped"free. Dropped back down through the GLM with no problem. Recorded a tie-in pass to the completion jewelry. Made a(+)4-ft correction. Position the Cutter in the middle of the joint at 6,996-ft elmd. Attempt to set the Anchor many times. Indications in the logging unit shows the arms are setting(opening and closing). However,the arms are not grabbing the tubing wall. Move Cutter depth up hole 3-ft and try a new spot. Same results. Discuss a plan forward with the Anchorage Engineer. Position the arms up hole to the bottom of the GLM at 6,982-ft elmd. Set Arms. Good. Cutter depth now at 6,987.5-ft elmd(5-ft below the top of the tubing joint). Fire Cutter. No indication on the Rig Floor of tubing movement. Pull out with Tool String to inspect. 10:45 13:00 2.25 COMPZ RPCOM ELNE T Lay down Tool String. Arms look OK....Cutter fired. Rig down Pump-in-Sub. Pick-up on Tubing to maximum overpull at 144K. Tubing not severed. Discuss options and a plan forward with Anchorage Engineer. (E-line Crew change). 13:00 18:30 5.50 COMPZ RPCOM ELNE T Decision made to make a second String Shot/RCT cut in the first joint above the bottom GLM. Build the String Shot. PJSM with All. Make-up the String Shot Tool String. Run in the hole. String Shot sat down at 6,940-ft. Attempted several times at different speeds. Unable to get any deeper. Pull up and record a tie in pass across GLM#8 at 6,606-ft. Drop back down and center the String Shot across the new cut depth target at 6,898-ft(10-ft below the collar on the second joint above GLM#9). Fire string Shot. POOH. 18:30 20:30 2.00 COMPZ RPCOM ELNE T M/U Radial Torch Cutter. Function test on surface; anchor arms won't extend. Call out for new arms. Page 4 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 22:00 1.50 COMPZ RPCOM ELNE T Make up Radioal Torch Cutter and RIH. No drag observe while RIH. Correlate to PBR. Attempt to engage anchors to make cut at 6,996'. Anchors won't engage. Pick up to 6,898'(depth of second string shot). Attempt to anchor RTC. Attempt multiple times,without success. 22:00 00:00 2.00 COMPZ RPCOM ELNE T Consult with town. Call out for Jet cutter. Continue to attempt and engage anchor arms, unsuccessful. POOH with E-Line. 32/13/2015 Cont. POOH with RCT. R/D E-Line. Break out landing joint due to ID restriction. M/U landing joint. M/U Jet cutter. RIH with E-Line and correlate. Cut tubing at 6,992'. POOH and R/D E-Line. POOH with 3-1/2" de-completion(free at 80K). Cut joint shows tubing pulled free from initial RCT cut, 5'above Jet cutter. Call out for fishing tools. R/D GBR. Install wear bushing. Pick up and stand back drill pipe while waiting on fishing tool. 00:00 02:30 2.50 COMPZ RPCOM ELNE T POOH with E-Line while waiting on Jet cutter. Stand back E-Line, 02:30 03:30 1.00 COMPZ RPCOM ELNE T Break out landing joint(crossover 2.5"ID;Jet Cutter 2.5"OD). 03:30 05:00 1.50 COMPZ RPCOM WAIT T Wrong pup joint to make up to tubing hanger arrived on site. Call out for pup joint. 05:00 06:30 1.50 COMPZ RPCOM ELNE T M/U crossover and pup joint to tubing hanger. Rig up Pump-in-Sub and Pack-Off. Make-up 2 1/2"Jet Cutter. 06:30 08:45 2.25 COMPZ RPCOM ELNE T Run in with the Jet Cutter. Tie into the bottom GLM. Make a(+)4-ft correction to the original tie-in jewelry log. Position the Jut Cutter at 6,992-ft elmd...10-ft below the top of the first full joint above the PBR. (note also saw CCL"kick"from the first attempt cut at 6,987-ft elmd). Fire Cutter. Log off. Observed a 4-ft shift on the tubing collars. POOH. 08:45 09:30 0.75 0 6,962 COMPZ RPCOM ELNE P Lay down Tool String. Rig back E-line. Pick-up on the tubing string. Tubing free. Pull the Tubing Hanger to the Floor at 80K with no drag. Rig down and release E-Line Unit. 09:30 11:00 1.50 6,962 6,962 COMPZ RPCOM RURD P Rig up GBR equipment to handle 3 1/2"Tubing. Break out the Tubing Hanger and lay down same. Rig up Schlumberger Spooling Unit. 11:00 12:15 1.25 6,962 6,962 COMPZ RPCOM CIRC P Circulate Well at 5.0 bpm/805 psi. Total volume=275 bbls. Monitor x 10 minutes x static. 12:15 15:30 3.25 6,962 5,115 COMPZ RPCOM PULL P Single down the 3 1/2"Completion Tubing while spooling SSSV Control Line from 6,962-ft to 5,115-ft. Lay down SSSV. Recovered 34 SS Bands. Page 5 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 16:00 0.50 5,115 5,115 COMPZ RPCOM RURD P Rig down the Schlumberger Spooling Unit. 16:00 21:30 5.50 5,115 0 COMPZ RPCOM PULL P Continue to single down the 3 1/2" Completion to surface. Cut joint 5' long-RCT cut not Jet cut.Jet cut was cut 5'below RCT cut. No evidence of a cut made above. Cut Jagged with evidence of"hangers". Pitting observed inside of tubing. (pictures in well file). Scale buildup from GLM#9 to bottom. (Pictures in well file) 21:30 22:30 1.00 0 0 COMPZ RPCOM RURD P RID GBR equipment, change elevators. Clean and clear rig floor. Simops-discuss options with Baker Fishing and town. 22:30 23:00 0.50 0 0 COMPZ RPCOM SVRG P Service and inspect top drive. 23:00 23:30 0.50 0 0 COMPZ RPCOM RURD P Install wear bushing. 9 23:30 00:00 0.50 0 0 COMPZ RPCOM PULD P PJSM P/U drill pipe while waiting on Baker Fishing tools 02/14/2015 M/U BHA#1 Overshot. Run in hole and tag fish at 6,948'(N7 RKB). Circulate annular volume and monitor well. Pull out of hole. Lay down BHA#1. Make up BHA#2 cleanout/dress off assembly. Run in hole and tag tubing stump at 6,952'(N7 RKB). Dress off tubing stump,washing down over stump to 6,966'. Circulate hole clean, monitor well. Pull out of hole with BHA#2 to 1,276'. 00:00 02:00 2.00 0 0 COMPZ RPCOM PULD P Single in hole with 66 joints of drill.pipe. 02:00 03:00 1.00 0 COMPZ RPCOM TRIP P POOH and stand back in derrick while waiting on Baker Fishing tools. 03:00 04:00 1.00 0 25 COMPZ RPCOM BHAH P M/U BHA#1. 5-3/4"overshot with 3-1/2"grapple as per Baker hand. 04:00 05:30 1.50 25 2,079 COMPZ RPCOM TRIP P RIH with BHA#1 with stands from derrick to 2079' 05:30 09:30 4.00 2,079 6,946 COMPZ RPCOM PULD P RIH with BHA#1 with 3 1/2"singles from the Pipe Shed. 09:30 10:00 0.50 6,946 6,948 COMPZ RPCOM FISH P Up weight= 145K. Down weight= 95K. RPMs= 17. Free spin torque =5K/ft/lbs. Tagged the top of the 3 1/2"Tubing Fish at 6,947-ft dpmd. Slowly rotate down over Fish. Set 20K. Pick up and repeat same 4 times. Final set down weight=30K. Tag depth now at 6,948-ft dpmd. Unable to swallow fish any deeper. Prep to trip back out of the hole. 10:00 11:15 1.25 6,948 6,942 COMPZ RPCOM CIRC P Circulate Well at 3.0 bpm/270 psi. (SIMOPS:service Top Drive). Monitor Well x 10 minutes x static. 11:15 14:15 3.00 6,942 25 COMPZ RPCOM TRIP P Trip out with BHA#1/Fish,standing back the 3 1/2" Drill Pipe in the Derrick from 6,942-ft dpmd. Up weight= 145K. Page 6 of 22 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 14:15 14:45 0.50 25 0 COMPZ RPCOM PULL P BHA#1 at surface. Lay down recovered Fish...3 1/2"RCT cut top x 3 7/8"flared out Jet Cut bottom. OAL=5.15-ft(note the RTC cut had evidence of a tab—3/4"that was not severed during the original attempt). 14:45 16:15 1.50 0 48 PROD1 WELLPF BHAH P Make-up BHA#2 as follows: 6"x 3 1/2"Dress-off Shoe,3 ea 5 3/4" Extensions,4 3/4"x 2 13/16"Inner Mill(up inside the extensions at the top),Washover Boot Basket, Casing Scraper, Double Pin Sub, Bit Sub, Bumper Sub, Oil Jar,XO. 16:15 19:30 3.25 48 6,952 PROD1 WELLPF TRIP P Trip in BHA#2 on 3 1/2"Drill Pipe from the Derrick to 6900'. Establish parameters: PUW 137K, SOW 95K. Obtain slow pump rates. Increase rate to 4 bpm 685 psi,free torque 6200 ft-lbs at 60 rpms. Shut down rotary and slack off. Tag tubing stub at 6,952'. 19:30 21:00 1.50 6,952 6,945 PROD1 WELLPF MILL P Pick up and establish rotary. Slack off and dress up outside of tubing stub,with 1 -2 KFt-lbs additional torque. Pick up and shut down rotary. Wash over tubing stump to 6,957',taking weight. Pick up and ream down to 6,965'with WOB 1 - 2K. Pick up and shut down rotary. Slack off and tag tubing stump with inner mill, observe pressure gain. Dress off top of tubing stump additional 8". Pick up off stump to 6,945'. Shut down rotary and pumps. Slack off over tubing stump to 6,966'with no issues. Pick up to 6,945'. 21:00 22:00 1.00 6,945 6,945 PROD1 WELLPF CIRC P Circulate hole clean,staging pumps up to 7 bpm 1700 psi. Monitor well for 10 minutes 22:00 00:00 2.00 6,945 1,276 PROD1 WELLPF TRIP P Pull out of the hole with drill pipe to 1,276-ft. 32/15/2015 POOH and lay down BHA#2 cleanout/dress off assembly. Install Dutch riser,spot in and rig up digital slickline. Run in the hole with cement mapping tool/Gamma Ray. Log cement from 6,900'to surface. Download and process log. Top of Cement at 2,100'. Make up string shot assembly. Run in hole and fire string shot at 2,057'. Pull out of hole. Make up RBP#1. 00:00 01:00 1.00 1,276 48 PROD1 WELLPF TRIP P Continue to Pull out of the hole with BHA#2; clean out assembly. 01:00 02:00 1.00 48 0 PROD1 WELLPF PULD P Lay down BHA#2;clean out assembly. 02:00 07:30 5.50 0 0 PROD1 WELLPF SLKL P Install Dutch Riser. Spot in and rig up digital slickline. Pick-up Lubricator. Make-up Cement Bond Logging Tool String. Stab Lubricator. Pressure testLubricator at 500 psi. Good. Page 7 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 13:30 6.00 0 0 PROD1 WELLPF SLKL P Run in with GR/Press/Temp/SCMT (Slim Cement Mapping Tool). Tie into the gamma ray spike at 5,332-ft. Continue on in to 6,900-ft Tie into the Production Profile Log dated, 12/27/2008. Record a short logging pass from 6,900-ft up to 6,600-ft. Drop back down to 6,900-ft. Record the cement bond log from 6,900-ft back to surface. 13:30 17:30 4.00 0 0 PROD1 WELLPF SLKL P Lay down logging tool. Process logs. Top of cement determined at 2,100'. Second collar above at 2,057'. Cut depth determined to be —2035'. 17:30 22:30 5.00 0 0 PROD1 WELLPF SLKL P Make up and run in hole on digital slickline with string shot tool correlate with SCMT log with gamma ray spikes at 5,332'; 5,554'; 5,563'. Pull up to shot depth and check correlation. Fire string shot across collar at 2,057'. POOH with string shot. Break down tools 22:30 00:00 1.50 0 0 PROD1 WELLPF SLKL P Make up RBP#1 on Digital Slickline 32/16/2015 RIH with RBP#1 on digital slickline(DSL)to 5,500'. Slickline lost communication with tools. Troubleshoot tools. POOH to 1,700'and regained communication with tools. RIH to 4,300'and lost communication again. POOH. Slip and cut digital slickline. Make up RBP#1 and RIH to 6,825'on DSL, lost communication to the tools. POOH and R/D and release DSL. M/U RBP on'J' hydraulic setting tool and RIH on drill pipe to 3,642'. 00:00 00:30 0.50 0 0 PROD1 WELLPF SLKL T Continue to make up RBP#1 to Digital Slickline. 00:30 02:00 1.50 0 0 PROD1 WELLPF SLKL T Run in hole with RBP#1 to 5500'at 60-70 fpm as per Baker,Attempt to correlate to Gamma Ray. 02:00 10:30 8.50 0 0 PROD1 WELLPF SLKL T Lost signal to tool string. Unable to read Gamma Ray, CCL. Slickline reading good quality signal, but not able to receive signal from tools. Troubleshoot, suspect software issues. POOH to 1,700'-no damage to cable noted. Signal obtained at 1,700'. Discuss options with Schlumberger. Still suspects software issues and said he's seen the software cut out and start up again. Run in hole as per recommended from Schlumberger to 4,300'lost signal;this confirms the signal is lost due to bad wire. POOH and cut 3,000'of wire. (SIMOPS: load and process 7"Casing in the Pipe Shed). Re-head the line. Make-up Tool String. Calibrate same. Page 8 of 22 Time Logs Date From To Dur S. Depth E. Dpth Phase Code Subcode T Comment 10:30 17:00 6.50 0 0 PROD1 WELLPF SLKL T Make-up Baker WL set RBP(Model 4762). Run in the hole.to 6,825-ft. Record the initial tie in pass and tie into the Gamma ray spike at —6,777-ft. Drop back down and attempted a tie-in pass. Data issues...software or tool string...? Troubleshoot. No-Joy. POOH. Lay down Tools. 17:00 19:00 2.00 0 0 PROD1 WELLPF SLKL T Rig down Digital Slick-line...unable to complete their mission due to software/tool issues. (SIMOPS: order out 2 ea Baker Hydraulic Setting Tools, Baker Multi-String Cutter dressed for 7"26 lb/ft Pipe, and a Stabilizer. Will continue operations using Drill Pipe when the tools arrive). 19:00 19:30 0.50 0 0 PROD1 WELLPF SVRG P Inspect and service top drive 19:30 21:30 2.00 0 0 PROD1 WELLPF WAIT T Wait on'J' Hydraulic setting tool. 21:30 22:30 1.00 0 10 PROD1 WELLPF BHAH P Pick up and make up setting tool and RBP#1 22:30 00:00 1.50 10 1,208 PROD1 WELLPF TRIP P RIH with RBP#1 to 1,208' 02/17/2015 Continue to RIH with RBP#1 on Drill pipe and set at 6840'dpmd. Pressure Test RBP. POOH. PU RBP#2 and RIH on Drill pipe and set at 2630'dpmd. Pressure Test RBP. Circulate well to Hot Seawater. POOH. PU muleshoe and RIH. Dump sand on plug.Tag sand at 2518'dpmd. POOH. Nipple Down BOP stack. Grow 7" casing. 00:00 01:45 1.75 1,208 6,840 PROD1 WELLPF TRIP P Continue to RIH with RBP#1 on drill pipe to 6,840'. PUW 132K, SOW 95K. 01:45 02:45 1.00 6,840 6,740 PROD1 WELLPF MPSP P Drop ball and pressure up on drill pipe to 3,000 psi to set RBP. Stand back 1 stand. Rig up and PT RBP #1 to 1000 psi for 10 minutes-good. 02:45 05:00 2.25 6,740 0 PROD1 WELLPF TRIP P POOH with'J' Hydraulic setting tool. 05:00 06:00 1.00 0 10 PROD1 WELLPF BHAH P Lay down Setting tool#1. Pick Setting Tool#2. 06:00 08:30 2.50 10 2,645 PROD1 WELLPF TRIP P Trip in with Baker RBP#2(upper RBP). 08:30 09:15 0.75 2,645 2,630 PROD1 WELLPF MPSP P Drop the 1 7/16"Setting Ball. Position the upper RBP at 2,630-ft dpmd. Bring Pump on line and walk pressure up to 3,380 psi. RBP set _ and sheared Setting Tool free. 09:15 09:45 0.50 2,630 2,620 PROD1 WELLPF PRTS P Pressure test the upper RBP at 1,000 psi x 10 minutes. Record on chart. 09:45 11:30 1.75 2,620 2,620 PROD1 WELLPF CIRC P PJSM. Mix and pump a—40 bbl Hi-Vis 10.3 lb/gal Spacer Pill. Start hot Sea Water and swap the Wellbore over from 10.3 lb/gal Brine to hot Sea Water at 5.0 bpm/545 psi. Total volume pumped 290 bbls. Fill Trip Tank. Blow down lines. Page 9 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 13:15 1.75 2,620 10 PROD1 WELLPF TRIP P Trip out with Setting Tool#2 on 3 1/2"Drill Pipe,standing back in the Derrick. 13:15 13:30 0.25 10 0 PROD1 WELLPF BHAH P Lay down Setting Tool#2. Pick Mule Shoe. 13:30 15:00 1.50 0 2,499 PROD1 WELLPF TRIP P Trip in to 2,499-ft dpmd. 15:00 16:45 1.75 2,499 2,499 PROD1 WELLPF CIRC P Rig up Sand Dump Hopper and flush line. Dump 2,200 lbs of 20/40 mesh sack sand in a slurry down the Drill Pipe on top of the upper RBP at 2,630-ft dpmd. Wait on Sand to settle 16:45 17:00 0.25 2,499 2,518 PROD1 WELLPF TRIP P Tag top of sand at 2518'dpmd. 17:00 18:30 1.50 2,518 0 PROD1 WELLPF TRIP P Trip out of hole. 18:30 19:00 0.50 0 0 PROD1 CSGRC'RURD P Remove wear ring. 19:00 20:30 1.50 0 0 PROD1 CSGRC'NUND P Nipple Down BOP stack. 20:30 00:00 3.50 0 0 PROD1 CSGRC'CUTP P Rig Up Hydratight and grow 7" casing. 02/18/2015 Continue to grow 7"casing;growth of 35-5/8". Spear casing, stretch 10-3/8", set in slips with 20k tension at cut location. Cut off 3.88'of 7"casing. Nipple Up BOP stack. PU and RIH with BHA#4(Multi-String Cutter). Cut 7"casing at 2023'dpmd. Circulate out arctic pack. POOH and LAD BHA#4. PU and RIH BHA#5(7" spear). Spear and LD 7"casing. Test Break in stack to 250/3000 psi. PU and RIH BHA#6(Flexible Tandem Mill). 00:00 03:00 3.00 0 0 PROD1 CSGRC'CUTP P Continue to grow 7"casing with IHydratight. Casing grew 35-5/8". Nipple Down Tubing Head. Remove casing packoff. Spear 7"stub and pull into tension with 20k at cut location, 110k indicated.Additional pull had 10-3/8"of stretch. Land 7" back in slips. Cut off 3.88'of excess _7"casing. 03:00 05:30 2.50 0 0 PROD1 CSGRC'NUND P Nipple Up BOP Stack. 05:30 06:00 0.50 0 8 PROD1 CSGRC'BHAH P Pick Up BHA#4(Multi-String Cutter).Total length: 8.44' 06:00 07:00 1.00 8 1,997 PROD1 CSGRC'TRIP P Trip in with the Multi-String Cutter dressed to cut 7"Casing(max blade swing 8.58")to 1,997-ft dpmd. Page 10 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 08:15 1.25 1,997 2,023 PROD1 CSGRC'CPBO P Establish parameters as follows: Up weight=60K. Down weight=60K. Bring Pump on line at 3.2 bpm/324 psi. Locate 7"Casing Collars at 2,002-ft dpmd(elmd on log 2,014-ft) and at 2,045-ft dpmd(elmd on log 2,057-ft). Position the MS Cutter to cut at 2,023-ft dpmd(elmd on log 2,035-ft)center of the joint. Bring Top Drive on at 80 rpms,free spin torque= 1,000 ft/lbs, bring Pump on line at 4.8 bpm/860 psi. Observed a drop in pressure down to 590 psi and an increase in pump speed up to 5.25 bpm...cut made in 4 minutes. Continue to"cut"for an additional 2 minutes until Arctic Pack observed at surface. 08:15 10:45 2.50 2,023 2,023 PROD1 CSGRC'CIRC P Circulate out Artic Pack with hot Sea Water(140°F.)at 5.0 bpm/360 psi. Total volume pumped=297 bbls. Sea Water returns near the end came back reasonable clean and at —116 d°F. Wash out Stack. 10:45 11:30 0.75 2,023 2,023 PROD1 CSGRC'OWFF P Monitor well x 30 minutes...static. (SIMOPS blow down Top Drive and lines). 11:30 12:30 1.00 2,023 8 PROD1 CSGRC'TRIP P Trip with BHA#4 on 3 1/2" Drill Pipe from 2,023-ft dpmd. BHA at surface. 12:30 13:30 1.00 8 0 PROD1 CSGRC'BHAH P Inspect MS-Cutter. Cutter Blades recovered complete and show the normal expected wear. Lay down MS-Cutter. Suck out Stack. Pick up 7" ITCO Spear w/Pack-Off. 13:30 13:45 0.25 0 2,023 PROD1 CSGRC'FISH P Plant the ITCO Spear in the 7" Casing. 13:45 16:00 2.25 2,023 2,020 PROD1 CSGRC'NUND P Split the BOP Stack and lift same. Pull the 7"Casing Slips. Set Stack back down and nipple up. 16:00 19:30 3.50 2,020 0 PROD1 CSGRC'PULL P Lay down the 7"Cut-Off Joint and break out ITCO Spear. Continue to single down 7"Casing. Bottom piece of 7"cut joint was 22.12'. 19:30 20:30 1.00 0 0 PROD1 CSGRC'BOPE P Clean and clear rig floor. Set test plug. and Rig Up test equipment. 20:30 21:30 1.00 0 0 PROD1 CSGRC'BOPE P Pressure test Break at base of stack to 250/3000 psi. 21:30 22:30 1.00 0 0 PROD1 CSGRC'SVRG P Service Rig,Top Drive Inspection. Install Blower hose. 22:30 23:30 1.00 0 54 PROD1 CSGRC'BHAH P Pick Up BHA#6(Flexible Tandem Mill). 23:30 00:00 0.50 54 54 PROD1 CSGRC'TRIP P Trip in 2 stands to ensure we could get through any tight spots in top of hole without having Drill Collars on top of string. No tight spots noted Page 11 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/19/2015 24 hr Summary Mill tight spots in surface casing down to 7"cut. Circulate well clean. Monitor well. POOH and LD BHA#6. PU and RIH with BHA#7(Rigid Tandem Mill). Mill tight spots in surface casing down to 7"cut. PU and RIH with BHA#8(Triple Connect Drift). POOH and LD BHA#8. PU and RIH with BHA#9(7"Cleanout). Cleanout inside 7". POOH and LD BHA#9. PU and RIH with BHA#10(Backoff). 00:00 01:30 1.50 54 240 PROD1 CSGRC'BHAH P Continue Picking Up BHA#6 component(six 6-1/4"drill collars). Overall length:240.19' 01:30 02:45 1.25 240 2,020 PROD1 CSGRC'TRIP P Trip in hole looking for any restrictions or tight spots. No problems noted. 02:45 03:15 0.50 2,020 2,020 PROD1 CSGRC'CIRC P Circulate hole clean. Returns dirty with arctic pack. Circulate until cleans up. Total of 200 bbls at 10 bpm 720psi. 03:15 03:30 0.25 2,020 2,020 PROD1 CSGRC'OWFF P Monitor well. Static 03:30 04:15 0.75 2,020 240 PROD1 CSGRC'TRIP P Trip out of hole looking for any restrictions. None noted. 04:15 04:30 0.25 240 240 PROD1 CSGRC'OWFF P Monitor well. Static 04:30 06:00 1.50 240 222 PROD1 CSGRC'BHAH P Lay Down BHA#6. Pick Up BHA#7 (Rigid Tandem Drift). 06:00 07:45 1.75 222 2,020 PROD1 CSGRC'TRIP P Trip in with BHA#7(Rigid Tandem Drift)with 3 1/2"Drill Pipe from the Derrick. 9 5/8"Casing appears clean...no tight spots or restrictions observed. Up Wt=70k 07:45 08:45 1.00 2,020 2,020 PROD1 CSGRC'CIRC P Circulate at 10 bpm/700 psi. Recovered some Arctic Pack rising from behind the 9 5/8"x 7"Annulus below the 7"cut. 08:45 10:00 1.25 2,020 222 PROD1 CSGRC'TRIP P Trip out with BHA#7,standing back the 3 1/2"Drill Pipe in the Derrick. BHA at surface. 10:00 11:15 1.25 222 0 PROD1 CSGRC'BHAH P Lay down BHA#7. 11:15 12:15 1.00 0 0 PROD1 CSGRC'SVRG P Inspect Top Drive. Perform Derrick Inspection. 12:15 13:00 0.75 0 54 PROD1 CSGRC'BHAH P Make up BHA#8(Drift Assembly)as follows:Triple Connection, ES Cementer, 1 Joint 7"Casing,XO Sub,XO. 13:00 14:30 1.50 54 2,020 PROD1 CSGRC'TRIP P Trip in with BHA#8. No problems or restrictions observed in the 9 5/8" Casing. Up Wt=60k, Dn Wt=60k 14:30 15:00 0.50 2,020 54 PROD1 CSGRC'TRIP P Trip out of hole with BHA#8. Up Wt =60k 15:00 15:45 0.75 54 0 PROD1 CSGRC'BHAH P Lay Down BHA#8. 15:45 16:30 0.75 0 0 PROD1 CSGRC'RURD P Rig Down GBR equipment. Clean and Clear rig floor. 16:30 17:45 1.25 0 326 PROD1 CSGRC'BHAH P Pick Up BHA#9(7in casing cleanout). Taper Mill,2 pin sub, 2 boot baskets, String Magnet, Bit sub, Bumper sub, Jar, 9 4-3/4"Drill Collars, Crossover. Overall length: 326'. ISI Page 12 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:45 18:00 0.25 326 326 PROD1 CSGRC'SFTY P Kick While Tripping Drill. Crew Response Time:Well shut in=22 sec,All crew in position=55 sec. AAR with crew. 18:00 19:00 1.00 326 2,314 PROD1 CSGRC'TRIP P Trip in hole with BHA#9. No issues getting into 7"casing. 19:00 19:45 0.75 2,314 2,314 PROD1 CSGRC'CIRC P Circulate BU @ 10 bpm/750 psi. 19:45 20:00 0.25 2,314 2,314 PROD1 CSGRC'OWFF P Monitor well. Static 20:00 20:30 0.50 2,314 326 PROD1 CSGRC'TRIP P Trip out of hole with BHA#9. 20:30 21:30 1.00 326 0 PROD1 CSGRC'BHAH P Lay Down BHA#9, standing back 3 stands of 4-3/4 Drill Collars. 21:30 23:00 1.50 0 314 PROD1 CSGRC'BHAH P Pick Up BHA#10(7" Backoff). Tapered Mill,6 4-3/4"DC, Port sub, Lower Anchor, Power section, Upper Section, Pump Out Sub, 3 4-3/4" DC, Crossover. Overall length=314' 23:00 00:00 1.00 314 1,127 PROD1 CSGRC'TRIP P Trip in hole with BHA#10. 02/20/2015 Backoff 7"cut joint. POOH and LD BHA#10. PU and RIH BHA#11 (7"Spear). Spear, backoff, POOH and LD cut joint. RU and run 7"casing tieback.Tie in Tie Back string to original 7"string. 00:00 01:00 1.00 1,127 2,254 PROD1 CSGRC'TRIP P Continue Trip in hole with BHA#10. 01:00 02:45 1.75 2,254 2,254 PROD1 CSGRC'CPBO P Back off 7"casing cut joint.Anchor Bottom and Top Anchors with power section across connection. Cycle tool per Baker Hughes Fishing Rep 11 times(pressures from 900 to 600 psi)for 5 complete turns.900 psi at initial break translates to 6080# torque. 02:45 03:15 0.50 2,254 2,254 PROD1 CSGRC'CIRC P Open Circ Sub and Circulate BU @ 10 bpm/800 psi. 03:15 05:00 1.75 2,254 314 PROD1 CSGRC'TRIP P Trip out of hole with BHA#10. 05:00 05:30 0.50 314 0 PROD1 CSGRC'BHAH P Lay Down BHA#10. 05:30 06:00 0.50 0 0 PROD1 CSGRC'RURD P Clean and Clear Rig floor. 06:00 06:30 0.50 0 224 PROD1 CSGRC'BHAH P Pick Up BHA#11 (7"Spear). 06:30 07:30 1.00 224 1,927 PROD1 CSGRC'TRIP P Trip in with BHA#11 on 3 1/2"Drill Pipe from the Derrick to 1,927-ft. Stop for Rig Service. 07:30 07:45 0.25 1,927 1,927 PROD1 CSGRC'SFTY P PJSM...Slip and Cut Drilling Line. 07:45 09:30 1.75 1,927 1,927 PROD1 CSGRC'SLPC P Slip and Cut Drilling Line. Adjust brake bands. Set Crown-O-Matic. 09:30 10:00 0.50 1,927 2,023 PROD1 CSGRC'TRIP P Continue to Trip in with BHA#11 to 2,023-ft dpmd. 10:00 10:45 0.75 2,023 2,023 PROD1 CSGRC'FISH P Up weight=70K. Down weight= 70K. Make-up top Drive. Tag the top of the 7"Casing. Plant Spear into the top of the 7"cut-off stump. Rotate string 6 turn to the left and back-out the 7"Casing stump for the connection at 2,045-ft dpmd. Page 13 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:45 11:45 1.00 2,023 224 PROD1 CSGRC'TRIP P Trip outwith BHA#11, standing back the 3 1/2"Drill Pipe in the Derrick. BHA to surface. 11:45 15:00 3.25 224 0 PROD1 CSGRC'BHAH P Single down 6 ea x 6 1/4"Drill Collars. Casing Spear and recovered 7"Casing back-off joint. OAL= 21.27-ft. 15:00 18:00 3.00 0 0 PROD1 CASING RURD P Pull Wear Ring. Clear and clean floor. Ready floor to handle 7" Casing. Rig up GBR equipment. Install Long bails. 18:00 18:30 0.50 0 0 PROD1 CASING SVRG P Service Rig, Drawworks. Calibrate Blocks. 18:30 19:30 1.00 0 0 PROD1 CASING RURD P Mobilize circulation equipment from HES Cementers to floor. 19:30 20:00 0.50 0 0 PROD1 CASING SFTY P PJSM with all hands for running 7" Casing tie-back string. 20:00 23:30 3.50 0 2,044 PROD1 CASING PUTB P Run Casing Tie Back String with Baker Triple Connect, HES ES Cementer and 48 joints of 7"26# Hydril 563 casing. Observed stub engaged at 2044'. Make-up connection with top drive and torque up connection working string up 50k and down 50k from String weight to ensure connection torqued to—9700 lb. Up Wt=74k, Dn Wt=74k, Rot Wt=74k @ 20 rpm. 23:30 00:00 0.50 2,044 2,044 PROD1 CASING RURD P Rig Down and Blow Down Top Drive. 02/21/2015 Open HES Cementer. Cement Tieback string to surface. Break BOP stack at wellhead. Set Emergency slips, cut 7"joint, set packoff and test them to 250/2500 psi. Nipple Up BOP. Set test plug.Test BOPE with 3.5"joint:All tests pass. Koomey 5 bottle avg 2040 psi, System Pressure 3000 psi,200 psi build 21 sec,full system pressure recovery 96 sec. PU and RIH with BHA#14(Cementer Plug Drill Out). 00:00 01:00 1.00 2,044 2,044 PROD1 CASING PRTS P Pressure test Casing to 2000 psi for 15 minutes,then pressure test to 2500 psi 15 min. Good.Tests charted. SIMOPS: Rig Up SLB Cement trucks and lines. 01:00 02:00 1.00 2,044 2,044 PROD1 CEMEN-RURD P Rig Up lines and Make Up Cement head with plug. Pusher and Company Rep witness plug loading. SIMOPS: Rig Up SLB Cement trucks and lines. 02:00 02:30 0.50 2,044 2,044 PROD1 CEMEN-SFTY P PJSM for cementing operations with all hands. Page 14 of 22 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 05:30 3.00 2,044 2,044 PROD1 CEMEN.CMNT P Cement 7"Tie Back as follows: (Pump 10 bbls of seawater ahead of cement, 23 BPM-325psi after opening ES Cementer prior to cement job.) Pump 5 bbls of Fresh water. Pressure test lines to 3500 psi, OK. Pump 10 bbls of Neat AS-1 @ 15.7 ppg. Swap to silo&pump 96 bbls of AS-1 blend Cement @ 5 BPM-200 psi. Chase w/10 bbls of Neat AS-1 @ 15.7 ppg. S/D&drop cement plug. Pump 2.0 bbls of neat AS-1 cement. Close lower 7" rams after 10 bbls away. Displace w/total of 81.0 bbls of seawater 3 BPM. After—30 bbls of displacement slowed pump to 2.0 BPM&@ 45 bbls away slowed to 1.5 BPM and slowly close the outer annular valve for back pressure(attempting to squeeze cement)holding 900 psi pump pressure. Bumped plug and increased pressure to 2500 psi&ES cementer closed. Bled back& checked for flow. Had—1/2 bbl flow back&cementer held. CIP @ 05:04 hrs. Had—49.5 bbls of cement to surface. 05:30 07:00 1.50 2,044 2,044 PROD1 CEMEN.RURD P Rig down Cementers, Halliburton Cementing Head, and GBR equipment. 07:00 13:30 6.50 0 0 PROD1 WELLPF NUND P Lift the BOP Stack. Observe Cement at surface(right at the OA Valve). Take picture of the top of cement. Set Emergency Slips and land the 7"Casing with 80K tension. Cut-off and dress-off the 7" Casing with the Wachs Cutter. Lay down the 7"cut-off joint...OAL=29.94-ft. Pull Riser. Remove Double Stud Adaptor. Set BOP Stack back on the stump. Install new 7" Pack-offs. Nipple up 11"x 3K x 7 1/16"x 5K Tubing Head. Test Pack-off at 250/2,500 psi. Nipple Up DSA and Stack, Torque up bolts. 13:30 14:00 0.50 0 0 PROD1 WELLPF BOPE P Install test plug. 14:00 16:00 2.00 0 0 PROD1 WELLPF BOPE P Change out 7" Rams for 2 7/8"x 5" VBRs in LPR cavity. Change out long bails for short bails. 16:00 16:30 0.50 0 0 PROD1 WHDBO RURD P Prep test equipment and cellar for BOPE test. Fill stack with water. Page 15 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 21:30 5.00 0 0 PROD1 WHDBO BOPE P Perform the weekly BOPE test(after coming off of diverter status)as per ConocoPhillips/AOGCC requirements at 250/3,000 psi with 3 1/2"Test Joint. Perform the Koomey draw down test. Test Gas Alarms. The State's right to witness the test was waived by AOGCC Field Inspector, Bob Noble.All pressure tests PASS.All tests recorded on a chart. Koomey draw test,good.4 bottle avg 2040 psi.Accum Pressure 3000 psi, Manifold Pressure 1680 psi,Annular Pressure 1140 psi. Pressure after all rams functioned 1650 psi. 200 psi recovery in 21 sec, full system pressure 96 sec. 21:30 22:00 0.50 0 0 PROD1 WHDBO RURD P Rig Down Test Joint and BOP Testing Eqpt. 22:00 22:30 0.50 0 0 PROD1 WELLPF PRTS P Pressure test 7"casing down to plug to 2500 psi for 10 min. Good test. Charted. 22:30 23:30 1.00 0 307 PROD1 WELLPF BHAH P Pick Up BHA#12 with 6 1/8" Tri-Cone bit. Overall length: 307.04" 23:30 00:00 0.50 307 1,100 PROD1 WELLPFITRIP P Trip in hole with BHA#12. 02/22/2015 Drill Out Plug and chase debris to bottom. POOH and LD BHA#12. PU and RIH with BHA#13(Concave Mill). Mill debris. POOH and LD BHA#13. PU and RIH BHA#14 Reverse Circulating Junk Basket). Run Junk Basket 3 times retrieving metal, rubber, brass. 00:00 00:30 0.50 1,100 2,000 PROD1 WELLPF TRIP P Trip in with BHA#12. 00:30 03:15 2.75 2,000 2,070 PROD1 WELLPF DRLG P Establish parameters. 80 rpm, 1.2 TQ,WOB 5k, 6 bpm @ 485 psi, Up Wt=60k, Dn Wt=60k, Rot Wt= 60k. Drill Cement/Plug at 2040' dpmd. 03:15 03:30 0.25 2,070 2,487 PROD1 WELLPF TRIP P Trip to bottom. Tag Cement on top of sand @ 2487'. 03:30 04:30 1.00 2,487 2,495 PROD1 WELLPF DRLG P Drill out Cement on top of sand from 2487'to 2495'dpmd. 80 rpm, 1.2 TQ, WOB 5k,6 bpm @ 485 psi, Up Wt= 60k, Dn Wt=60k 04:30 05:30 1.00 2,495 307 PROD1 WELLPF TRIP P Trip out of hole with BHA#12. 05:30 06:00 0.50 307 0 PROD1 WELLPF BHAH P Lay Down BHA#12. 06:00 07:00 1.00 0 0 PROD1 WELLPF PRTS P Pressure test the 7"Casing at 250 x 10 minutes and at 2,500 x 30 minutes. Good. Recorded on chart. 07:00 07:00 0.00 0 314 PROD1 WELLPF BHAH P Make-up BHA#13 as follows: 6 1/8" Concave Mill, 2 ea Boot Baskets, Bit Sub, Bumper Sub,Oil Jar, Pump-Out-Sub, 9 ea 4 3/4" Drill Collars,XO. 07:00 08:30 1.50 314 2,495 PROD1 WELLPF TRIP P Trip in BHA#13 on 3 1/2"Drill Plpe from the Derrick to 2,495-ft dpmd. Up weight=74K. Page 16 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 09:30 1.00 2,495 2,522 PROD1 WELLPF MILL P Establish parameters as follows: Pump Rate at 5.7 bpm/555 psi. RPMs=80, Free Spin Torque= 1,400 ft/lbs. Mill through cement stringer and or debris at 2,495-ft with ease. Continue to push debris down to top of sand at 2,518-ft Pick up to 2,495-ft. Circulate bottoms up. Returns CemNet fiber wads and 20/40 Sand. Allow well to clean up. End Pump. Drop back down to 2,522-ft dpmd. Dry drill on debris with the Concave Mill at 75 RPMs x 15 minutes. 09:30 11:00 1.50 2,522 314 PROD1 WELLPF TRIP P Up weight=74K. Set back one Stand. Blow down Top Drive. Trip out with BHA#14,standing the 3 1/2"Drill Pipe in the Derrick. 11:00 11:30 0.50 314 0 PROD1 WELLPF BHAH P Lay down BHA#13. 11:30 12:00 0.50 0 319 PROD1 WELLPF BHAH P Make-up BHA#14 as follows: 5 3/4" Reverse Circulating Junk Basket, String Magnet, Bumper sub, Oil Jar, Pump-Out-Sub, 9 ea 4 3/4" Drill Collars,XO. 12:00 13:30 1.50 319 2,496 PROD1 WELLPF TRIP P Trip in with BHA#14 on 3 1/2"Drill Pipe from the Derrick to 2,496-ft dpmd. 13:30 14:00 0.50 2,496 2,538 PROD1 WELLPF WASH P Up weight=75K. Bring Pump on at 8.0 bpm/1,648 psi. Tag top of Sand at 2,522-ft. Rotate and wash into the sand column from 2,523-ft to 2,538-ft. Clean up Well. 14:00 15:15 1.25 2,538 319 PROD1 WELLPF TRIP P Trip out with BHA#14 standing back 3 1/2" Drill Pipe in the Derrick. BHA at surface. 15:15 16:00 0.75 319 0 PROD1 WELLPF BHAH P Clean String Magnet. Recover metal filings. Empty RCJB. Recovered one large piece of the Closing Plug rubber and several smaller pieces. Also recovered two small piece of pot metal. 16:00 16:30 0.50 0 0 PROD1 WELLPF SVRG P Service Rig; Change out encoder on Draw works. Service Top Drive and do daily inspection. 16:30 17:00 0.50 0 319 PROD1 WELLPF BHAH P Re-load RCJB for run#2. 17:00 18:15 1.25 0 2,530 PROD1 WELLPF TRIP P Trip in with BHA#15...RCJB run#2 on 3 1/2"Drill Pipe from the Derrick to 2,538-ft dpmd. 18:15 18:30 0.25 2,530 2,550 PROD1 WELLPF WASH P Dry Drill to 2550 @ 60 rpm,2.1 k Tq. Up Wt=71k; Dn Wt=69k. Bring Pump on at 8.0 bpm/1760 psi. Wash into the sand column to 2,550-ft. 18:30 19:45 1.25 2,550 42 PROD1 WELLPF TRIP P Trip out with BHA#15 standing back 3 1/2" Drill Pipe in the Derrick. BHA at surface. Page 17 of 22 • Time Logs Date From To Dur S. Depth F. Depth Phase Code " Subcode T ' Comment 19:45 20:30 0.75 42 42 PROD1 WELLPF BHAH P Clean String Magnet. Recover metal filings. Empty RCJB. Recovered 5 large pieces of aluminum from the ES Cementer, Rubber pieces from the Closing Plug and 3 chunks of Brass shear screws. Re-load RCJB for run#3. 20:30 21:00 0.50 0 1,076 PROD1 WELLPF TRIP P Trip in with BHA#16...RCJB run#3 on 3 1/2"Drill Pipe from the Derrick. 21:00 21:15 0.25 1,076 1,076 PROD1 WELLPF SFTY P BOPE D1 drill and After action.Well shut in 26 sec.All crew in position in 60 sec. 21:15 21:45 0.50 1,076 2,540 PROD1 WELLPF TRIP P Continue Trip in hole to 2540'dpmd. 21:45 22:00 0.25 2,540 2,565 PROD1 WELLPF WASH P Dry Drill to 2565'@ 60 rpm,2.1k Tq. Up Wt=71k; Dn Wt=69k. Bring Pump on at 8.0 bpm/1760 psi. Wash into the sand column to 2,565-ft. 22:00 23:00 1.00 2,565 42 PROD1 WELLPF TRIP P Trip out with BHA#16 standing back 3 1/2"Drill Pipe in the Derrick. BHA at surface. 23:00 23:30 0.50 42 42 PROD1 WELLPF BHAH P Clean String Magnet. Recover metal filings. Empty RCJB. Recovered 2 large pieces of aluminum from the ES Cementer. Re-load RCJB for run #4. 23:30 00:00 0.50 42 878 PROD1 1 WELLPF TRIP IP Trip in with BHA#17...RCJB run#4 on 3 1/2"Drill Pipe from the Derrick. 02/23/2015 Run Junk Basket BHA 2 more times. Lay Down BHA#18(RCJB run#5). PU and RIH with Retrieval tool for RBP. Circulate well clean. Release RBP. Monitor well. POOH and LD RBP and tool. PU and RIH with Retrieval tool for RBP. Circulate well clean. Release RBP. Circulate well. Monitor well. POOH and LD Drill Pipe. 00:00 00:30 0.50 878 2,565 PROD1 WELLPF TRIP P Continue Trip in with BHA#17 to 2,565-ft dpmd 00:30 01:30 1.00 2,565 2,580 PROD1 WELLPF WASH P Dry Drill to 2580'@ 60 rpm,2.1k Tq. Up Wt=72k; Dn Wt=70k. Bring Pump on at 8.0 bpm/1630 psi. Wash into the sand column to 2,580-ft. 01:30 02:30 1.00 2,580 42 PROD1 WELLPF TRIP P Trip out with BHA#17 standing back 3 1/2" Drill Pipe in the Derrick. BHA at surface. 02:30 03:00 0.50 42 42 PROD1 WELLPF BHAH P Clean String Magnet. Recover metal filings. RCJB-recovered 1 piece of rubber. Re-load RCJB for run#5. 03:00 04:00 1.00 42 2,583 PROD1 WELLPF TRIP P Trip in with BHA#18 to 2,580-ft dpmd 04:00 04:30 0.50 2,583 2,600 PROD1 WELLPF WASH P Dry Drill to 2590'@ 60 rpm,2.1k Tq. Up Wt=72k; Dn Wt=70k. Bring Pump on at 8.0 bpm/1630 psi. Wash into the sand column to 2,595-ft. 04:30 05:30 1.00 2,600 42 PROD1 WELLPF TRIP P Trip out with BHA#18 standing back 3 1/2"Drill Pipe in the Derrick. BHA at surface. Page 18 of 22 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 05:30 06:30 1.00 42 0 PROD1 WELLPF BHAH P Clean String Magnet. Recover metal filings. RCJB-Empty. Lay Down BHA#18 Components. 06:30 07:00 0.50 0 4 PROD1 WELLPF BHAH P Make-up the Baker Retrieving Head. 07:00 08:30 1.50 4 2,600 PROD1 WELLPF TRIP P Trip in with the Retrieving Head to 2,600-ft dpmd,just above the sand top. Up weight=65K 08:30 09:00 0.50 2,600 2,638 PROD1 WELLPF CIRC P Displace Sea Water with 10.3 lb/gal Brine at 4.5 bpm/200 psi. Total volume pumped= 115 bbls. 10.3 lb/gal returned to surface. Start easing down, cleaning out sand to 2,626-ft dpmd. Allow well to clean up. Reduce pump rate to 1.0 bpm/85 psi. 09:00 09:30 0.50 2,638 2,638 PROD1 WELLPF MPSP P Ease down to 2,627-ft. Swallow the fishing neck and set down at 2,629-ft with 5K. Pick up to 15K over. Release the Retrievable Bridge Plug at 2,630-ft(center element). Ease back down to 2,637-ft...RBP released. Allow elements to relax. 09:30 11:00 1.50 2,638 7 PROD1 WELLPF TRIP P Set back one stand. Blow down Top Drive. Up weight=65. Trip out with the upper RBP, standing back the 3 1/2"Drill Pipe in the Derrick. 11:00 11:30 0.50 7 0 PROD1 WELLPF MPSP P Lay down the upper Baker Retrievable Bridge Plug...complete. 11:30 15:00 3.50 0 6,815 PROD1 WELLPF TRIP P Trip back in to retrieve the lower RBP at 6,840-ft(center element). Tagged high at 6,815-ft dpmd. Up weight= 130K. Down weight=95K 15:00 17:00 2.00 6,815 6,836 PROD1 WELLPF CIRC P Bring Pump on at 5.0 bpm/860 psi. Wash down to 6,836-ft, 1-ft above the RBP. Continue to circulate. Mix and pump a 40 bbl Hi-Vis Sweep. Circulate back to surface with 10.3 lb/gal Brine. Sand recovered at shakers. Reduce pump rate to 1.0 bpm. 17:00 17:30 0.50 6,836 6,836 PROD1 WELLPF MPSP P Ease down to 6,840-ft. Swallow the fishing neck and set down at 6,840-ft with 5K. Pick up to 15K over. Release the Retrievable Bridge Plug at 6,8400-ft(center element). Ease back down to 6,847-ft...RBP released. Allow elements to relax. 17:30 17:45 0.25 6,836 6,836 PROD1 WELLPF OWFF P Monitor well. Static. 17:45 18:45 1.00 6,836 6,836 PROD1 WELLPF CIRC P Circulate Bottoms Up to ensure below RBP is clear. ICP 5 bpm/ 1050 psi, FCP 5 bpm/980 psi. SPRs taken. Pump 1: 2 bpm =250 psi, 30 bpm= 400 psi Pump 2: 2 bpm =250 psi, 30 bpm= 400 psi Page 19 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:45 19:00 0.25 6,836 6,836 PROD1 WELLPF SFTY P Well Control Drill. Kick While Tripping.Well Secure in 26 sec, Crew in position in 48 sec.AAR with crew. 19:00 19:30 0.50 6,836 6,442 PROD1 WELLPF PULD P Pull out of hole laying down drill pipe to 6442'.Well slightly out of balance. 19:30 20:15 0.75 6,442 6,442 PROD1 WELLPF CIRC P Circulate hole volume at 5 bpm/985 psi to ensure well balanced and dead. 20:15 20:30 0.25 6,442 6,442 PROD1 WELLPF OWFF P Monitor Well. Static 20:30 00:00 3.50 6,442 1,200 PROD1 WELLPF PULD P Pull out of hole while laying down drill pipe to 1200'. 02/24/2015 Lay Down Drill Pipe and RBP and retrieval tool. Run 3.5"completion per detail. Spot CI Brine. Set Packer. SOV sheared suring Packer/IA test. Shear out Seals. Space out completion. Hang off completion. Test Hanger/Packer. Set BPV. Nipple Down BOP. Nipple Up tree.Verify orientation with DSO.Test Void. Remove BPV and set tree test plug. 00:00 00:45 0.75 1,200 7 PROD1 WELLPF PULD P Pull out of hole while laying down drill pipe. 00:45 01:00 0.25 7 0 PROD1 WELLPF MPSP P Lay Down RBP and retrieving head. 01:00 01:15 0.25 0 372 PROD1 WELLPF TRIP P Trip in hole with 1 stand of Drill Pipe and 3 stands of Drill Collars from Derrick. 01:15 02:00 0.75 372 0 PROD1 WELLPF PULD P Pull out of hole while laying down drill pipe and drill collars. 02:00 02:15 0.25 0 0 PROD1 WELLPF RURD P Remove Wear Ring. 02:15 02:45 0.50 0 0 PROD1 WELLPF WWWH P Wash stack and wellhead with Jetting Tool. 02:45 03:45 1.00 0 0 PROD1 WELLPF RURD P Clean and Clear rig floor. 03:45 04:15 0.50 0 0 COMPZ RPCOM RURD P Rig Up Tubing tongs and elevators. SIMOPS: Go over completion in pipe shed and double check running order. 04:15 04:30 0.25 0 0 COMPZ RPCOM SFTY P PJSM with all hands for running 3.5" completion. 04:30 07:45 3.25 0 1,900 COMPZ RPCOM PUTB P Pick Up and RIH with 3.5"EUE8rd completion per detail. 07:45 08:00 0.25 1,900 1,900 COMPZ RPCOM SFTY P BOP Drill and AAR with rig crew. 08:00 08:30 0.50 1,900 1,900 COMPZ RPCOM SVRG P Service Rig(Top Drive and Drawworks. Daily Top Drive Inspection. 08:30 14:00 5.50 1,900 6,940 COMPZ RPCOM PUTB P Continue to Pick Up and RIH with 3.5"EUE8rd completion per detail. 14:00 14:30 0.50 6,940 6,940 COMPZ RPCOM RURD P Rig Up circulating equipment to locate Overshot on stub. 14:30 15:00 0.50 6,940 6,950 COMPZ RPCOM HOSO P Pick up and Make up joint with circulating equipment. Observe pressure increase as overshot swallowed tubing stub. Observed good indication of Shear screws shearing in overshot. Fully locate @ 6959. Mark 1'space out and prepare to circulate CI Brine. Page 20 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 15:30 0.50 6,950 6,950 COMPZ RPCOM'CRIH P Pump 100 bbls of Corrosion Inhibited (1%Concor 303) 10.3 ppg Brine, chase with 60 bbls 10.3 Brine. pumped at 4 bpm/420 psi. 15:30 16:00 0.50 6,950 6,958 COMPZ RPCOM PACK P Drop Ball and rod and let fall. (setting pressures charted)Pressure up to 2500 psi, observe packer setting @ 1800 psi. Set 10k down. Pressure up to 300 psi and hold for 5 minutes. Bleed down pressure from setting. 16:00 16:30 0.50 6,958 6,834 COMPZ RPCOM PRTS P Test Packer set by pressuring IA to 500 psi. SOV shear indication @ —400 psi. Observed returns out tubing. Pumped opposite direction to confirm and observed returns from IA. Shear seal out of PBR. 16:30 17:00 0.50 6,834 6,834 COMPZ RPCOM HOSO P Pick Up Tubing Hanger. Lay Down 3 joints of tubing, Pick up Space out pups(2.25', 10.25'), 1 full joint between space out pups and hanger. Make Up Tubing Hanger and landing joint. 17:00 18:00 1.00 6,834 ' 0 COMPZ RPCOM THGR P Circulate and observe pressure change as seals enter PBR. Shut down pumps and drain stack. Land hanger and RILDS. 18:00 19:00 1.00 0 0 COMPZ RPCOM PRTS P Pressure test Packer, Casing, Hanger to 2500 psi for 30 min. (Charted) 19:00 19:30 0.50 0 0 COMPZ RPCOM RURD P Rig down GBR tongs. Rig Down completion running equipment. Lay Down landing joint and clear rig floor. 19:30 20:00 0.50 0 0 COMPZ WHDBO MPSP P Set BPV per FMC Rep and test to 1000 psi from below. 20:00' 20:15 0.25 0 0 COMPZ WHDBO SFTY P PJSM for Nippling Down BOP stack and equipment. 20:15 21:30 1.25 0 0 COMPZ WHDBO NUND P Nipple Down BOP stack and set 1 back on stump. Secure stack. Remove DSA. 21:30 21:45 0.25 0 0 COMPZ WHDBO SFTY P PJSM for nippling up tree with all personnel. 21:45 23:00 1.25 0 0 COMPZ WHDBO NUND P Nipple Up tree per FMC Rep.Verify Orientation with DSO. 23:001 23:30 0.50 0 0 COMPZ WHDBO MPSP P Pull BPV. Set Tree test plug. 23:30 00:00 0.50 0 0 COMPZ WHDBO PRTS P Pressure Test tree to 250/5000 psi. Charted 02/25/2015 Test tree. Pull tree tet plug. Freeze Protect well. Clean Pits. Secure tree and cellar. Pull fluid from pits. Rig released at 0900 HRS. Prep rig for move. RDMO. 00:00 00:30 0.50 0 0 COMPZ WHDBO PRTS P Continue Pressure test tree to 250/ 5000. (Charted) 00:30 00:45 0.25 0 0 COMPZ WHDBO SFTY P PJSM for freeze protecting well. Page 21 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:45 03:30 2.75 0 0 COMPZ WHDBO FRZP P Freeze protect well with Little Red Services. Pressure test lines to 2500 psi. Circulate 58 bbls in Diesel Freeze Protect down IA. ICP 175 psi, FCP 1050 psi. Hook up jumper lines and allow to U-Tube. Final pressure tubing and IA=0 psi. 03:30 04:00 0.50 0 0 COMPZ WHDBO MPSP P Set BPV per FMC Rep.Verify tbg, IA and OA pressures at 0 PSI. 04:00 09:00 5.00 0 0 DEMOB MOVE RURD P Rig Down Freeze Protect lines. Remove secondary Annulus Valve. Install tree gauges, Secure cellar, Clean pits. Rig released at 0900 HRS. Page 22 of 22 3F-06 POST RIG WELL WORK DATE SUMMARY 3/7/2015 PULLED BALL n' ROD @ 6974' RKB; PULL SOV& SET DV© 4207' RKB; MITT (PASS) MITIA (PASS); PULLED DV @ 4207' RKB & SET OV; PULLED DV @ 2644' RKB & SET GLV. IN PROGRESS. 3/8/2015 PULL RHC BODY @ 6974' RKB, BAIL SAND/METAL SHAVINGS FROM 6988'-7003' SLM, IN PROGRESS 3/9/2015 BAIL. SAND/METAL SHAVINGS FROM 7001-7008' SLM, ON HOLD FOR WEATHER 3/10/2015 BAIL. SAND FROM 7009-7023' SLM, IN PROGRESS 3/11/2015 BAIL FILL F/7019-7026' SLM, METAL MARKS ON BAILER, ATTEMPT TO LATCH CATCHER, IN PROGRESS 3/12/2015 BAIL.SAND OFF CATCHER © 7062' RKB, IN PROGRESS 3/13/2015 BAIL. FILL FROM CATCHER @ 7062' RKB, RECOVER LARGE METAL CHUNKS, IN PROGRESS 3/14/2015 MADE COUPLE MAGNET RUNS AND BAILED DEBRIS OFF CATCHER @ 7062' RKB.IN PROGRESS 3/15/2015 RAN ASSORTED MAGNETS AND 2.5" BAILER TO 7027' SLM RECOVERING COUPLE LARGE METAL PIECES.ATTEMPT TO LATCH CATCHER.IN PROGRESS 3/16/2015 CONTINUE TO REMOVE SMALLER METAL CHUNKS BY ASSORTED MAGNETS.IN PROGRESS 3/17/2015 RECOVERED METAL DEBRIS @ 7029' SLM. ENGAGED CATCHER SUB © 7062' RKB, UNABLE TO PULL. IN PROGRESS. 185244 25478 WELL LOG TRANSMITTAL DATA LOGGED 3ivno15 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. February 26, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED MAR 0 6 2015 RE: Tubing Cut Record: 3F-06 AOGCC Run Date: 2/12/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3F-06 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21462-00 SEED 1\: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: `eiti"-""C Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (done)/~~Two-Sided RESCAN [] Color items: [] Grayscale items: [] Poor Quality Origine,[s: Other: DIGITAL DATA [] Diskettes, No. [] Other, No/Type TOTAL PAGES: ~:::~ ~ ORGANIZED BY: BL~VERLY NOTES: BREN VINCENT SHERYL MARIA LOWELL E] DATE: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Is~ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /si Scanned (done) I1'1 IIIIIIIIIII IIIII PAGES: ~ (at the time of scanning) SCANNED BY; ~BREN VINCENT SHERYL MARIA LOWELL Is~ ~. ReScanned (done) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ~si General Notes or Comments about this file: PAGES:~~ Quality Checked (done) RevlNOTScanned.wpd • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 24, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 3F -06 Run Date: 6/11/2011 SEP The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3F -06 Digital Data in LAS format, Digital Log Image file, Interpretation Report _ 1 CD Rom .. 50- 029 - 21462 -00 *Ibt Production Profile Log 1 Color Log ✓ 50- 029 - 21462 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 7 L l Signed: 010 r I I 1 85 — 2`fct /' ,/ / // ~_~ d' ;~;~--------~-~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # NO.5035 Company: Alaska Oil & Gas Cons Comm ~,,,_ ~ .--r- Ri C, ~; ~!n Attn: ChristineMahnken ~'~` ~~~ ~ ~ ~ ~~~'~`~ ~~ ~~`''°' 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 01 /08/09 3F-05 12115003 PRODUCTIO 1E-22 12115008 N PROFILE ~ ;;~ - ;;~.~,,_~ - t;4_'_ ~ r~~ INJECTION PROFI " ~ 12/20/08 1 1 3F-12 12115008 LE j .L_ j ~)._rj ~. ~ .- C_- "? INJECTION PROFI - %'~ _' 12/24/08 1 1 1D-136 12115008 LE ~ j ~ _ . !r ^: ~--> r. ./-~ x INJECTION PRO ' 12/25/08 1 1 3F-06 3J-02 2N-332 AZED-00003 12115008 12096514 FILE ~_ ~ _ ~ -) -. ..,_ « , ~I,zq PRODUCTION PROFILE ',g,~j---~~<~~- L 1~ INJECTION PROFILE ; ~ ' -^~ - < :- _ / ,, °'7~ , -, _ C. r[-` SBHP SURVEY `-;~ ~` ' = ' 12/26/08 12/27/08 12/29!08 1 1 1 1 1 1 2N-323 AZED-00008 .~j _ :~_ = j ,,~~ _~ SBHP SURV ~= ` ' • - ! '~ 12/30/08 1 1 2N-342 12096514 EY - , - - ,~ ;' ; - j ; - ~-C ~/_~~. SBHP SURVEY ~ '"= ' 12/30/08 1 1 2N-302 AZED-00007 ~) , c_~~ ~ j I- _. ; (L, - i ~ SBHP SURVE 12!30/08 1 1 2P-417 AZED-00012 Y ~ ;_ ~ ~ l _. I.~~ ' >' <-, ~- `; SBHP SURVEY - ' ~ ' 12/30/08 1 1 2V-03 12115000 . j ~ ~ > l ..._ i. -: f- -- INJECTION P L '~ 01/02/09 1 1 1R-13 AYS4-00019 ROFI E (} -"~; - ~,,+; _ INJECTION PR - `- ' iy17/pg 1 1 iB-02 AYS4-00020 -- ,,-~, . ~ ,, j<r, ~ OFILE :a-C,~?~ INJECTION PRO ' ~ 01/03/09 1 1 FILE c~lT:. . ~_ :~`j 01/04/09 1 1 • • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . ~ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 2, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 S(;ANNED SEP 0 8 2006 Anchorage, AK 99501 \ /fi G~ ';}.4-L\' Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU) 3F Pad. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on August 14, 2006 and is reported as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 21-29, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907-659-7043.,·¡(you have any questions. //' /7 // Sincerely, // il' // f ~/ ¿' 7 ./ .~/ y' :yIp-. / /1 f/7./¡~/!r~ -:7' /. I if /Í f M.J. toveland ConocoPhillips Well Integrity Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 8/31/2006 Initial Top Cement Fi nal Top Sealant Well Name PTD # of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Date Gallons Date 3f,01. '.' ." . l8:~~25 . . ". .·NA. . .' . , . .; I.·.· . '. :8ft~&"'QQ~ ; 3F-02 1 85-226 24' 7.0 8/1 4/2006 7.5 8/2 1 /2006 3F;U3. ·Hi~¥~2.1; ;, ":f~~' : .. 2:3, '. '. .:c: . . 8/1(4'lìttØ.~;; '." ;'. ;'8't~1iI.2:.'Œø,~i/ 3F-04 1 85-228 80' 22. 7 1 0' 8" 8/1 4/2006 38.2 8/21 /2006 c. ,', . 5.1 . . ',. . : 'c; ".. /?8/,1;~f2ø'r6 .;~, " , ·'8~1.ì2'ãÐ:$''!' . '.' , 3F-06 1 85-244 Did not modify '3¡;':;Ó·7· .. .": ,,:f.~2tw::·; '. ~'/ . ,6:6 . " . ~tf~I2:(Uf6 ; :.' '1.5 ",.' ;-'" ;8J2:ji2~~4) .' 3F-08 1 85-246 1 1 '4" 2 .6 8/1 4/2006 6.6 8/2 1 /2006 3F;a$ . : I., ,lå~.O . Did not modify 3F-1 0 1 85-27 1 SF NA NA 6.6 8/2 1 /2006 . .·.3F":':r-r, ':'la5;:2("2" ' ; ........ .' NA . : ..' ...NA·; ,;. , 1,,7" '.. . 8'lï~la!)~ø'Q .. c 3F-12 1 85-273 7'4" 1 .8 8/1 4/2006 6.2 8/23/2006 ~.. . ' ·1~&1m~'~:¿ ~ NA;·· .' "'..' < L~'¡ØÞ2'Æ2Ðqß': : . '. 3F-14 1 85-292 Did not IIUUII ~ , ···..'l~.~{'? 2,4. . . ..... , 6'''j;~f~f,là~:¡ , ;81~~12.()~:ø;, <." . ,. '.' : " 3F-1 6 ~1 6" NA NA 2.7 8/23/2006 3E~1:1, ' '.. 3.'1 '.' , .. 'ff¡'1~I2:QQ6¡;: ; ~<' 8, ". SI2ø:12:önß:, . .. '. 3F-1 8 196-112 4' NA NA 28 8/23/2006 :áF;,;'1f9: '. .,' . 2~4rÐf1;ß;~' ;.:, " 8"". ," NA.,· .. 8", . . . , ¡: .; 2.· . . .. 'iaf2~J2â'Øfk '...... .: . 3F-ZO 1 99-079 36" NA NA 1 7.7 8/23/2006 jF-Z1 " --;\;, ...2QÓ~2Ö3 . 45" ' . . NA . NA .. I 31 . .812;1f2006 . Schlumbepgep Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth -. Well Job# Ii' !-ðY¡' 1A-01 JJ:J- 27C3F-09 i$ß-D~~; 3N-07 lc¡j"/ï D 1G-13 legS ~Z~~ 3F-06 /85-01(/2W-03 I CL- 2ì!~ - 3F-02 !, í/) - ~ If' / 1 E-114 L 1 ~o if - /1(1 10922488 10922490 10922491 10922487 10922489 10942791 10942790 10687709 -- Log Description Date NO. 3267 Company: 11/19/04 \f6" - ~L\;l\' Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL 1 1 1 1 1 1 1 sÇ;;)áJ jk~~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. LEAK DETECTION LOG PRODUCTION PROFILE PRODUCTION PROFILE LEAK DETECTION LOG PRODUCTION PROFILE LEAK DETECTION LOG PROD PROFILE/DEFT USIT 11108/04 11/10/04 11//11/04 11/07/04 11109/04 10/30/04 10/29/04 10107/04 SCANNED APR ~~_ 5 2005 Color CD DATE: /~ jo cf RE: OOA Cement Top-offs Subject: RE: OOA Cement Top-ofTs From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Mon, 27 Sep 200416:45:56 -0800 To: Thomas Maunder <tom - maunder@admin.state.ak.us> rð~~ (tP Tom, There is a couple reasons for the excess cement. The depth is calculated by a string, so if that hangs up on any debris in the OOA, it may give us a false depth. Also since there is no way to circulate, your right, we rely on the hose to fill up the OOA. We just wanted to make sure we had enough cement to fill to surface. Brad Gathman Problem Well Supervisor 907-659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom Sent: Monday, September 27,2004 To: NSK Problem Well Supv Subject: OOA Cement Top-offs maunder@admin.state.ak.us] 9:44 AM MJ and Brad, I was looking at the packet recently sent on the 6 wells that had the OOAs topped-off. It appears that the pumped volumes varied anywhere from 1.3 to 2.2 times calculated. Was XS cement circulated to assure that the OOA was full?? That would seem prudent, since it may not have been possible to get the hose all the way down. Thanks in advance for your reply. Tom Maunder, PE AOGCC <-~~~ -...Ja \ ~~íè d-C:>-C) d \\ ~ i- ~C\ ~Q- d~-~'-\. \ Sß-OC:::> .~ \=- - o(ò ;~-O,\ ?,\.\- 0 ~ \ \ 0 \ \. ¥ d'd \" '1 \ ~~ lofl 10/1120048:28 AM , . .) ConocJP'hiiii ps Alaska ~) P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 lC6 t)/ ~ September 15, 2004 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 RECEIVED SEP 1 7 2004 Alaska Oil & Gas Cons. Commission Anchorage Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from theJ~ì.ì.@aíWlk and Tam fields. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the circulation ports in the conductor, or in some cases holes were cut in the conductor to facilitate fill-up. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The top-fill operation was completed on September 14, 2004. Dowell-Schlumberger batch- mixed Arctic Set I cement to 15.8 ppg in a blender tub. The cement was placed in the conductor from the bottom-up via a hose ran to the bottom of the void. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volume used on each conductor. Note that in most cases these wells<4ave been previously reported as having surface casing leaks and have either been repaired by ~xtavation and patching or injection of sealant material. Please call Marie McConnell or me at 907-659-7224, if you have any questions. Sincerely, ~~ ~/C ~ Jerry Dethlefs ConocoPhillips Problem Well Supervisor SCANNED NO\! 1 5 2004 Attachment WELL NAME 2G-02 2N-341 38-06 3F-06 3F-09 3H-05 PTD# 1841210 1981030 1850760 1852440 1852700 1870770 ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off Kuparuk and Tarn Fields September 14, 2004 SERVICE CEMENT TOP VOLUME REASON TYPE ft Bbls .. Producer 82 14.5 SC leak @ 32' previously sealant repaired ~ Producer 3 0.5 Wobbly tree Producer 8 2 Post SC leak patch repair; Sundry 304-225 Producer 40 11.8 SC leak @ 64' previously sealant repaired Producer 17 3.9 SC leak @ 24' previously sealant repaired Producer 8 2 Post SC leak patch repair; Sundry 304-228 All cement pumped is Arctic Set I 15.8 PPG Cement This report is submitted in substitution for Sundry 10-404, Report of Sundry Operations NSK Problem Well Supervisor ". --/ SCANNED NO\f 1 5 2004 M, r 0 Se KRU 3F -06 Inc. C onocoPhillips Alaska, OA' 3F -06 API: 1500292146200 Well Type: PROD Angle @ TS: 39 deg @ 7089 TUBING - SSSV Type: LOCKED OUT Orig 10/28/1985 Angle @ TD: 36 deg @ 7721 (0 Completion: 00:2.902) Last W /O: Rev Reason: Set Panex off 0:2.992) - — �� A nnular Fluid: as Capillary Tube Reference Log: Ref Log Date: Last Update: 7/22/2004 Last Tag: 7419 TD: 7721 ftKB ` Last Tag Date: 6/10/2004 Max Hole Angle: 44 deg 0-h 6200 J Casing String - ALL STRINGS Description CONDUCTOR SUR. CASING Size Top Bottom ND Wt Grade Thread 16.000 0 115 115 62.50 H -40 9.625 0 3384 3047 36.00 J-55 PROD. CASING 7.000 0 7701 6300 26.00 J -55 Tubing String - TUBING Size Top Bottom ND Wt Grade Thread 3.500 0 7223 5921 9.30 J-55 8RD EUE 2.875 7223 7257 5947 6.50 J -55 8RD EUE Perforations Summary Interval TVD Zone Status Ft SPF Date Type Comment 7090 - 7160 5818 - 5872 t,C- 3,C -1,U1 70 12 12/6/1985 IPERF 90 deg. ph; 5" HJ II Csg B Gun ' I 7289 - 7326 5972 - 6001 A -4,A -3 37 4 12/6/1985 IPERF 90 deg. ph; 4" HJ II Csg Gun 7344 - 7384 6015 - 6046 A -2 40 4 12/6/1985 IPERF 90 deg. ph; 4" HJ II Csg Gun I Gas Lift MandreisNalves St MD ND Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Mfr Run Cmnt i ll 1 2391 2314 Camco KBUG CAMCO DMY 1.0 BK 0.000 0 1/17/1999 I 2 3886 3416 Camco KBUG CAMCO DMY 1.0 BK 0.000 0 1/17/1999 3 4495 3867 Camco KBUG CAMCO DMY 1.0 BK 0.000 0 1/17/1999 4 4903 4175 Camco KBUG CAMCO DMY 1.0 BK 0.000 0 12/6/1985 5 5309 4485 Camco KBUG CAMCO DMY 1.0 BK 0.000 0 12/6/1985 6 5742 4820 Camco KBUG CAMCO DMY 1.0 BK 0.000 0 12/6/1985 7 6174 5140 Camco KBUG CAMCO DMY 1.0 BK 0.000 0 2/14/1998 8 6606 5453 Camco KBUG CAMCO DMY 1.0 BK 0.000 0 12/6/1985 9 6979 5732 Merla TPDX CAMCO DMY 1.5 RM 0.000 0 6/10/2004 Production MandreisNalves St MD ND Man Man Type V Mfr V Type V OD Latch Port TRO Date Viv Mfr Run , Cmnt 10 7081 5811 Camco KBUG DMY 1.0 BK 0.000 0 1/15/1988 Closed Other (plugs, equip., etc.) - JEWELRY Depth ND Type Description ID 1845 1836 SSSV Camco'TRDP -IA -SSA' (Locked Out 3/19/86) 2.813 7029 5771 PBR Baker 3.000 7043 5782 PKR Baker'FHL' 3.000 7176 5884 SLEEVE -O AVA; Set 2.75" BPI sleeve w /four 1/4" ports, set 5/16/2003 - OPEN 2.313 7176 5884 NIP AVA, BPL LANDING NIPPLE 2.750 7235 5930 PKR Baker'FB -1' 4.000 III 7250 5942 NIP Camco 'D' Nipple NO GO 2.250 7257 5947 TTL 2.438 7257 5947 SOS Camco 2.438 General Notes - Date Note Perf - 2/2/1998 TRASH BESIDE DMY VALVE (a) 7081' -7082' (7090-7160) - 1/17/1999 Loaded 7" casing w/185 bbls of diesel 5/28/2003 WAIVERED WELL: IA x OA COMMUNICATION OA x ATMOSPHERE COMMUNICATION - SURFACE CASING LEAK REPAIRED WITH SEALANT. 7/12/2004 1/4" CAPILLARY TUBE INSTALLED FROM SURFACE TO 7257' CTMD. PANEX GUAGE HUNG OFF ril - BOTTM OF CAPILLARY TUBE. TUBING (7223 -7257, OD:2.875, ID:2.441) ' SCANNED NOV 1 5 2004 Perf (7289 -7326) Perf (7344 -7384) ConocoPhillips Alaska, Inc. 3F-06 (PTD 1852440) Surface Casing Leak Repair ~~-(~" SealTite Sealant 5~24~2003 MITOA- passed (Post SeaI-Tite treatment OA). T/I/O-180/350/1200. Pressure up OA to 1800 ~si with diesel, T/I/O-180/400/1800, start MITOA, 15 minute reading-T/l/O=180/400/1800, 30 minute reading- T/1/O-180/400/1800. Bleed OA down, final T/1/O-180/350/550 5/22/2003 OA Seal-Tite treatment. (OA x OOA ANN-COMM repair). T/IlO = 200/350/0. Initial OA FL @ surface with Seal-Tite pad from previous day. Pumped 1.24 bbls or 52 gallons of SeaI-Tite seal ~roduct to pressure OA up to 2000 psi. Monitored pressure for 45 minutes with no significant loss in pressure of fluid returns out of Conductor pipe. Bled OA back down to 800 psi, then :repressured with a diesel cap to 1220 psi. Final pressures; 200/350/1220. 5/21/2003 LLR OA x OOA of .75 gpm @ 2000 psi, .55 gpm @ 1000 psi. T/IlO = 200/350/50. Initial IA FL @ 74'. Pumped 3.5 bbls of diesel down OA to pressure up to 2000 psi. Maintained pressure for 10 minutes establishing leak rate of .75 gpm @ 2000 psi. Allowed pressure to fall off to 1000 psi, maintained for 10 minutes and estabished leak fate of .55 gpm @ 1000 psi. Purged OA with 3 bottles of N2 taking returns out of Conductor pipe until N2 to surface. Strapped OA FL depth @ 64' post purge. Loaded OA with 2+ bbls of Seal-Tite pre-treatment gel, prepped for treatment in the A.M. . Kuparuk Surface Casing Leak Repairs Subject: Kuparuk Surface Casing Leak Repairs Date: Sun, 25 May 2003 15:26:00 -0800 From: "Jerry C Dethlefs" <Jerry. C.Dethlefs@conocophillips.com> To: tom_maunder@admin.state.ak.us CC: "n1617" <n1617@conocophillips.com> Tom: It appears we have sealed up a couple of our Kuparuk surface casing leaks, at least temporarily. Attached are log entries for 2E-14 and 3F-06 SealTite treatments. The wells are on line and will remain on line unless the repairs break down. Pretty spendy operation, but I hope it ends up to be worth it. Drop me a line if you have any questions.(See attached file: 2E-14 SealTite Job Log 05-25-03.xls)(See attached file: 3F-06 SealTite Job Log 05-25-03.xls) Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska [~2E-14 SealTite Job Loq 05-25-03.xls Name: 2E-14 SealTite Job Log 05-25-03.xls Type: EXCEL File (application/msexcel) Encoding: base64 Name: 3F-06 SealTite Job Log 05-25-03.xls! i ['~3F-06 SealTite Job Lo,q 05-25-03.xls Type: EXCEL File (application/msexcel) i i Encoding; base64 1 of ~C~~,,~' J~¥ ~ 7 2003 5/27/2003 7:35 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 39' FNL, 48' FWL, Sec. 29, T12N, R9E, UM At top of productive interval 824' FSL, 1870' FEL, Sec. 20, T12N, R9E, UM At effective depth 905' FSL, 1557' FEL, Sec. 20, T12N, R9E, UM At total depth 919' FSL, 1495' FEL, Sec. 20, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7717 6312 6. Datum elevation (DF or KB) RKB 93 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3F-06 9. Permit number/approval number 85-244 10. APl number 50-103-21462-00 11. Field/Pool Kuparuk River Field/Oil Pool fe et et Plugs (measured) None Effective depth: measured 7 61 1 true vertical 6227 feet feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 322 Sx AS II 865 Sx PF E & 335 Sx PFC 325 Sx Class G & 175 Sx PFC 80' 16" 3347' 9-5/8" 7666' 7" measured 7090'-7160',7289'-7326',7344'-7384' true vertical 5837'-5919',5846'-5878',6036'-6055' Tubing (size, grade, and measured depth) 3.'5", 9.3#/ft., J-55 Measureddepth 115' 3384' 7701' @ 7179', & 2.875", 6.5#/ft., J-55 @ 7179'-7213' True vertical depth 115' 3046' 6299' RECEIVED D[C 22 1997 Packers and SSSV (type and measured depth) ~8.S~Dii & Gas Cofls. Comaissioll Packers: Baker FHL @ 7000~ Baker FB-1 @ 7192'; SSSV: Camco TRDP-1A-SSA @ 1845Anchorage 13. Stimulation or cement squeeze summary Fracture stimulate 'A' Sands on 7/5/97. Intervals treated (measured) ORIGINAL 7289'-7326' ,7344'-7384' Treatment description including volumes used and final pressure Pumped 182.9 Mlbs of 20/40 and 12/18 ceramic proppant into formation, fl:) was 5000 psi 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3 8 7 313 318 1043 173 Subsequent to operation 617 679 643 1057 193 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed , Title Wells Superintendent Form ~'0-404 Rev 06/15/88 ,~ ' Date SUBMIT IN DUPLICATE AR'CO Alaska, Inc. i )KUPARUK RIVER UNIT ~' WELL SERVICE REPORT '~' K1(3F-06(W4-6)) 'WELl' JOB SCOPE JOB NUMBER 3F-06 FRAC, FRAC SUPPORT 0606970441.2 , DATE DAILY WORK UNIT NUMBER 07/05/97; "A" SAND REFRAC , , DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 5 (~ Yes. O NoI (~) Yes O No DS-YOAKUM CHANEY "' FIELD AFC# CC.,~ DALLY COST ACCUM COST Signed' ..? .... ESTIMATE KDl159 230DS36FL $1 18,463 $137,816 (.~.././ Initial Tb.cl Press Final Tb.q press Initial Inner Ann Final Inner Ann ,Initial outer Ann' ,-Final Outer Ann 900 PSI 1500 PSI 600 PSI 500 PSII 900 PSII 200 PSI DAILY SUMMARY "A" SAND REFRAC COMPLETED THRU FLUSH. INJECTED 182924 LBS OF PROP IN THE FORMATION W/12# PPA OF #12/18 @ THE PERF'S. FREEZE PROTECTED TBG W/20 BBLS OF DIESEL. MAXIMUM PRESSURE 7200 PSI & F.G. @ (.79). TIME 06:30 08:00 09:20 10:20 LOG ENTRY MIRU DOWELL FRAC, APC PUMP TRUCK, & APC VAC TRUCK. HELD SAFETY MEETING (15 ON LOCATION). PT'D BACKSIDE LINES TO 4000 PSI AND RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 9200 PSI. PUMP BREAKDOWN W/50# DELAYED XL .C-.W @ C0 TO 15 BPM. VOLUME PUMPED 283 BBLS. USED 2833 LBS OF #20/40 PROP. MAXIMUM PRESSURE 7100 ~ A"'~,~'.:~ ~' ~'~ ~" .,~.,~ c.,.,~ ..... .~ PRESSURE 3100 PSI. S/D AND OBTAINED ISIP OF 2073 PSI W/F.G. OF (.79). MONITORED WHTP AND PULSED TO DETERMINE CLOSURE: PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. VOLUME PUMPED 177 BBLS. MAXIMUM PRESSURE 4400 PSI AND ENDING PRESSURE 3400 PSI. S/D AND OBTAINED ISIP OF 2279 PSI W/F.G. OF (.82). STOOD-BY AND MONITORED WHTP FOR CLOSURE. PUMP FRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. COMPLETED THRU FLUSH. S/D AND MONITORED WHTP FOR 5 MINS. VOLUME PUMPED 1401 BBLS. MAXIMUM PRESSURE 5000 PSI AND ENDING PRESSURE 3700 PSI. PUMPED 183884 LBS OF PROP (13500 LBS OF #20/40 & 170384 LBS OF #12/18) INJECTED 182924 LBS OF PROP IN THE FORMATION W/12# PPA OF #12/18 @ THE PERF'S. LEFT 960 LBS OF PROP IN THE WELLBORE. FREEZE PROTECTED TBG W/20 BBLS OF DIESEL. 12:00 STARTED R/D. DEPRESSURE INNER CSG TO 500 PSI AND R/D APC PUMP TRK. 12:30 13:30 REMOVED TREESAVER (ALL CUPS RETURNED). R/D COMPLETE AND DOWELL LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $665.00 APC ~6,600.00 $8,100.00 ARCO $0.00 $200.00 DIESEL $250.00 $250.00 DOWELL $111,613.00 $116,813.00 HALLIBURTON $0.00 $6,208.00 LI'I-I'LE RED $0.00 $5,580.00 TOTAL FIELD ESTIMATE $118,463.00 $137,816.00 STATE OFALASKA ) 0 ~ l'~ J~ j~ l. ,. ,. ,. ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Stimulate ;~ Plugging Perforate _ Pull tubing Alter casing Repair well Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X ARCO Alaska. Inc. Exploratory _ 93' RKI~ feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 39' FNL, 48' FWL, Sec. 29, T12N, R9E, UM 3F-06 At top of productive interval 9. Permit number/approval number 824' FSL, 1870' FEL, Sec. 20, T12N, R9E, UM 85-244 At effective depth 10. APl number 902' FSL, 1562' FEL, Sec.20, T12N,. R9E, UM so-029-2146~ At total depth 11. Field/Pool 919' FSL, 1495' FEL~ Sec. 20, T12N, R9E, UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 771 7' feet Plugs (measured) true vertical 631 2' feet None Effective depth: measured 7611 ' feet Junk (measured) true vertical 622 7' feet None Casing Length Size Cemented Measured depth True vertical depth Stru ctu ral Conductor 8 2' 1 6" 322 Sx AS II 1 1 5' 1 1 5' Surface 3 3 5 1 ' 9 5/8" 865 Sx PF E & 3 3 8 4 3 0 4 6' Intermediate 335 Sx PFC Production 7 6 6 8' 7" 325 Sx Class G & 7 7 01' 6 2 9 9' Liner 175Sx PFC Perforation depth: measured 7090'-71 60', 7289'-7326', 7344'-7384' true vertical 581 7'-5871', 5971 '-6000', 6014'-6045' Tubing (size, grade, and measured depth) 3 1/2" J-55 W/ tbg tail at 7213' Packers and SSSV (type and measured depth) Baker FHL @ 7000', Baker FB-1 @ 7192', Camco SSSV @ 1845' SF'P ~ ? 13. Stimulation or cement squeeze summary Alaska 011 & Gas Cons. (;0mmisst~n Intervals treated (measured) Anchorage ' 7289'-7384' Treatment description including volumes used and final' pressure See attached 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - 1 0 0 0 - - 4 0 0 - 4600 1 200 22 0 Subsequent to operation - 1 3 0 0 - - 6 0 0 - 0 11 50 1 5 0 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Water Injector __ Daily Report of Well Operations X Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~ ./~~ ,~. ~ Title 4::~'~~' ~)~~rt/~ ~1.,~ Date Fnrrn 1 f~.z~z FlAy 13.q/lP/fill RI IRMIT IN 1311Pl lC, AT[: ARCO Alaska, Inr ~ Subsidiary of Atlantic Richfield Compaf,, .WELl. ,- ?ONTRACTOR REMARKS WELL SERVICE REPOR IPBDT FIELD- DISTRICT-STATE opERATiO~N ~ (.L AT REPORT TIME ~.O,~? I ~+~ . IDAYS l DATE I 7/zo/. I ' SEP' 2 ? 0~t Alaska 011 & (~as (~0ns, ~,ummi$ste' An~rtorage ~ I'"] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO Alaska, Inc. Date: February 17, 1989 Transmittal #: 7429 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3F-11 3H-12 30-07 3F-10 3F-06 3F-02 3F-16 3F-16 3F-11 3F-04 3F-05 3F-13 3N-10 3N-10 3N-04 3N-09 30-14 30-14 3M-18 3F-16 3F-13 3F-13 3F-13 3F-13 3F-08 3F-16 3F-16 3F-13 3F-16 3F-16 3F-16 3F-14 Sub-Surface Pressure Survey Kuparuk Well Pressure Report Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuapruk Ku )aruk Ku )aruk Ku ~aruk Ku,~aruk Ku ~aruk Ku ~aruk Ku~aruk Ku ~aruk Ku~aruk Ku3aruk Ku~aruk Ku~aruk Ku:)aruk Ku )aruk Ku )aruk Ku ~aruk Well Well Well Well Well Well Well Well Well Well Well Well Well Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Pressure Report Pressure Report Pressure Report Pressure Report Pressure Report Pressure Report Pressure Report Pressure Report Pressure Report Pressure Report Pressure Report Pressure Report Pressure Report Level Re Level Re Level Re Level Re Level Re Level Re Level Re Level Re, Level Re Level Re Level Re Level Re Level Re Level Re Level Re Level Re Level Re )ort )oft )ort )ort )ort )ort )ort ~ort ~ort ~ort ~ort 2ort 2ort :)ort 2ort 3ort )ort 10-06-88 8-29-88 12-20-88 8-29-87 8-29-87 8-29-89 8-17-87 8-17-87 8-29-87 6-26-87 12-12-88 12-31-88 6-11-87 6-11-87 9-01 -87 5-04-87 2-13-89 2-10-89 2-10-89 6-05-87 6-09-87 6-18-87 6-16-87 6-21 -87 5-08-87 8-18-87 8-24-87 6-05-87 6-2/3-87 8-5-87 6-5-87 9-8-87 #7-889 Amerada Sand 'A' Amerada Amerada Amerada Sand 'A' Sand 'A' Amerada Sand 'A' Both Sands Both Sands Sand 'A' Casing Casing Casing Casing Tubing Casing Casing Casin( Casin~ Casincj Cas~ Casinc. Tubing Casing Casing & Gas Cons. Anchorage 3 F- 1 4 Kuparuk Fluid Level Report 9 - 1 1 - 8 7 3 F - 0 6 Kuparuk Fluid Level Report 1 2 - 0 6 - 8 6 3 F- 1 4 Kuparuk Fluid Level Report 9 - 1 I - 8 7 3 F - 0 8 Kuparuk Fluid Level Report 1 0 - 1 1 - 8 7 3 F- 1 4 Kuparuk Fluid Level Report 9 - 1 6 - 8 7 3 F - 0 9 Kuparuk Fluid Level Report 4 - 1 1 - 8 8 3 F - 0 5 Kuparuk Fluid Level Report 4 - 0 8 - 8 8 3 F - 0 9 Kuparuk Fluid Leyel Report 4 - 0 1 - 8 8 3 F - 0 6 Kuparuk Fluid Level Report 3- 2 6 - 8 8 3 F - 0 5 Kuparuk Fluid Level Report 1 - 3 0 - 8 8 3 N - 1 0 Kuparuk Fluid Level Report 1 0 - 1 2 - 8 7 3 N - 1 0 Kuparuk Fluid Level Report 1 0 - 1 5 - 8 7 3 N - 1 1 Kuparuk Fluid Level Report I 0 - 2 8 - 8 7 3 N - 1 0 Kuparuk Fluid Level Report 1 0 - 2 8 - 8 7 3 N - 0 5 Kuparuk Fluid Level Report I 0 - 2 8 - 8 7 3 N - 0 4 Kuparuk Fluid Level Report 1 0- 2 8 - 8 7 3 N - 1 3 Kuparuk Fluid Level Report 3- 1 9 - 8 7 3 N - 1 1 Kuparuk Fluid Level Report 9- 1 2 - 8 7 3 N - 1 8 Kuparuk Fluid Level Report 9 - 1 0 - 9 8 3 N - 1 7 Kuparuk Fluid Level Report 9 - 1 0 - 8 7 3 N - 0 7 Kuparuk Fluid Level Report 9- 1 0 - 8 7 3 N - 1 5 Kuparuk Fluid Level Report 9- 1 2 - 8 7 3 N - 0 5 Kuparuk Fluid Level Report 9 - 0 8 - 8 7 3 N - 0 9 Kuparuk Fluid Level Report 9 - 0 1 - 8 7 3 N - 0 4 Kuparuk Fluid Level Report 9 - 0 1 - 8 7 3 N - 1 4 Kuparuk Fluid Level Report 9 - 0 6 - 8 7 3 N - 0 8 Kuparuk Fluid Level Report 9 - 0 6 - 8 7 3 N - 0 6 Kuparuk Fluid Level Report 9 - 0 6 - 8 7 3 N - 0 2 Kuparuk Fluid Level Report 9 - 0 6 - 8 7 3 N - 1 0 Kuparuk Fluid Level Report 6- 0 1 - 8 7 3 N - 1 0 Kuparuk Fluid Level Report 5 - 3 1 - 8 7 3 N - 1 0 Kuparuk Fluid Level Report 6 - 0 3 - 8 7 3 N - 1 0 Kuparuk. Fluid Level Report 6 - 0 6 - 8 7 3N - 1 0 Kuparuk Fluid Level Report .6 - 0 8 - 8 7 3 N - 1 0 Kuparuk Fluid Level Report 6 - 0 9 - 8 7 3 N - 1 0 Kuparuk Fluid Level Report 6 - 2 5 - 8 7 3 N - 0 7 Kuparuk Fluid Level Report 4 - 1 7 - 8 7 3 N - 01 Kuparuk Fluid Level Report 4 - 1 8 - 8 7 3 N - 0 4 Kuparuk Fluid Level Report 6 - 1 7 - 8 7 3 N - 0 4 Kuparuk Fluid Level Report 6 - 2 0 - 8 7 3 N - 0 9 Kuparuk Fluid Level Report 5 - 0 7 - 8 7 3 N - 1 0 Kuparuk Fluid Level Report 8 - 2 4 - 8 7 Receipt Acknowledged: Casing Tubing Casing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing ........................... D at e' Alaska Oil & G3s Conj. Ccmmissjoi., DISTRIBi.R'IQN; D&M State of Alaska - Mobil Chevron Unocal SAPC ARCO Alaska, Inc. Date: February 23, 1989 Transmittal #: 7432 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3F-15 3N-18 3F-01 3F-02 3F-09 3F-06 3F-10 3F-11 3F-15 3F-14 3N-10 3N-06 3N-09 31-01 3N-11 3N-14 3F-08 3N-01 3N-14 3F-15 3F-15 3F-13 3F-15 1B-05 1E-25 3B-11 3A-03 3H-01 2Z-19 31-12 1E-08 3M-18 Kupaurk Kupaurk Ku 3aurk Ku )aurk Ku 3aurk Ku 3aurk Ku 3aurk Ku 3aurk Ku 3aurk Ku 3aurk Ku3aurk Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Kuparuk Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Well Pressure Report Kuparuk Well Pressure Report Bottom-Hole Pressure Survey Kuapruk Well Pressure Report Kuparuk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report 12-03-87 12-18-87 8-29-87 8-29'87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 5-18-87 5-22-87 5-21-87 4-24-87 4-15-87 4-13-87 4-14-87 4-20-87 12-04-87 2-02-89 8-27-87 8-27-87 8-25-87 2-20-89 2-19-89 2-20-89 2-21-89 2-21-89 2-20-89 2-20-89 2-19-89 2-15-89 Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Sand 'C' Sand 'C' BHP Amerada Casing Casing Casing Casing Tubing Tubin. C; 3 H- 01 Kupaurk Fluid Level Report 2-15-89 Casing 3B-1 3 Kupaurk Fluid Level Report 2-17-89 Casing 1 F_.-29 Kupaurk Fluid Level Report 2-15-89 Casing 10-05 Kupaurk Fluid Level Report 2-18-89 Casing/Tubing 3M-1 7 Kupaurk Fluid Level Report 2-16-89 Casing 2 Z - 2 0 Kupaurk Fluid Level Report 2-18-89 Tubing 30-10 Kupaurk Fluid Level Report 2-16-89 Casing 31-1 2 Kupaurk Fluid Level Report 2-20-89 Tubing 3 H- 1 0 BHP Report 2-13-89 BHP Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: D&M State of Alaska SAPC Unocal Mobil Chevron ARCO Alaska. In~ r. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. return one signed copy of this transmittal. Final Prints: Schl: CET or CBL Logs: lA-7 12-03.85 Run #3 7585-8532 · lA-14 .12-05-S5 Run #1 4550-4850 1H-4 12-26-85 Run #2 6893-7466 1H-8 12-08-86 Run #3 7875-8368 1H-8 12-09-86 Run #4 7850-8450 lQ-9 01-28-85 Run #1 4898-6534 lQ-13 06-02-85 Run #1 5300-7621 2C-16 02-19-85 Run #1 7200-8294 2E-9 01-14-85. Run #1 6780-8052 2E-15 01-12-85 Run #1 3350-6874 2E-16 01-12-85 Run #1 4840-7578 2H-10 12-05-85 Run #1 6500-7863 3A-7 11-04-85 Run #1 5726-7164 3A-11 12-15-85 Run #1 5796-7206 3A-12 12-16-85 Run #1 6426-7768 3A-13 12-29-85 Run #2 5644-7482 3A-14 12-29-85 Run #2 5462-7744 3C-13 10-30-85 Run #1 7075-9474 3F-5 11-13-85 Run #1 6947-8647 3F-6 11-13-85 Run #1 4600-7570 3F-9 12-19-85 Run #1 6188-7490 3J-5 12-22-85 RUn #1 7000-8636 DATE 09-15-86 TRANSMITTAL # 5761 Please acknowledge receipt and One * of each Receipt Acknowledged: Vault*£-i lms Alaska Oil & Gas Cons. Commission Anchorage Date: NSK Files*bl ARCO Alaska, Inc. ~s · Subsidiary Of &llanticRichfieldComl:~afl¥ ALASKA~ AND GAS CONSERVATION C , ISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG , 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Op. erator 7. Permit Number ARCO Alaska, Inc. 85-244 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21462 4. Location of well at surface 9. Unit or Lease Name 39' FNL, 48' FWL, Sec.29, T12N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 824' FSL, 1870' FEL, Sec.20, T12N, R9E, UM 3F-6 At Total Depth 11. Field and Pool 919' FSL, 1495' FEL, Sec.20, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i I Pool 93' RKB ADL 25632 ALK 2565 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115. Water Depth, if offshore 116. No. of CompIetions 10/21/85 1 0/27/85 10/28/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7717'MD, 6312'TVD 7611 'MD, 6227'TVD YES~ NO []I 1845 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run D IL/GR/SP/SFL, FDC/CNL, Cal, GR/CCL/CET/Gauge ring, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i6:: 62.)~ Id-b~U 5urt 115' 24" 322 sx AS II 9'5/8" 36.0# J-55 Surf 3384' 12-1/4" 865 sx PF "E" & 335 sx F F "C" 7" 26.0# J-55 Surf 7701' 8-1/2" 325 sx Class G & 175 sx PF "C" 24. Perforations open to Production (MD+TVD of TOp and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7384' - 7344' 3-1/2" 7257' 7043' & 7235' 7316' - 7326' w/4 spf 7306' - 7289' 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7160' - 7090' w/12 spf N/A 27.N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~' Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE Form 10-407 * NOTE: Tubing was run and the well perforated 12/6/85. Rev. 7-1-80 CONTINUED ON REVERSE SIDE WC1/048 Submit in duplicate GEOLOGIC MA FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7088' 5816' N/A Base Kuparuk C 7161' 5872' Top Kuparuk A 7273' 5959' Base Kuparuk A 7436' 6087' 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ ~~ TitleA$$Ociat:e Engineer' Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Itcm 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27. Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 12, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3F-6 Dear Mr. Chatterton: Enclosed the Well question is an addendum to the 3F-6 Well History to include wi th Completion Report, dated 1/21/86. If you have any s, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L114 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichtieldCompany ADDENDUM WELL: 11/06/85 3F-6 Arctic Pak w/175 sx PF "C", followed by 59 bbls Arctic Pak. Log GR/CCL/CET/gage ring f/7576'-4600'. Rn GCT gyro f/PBTD-surf. Drilling ~Superintendent Date ARCO Alaska, Inc. / Post Office Box ,'~)0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 11, 1986 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 3F-6 Dear Mr. Chatterton' Enclosed is a copy of the 3F-6 Well Hi story to include wi th the Well Completion Report, dated 1/21/86. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L102 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Oil and Gas ComPany Well History - Initial Report- Daily InstructionS: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field Alaska lCounty, parish or borough North Slope Borough Lease or Unit ADL 25632 Title Drill Kuparuk River Auth. or W,O. no. AFE AK0446 State Alaska Well no. 3F-6 Doyon 9 AP1 50-029021462 Operator ARCO Alaska, Inc. Spudded or W.O. begun IDate ]Hour Spudded 10/21/85 Date and depth as of 8:00 a.m. 10/22/85 10/23/85 10/24/85 10/25/85 Complete record for each day reported 1200 hrs. 16" @ 115' 2256', (2141'), Navi-Drl Wt. 9.5, PV 20, YP 26, PH 9.0, WL 11.8, Sol 8 Accept ri~ @ 0900 hfs, 10/21/85. NU diverter sys. 1200 hfs, 10/21/85. Drl 12¼" hole to 1311' 2256'. 1300', Assumed vertical 1428', 3.1°, N86.25E, 1427 TVD, 3.39 VS, 1927', 22.2°, N77.25E, 1913 TVD, 107 VS, 2174', 29.8°, N72.25E, 2134 TVD, 217 VS, ]^Rco w.t Prior status if a W.O. 56.24% Spud well @ · Navi-Drl & surv to .23N, 3.45E 32N, 102E 61N, 208E 16" @ 115' 3392', (1136'), RIH w/9-5/8" csg Wt. 9.7, PV 16, YP 16, PH 9.0, WL 12.2, Sol 10 Drl & surv 12¼" hole to 3392', cond well & short trip to MW'DP, TOH f/csg. RU & rn 9-5/8"; hit bridge & packed off @ 2244'. Circ thru &cont rn'g csg. 2743', 43.3°, N74.25E, 2579 TVD, 569 VS, 159N, 546E 3061', 43.2°, N75.25E, 2811TVD, 787 VS, 217N, 756E 3347', 42.8°, N76.25E, 3020 TVD, 982 VS, 265N, 945E 9-5/8" @ 3384' 4267', (875'), Navi Drl Wt. 8.8, PV 5, YP 2, PH 9.5, WL 10.4, Sol 3 F±n RIH w/85 its 9-5/8", FS @ 3384t, FC @ 3298t. C±rc hole, Howco & cmt w/865 sx ?F "E", & 335 sx FF "C". 9±spl w/250 mud, bmp plus w/1500 ps±; ~loats held 0~. C;? @ 0952 hrs, 10-23-85. ~ d±~erter, ~U ~O?E & ~st. ?U ~HA, cmt, & FS, + 10' new hole. Rn shoe tst @ 12.7 EMW, chg o~er to ×C MWD, ?OO~. ~U b±t & ~ach ;~. AI~, dr1 & sur~ to 4267t. 3506', 42.5°, ~74.25E, 3137.5 ~VD, 1089.7 V$, ~292.5, E1049.7 4073t, 42.4°, ~76.25E, 3555.4 ~VD, 1472.8 VS, ~387.2, E1421.0 9-5/8" @ 3384' 5496', (1229'), POH w/bit Wt. 9.2, PV 7, YP 3, PH 9.5, WL 6.8, Sol 6 Navi-Drl & surv 8½" hole to 5496'. 4327', 42°, N75.25E, 3743.6 TVD, 1643.3 VS, 429.2N, 1586.4E 4639', 41.1°, N75.25E, 3977.1TVD, 1850.2 VS, 481.8N, 1786.5E 4955', 39.9°, N76.25E, 4217.3 TVD, 2055.4 VS, 532.4N, 1985.4E 5303', 39.2°, N75.25E, 4485.7 TVD, 2276.9 VS, 586.9N, 2200.2E The above is correct For form p-reparation and dlstrlb~lon, see Procedures Manual, Section I'0, Orllling, Pages 86 and 87. Date [ Title Drilling Superintendent ARCO Oil and Gas'Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold, "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available, District Alaska County or Parish Field Lease or Unit Kuparuk River Auth. or W.O. no. ITitle AFE AK0446 I Accounting cost center code State Alaska North Slope Borough Well no. ADL 25632 3F-6 Drill API 50-029021462 DoYon 9 Operator A,R.Co. W.I, ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Spudded 10/21/85 Date and depth Complete record for each day reported as of 8:00 a.m. I otal number of wells (active or inactive) on this est center prior to plugging and I bandonment of this well I our I Prtor status if a W.O. 1200 hrs. { 10/26/85 thru 10/28/85 10/29/85 9-5/8" @ 3384' 7717', (2221'), Chg rams to 7" Wt. 9.8+, PV 16, YP 11, PE 9.5, WL 4.8, Sol 10 RIH, Navi-Drl & surv 8½" hole to 7436', drl to 7717', 20 std short trip, circ hole cln, POOH. RU Schl, log DIL/GR/SP/SFL f/7715'-3384', FDC/CNL f/7715'-6750' & 5500'-4700', CAL f/7715'-3384'. WLTD = 7721'. RD Schl. RIH, circ hole cln, POH, LD DP. Chg rams to 7". 5642', 40.0°, N72.25E, 4746.9 TVD, 2492.9 VS, 647.4N, 2407.6E 5955', 41.9°, N74.25E, 4983.5 TVD, 2697.7 VS, 704.7N, 2604.3E 6459', 43.0°, N74.25E, 5348.5 TVD, 3045.3 VS, 799.0N, 2938.7E 6930', 44.4°, N74.25E, 5689.0 TVD, 3370.6 VS, 887.3N, 3251.9E 7376', 38.6°, N75.25E, 6044.3 TVD, 3642.2 VS, 958.6N, 3513.9E 7642', 35.75°, N79.25E, 6256.2 TVD, 3802.7 VS, 994.1N, 3670.7E 7" @ 7701' 7717' TD, 7611' PBTD, RR 9.8 Brine in csg Fin chg & tst FS @ 7701', FC @ 7611'. rams. RU & rn 177 its + marker jr, 7", 26#, J-55 BTC csg. Cmt w/150 sx C1 "G" w/l% CFR-2, 1.25% Halad 22A & 12% Gel & 175 sx C1 "G" w/.6% FDP-C344 + 1/4% HR-7. CIP @ 1943 hrs, 10/28/85. Bump plug. ND NU & tst tree to 3000 psi. RR @ 2400 hrs, 10/28/85. Old TD New TD PB Depth 7717' TD (10/27/85) Released rig Date K nd of rig 2400 hrs. 10/28/85 Rotary Classifications (oil, gas, etc,) I Type completion (single, dual, etc.) Oil ISingle Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no, Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature~,/~ ~ .~,~..~~ _/ I Date ITitle y- For form preparation and~istribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. Post Office Bc, x~.100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 10, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3F-6 Dear Mr. Chatterton- Enclosed is a copy of the 3F-6 Well History (completion details) to include with the Well Completion Report, dated 01/21/86. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU13/L77 Enclosure cc' 3F-6 Well File A!~ska O!i & Gas Con~. commissior~, ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District County or Parish State Alaska Alaska NOrth Slope Borough Field Lease or Unit I Well no. Kuparuk River ADL 25632 I 3F-6 Auth. or W.O. no. T tie AFE AK0448 Completion Nordic 1 Operator I A.R.Co. ARCO Alaska, Inc. Spudded or W.O. begun ~ Date Complete I 12/06/85 Date and depth as of 8:00 a.m. 12/07/85 thru 12/o9/85 Complete record for each day reported API 50-029-21462 W,I. 56.24% 12/5/85 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well I our ' I Prlor status if a W.O. ,2000 hrs. I 7" @ 7701' 7611' PBTD, Perf'g 9.9 ppg NaCl/NaBr Accept rig @ 2000 hfs, 12/5/85. RU Schl, perf w/4" gun, 4 SPF, 90° phasing f/7374'-7384', 7364'-7374', 7354'-7364', 7344'-7354', 7316'-7326' & 7306'-7299' & 7289'-7299'. Perf w/5" gun, 12 SPF f/7110'-7160'. 7" @ 7701' 7611' PBTD, RR Diesel Fin perf'g w/5" gun, 12 SPF, 120° phasing, f/7110'-7090'. Rn 6-1/8" gage ring/JB. RIH w/FB-1 pAr, set @ 7192' WLM, RD Schl. Rn 228 its, 3½", 9.3#, J-55 BTC csg w/SSSV @ 1845', FHL pAr @ 7043', FB-1 PAr @ 7235', "D" Nipple.@ 7250', TT @ 7257'. Tst tbg, set pAr, displ well to diesel, set BPV. RR @ 2115 hrs, 12/6/85. Old TD New TD 7611 ' ?B'~D Released rig Date 2115 hrs. Classifications (oil, gas, etc,) Oil Producing method ,Flowing Potential test data PB Depth Kind of rig 12/6/85 Type completion.~le, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production. Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature Date ITitle /J~ ~-~'Z~~ I //~Z~/F'~ Drilling Superintendent For form preparation ~nd distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Alaska, Inc. ~~ Post Office Box 100360 Anchorage, A~aska 99510-0360 Telephone 907 276 1215 January 20, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3F-6 Dear Mr. Chatterton' Enclosed are the 3F-6 Well Completion Report and gyroscopic survey. I have not yet received the Well History (completion details). When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU13/L14 Enclosures RECEIVED 2 ,k 1986 Alaska Oil & Gas 6ons. Oor~mission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA CI -)AND GAS CONSERVATION C~ 'i'ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-244 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21462 4. Location of well at surface , ',-'---------~,'~ ~. 9. Unit or Lease Name 39' FNL, 48' FWL, Sec.29, T12N, R9E, UN LOCATIONS Kuparuk River Unit VE~tFI,E]) , At Top Producing Interval ~.~ 10. Well Number 824' FSL, 1870' FEL, Sec.20, T12N, R9E, UM 'i'%~L ..........~ ~' 3F-6 At Total Depth J~~~ 11. Field and Pool 919' FSL, 1495' FEL, Sec.20, T12N, RgE, UM Kuparuk River Field 5. Elevation93, RKBin feet (indicate KB, DF, etc.) 6.ADLLease25632DesignationALKand2565Serial No. Kuparuk River 0i 1 Pool 12. Date Spudded 13.' Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 10/21/85 10/27/85 10/28/85*I N/A feet MSLI 1 , 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I'VD) 19. Directional Survey .20. Depth.where SSSV set I 21. Thickness of Permafrost 7717'MD, 6312'TVD 7611 'MD, 6227'TVD YES [~X NO [] 1845 feetMDI 1500' (Approx) 22. Type Electric or Other Logs Run D IL/GR/SP/SFL, FDC/CNL, Cal, GR/CCL/CET/Gauge ring, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEME.NTINGRECORD .AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" Conductor report not ¥~;t received. 9-5/8" 36.0# J-55 Surf 3384' 12-1/4" 865 sx PF "E" & 335 sx PF "C" 7" 26.0# J-55 Surf 7701' 8-1/2" 325 sx Class G & 175 s~ PF "C" , 24. Perforations .oPen to Production .(MD+TVD of Top and Bottom and 25. TUBING RECORD interrval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7384' - 7344' 3-1/2" 7257' 7043' & 7235' 7316' - 7326' .w/4 spf 7306' - 7289' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. :DEPTH INTERVAL (.MD) AMouNT& KIND OF MATERIAL USED 7160' - 7090' w/12 spf N/A .,, 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~l~ Flow Tubing Casing Pressure CALCULATED=1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE Alaska Oil & Gas Cons. Coamissio~ Form 10-407 * NOTE: Tubing was run and the well perforated 12/6/85. TEMP3/WC52 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ~ 30. ' GEOLOGIC MARKERS - 'FORMATION TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7088' 5816' N/A Base Kuparuk C 7161' 5872' Top Kuparuk A 7273' 5959' Base Kupar'uk A 7436' 6087' 31. LIST OF ATTACHMENTS Gyroscopic Surve), (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /(~~ ~ Title Associate EngineerDate INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt Water disposal, water supply for injection, observation, injection for in-situ combustion. item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". TEMP3/WC40a SUB. SURFACE DIRECTIONAL SURVEY r~UIDANCE [~ONTINUOU$ ['~OOL ARCO ALASKA INCORPORATED Company W~l N~lle 3F-6 (39' FNL, 48' FkrL, S29, T12N, R9E, UM) KUPARUK, NORTH SLOPE, ALASKA Fleld/t,~&tlon 71101 ii E C E iV ~ D 19-DECEMBER-85 SARBER/LESNIE GCT OIRECTI~NAL SURVEY SUSTOMER LISTINS FOR ARCD ALASKA~ INC. 3F-5 N2RTH SLgPE~AL~SKA SURVEY DATE: 1~, NOV 35 ~NGINEER: S~RBER/LESNIE M~TM30S 3~ CDMPUTATID~4 TO3L c3CAT!gN: TANS~NTi~L- INTLRPCLATISN: LiNeAR VERTICAL SECTI3N: qORiZ, DIST. AVERAGED PROJ=CTED DEVIATION AND AZIMUTH ONTO A TARGET AZIMUTH OF NORTH 74 DES 14 MIN EAST A2CO ALASKA, 3~-6 KJP~R~K NO~TH SLOPEtALASKA COMPUTATZONt 19-DEC-85 PAGE OATE OF SURVEY: 14 NDV 85 KELLY BUSHING ELEVATION: ENGINEER: SAREER/LESNIE 93.00 FT INTERPOL4TED VALUES FOR TRUE SUB-SEA HEASURE3 VERTICAL VERTICAL DEPTH DEPTH DEPTH 0.00 0.00 -93.00 100.00 100.00 7.00 200.00 200.00 107.00 300,00 300.00 207,00 400.00 400.03 307.00 500.00 500.30 407.00 500.30 600.00 507.00 700.00 700.00 607.30 800.03 799.99 706.99 900.00 899.99 806.99 lO00.OO 99'9.98 905.98 1100.00 1099.98 1006.98 1200.00 1199.98 1106.98 1300.00 1299.9~ 1206.9~ 1400.00 1399.95 1306.95 1500.00 1499.57 1405.57 1600.00 1598.92 1505.92 1700.00 1697.09 1604.09 1800.00 17'93.69 1700.69 1900.00 1888.24 1795.24 2000.00 1930.03 1537.03 2100.00 2059.02 1976.02 2200.00 2155.99 2052.99 2300.00 2239.82 2145.82 2400.00 2320.90 2227.90 2500.00 2399.10 2306.10 2600.00 2473.54 2380.54 2700.00 2546.36 2453.36 2300.00 2619.16 2526.16 2900.00 2692.10 2599.10 3000.00 2764.93 2571.93 3100.00 2837.~0 27~4.80 3200.00 2911.04 2~1~.04 3300.00 29~4.~1 2891.41 3~00.00 3058.11 2965.11 3500.00 3131.93 3038.93 3600.00 3205.44 3112.44 3700.00 3278.86 3185.86 3800.00 3352.34 3259.34 3900.00 3425.80 3332.80 COUR'SE DEVIATIDN ~ZIMUT~ ,D~G · 0 0 0 6 0 15 0 12 0 9 0 10 0 11 0 24 0 31 0 3'3 DEG MIN N 0 0_ S 37 44 S 74 27 E N 7'915 E S 61 48 E S 51 39 5 S 72 50 E S 79 44 E S 73 41 E S 60 27 .E 0 0 0 0 2 5 8 12 16 21 25 28 30 34 36 40 43 43 43 24 16 22 22 3O 43 55 55 7 18 35 51 17 20 i1 10 S 58 35 -Z S 57 4 ~ S 24 42~ = N 85 28 E N 71 41 E N 67 55 E N 68 26 ' N 75 50 E N 78 35 E N 76 3~ ~ N 7~ 35 E N 74 48 E N 76 12 E N 75 37 = N 74 58 ~ N 74 15 = N 74 25 ~ N 74 40 ~.. N 7~ 45 c 43 16 N 74 59 E 43 6 N 75 15 E 42 46 N 75 57~ = 42 45 N 76 15 E 42 18 N 75 52 ~ 42 36 N 15 52 5 42 46 N 76 9 5 42 ~3 N 7A 30 E 42 ~2 N 75 55 E 42 ~3 N 77 11 ~ EVeN 100 VERTIC4L SECTION F::T 0.00 0.04 0.21 0.62 0.89 1.07 1.28 1.76 2.47 3.22 3.82 4.22 4.49 4.45 6.08 13.36 25.38 44.23 69.94 102.39 141.91 187.49 236.82 291.26 349.76 412.05 478.81 547.35 615.89 58~.31 752.82 821.30 :'389.36 957.28 1024.82 1092.25 1160.02 1227.~6 1295.63 1363.39 FEET OF MEASURED DEPTH DOGLEG SEVERITY D~G/IO0 0.00 0.06 0.16 0.06 0.06 0.07 0.23 0.19 0.04 0.19 0.20 0.12 0.31 0.61 4.18 2.62 ~.63 3.92 4.47 4.32 3.90 1.98 3.81 2.96 3.16 3.37 1.12 0.19 0.35 0.27 0.24 0.50 0.57 0.38 0.45 0.21 0.40 0.43 0.25 0.11' RECTANGULAR COORO NORTH/SOUTH EAST/ FEET FEET 0.00 0.12 0.31 0.33 0.35 0.51 0.$5 0.7A 0.94 1.33 1.76 2.03 2.46 3.15 .3.42 1.80 2.50 9.77 17.51 N 24.43 N 3-2.82 N 44.25 N 57.44 N 70.91 N 85.07 N 101.09 N 118.69 N 137.23 N 155.46 N 173.~8 N 191.35 N 208.95 N 225.88 N 242.14 N 258.29 N 27~.77 N 291.21 N 307.23 N 322.80 N 337.97 N N 0.0 S 0.0 S 0.3 S 0.7 S 1.0 S 1.26 S 1.51 S 2.04 S 2.83 S 3.72 S 4.46 S 4.96 S 5.36 S 5.52 S 7.28 S 14,39 N 25.64 N 43.20 67.73 99.50 182.32 229.~7 282.63 339.41 39~.62 464.02 530.00 596.08 662.08 728.23 794.42 860.36 926.34 991.96 1057.38 1123.15 1189.12 1255.14 1321.27 INATES WEST 0 E 8 E 1 E 4 E 2 E E E E "Di~IZ. 'DEP~RTUMRE O! $1'~+,' ::' A Z I HUT FE~i.:F.!. DEG MIN 0; 0~::'i 0 0 : 0.~. S 32 0.~'4 $ 44 0.,80 :'S 65 1.08 S 71 1.36 S 67 1,65 S 66 2.18 S 69 2.98 S 71 3.95 S 70 4.80 S 68 5.36 S 67 5.90 S 65 6.36 S 60 8.05 S 64 14.50 S 82 25.78 N 84 4~.30 N 77 69.96 N 75 102.45 N 76 19 E 58 E 0 E 4 E 48 38 -,_~ 34 E 40 E 21 E 28 E 41 E 21 E 15 E 52 E 53 E 12 : 15 E 30 E 12 E 142.04 N 76 38 187.62 N 76 21 236.93 N 75 58 291.39 N 75 54 349.91 N 75 55 412.21 N 75 48 ~78.96 N 75 39 547.48 N 75 29 616.02 N 75 22 $~.43 N 75 i9 E E E E E E E 752.95 N 75 16 E 821.44 N 75 15 E 889.52 N 75 17 E 957.46 N 75 21 E 1025.04 N 75 24 E 1092.49 N 75 26 E 1160.29 N 75 27 E 1228.17 N 75 30 E 1295.99 N 75 34 E 1363.81 N 75 39 E ARCO ALASKA, INC. 3F-6 KUPARUK NORTH SLgPE,ALASKA C 3MPUTA T i 3N gAT:: 19-Der-85 PAGE DATE OF SURVEY: 14 NOV 85 KELLY BUSHING ;L:VATZON: ENGINEER: SARBER/LESNiE 93.00 FT TRUE ~EASURED VERTICAL DEPTH DEPTN iNTERPOLAT~O VALUES FOR SJB-SEA VERTIC~ OEPT , 4000.00 3499.32 3405.32 4100.00 3572.99 3479.99 4200.00 3646.59 3553.69 4300.00 3720.77 3627.77 ~400.00 3795.05 370£.05 4500.00 3369.57 3775.67 4600.00 3944.72 3851.72 4700.00 4020.07 3927.07 4800.00 4095.57 4002.57 4900.00 4171.53 4078.53 5000.00 4248.34 4155.34 5100.00 4324.92 ~231.'~2 5200.00 4400.92 4307.92 5300.00 4477.50 43~4.50 5400.00 4555.37 4462.37 5500.00 4633.74 4540.74 5500.00 4711.12 4618.12 5700.00 4787.72 4694.72 5800.00 4863.54 4770.64 5900.30 4939.08 ~845.08 6000.00 5013.35 4920.35 6100.00 5086.47 4993.47 6200.00 5157.59 5064.69 6300.09 5229.29 5136.29 6400.00 5301.58 5208.58 6500.00 5374.54 5281.54 6600.00 5~47.90 535~.90 6700.00 5521.76 5428.76 6800.00 5596.14 5503.14 6900.00 5671.59 5578.59 700O.OO 5747.97 5554.87 7100.00 5825.07 5732.07 7200.00 5902.53 5809.53 7300.00 5980.18 5887.18 7400.00 6058.26 5965.26 7500.00 6137.51 5044.61 7600.00 5218.04 6125.04 7700.00 6298.50 5205.50 7717.00 6312.18 6219.18 COUR'SE DEVIATION AZIMUTq DEG MIN DEG M!N 42 35 N 77 Z1 42 32' N 77 26 42 17 N 77 25 42 5 N 76 21 41 51 N 76 il 41 35 N 76 20 41 12 N 76 30 41 2 N 76 43 40 52 N 77 4 40 '5 N 77 9 39 46 N 77 40 !8 N 76 40 29 N 75 39 14 N 75 38 ¢0 N 74 38 28 N 74 39 57 N 73 40 9 N 73 40 ~9 N 73 41 46 N 74 9 E 5 E 25 E I0 E 30 E 40 E 57 E 24 -Z ~1 59 N 74 44 19 N 75 44 24 N 75 44 4 N 75 43 24 N 74 42 59 N 74 42 35' N 74 42 14 N 7~ 41 30 N 74 40 33 N 74 52 E 1T E 12 E 7 E 55 E 50 E 51 E 3~ E '~5 E 55 E 39 52 N 75 39 19 N 75 39 14 N 75 38 47 N 75 38 21 N 75 36 44 N 76 36 25 N 76 36 25 M 76 36 25 N 76 2 37 13 13 11 11 26 26 25 EVEN 100 VERTICAL SECTION FEET IC31.09 1498.61 1566.08 1633.18 1700.08 1756,62 1832.66 1898.34 1963.84 2028.68 2092.76 2155.99 2221.97 22~6.25 2348.98 2411.10 2474.43 2538.71 2603.79 266~.42 2736.37 2804.56 2874.75 2944.56 3013.64 3082.02 3149.97 321T.39 3284.23 3349.85 3414.51 3478,05 3541.28 36D4.29 3666.76 3727.59 3786.97 3846.31 3856.39 FEET OF MEASURE D DEPTH DOGLEG RECTANGULAR CO SEVERITY NORTH/SOUTH EA DEG/iO0 FEET F 0.22 352.86 N 138 0.24 367.63 N 145 0.52 382.26 N 1~1 0.46 397.48 N 1584.81 -0.52 413.42 N 1649.82 0.48 429.23 N 1714.49 0.33 444.77 N 1778.73 0.40 460.00 N 1842.68 0.32 ~74.88 N 1906.54 0.56 489.31 N 1969.84 0.73 503.59 N 2032.39 E 1.67 518.13 N 2095.03 E 0.39 534.36 N 2157.97 E 1.44 550.43 N 2220.22 E 0.52 566.79 N 2280.79 E 1.07 583.23 N 2340.69 E 1.10 600.~7 N 2401.63 E 0.88 618.96 N 2463.Z0 E 0.40 637.33 N 2525.64 E 2.37 655.26 N 2588.78 E . 0.86 57'2.93 N 2653.36 E 1.89 690.41 N 2719.28 E 0,50 708.28 N 2787.17 E 1.00 726.14 N 2854.65 E 0.87 744.00 N 2921.39 E 0.39 761.85 N 2987.~1 E 0.67 779.57 N 3053.02 E 0.48 797.30 N 3118.05 E 1.30 815.01 N 3182.52 E 0.78 832.19 N 3245.85 E 1.57 848.94 N 3308.31 E 0.29 865.11 N 3369.77 E 0.40 880.96 N 3431.00 ~ 0.22 897.12 N 3491.91 E 1.25 913.05 N 3552.32 E 2.19 928.24 N 3611.24 E 0.00 942.21 N 3669.00 E 0.00. 956.13 N 3726.73 E 0.00 958.49 N 3736.54 ORDINATES H~R]:~ ~:..~-D E P A R T U R E S T / W E S T O j~~%A Z I M U T E 3.40 E 14994, I.8':''N: 75 48 E 9.38 5 1566.72 N 75 52 ~ ~ 1633.89 N 75 55 ~ ~ 1700,83 N 75 55 E E 1767.%1- N 75 56 E 1833.49 N 75 57 ~ ~ 1899.23 N 75 59 E ~ 1964.79 N 7~ 0 ~ E Z029.T1 N 76 3 ~ 2093.85 N 76 5 E 2158.15 N 76 6 E 2223.14 N 76 5 E 2287.43 N 75 4 E 2350.16 N 76 2 E 2412.26 N 76 0 E 2~75.56 N 75 57 E 2539.78 N 75 53 E 2604.31 N 75 50 E 2670.42 N 75 47 E 2737.36 N 75 46 E 2~05.56 N 75 45 E 2875.75 N 75 44 E 2945.56 N 75 43 E 3014.65 N 75 42 E 3083.02 N 75 41 r 3150.98 N 75 40 ~,- 3218.39 M 75 39 E 3285.22 N 75 38 E 3350.84 N 7~ 37 E 3415.50 N 75 36 E 3479.05 N 75 36 E 3542.30 N 75 35 E 3505.31 N 75 35 E 3567.79 N 75 35 E 3728.63 N 75 35 E 378~.05 N 75 35 E 3847.42 N 75 36 E E 3857.52 N 75 36 E ARCC ALASKA, INC. 3~-6 KUPARUK NORTH SLOPE,ALASKA TRU~ MEASURE3 VERTICAL DEPTH DEPTH 0.00 0.00 1000.00 999.93 2000.00 1980.03 3000.00 2764.93 4000.00 3499.32 5000.00 4248.34 6000.00 5013.35 7000.00 5747.87 7717.00 6312.13 COMPUTATION INTERPOLATED VALUES FiR SUB-SEA COUR'S~ VERTICAL DEVIATION AZIMUTH DEPTH DEG MiN DES MIN -93.00 0 0 N 0 0 906.98 0 24 S 58 33 1887.03 25 18 N 76 34 2671.93 43 16 N 74 59 3406.32 42 35 N 77 21 ~155.34 39 ~6 N 77 9 ~92D.35 41 59 N 74 52 5654.37 39 52 N 75 2 6219.1~ 36 25 N 76 25 DATE: EVEN VERTIC S~CTI . 3. 141. 752. 1431. 2092. 2736. 3414. 3856. 19-DEC-85 PAGE D~TE OF SURVEY: 14 NOV 85 KELLY BUSHING ELEVATION:' ~NGINEER: SAR~ER/LESNIE 93.00 FT 1000 AL ON T FEET 3F MEASURED DEPT DOGLEG RECTANGULAR COOR SEVERITY NORTH/SOUTH E~ST/WEST OEG/IO0 FEET FEET OINATES HORIZ,-DEPARTURE 0.00 0.00 N . 0.00 E 0.20 1.76 S 4.45 E 3.90 32.82 N 138.20 E 0.24 191.35 N 728.23 E 0.22 352.86 N 1387.41 E 0.73 503.59 N 2032.39 E 0.85 672.93 N 2653.36 E 1.57 848.94 N 3308.31 E 0.00 958.49 N 3736.54 ~ PAGf: 4 ARCO ALASKA, INC· 3P-6 KUPARUK NORTH SLOPE,ALASKA TRUF ME4SURr-D VERTICAL O':PTH D6PTH 0.00 0.00 93.00 93.00 193.00 193.00 293.00 293.00 393.00 393.00 493.00 493.00 593.00 593.00 693.00 693.J0 793.01 793.00 293.01 893.00 993.02 993.00 1093.02 1093.00 1193.02 1193.00 1293.02 1293.00 1393.04 1393.00 1193.30 1493.00 1594.01 15'93.00 1695.81 1693.00 1799.27 1793.00 1905.13 1893.00 2014.36 1993.00 2127.39 2093.00 2243.58 2193.00 2355.37 2293.00 2491.99 2393.00 2626.67 2493.00 2764.09 2593.03 2901.24 2693.00 3038.55 2793.00 3175.41 2893.00 3311.70 2993.00 3447.17 3093.00 3583.05 3193.00 3719.26 3293.00 3855.35 3393.00 3991.42 3493.00 4127.17 3593.00 4262.56 3693.00 4397.24 3793.00 4531.15 3893.00 CO~IPUTATI3~ INTERPOLATED SUS-S~A COJRSE VERTICAL D'EVI~TION AZIMUTH DEPTH ~:EG MIN -93.00 0 0 0.00 0 6 100.00" 0 14 200.00 0 12 300.00 O- 9 400.00 0 10 500.00 0 10 600.00 0 23 700.00 0 31 SO0.00 0 34 900.00 0 25 1000.00 0 16 1100.00 0 22 1200.00 0 22 1300.00 2 23 1400.00 5 20 1500.00 8 27 1600.00 !Z 49 1700.00 16 54 1800.00 Z1 21 VALUES FOR DEG HIM N 0 0 S 37 3 S 70 24 N 78 55 S 63 34 S 51 59 S 71 3 S 8O 0 S 74 2 S 61 1 DATE: EVEN 1900.00 25 50 ZO00.O0 29 3 2100.00 32 ~4 2200.00 36 3 2300.00 40 0 2400.00 43 11 2500.00 43 14 2600.00 43 I0 2700.00 &3 15 2800.00 42 49 2900.00 42 ~2 3000.00 42 23 3100.00 42 ~4 3200.00 42 ~3 3300.00 42 ~3 3400.00 42 36 3500.00 42 34 3600.00 42 12 3700.00 41 52 ~800,00 41 25 VERTIC SECTI 19-DEC-85 100 ~EET OF AL DOGLEG ON SEV=RITY T DES/lO0 =_ 0.00 0.00 E 0.04 0.08 E 0.19 0.28 E 0.59 0.08 E 0.87 0.11 ; 1.06 0.05 E 1.26 0.11 5 1.71 0.23 E 2.42 0.02 E 3.17 0.13 3.78 0.17 {.19 0.07 4.48 0.30 4.45 0.54 5.78 12.72 2.67 24.50 4.51 43.30 3.94 69.73 4.47 104.28 4.40 148.05 4.01 200.71 1.60 259,80 4.47 329.26 1,60 406.86 3.27 497.05 0.58 591.29 0.12 685.16 0,29 779.24 0.13 872.66 0.57 S 59 35 ~- S 67 38 E S 27 40 E S 16 7 = N 87 37 ~: N T2 21 E N 67 49 E N 58 11E N 75 47 E N 7~ 33 E N 76 12 E N 74 26 E N 73 35 N 73 54 E N 74 57 E N 74 15 E N 74 36 E N 74 45 E N 75 5 t- N 75 4.8 E N 76 16 ; N 75 52 5 N 76 5 E N 76 35 E N 77 6 E N 77 21E N 77 29 E N 76 44 E N 76 I1 E N 75 21 E 965.21 0.29 1056.56 0.56 1148.51 0.43 1240.93 0.52 1333.14 0.24 1425.29 0.20 1516.96 0.19 160~.09 1.13 1698.24 0.50 1787.25 0.55 DATE OF SURVEY: 14 NOV 85 KELLY BUSHING ELEVATION: ENGINEER: SARBER/LESNIE 93.00 FT SUB-SEA DEPTH RECTANGULAR CDOR NORTH/SOUTH EAST. FEET FEE 0.00 N ,. O. 0.11 S . O. 0.30 S O. 0.33 S O. 0.34 S 1. 0.50 S 1. 0.65 S 1. '0.75 S 1. 0.92 S 2. 1.29 S 3. 1.73 S 4. 2.OZ S 4. 2.42 S 5. 3.11 S 5. 3.43 S 6. 1.99 S 13. 2.26 N 24. 9.42 N 42. 17.46 N 67. 24.80 N 10.~1 · 34.25 N i44. 47.80 N 195. 63.33 N 252. 80.04 N 319. 99.74 N 394. 123.65 N 481. 148.95 N 572. 173.70 N 662. 198.17 N 753. 221.80 N 844. 244.03 N 934. 266.06 N 1022. 288.44 N 1111. 310.28 N 1201. 331.23 N 1291. 351.59 N 1381. 371.61 N 1471. 391.50 N 1560. 412.98 N 1648. 434.10 N 1734. ~.i~ OEPARTUREE ~-.A Z I MUTH qDEG MIN ~ 42 56 E ?.. S 64 57 E 1.06J:~ S 71 1.3:4 S 68 3 1.62 S 66 33 2.13 S 69 22 E 2.92 S 71 37 E 3.88 S 70 31 E 42 E 4.75 S 68 34 E 93 E 5.32 S 67 40 E 34 E 5.86 S 65 38 E 50 E 6.32 S 60 32 E 98 = 7 77 S 63 48 E 78 E 13.93 S 81 46 E 81 E 24.92 N 84 47 E 3~ E 43.37 N 77 27 E 53 E 69.75 N 75 30 E 35 E 104.34 N 76 14 E 17 f 148.18 N 76 38 06 E 200.83 N 75 13 08 E 259.91 N 75 53 53 E 329.41 N 75 56 60 E 407.01 N 75 48 57 E 497.19 N 75 35 36 E 591.42 N 75 24 90 E 685.28 N 75 19 75 E 779.37 N 75 16 15 E 872.80 N 75 16 05 E 965.40 N 75 21 74 E 1056.79 N 75 25 97 E 1148.77 N 75 27 83 E 1241.24 N 75 31 74 E 1333.53 N 75 37 74 E 1425.77 N 75 43 34 E 1317.54 N 75 49 39 E 1608.78 N 75 54 03 E 1698.99 N 75 55 56 E 1788.05 N 75 56 E E E E E E E E E COMPUTAT!ON DATE: lg-0=C-85 PAGE 5 ARCO ALASKA, INC. 3~-6 KUP~RUK N2RTH SLOPEgAL~SKA DATE DF SURVEY: 14 NOV 85 KELLY BUSHING ELEVATION: ENGINEER: SARBER/LESNIE 93.00 FT ME&SURED 2EPTH 4564.08 4796.60 4927.90 5058.14 5189.59 5319.98 5448.09 5576.35 5706.90 5838.82 5972 6109 6249 6388 6525 6561 6795 6928 7058 7187 7316 7444 7568 7593 7717 .65 .1~ .35 .19 .Il .11 .82 .14 .51 .69 .44 .05 .88 .16 .00 INTERPOL&TE9 VALU=S FOR EVEN 100 FEET DF SUB-SEA COORSE DEVIATION AZIMUTH MIN DEG MIN TRUE VERTICAL VERTICAL 5 N 76 37 E 53 N 77 3 E 57 N 77 8 E 3 N 76 55 E 30 N 75 25 E Z1 N 74 39 E 47 N 73 58 E 11 N 7~ 15 ~ 50 N 74 5 E 3993.00 3900.00 41 4093.00 4000.00 40 4193.00 4100.00 39 4293.00 4200.00 40 4393.00 4300.00 40 4493.00 4400.00 39 4593.00 4500.00 38 4693.00 4600.00 39 4793.90 4700.00 40 4893.00 4800.00 40 4993.00 4900.00 ~1 5093.00 5000.00 44 5193.00 5100.00 44 5293.00 5200.00 43 5393.00 5300.00 42 5493.00 5~00.00 42 5593.00 5500.00 41 5693.00 5600.00 40 5793.00 5700.00 39 5893.00 5300.00 39 57 N 74 46 E 31 N 75 17 E 16 N 75 10 -: 29 N 74 58 E 53 N 74 50 E 21 N 7~ 44 E 33 N 74 44 E 23 N 74 57 F 24 N 75 18 E 12 N 75 1T E 59~3.00 5')00.00 33 50~3.00' ~000.00 37 6193.00 5100.00 35 6293.00 6200.00 36 5312.18 521~.18 36 45 N 75 15_ : 29 N 75 26 25 N 76 25 E 25 N 76 25 E 25 N 76 26 E VERTICAL DOGLEG SECTION SEVERITY FEET DEG/iO0 1874.76 0.35 1961.61 0.29 2046.60 0.45 2129.92 1.43 2215.21 0.32 2298.85 1.19 2378.93 0.62 2459.24 1.70 2543.14 1.08 2629.17 0.56 SUB-SEA RECTAN NORTH/ FEE 454. 474. 493. 511. 532. 553. 574. 596. 620. 644. 2718.11 0.49 668. 2810.96 1.20 592. ~'909 23 0.14 717. ~ m 3005.52 0.85 741. 3099.19 0.35 766. 3191.21 0.39 790. 32~1.47 1.44 814. 3368.10 0.47 836. 3451.75 0.89 858. 3533.50 0.43 878. 3514.59 0.22 899. 3693.83 1.88 919. 3768.51 0.00 937. 3842.25 0.00 955. 3856.39 O.OO 958. DEPTH GULAR C SOU'TM E T 55 N 1.8 38 N 19 30 N 19 85 N 20 66 N 21 69 N 22 67 N 23 23 N 23 24 N 24 30 N 25 13 N 26 03 N 27 11 N 28 90 N 29 34 N 30 38 N 30 29 N 31 92 N 32 54 N 33 9.7 N 34 74 N 3'5 94 N 35 87 N 36 18 N 37 49 N 37 68.68 E 51.43 E 32.40 E 09.68 E 87.05 E 67.45 E 50.05 E 35.73 E 25.47 E 20.50 E 13.56 E 03.98 E 92.82 E 79.85 E 63.48 E 44.29 E 23.47 E .. 01.~7 E 78.51 E 51.04 E 22.78 E 36.54 E 2131.06. ~ 76 6 E 2216.39":~N 76 5 E 2300,04 2380'10 N 76 1 2460.38 N 75 58 2544.21 N 75 53 E 2630.19 N 75 49 E 2719.10 N 75 46 E 2811.95 N 75 45 E 2910.23 N 75 44 E 3006.53 N 75 42 E 3100.19 N 75 41 E 3192.21 N 75 39 E 3282.46 N 75 38 E 3369.09 N 75 36 E 3452.74 N 75 36 E 3534.51 N ?5 36 E 3615.61 N 75 35 E 3694.86 N 75 34 E 3769.57 N 75 35 E 3~43.36 N 75 3'6 E 3857.52 N 75 36 E ARCO ALASKA, INC. 3F-6 NORTH SLOPE,AL~SK~ TOP BASE TOP BASE PBTD TD MARKER KUPARUK ~ KUP~RUK C KUP~RUK ~ KUPARUK A CD~PUTATIDN INT~RPOL&T"D_ ~ VALUCS~ FOR · MEASURED DEPTH 70~8.00 7161.00 7273,00 7436.00 7611.00 7717.00 DAT=: 19-D5C-85 ~MOSEN HORIZONS FROM KB 5815.79 5872.31 5959.14 6086.61 6226.89 6312.18 PAGE DATE DF SURVEY: 1~ NJV 85 KELLY BUSHING ELEVATION: ENGINEER: SARBER/LESNIE ORIGIN= 39' FNL, TVD S~B-SEA 5722.7g 5779.31 5866.14 5993.51 5133.89 6219.18 93.00 SURFACE FWL, SEC RECTANGU' NORTH/S 863.2 87~.7 892.8 918.7 943.7 958.4 L OCA..]'..I ON Air' 2g~:f!~T].::EN, RgE, OM 3UTH". 2 N ' 33:62.4.0 E 1 N ~407.16 E 0 N 3475.55 E 0 N 3573.78 E ~ N 3675.35 E 9 N 3735.54 E FT ARCO ALASKA, INC. 3F-6 KJPARJK NORTH SLOPE,ALASKA COMPUTATION~,mATE: 19-DEC-85 PAGE DATE OF SURVEY: 14 NDV 85 KELLY BUSHING ELEVATION: ENGINEER: SARBER/LESNIE 93.00 MARKER TOP KUP6RUK ~ SASE KUPARUK C TOP KUPARUK ~ BASE KUPARUK A PBTD TD FINAL MEASURED DEPTH 7717.00 ORIGIN= 39' FNL~ -BELOW K5 FROM KB SUB-SEA 7088.00 5815.79 5722.79 7151.00 5872.31- 5779.31 7273.00 5959.14 5856.14 7436.00 50~6.51 5993.61 7611.00 5226.89 6133.89 7717.00 6312.18 5219.18 W2LL LOCATISN TRUE V~RTISAL DEPTH 5312.1B ~T TO: SJ~-SE~ V~RTISAL DEPTH 5219.18 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DES MiN 3857.52 N 75 36 S~RF FW'L, SE RECTANG NORTH/ 863. 8?4. 892. 918. 94.3. 958. ACE LOCATION C 2~':,;,~;~~ 9 · ~ ~!:'N;~ R E,UM U L A R-<tC~:~iROI N A T E S s o UT.:',q]~ ~AST/WEST FT 22 N 3362.40 E 71 N 3407.16 E 80 N, 3475.55 E 70 N 3573.78 E 74 N 3575.35 E 49 N 3736.5~ E SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC. WELL 9F-6 FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO REFERENCE 000071101 WELL NAME: 3F-6 SURFACE LOCATION: 39' FNL, 48' FWL, S29, T12N, R9E, UM 2M4. -2000 - ! 0013 0 0 ! 0120 2000 ~000 41300 iii ii i i iii il ..... iiii iiii ...;~. ~ ~ ~ ~ ' ' i ~; ii ~_~i i j~.; ~,,~ ~_;~-;~'~'"~ ...... m-T'; ...... ?'T'-t";'T'~'~-',-T-m'" "T-;-~;"r'"~'-'~ ~:~: '~1 . 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H.i.-.~-.?.--.-..L.L.i--i ....... i--.H.!...~ ....... .............. L.L-L.I ...... L..i...L.i ....... i...i...i...i ....... L.i...L.i ....... i...~...L.:~ ....... L..L..i...i. . ....... L..L.,,'..,~ ....... ~,,,~ ..L.~...~ .... -:>000 - 1000 0 1000 ~000 9000 4000 ~000 6000 N£S? I='I~T Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. ~E~A~OR, 'w~.L~ N~ ~D' ~u~ . Reports and Materials to be received by: ~ Date - Required Date Received Remarks Cbr~ 'Description Registered Survey Plat ,. L. FJ. 04 ARCO Alaska, Inc. Post Office E 1100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 12-19-85 TRANSMITTAL # 5481C Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of th:'.s transmittal. Open Hole Finals/ Schl/ One * of Each 3F-7//~5'' DIL/SFL-GR \ ~2" DIL/SFL-GR ~5" Den/Neu ~J2" Den/Neu ~%~5" Den/Neu ~%~2" Den/Neu ~ ~ Cyberlook ~5" DIL/SFL-GR 3F-6'Q~'~2" DIL/SFL-GR ~ 5" Den/Neu '~J 2" Den/Neu %'~ ko 5" Den/Neu %~ ~ 2" Den/Neu ~ Cyberlook ~5" DIL/SFL-GR 3F-5 ~ ~ 2" DIL/SFL-GR 5" Den/Neu ~J ~2" Den/Neu ~ ~5" Den/Neu ~2" Dem/Neu ~D k~Cyberlook 11-03-85 Run#1 11~03~85 Run#1 (poro) 11-03-85 Run#1 (poro) 11-03-85 Run#1 (~aw) 11-03-85 Run#1 (raw) 11-03-85 Run#l_ 11-03-85 Run#1 1~-27-85 Run #1 10-27-85 Run #1 (poro) 10-27-85 Run #1 (poro) 10-27-85 Run #1 (raw) 10-27-85 Run #1 (raw) 10-27-85 Ran #1 10-27-85 Run #1 10-20-85 Run #1 10-20-85 Run #1 (poro) 10-20-85 Run #1 (poro) 10-20-85 Run #1 (raw) 10-20-85 Run #1 (raw) 10-20-85 Run #1 10-20-85 Run #1 3457-8033 3457-8033 4800'8007 4800-8007 4800-8007 4800-8007 7300-7984 3384-7715 3384-7715 3384-7689 3384-~689 3384-7689. 3384-7689 3384-7689 2000-8862 2008-8862 ~5600-8836 5600-8836 5600-8836 5600-8836 7500-8813 R~¢eipt Acknowledged: STATE OF ALASKA * BL & SE RAT~MELL *BL NSK CLERK *BL DRILLING *BL. VAULT *FILMS DEGL©YER & MACNAUGHTON *BL Date: ARCO Alaska. In(:. ,I, · SuDlidial'y of AllanticRicllfleldComlD·ny ARCO Alaska, Inc ... Post Office Box 100360 .'- 'Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ..: i~ ..:" -. ..... '.~.~:i'*'-- ':'~ ,-, . . . ~U~ ~0= ~:' ~~ ;~C KUPA~E OPE~TIONS ENGIN~~G ~CO~S AT~lllS~ P.O. ~OX 100360 ANCHO~GE, AK 99510 DATE:Il-19-85 TRANSMITTAL NO:5453 TRANSMITTED HERE~gITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND Pd/TURN ONE SIGNED COPY OF THIS TRANSMITTAL. OPEN HOLE LIS TAPES PLUS LISk'ING/ $CHL/ ONE COPY OF EACH 3F-7 11-03-85 3F-6 . 10-27-~5 3C-13 10-26-85 3A-8 10-30-85 3A-1 09-30-85 2A-8 10-29-85 RUN RUN RUN #1 RUN ~UN RDN 3384.0-7689 0~~7~-S-Dpe/~--3.~-~~ 4793.0-9420 ] 0~Oa g~3 - S - D~e~ -~3 - ~'~J 71/7 3392 5-8527.~d~? e-J-d~e~-'~o-~'5~ RECEIPT ACKNOWLEDGED: BPAE B. CURRIER CHEVRON D & M DRILLING L. JOHNbTON MOBIL NSK CLERK DISTRIBUTION: W. PASHER EXXON PHILLIPS OIL J. RAThMELL UNION VAULT/ANO ARCC AlasV, a, Inc. is a Subs~chary of AHanticRichfielclCompan¥ ARCO Alaska, Inc. Post Office E )00360~ Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 15, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are the October monthly reports for the following wells' 1B-1 (workover) 3A-7 3C-15 3J-6 9-24 L2-3 2A-8 3A-8 3F-3 3J-7 9-36 L2-13 2D-12 (workover) 3C-6 3F-4 3J-8 16-17 L3-5 3A-5 3C-13 3F-5 4-21 16-18 L3-11 3A-6 3C-14 3F-6 4-22 18-6 (workover) If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU12/L80 Enclosures [ ECEIVED NOV Alaska Oil & Gas Cons. Comm!ssJon Anchorag~ ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA G.-'"lAND GAS CONSERVATION COk ]ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling wel~()~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-244 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21462 9. Unit or Lease Name 38' FNL, 48' FWL, $ec.29, T12N, R9E, UM Kuparuk River Unit 4. Location of Well at surface 5. Elevation in feet (indicate KB, DF, etc.) 93 ' RKB 6. Lease Designation and Serial No. ADL 25632 ALK 2565 For the Month of. October , 19 85 10. Well No. 3F-6 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1200 hfs, 10/21/85. Drilled 12-1/4" hole to 3392'. Ran, cmtd & tstd 9-5/8" csg. Drilled 8-1/2" hole to 7717'TD (10/27/85). Ran logs. Ran, cmtd & tstd 7" csg. PBTD = 7611' Secured well & RR ~ 2400 hrs, 10/28/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests , 16", 62.5#/ft, H-40 weld conductor set @ 115'. Conductor Report has not been received. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 3384'. Cmtd w/865 sx PF "E" & :335 sx PF "C". 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 7701', Cmtd w/:325 sx Class G. 14. Coring resume and brief description None 15. Logsrunanddepthwhererun DIL/GR/SP/SFL f/7715' - 3384' FDC/CNL f/7715' - 6750' & 5500' - 4700' Cal f/7715' - 3385' 16. DST data, perforatingdata, showsof H2S, miscellaneousdata None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. II-b-~$ NOTE--Report/on this form is required for each calendar month, regardless of the status of operations, and must be flied in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP2/MR51 Submit in duplicate MEMORANOUM State"of Alaska ALASKA.0IL AND GAS CONSERVATION COI:.fMISSION -i'~/. ,;~./,.~;, TO: C.V./(~terton DATE= October 28, 1985 Chai~¢ ~t~ ~o: D. HRH. 84 THRU: Lonnie C. Smith .... ~"~ Co~iss ioner ~t~o~ ~o~ FROM: Harold R. Hawkzns . f.~,,/¢~ SUBJECT: Petroleum Inspector.:,~'~/~ ~'~ BOPE Test ARCO 3F-6 K.R.U. Permit 85-244 Iiuparuk River Field Wednesday, October 23, 1985: I left the DS L2-3, subject of '~n0the~ Eep0rt-; to ~CO'"SL-D~g' 3F-6 K.R.U. to witness a BOPE Test. I witnessed the BOPE Test on ARCO's 3F-6 well. There were no failures. I filled out an A.O.G.C.C. report which is attached. In summary, I witnessed the successful BOPE test that Doyan 9 Crew performed for ARCO on WEll No. 3F-6. K.R.U. Attachment 02-00IA(Rev. 10/79) O&C //4 5/-84 ,Inspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report , :, Well ',:" Location: Sec.~? T~A~/R.~;~O M Drillin§ Contractor /~0~A./b/ ,Ri, Location, General ~J'? Well Sign~7/r General Housekeeping ~/~ Rig ~/~. Reserve Pit Mud Systems Visual Trip Tank Pit ,Gauge Flow Monitor Oas' Detectors 0'/~" Audio BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H. C.R. Valve Kill Line Valves Check Valve Test Pressure Test Results: Failures Representative A~..//.4/~X/~: /f~"~ Representative ~:V' ~/~X ~P ACC~LATOR SYST~ Full Charge Pressure ,~~ psi~ Pressure After Closure /~ psig Pump incr. clos. pres. 200~.psi~ .-- min3~ sec. Full Charge Pressure'Attained: ~ min3~ sec. Controls: ~aster ~ Remote ~ Blinds s~teh cover ~ Ke11~ and Floor Safety Valves Upper Kelly Lower Kelly Ball Type Inside BOP Choke Manifold No. Valves /~ No. flanges 2~ Test Pressure ~'~ ~ Test Pressure ~ ~; Test Pressure ~ 0 Test Pressure ~'~ _ Test Pressure .,,~~ Adjustable Chokes ~/.z~ ~/t; ' Hydrauically operated choke ~.z~C- ~/~- '7",ff/--/--Z~' Test Time /, hrs. / 9- z~/'~ ,.. Repair or Replacement of failed equipment to be made within --_- days and Inspector/ Commission office notified. Remarks: t~ ~.--~ 5/ ~ ?~'~0 ~T'~'V'- Distribution orig. - AG&GCC cc - Operator ce - Supervisor Inspector, ARCO Alaska, Inc, Post Office .... Ix 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 21, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK_ .99501 SUBJECT: .Conductor As-Built Location Plat - 3F Pad "Wells 1-16 · Dear Mr. Chatterton: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber · Associate Engineer JG/tw GRUll/L22 Enclosure If RECEIVED OCT 2 51 85 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ) As Bi' ~ CONOUCrQR~ I-e ~N SECTmN ~_ 1- ¥=5,~'~5,734.98 LAT=70°22,20.0858,, X= 508,662.35 LONG=149°55,46. 549'' 89 FNL,. 162 FWL, 52 C.G., 56.1 PAD. 2- Y=5,985,745.10 LAT=70°22,20. 1856,, X= 508,638.99 LONG=149°55,47.233,, 78 FNL, 139 FWL, 52 C.G., 56.3 PAD 3- Y=5,985,754.79 LAT=7OO22'20.2812,, . XTM 508,616.29 LONG=149°55' 47. 896,, 69 FNL, 116 FWL, 52 O.G. 56.3 PAD 4- Y=5,985,764.77 LAT=70°22,20.3796,, ' X= 508,593.66 LONG=149°55' 48. 558- . 59 FNL, 93 FWL, 52 C.G. 56.2 PAD 5- Y=5,985,774.87. LAT=70°22'20.4792'' X= 508,570.43 LONG=149o55,49. 237 J~[[~ 49 FNL, ?O FWL, 52 O'.G. 56.2 PAD 6- Y=5,985,784.84 LAT=?0°22'20.5776,, ~ X= 508' 547' 58 LONG--149°55' 49 '906" NOTE, 39 FNL, 48 FWL, 52 C.G. 56.1 PAD I. COORDINATES ARE A.$.P.,ZONE4.. 7- Y=5,985,794.93 LAT=70°22'20.6771'' 2. SECTION LINE DISTANCE, ARE TRUE. X= 508,524.44 LONG.149°55'50.582', 28 FNL, 24 FWL, 52 0.G.,55.9 PAD. 3. HORIZONTAL AND VERTICAL POSITIONS ARE BASED 8- Y=5,985,804o81 LAT=70°22'20.7744,, ON MONUMENTS SF-MIDDLE & 3F-EAST PER L.H.D&ASSOC. X= 508,501.41 LONG=149°55,51.256,, 4. O.G. ELEVATIONS INTERPOLATED FROM S/C DWG. NO. 18 FNL, 1 FWL, 52 O.C. ,55.9 PAD co.,:,uc'ro.. .- ,. ,. .'~.~...".'""r'.~.'~ x= sos ~,~:~ s~ ~o.,::;=~.4,~o:~s.~:~ ~6~,, ' , , · . ',,r.,,~_-_.. ~..~..~ '-.~.a~'~' ~ .:'~-. ' 12 FSL, 67 FEL, 51.2 C.G., 56.1 PAD :-:...,' , , . 10- Y=5 985 844 70 LAT=70°22'21.1678" · ~o,,~4,eee,,,,,.,,~,~,o-- ' '-- ..... · ,_~~ X= 508,410.73 LONG=149°55' 53. 908'' ' 21' FSL 89 FEL 51 2 O G 56 2 PAD ' , , , , t · · · , e ~:... ' ,~..ow^,D~..~,-^, · ,~ 11- Y=5 985'855 14 LAT=70°22'21 2708" .... . ..~ · . .. · , , · · ' t,"'%~:....__ __..--,o-, ..'.~'_" x= so~,~.~,~. ~.o,~=~.~°ss,s~,.s~o,, ,~_ ~ ...~_../~111~;~- 12- Y=5,985,865.19 LAT=70°22'21.3699'' ' "~,~i~.'~,'~'''e'' 'X= 508,364· 05 LONG= 149°55' 55. 273" I HEREBY'CERTIFY THAT I AM PROPERLY REGISTERED 42 FSL, 136 FEL, 51.1 C.G. 56.2 PAD AND.LICENSED TO PRACTICE LAND IUIIVEYIN~'IN 13- Y=5,985,874.97 LAT=70°22'21.4663,, THE .STATE OF ALASKA, THAT THII PLAT ,IPIESENT8 x= 508,341.36 LONG=149°55' 55.937" A SURVEY MADE UNDER MY DIRECT SUI~R¥1110# AND 52 FSL, 158 FEL, 51.1 C.G., 56.3 PAD THAT CONDUCTORS I THII~ S AN~.CORIIICT Al OF 14- Y=5 985 885 08 LAT=70°22'21 5660" SEPTEMBER 19,19~ AMO.CONDUCTOII't THRU lB ' ' ' ' ARE CORRECT AS OFS,~PTEMBER iS, l~[. X:. 508,318.27 LONG=149°55'56.612'' , 62 FSL, 181 FEL, 51.1 O.G.,56.3 PAD -L~20 ~~~~ ~ ~~. EiVE'D15- Y:5'985'894'96 LAT:70°22'21'6635" 19s 2 X= 508,295.72 .LONG=149°55' 57.271'' --~~ 72 FSL, 204 EEL, 51 C.G. 56.1 PAD . 27~ -~ ~-5 1~]~5 16- Y:5,985,904.95 LAT=70°22'21.7619'' X= 508,272.74 LONG=149°55' 57. 943'' · : . ~.,, ..~ .... r,..--~2 FSL~ 227 FEL~ 51 C.G. 56 P%p _ 6 < ' CONDUCTOR AS BUILT ~1 LOCATIONI CONDUCTORS I THRU 8 LOCATED IN PROTRACTED .. SEC. 29, T. I2N.,R.gE., U. MER. llS~I[ D.t.: October 11,1985 ,..Il:' N.T.S. CONDUCTORS 9 THRU 16 LOCATED IN PROTRACTED SEC. 19, T. 12 N.,R. gE.,U. MER. ,~-,- -. ,,,, ,,.,,,, Drifted by: Sydney2 DII. Ne. N~K 85-26 October 15, 1985 Mr. J. B. Kew in Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box !00360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3F-6 ARCO Alaska, Inc. Permit Mo. 85-244 Sur. Loc. 38'FNL, 48'FWL, Sec. 29, T12N, R9E, UM. Btm~ole Loc. 1043'FSL, 1404'FEL, Sec. 20, T12N, RgE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. c.v. Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. }. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 3, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 3F-6 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk 3F-6, along with a $100 application fee / Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plot A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment We estimate spudding this well on October 24, 1985. any questions, please call me at 263-4970. ~/erely, Regional Drill.ing Engineer JBK/HRE/lt PD/L06 Enclosures If you have ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany · ~) STATE OF ALASKA ALASKA O~[ AND GAS CONSERVATION CO PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [-X]X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPH,.IC SINGLE ZONE ~ MULTIPLE ZONE [] 9 Unit or lease name . Kuparuk River Unit 10. Well number ~F-6 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 38' FNL, 48' FWL, Sec.29, T12N, RgE, UM At top of proposed producing interval 927' FSL, 1816' FEL, Sec.20, T12N, R9E, UM At total depth 1043' FSL, 1404' FEL, Sec.20, T12N, RgE, UN 5. Elevation in feet (indicate KB, DF etc.) T 6. Lease designation and serial no. RKB 93', PAD 56' ~ ADL 25632 ALK 2565 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 38' ~ surface feet 3F-5 well 25' ~ SURFACE feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 7808' MD, 6311 ' TV• feet 2560 10/24/85 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2600 psig@JO°F Surface KICK OFF POINT 1300 feet. MAXIMUM HOLE ANGLE 43 Ol(see2OAAC25.035(c) (2) psig@ $853 ft. TD (TVD) 2985 21 Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT SIZE Hole Casing Weight 24" 16" 62.5# 12-1/4" 9'5/8" 36. O# 8-1/2" 7" 26. O# 22. Describe proposed program: CASING AND LINER Grade Coupling Length H-40 ~ Weld -55/HF-EIW BTC MD TOP TVD 80' 35' I 35' 3356' 35' I 35' I I 34, x 34' I MD BOTTOM TVD 115' 115' 3391'I 3083' I 7808'] 6311' I (include stage data) · 200 cf 865 sx PF "E" & 400 sx PF "C" 330 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7808' MD (6311' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2600 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3F-6 will be 25' away from 3F-5 at the SURFACE. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby~ that the foregoing is true and correct to the best of my knowledge SIGNED////~_~~ TITLE Regional Drilling Engr. The spac~/~w ~oymission u~ CONDITIONS OF APPROVAL Samples required DYES Permit number ~ ~..~.~/~ · APPROVED BY Form 10401 ~ PD/PD155' Rev. 7-1-80 Mud log required []YES [~NO Approval date 85 Directional Survey required I APl number DYES []NO I 50_O -~ ~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE October 15, 1985 by order of the Commission Submit in triplicate PERNIT TO DRILL 3F-6 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 200 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. kECEiv£b · ~,,,~, 4laska Oil &ASa~ COns. S°mm~ssion .nCtTorago EASTtkMt tdH[IPSTOCKi. INC. 6000 .., ?000 KOP' TVD=1300 THD=! 300 DEP=O :3' pERHAFROSTi. TVD=.t$.2;~ T~1524 DEP-13 ......... t TOP ~NU SNDS T~-1924 DEP-101 TVD~1913, ~a~ ~' U- S~-S~S TV~'2$~ T~D=26?3 DEP=4Z3 ~ EOC TVD=2604 THD=2Z3S DEP=514 ........ ~ ~.,_.~n~.,,..cs=.~.er., . ~ ~vo ~o~= T~ ==s~ oEP ~ AVERAGE ANGLE ~ 43,,DEG 3 H IN =468~ T~B=5580 BEP=2457 T/ZONE O TVB=5853 TMB-7182 BEP-~550 T/ZONE C TVB=5857 ~ ~ TAEQET CNTE TVB-6011 TMB-7~.~ ~ ~ T/ZONE A TVD=6024 TMB=74~6 BASE KUP SNBS TVB-6~65 TB (LO~ PT) TVB=6~3~ T~=~a08 1 000 2000 3000 4000 VERTICAL SECTION Alaska Oil & Gas Cons. Comm!ssion A~c~orage 3000 , 2000 - o ~.. -~.;~ !000 ., ..... ~,~ 0 S~A~ L~AT ION ~ ~C.20, tl2N. R~ 1 000 _ HUN l/_UN I AL I~I~UJI:.U ! ,,,. KUPARpK FI,ELD, NORTH SLOPE. ALASKA ~,,,,~,,,,,~,oc,. ,~c. ; 1000 0 1000 2000 I , 1, N 74 3697' DEO 14 HI N E (TO TARoET) ~ ~ : , i , , l, , i i i., ~ ; ...... i,., I ,. ~ . 3O0 . , :300 200 1 O0 0 1 O0 200 300 400 i I I INC, PAD 3F'. WELL NO, 5-6-7'-8 PROPOSED I KUPARUK FIELD, NORTH SLOPE, Al< I I EASTMAN WH[PSTOCK. INC. ~' f 1955 .. WE;L pATHs EXTEND :BEYOND / TH~S VIEWING WINDOW / . ~ '/ //4067 i 1 ?ri 3oo / / / / / / //4240 / / / ~' 1 305 / / / 4402 / / / //"1473 0 iO0 \ \ \ 200 300 4OO 500 I 6O0 I '257'8 i · I I _ I 500 600 .300 .200 100 _0 .100 2OO 300 KUPARUK RIVER UNIT '20" DIVERTER SCHEMATIC DE $CR I PT I ON . MAINTENANCE & OPERATION I. UPON INITIAL INSTALLATION, CLOSE PREVENTER AI~) VERIFY THAT VALVES HAVE OPENED PROPERI. Y. 2. CLOSE AI~UI. AR PREVENTER AM) BI. OR AIR TI-tROUGH OIVERTER LI~E,~I EVERY 12 HOURS. $. CLOSE AI~aJLAR PREVENTER IN THE EVENT THAT AN I~FLUX FLUII:)~ OR GAS IS ~TECTED. IF ~~ ~~IATE V~VE TO ACHIEVE ~I~ OIVERSI~ DO NOT SHUT IN WI[LL U~:)ER ANY C I RCUMSTANCE$. Alaska Oil & Gas CoP, s. uu~;,i'..:~~. ..r, .AP~L:: ~orag~ 7 6 AC~TC~ CAPACITY TEST I. Q~{3( AhD FILL ~TCR ~OIR TO LEVEL WlTN NYERNJLIC FLUID. ~ ~ ~T ~T~ ~ IS ~ ~I WI~ 4. ~~ ~ ~ ~, ~ ~~ L~ kl~IT 5 4 . 13-5/8' B(~ :STACK TEST ,A~'chora[i.~ I~AY 15o1~ CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. /fi]. ~ ~? ITEM APPROVE DATE (1) Fee (2) Loc (.2 thru 8) (13 thru 21) (5) (22 tlir'u 26) " 1. Is the permit fee attached ......................................... 2. Is well to be located in a defined pool ........................... 3. Is well located proper distance from property line .... ' ..... 4. Is well located proper distance from other wells ................... 5. Is sufficient undedicated acreage available in this pool............ 6. Is well to be deviated and is wellbore plat included .............. 7. Is operator the only affected party ................................ 8. Can permit be approved before ten-day wait ......................... e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. YES NO · [/ ." .. · Does operator have a bond in force .................................. ~- Is a conservation order needed ...................................... ~ Is administrative approval needed ................................... ,~ Is the lease number appropriate ..................................... ~f. Is conductor string provided ........................................ ~ Is enough cement used to circulate on conductor and surface ......... ~ Will cement tie in sUrface and intermediate or production strings ... ~f Will cement cover all known productive horizons ................ ~ Will surface casing protect fresh water zones ........ [ ....... i i11 Will all casing give adequate safety in collapse, tension and burst..~ Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............. ............... ~ Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... //4f Does BOPE have sufficient pressure rating - Test to 3000 psig .. /3Y Does the choke manifold comply w/API RP-53 (Feb 78) .................. Is the presence of H2S gas probable ................................. ,,,, Additional requirements ............................................. ~ ,. REMARKS Additional Remarks: ,Geology: EngiBeer ing: HWK ~.~ LCS~-~'~' ~E~ JAL~,'~-.. rev: 03/13/85 6.011 ' ' INITIAL .GEO. UNIT O'N/OFF POOL CLASS STATUS AREA NO. SHORE ........ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. II II : Ill I I I I{ ll I ll 'lll I ~lllI I I I I I II I ll ~I, : lI I I ' I :lllll lll l}llI I I I : llI I I' I lll~l ,llllI IIll Ill ~llll}~` I : I I I ~lI : ll: :ll~:ll~' ll I l~l : ll I I I II llI I I II I I I l I I I I I I I I I ~I I I I I I I I II I I I I :ll, l I I : ] I I ] I I I I l]l lllll I llI lll ll I ll~] II ] Ill I l]l]l II I I I ]lll l] ll] I I I I ll , ] II I Ill ll I, l] llll ~l{~llI I ~l ] ]l l'l I ] ~] ll ::lll~ll llllll I ~ I ll l~l I] .... I I I I I I ll l l · II il il il II ...... I il I : I I' , ill] il ilI I llll il I I I il ll:~l llll I I I I :l I I :l, lll~ 'il l~ , I lI :ill:il l: ~l I ,llll il l~lllll I I lllllI l: ill I , ~l ll~I I I I ilI il L¥m, OIO·.M~ V~iCATION~ ~ LISTi~ o~. 1 ~',~:: R~EL_ HEADER '""'.,--,- u T~ :85/i1/ 8 ORIGIN : R~L NAH~ :135397 CONTINUATION ~ :0! COMMENTS :LI~R~RY T~PE ..... T:&P¢, HEADER. ....,. :SERVTC~_ ' NAME :~- ~-;O~T DATE :85/11/ 8 ORIGIN :0000 TAPE NAM~ :0920 CONTINUATION ~ :01 PREVIOUS T,aPE : COMMENTS :LIBRARY TAPE =iLE NAM~ :EDIT O0 SE~VZCE NAME VERSZDN ~ : DATE : MAXIMUM LENGTH : 1024 ~-iLE TYPE : PREVIOUS FILE : iNFORMATION RECORDS MN~H. ~ r 0 NT: N T S~ ; CN : ARCO ALASKA INC WN : 3F-6 FN : KUPARUK RANG: 9E TOWN: !2N SECT', ~°9 COUN: N.SLOPE ST~T: ~LASKA CTRY: USA M~M ~c, CONTENTS UNiT Tyo~ CATE SiZE CODE 000 000 016 065 000 000 012 055 000 000 008 065 000 000 002 065 OOO 000 004 055 000 GOO 002 065 000 000 012 065 000 OOO 006 065 000 000 003 055 UNIT TYPE CAT~-- SIZ: CODE PRES: -g~;~ COMMENTS 000 000 001 065 LVP O!O.H02 V~RiFtCAT!ON LiSTiNG O~GE 2 JO~ NU, MBER AT ACC: 709Z0 RUN ~ONE, DATE LOGGED: 27-0CT-85 LDP: M. OGD£N CASING = 9.625'' B 3384,0' - ~I'T SIZE = 8,5" TO 7TI7.0' TYPE FLUID = WEIGHTED POLYME~ DENSITY = 9.70 L~/G RM = 3.280 ~ 68.0 DF VISCOSITY = 39.0 S RMF = 3.270 a 58.0 DF PM = 9.~ RMC = 3,210 ~ 68.0 DF =LUiD LOSS = 5.,2 C3 RM AT BHT = 1,573 ~ 140. DF MATRIX S~NOSTONE .........~--,-~-~-~ .... -,- THIS~a,~T~ H~S NOT. BEEN D:OTH_~ ~ SHTFT~..~_ . - OVERL.aYS. :I:L~, ~ PRINTS. LVP OiO.M02 VERT~IC~,iON LISTiNg P,~g~ 3 "' 'qrHLU,M~RG~R L3GS lng' ,,D: ~..~ ~.u O ~ZTH THiS MAGN~TrC TAP~ -,- DU~L iNOUCTiON SPHfiRICALLY FgCU~ED LOG (DiL) .,."' DATA AVAiLABt E:~ 7715'0~ T~ 3384.0~ ~;~ FO-RHATZON DENSITY COMPENS~TE~ LuG (FON) .,. COMPENSATED NEUTRON~ L~¢ (~DN) -,-"' q: uAT~ AVA~LABL~' ~689.0' TO 57~5.0 ~',~ .,.-'- OAT~ AVaiLaBLe: 5>~.u TO 33~4.0~ -.--'- X-'<: DATA $:'DRMAT R',~rORu .,..,. ENTRY BLOCKS TYPE SiZE REPR COOE 7, i 66 4 1 66 8 ~ 73 '9 4 65 16 1 66 ENTRY 0 i 6O .lin I 0 DATUM SPECiFiCATION BLOCKS MNEM SERVICE SERVICE UNIT AP1 APl AP1 APl FILE SiZE SPL REPR oROCBSS LVP OIO.H02 V:RIFICAT!CN LISTING PAGE 4 ID DEPT SFLU DiL iLD ~ u~L ~LM DIL SP OIL GR DIL C~u~ NRAT FDN RNRA ~DN NCNL FDN ~CNL FON ORDER LOG TYPE CLASS MOO '..=T 30 000 O0 0 O~MM 00 220 0i 0 DHMM O0 t20 46 OHMM O0 120 44 0 NV' O0 010 Ol 0 GAPi. O0 310 GAOl OO 310 Ol 0 "' -~ 280 Ol 0 ~N Ou G/C3 O0 350 02 G/C3 O0 356 Oi 0 ~-~ 420 O1 u 000 O0 0 ,~U On~ 890 nO CPS O0 330 31 0 ~ '~ :~3n 30 0 ,...PS Ou ., NO 0 0 0 0 0 0 0 0 0 O 0 0 0 4 4 4 4 4 4 4 4 4 4 4 (OCTAL) 00000003300000 CODE 1 58 1 68 00000000000000 1 68 O000000CO00000 I 68 O0000OOOOOOOO0 1 6-8 00000000000000 I 68 O0000000000000 I 68 00000030000000 I 68 00000000000000 t 58 00000000000000 1 68 OOOO0000OOOOOO 1 68 O000OO00000000 1 68 00000000000000 t 68 O000000000000O i 68 O000000OO00000 I 68 0000000000000'3 DEOT SP 7737.0000 -6.7180 1.3955 25.5859 OEPT SP NPH! 7700.0000 -4.9580 1.4063 29.4434 SP RHDB NPHI 7600.0000 -2.9939 2.4573 OEPT Rd'~Su NPHI 7500.0000 -29.0!07 2.3889 43.3105 RHO8 NPHi 7400.0000 -32.51:95 2.3811 33.7891 uEmT SP NPHI 7300.0000 -59.3008 2.3401 38.1835 OcpT £P HPHi 7200.0000 -39.0195 2..3859 30.0293 SFLU DRH~ NCNL SFLU GR DRHO NCNL SFLiJ GR ORHO NCNL S=LU GR DRHO NCNL SFLU GR ORH~ NC N L SFLU GR SFLU Gq NuNL 3.3127 ILO !Z7.8398 GR -0.0239 NR~T 1812. ~875 FC""' ~. ~9 ~LD 127.8398 GR -0.3137 NR&T 1812.6875 FCNL 3.5549 iLD 99.4648 GR 0.0522 NRAT 2199.5000 PCNL 3°0959 i~¢ 95.7773 GR 0.0615 NRAT 1865.6875 FCNL 6.0945 ~' ~u 90.7148 GR 2259.5000 FCNL 70.8398 tLD 45.2617 GR 0.0~25 NRaT 2715. 5000 FCML 7.0046 ILD s5.o89a GR 0.0073 NRAT i477.5000 FCNL 3.2639 127.8398 Z.4~55 678.3125 2.5002 127.8398 2.4456 678.3125 3.1741 99.4648 3.1077 626.3125 2.7073 95.7773 3.~530 496.8906 6.0320 90.7148 3.0237 720.8125 16.27~ 45.2617 749.3t25 7 2~ 85.0898 2.7874 775. ~ p - iL~ ~ 7444 C~L! B.3020 RNR~ 2.6721 ILM 2.3~32 CALI 4.4578 RNRA 2.6721 iLM 3.3030 CAi~ ~ 697~ RNRA 3.5i00 iLM 2.82~4 CALl 9.0801 RNRA 3.7542 iLM 5.9343 CALi 8.9473 RNRA 3.1331 ILM 25.4580 CA:LI 8.0566 RNR~ 3.6233 ILM 7.3093 CALl 9.0254 RNRA 3.1936 ~ VP 010 HO2 V:"' ~.."' ~' - ~_ . ~_ ,'~ Z ~ 'F ,., A T l 9N LZ$T~.N5 PAGF 5 S? NPHI ~F-pT S? NPHT "":PT SP RHO8 NPHI RHO3 NPHi OSPT SP RH06 NPHi. DEPT SP RHOB NoHi DEPT SP NPHI 9EPT S? NPHi DEPT Sm NPHi RHOB NPHi 3EPT SP RHO~ 710 -5 3 700 -4 4 690 -6 4 680 670 -2 -99 -99 660 -3 -99 -99 65O -2 -99 -99 640 -2 -99 -99 630 -3 -99 -99 620 -! -99 -99 610 -2 - 9 '9 0.0 '"" n Ou_ SFLU 3.9258 GR 2,6565 DRHO 9.7949 NCNL 0.0000 SFLU 3.9258 GR 2.3245 DRHO 6. 7285 NCNL 0.0000 SFLU 7.4727 GR 2.3733 DRH~ 3.9453 NCNL 0.0000 SFLU 8.0215 GR 2.4280 DRH3 ? 6270 NC~ ~ · ~L 0.0000 SFLU 7.2295 GR 9.2500 ORH$ 9.2500 NCNL 0.0000 SFLU 0.7607 GR 9.2500 DRHO 9.2500 NCNL 0.0003 SFLU 5.5254 GR 9.2~00 DRHO 9.2500 NCNL 0.0000 SFLU 6.1357 GR 9.2500 DRHO 9.2500 NCNL 0.0000 6.8945 9.2500 9.2500 , 2. 9. 9. , 0000 2793 Z~O0 2500 0000 4482 250O SFLJ GR NCNL SFLU uRHu NCNL SFLU SR DRHG 217.~375 ILO 61.3867 GR -0.0239 NRAT 2012.6875 FCNL 3.5667 ILO i49.6875 GR 0.0073 NRAT 1874.5875 FCNL 2.8147 ILD 115.9023 GR 0.0151 NRAT 1888.6875 FCNL 2.6077 iLO 234.8906 GR 0.0029 NRAT 2581.¢:000 FCNL. 3.3127 ILD 19!.&375 GR -999.2500 NRAT -999.2500 FCNL 4.1296 ILD 145.8125 GR -999.2500 NRAT -999.2500 FCNL 4.0867 ILO 107.5898 Gq -999.2500 NRAT -999.2500 =CNL = 9382 t00.1523 GR -999 25u0 N T -999. 2500 FCNL ~6.90~3 GR -9'99. 2500 NRAT -999.2500 4.55t5 106.9648 -999.2500 -999.2500 iLD GR NRAT ~CN' 3.2~874 iLO 9:5.7773 GR -999.2500 NRAT 112.7773 61.3867 3.3596 596.3125 3.1519 149.6375 3.7502 454.1406 2.4768 !i5.9023 3.6272 445.3906 2.9827 ~4 8906 ~ 5002 645.3125 3.6975 ~9t.4375 -999.2500 -999,2500 4.0398 146.8125 -999.2500 -999.2500 ~ 4~19 107.5898 -999,2500 -999.2500 5.1531 100.1523 -999.2500 -999.2500 4.8796 96.9023 -999.2500 -999.2500 4.0359 106.9648 -999.2500 -999.2500 ~ 0754 96.7773 -999,2500 TLt~ CALl RNRA ILM CAL~ RNRA ILM CALI RNRA ILM CALl RNR~ ILM CAL; RNRA CALi RNRA ILM CALI RNRa i'"~ CALi RNRA iLM CALl RNRA ILM CALl RNRA ILM CALl R NR 4 82.9648 9.0332 3.3752 3.0999 9.1895 4.1237 2.5842 9.5410 4.2390 2.8049 8.8691 4.0007 3.5334 9.4004 -999.2500 3.8948 9.5879 -999.2500 3.4788 9.5332 -999.2500 4.9578 9.77~4 -999.2500 5.0828 8.5254 -999.2500 4.2546 10.0957 -999.2500 3.2112 9.9941 -999,°500~ LV? OlO.H02 VERIFICATION LISTING NPHi -999· DEPT 6000. SP -31. RHOB -999. NPHI -999. DEPT 5900. SP -42. RMO~ -999. NPHI -999· DEPT 5800. S? -64· RHO6 -999. NPHi -999. D~OT 5?00. SP -68. RHO~ -999. NPHI -999. DEPT 5600. SP -20. RHOB -999. NPHI -999. ~'~PT 5500 SP -3. RHOB 2. NPHi 44. O~OT 5400. S? -6. NP~I 38. OEPT 5300. SP -88. RHO5 2. NPHI 20. OEPT 5200. SP -139. RH06 Z. NPHi 39. O~PT SP NPHI DEPT $? 5100. -34. 2. 5000. -35 o 2500 NCNL 0000 SFLU 4795 GR 2500 ORHO 2500 NCNL O000 SFLU 3633 GR 2500 DRH~' 2500 NCNL 0000 SFLU 4727 GR 2500 9RHO ~00 ~'~NL _ ~ _ 0000 SPLU 3477 GR 2500 ORH~ 2500 NCNL 0000 SFLU 1201 GR 2500 DRHO 2500 NCNL 0000 SFLU 6658 GR 3049 DRHO 0430 NCNL 0000 SFLU 6204 GR 3655 ORHO 7695 NCNL 0000 SPLU 5'977 3909 DRH$ 3125 NCNL 0000 SFLU 1875 GR 324~ DRH~ 2578 NCNL OOO0 SFLU 4883 GR 3049 DRMO 5508 NCNL 0000 SFLU -999.2500 3·498B 108.3398 -999.~500 -999·2300 3.0!59 122.4023 _99~ ..~500 -999.2500 4.1179 133.1~75 -999.2500 -999.2500 &.1062 1~0.9375 -999.2~00 -99~.2500 1.5391 1~6.~37~ -999.2500 -999.2500 1.8223 t04.5273 O.OZg~ 2008.8875 2.3635 100.5898 0.0518 2073.5000 ~ ~. 6816 0.0161 3553.5000 2.9319 90.2148 0.0554 !995.6~75 2.7522 97.0~98 0.0391 1924.6875 2.9124 117.1523 -999. . 108. -999. -999. · 122. -999· -999. 133. -999. -999. · 140. -999. -999 · I · 146. -999. -999. 104. 3. 518. · I00 · 3. 602. . 41. 2. 1624. 90. 3. 563. · 97. 3. 540. t17. 250O 8967 3398 2500 2500 7366 4023 2500 2500 1609 1875 2500 2500 9709 9375 2500 2500 9835 4375 2500 1448 :~73 4983 8125 5491 5898 2737 3125 6179 1055 1252 6875 0393 2148 3206 3125 7932 0:898 8125 5315 1523 ILM CALl RNRA ILM CALl ILM CALl R NRA ~'LM ~l. - C~Li RNR -4 TLM CALl RNRA ILM CALl RNRA ILM CALl RN R A !LM CALl RNRA ILM CALi RNRA ILM CALl RNR~ ILM CALl PAGE 2.9885 9.5020 -999.2500 2.8284 8.9941 -999.2500 4.2000 9.7676 -999.2500 4.0125 8.6270 -999.25'30 1.7471 7,4695 -999.2500 2.1409 7.9148 3.8713 2.7229 8.6895 3.4417 8.5566 B.8848 2.~48TM~ ~ 3.0940 8.9160 3.5432 2.7913 8.2988 3.5588 3.3928 9.3379 LVP. OiO.Hn.~_ VERi:ICATiON, LISTi~.'G~ PAGE. ., 7 NPHi 3 490 -3 4 480 -4 3 470 -3 4 460 -3 -99 -99 450 -99 -9'9 -4 -99 -99 430 -4 -99 -99 420 -4 -99 -99 ~10 -4 -99 -99 400 -4 -99 -99 2.2893 DRHO 8.4766 NCNL 0.0000 SFLU 4.7070 GR 2.0920 DRMO 2.8223 NCNL 0.0000 SFLU 3.1758 GR 2.3088 DRHO 8.81~4~ ~ N~NLu 0.0000 $FLU 8.1758 GR 2.3362 DRHO 0.7715 NCNL 0.0000 SFLU 9.5508 GR 9.2500 DRH~*~ 9.2500 NCNL O.O000 SFLU 0.3320 GR 9.2500 DR~O 9.2500 NCNL 0,0000 SFLU 0.2695 GR 9.2500 DRHC 9.2500 NCNL 0.0000 SFLU 0.7695 GR 9.2500 DRHS 9.2.500 NCNL 0.0000 SPLU 0.7695 GR 9. 250~ DRHO 9.2500 NCNL 0.0000 SFLU 2.8633 GR 9.2500 DRHO 9.2x00 NCNL 0.0000 S~LU 3 P~70 G~ 9.2500 DRHO 9.2500 NCNL 0.0000 SFLU 0.0122 2109.5000 4.~953~ 92.90:23 -0.0005 2083.5000 3.8557 124.5273 0.0059 1971.6875 2.713! 99-8398 0.02!0 197!.6875 2.4885 100.3398 -999.2500 -999.2500 2.338i i02.4648 -999o2500 2.3850 97.9648 -999.2~00 -999.2500 2,6663 99.9648 -999.2500 ~o51 -999.2500 -999.2500 3.4~17 102.9648 -999.2500 -999.2500 3.3264 -999.2500 -999. 2500 4.1'48 NRA'T FCNL iLD NRAT FCNL ILO GR NRAT FCNL iLD ~R NRAT FCNL iLO NRAT ~CNL ILO GR NR:&T FCNL iLD GR NRAT FCNL GR NRAT ~CNL ~LD GR NRAT FCN~ IL~ GR NRAT FCNL GR NRAT 4.387~ 92.9023 3.4963 534.8125 3.9377 124.5273 3.3850 ~46.8125 3.0178 99.839~ 3.463I 556.3125 2.6077 100.3398 -999.2500 a99.2 2,2698 I02.4648 -999.2500 -999.2500 ~ ~608 97.9648 -999.2500 -999.2500 2.9507 99.9648 -999.2500 -999.2500 3.1370 96.5273 -999.2500 m99.PSn0 ~ 0164 !02.9648 -999.2500 -999.2500 3.91~3 ~9.~023 -999.2500 -999.2500 4.2554 RNRA ZLM CALl RNR~ ZLM C~LT RNRA IL~ CALI RNRA !LM CALl RNR~ !LM CALl RNRA ZLM C~L'Z RNRA ILM CALl RNRA ~LM CALl RNR4 !LM CALl RNRA ILM ~ALI RNRA !LM 3.6917 4,4304 8.7051 3.~948 3.9905 10.0098 3.6057 2.9983 9.6738 3.5452 2.6311 9.4529 -999.2500 2.2405 10.3926 -999.2500 2.5452 10.4395 -999.2500 2.~221 9.9707 -999.2500 i0.1973 -999.2500 m.87~2 10.1895 -999.2500 3,7795 9.9785 -999.2500 4.1453 LVP 0iO.HO~. VEmZFiCAT~.~~, 'mN L$$TiNG' - mA<SE, o~' SP -42,9258 GR RHOB -999,2-~00 DRHO NPHI -999,2500 NCNL DEmT 3800.0000 SFLU SP -62,6758 GR RHO5 -999,2500 DRHO NPHZ -999.2500 NCNL DEbT 3700.0000 SFLU SP -40,6?58 GR RHO~ -999.2500 DRH~ NPHI -999.2500 N~N~ 9EPT 3600.0000 SFLU SP -39.6758 GR RHOB -999.2500 DRHD NPHI -999.2500 NCNL OEPT 3500,0000 S~LU SP -3'9.1133 GR RHOB -999.2500 DRHO NPHi -999.2500 NCNL OEPT 3400.0000 SFLU SO -39.3008 GR RHOB -999.2500 DRHO NPHI -999.2500 NCNL ~E~T~ 336~,0000~ SmLU, S? -15.7168 GR RHO~ -999.2500 DRHO NPHI -999 ~5~ " · ~ uu N~N~ I0! .9023 -999.~~ -999.2500 GR NRAT FCNL 4.4578 ILO 91.9648 GR -999,2500 NRAT -999.2500 FCNL i04, 2'773 GR -999.2500 NRAT -999,2500 FCNL 3.4084 101.1523 -99:~=._pSO0 -999.2500 3,9456 88,0898 -999.~5~ -999.2500 ILO GR NRAT FCNL ZLD GR NRAT FCNL 4.7312 iLO 83.2773 GR -999,2500 NRAT -9'99.2.500 ~CNL 0.8115 iLC 46.1992 GR -999.2500 NRAT -999.25~-0v~=rNL~ 101.9023 -9'99.2500 -999.2500 5.u032 91.9648 -999.g~00 -999.2500 3.9~56 !04.2773 -999.2500 -999.2500 3.8440 I01.t523 -999.2500 -999.2500 4.6765 8~.0898 -999.2500 -999.2500 5.3796 83,2773 -999-2500 -999.2~00 1: 0957 46.i99~ -999. _~?~00 -999.2500 CAL! RNR~ ~'LM CALl RNR~ !LM CALl RNRA ILM CALl RNRA iLM CALl RNRA ILM CALl RNRA iLM CALI RNRA 9.7598 -999.2500 4.8875 9.8301 -999.2500 3.8010 10.1816 -999.2500 3.6819 !0.2129 -999.2500 4.3562 10.2285 -999,2500 5,1414 9.0332 -999.2500 2000.6675 7.8093 -999.2~00 ~:~;:~ FiLE TRAILER FiLE NAME :EDIT .001 S~RVICE N~M~ : VERSION ~ : . D A T F. : ~AXIMUM L~NGTH : ~024 FIL~ TYPE ~.~EXT FiL~ NAMe : ~',-'::: TAPE TRAILER SERV~'CE,~ NAME : EDIT DATE :85/11/ 8 ORIGIN :0000 TAPE N '~ ?,I £ :0920 C~NT~'NUATiON.~, ~ :01 NEXT TAP~ NA~E LVO 010.H02 VERIFICATION LISTING OAGE 9 COHHENTS :LiBRaRY TAPE .,-.,., F_L TRAILF~D~_,. SERVICE NAM=~. :~-D~'T~, OAT~ :~5/II/ 8 ORIGIN : R~L NAMf :135397 CONTINUATION ~ :01 NEXT ~L NAME : COMMENTS :LIBRARY TAP~