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186-101
STATE OF ALASKA AL :KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing I✓ Operations Shutdown r Performed: Suspend r Perforate r Other Stimulate Casing 9 r Change Approved Program r Rug for Redrill rJ Perforate New Pool r Repair Well Re-enter Susp Well r Other: CTD Set-upiTo 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory E 186-101 3 Address: 6.API Number: Stratigraphic r- Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-21600-00 7.Property Designation(Lease Number). 8.Well Name and Number: ADL 25520 KRU 3K-01 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 9150 feet Plugs(measured) 8643 true vertical 6878 feet Junk(measured) none Effective Depth measured 9055 feet Packer(measured) 8590 true vertical 6809 feet (true vertical) 6476 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115 115 SURFACE 4882 9.625 4919 3852 PRODUCTION 9114 7 9140 6871 RECEIVED SCANNED / J' 0 2rJF la 2 8 2015 Perforation depth: Measured depth: 8818-8896 5 True Vertical Depth: 6641-6697 A,O G C C Tubing(size,grade,MD,and TVD) 3.5x5.5, L-80&J55, 8686&8768 MD, 6545&6605 TVD ,• Packers&SSSV(type,MD,and TVD) PACKER-47B2 FHL RETRIEVABLE PACKER @ 8590 MD and 6476 TVD SSSV-CAMCO'TRDP-IA-SSA'@ 1792 MD and 1680 TVD 12 Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this workover 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 28 408 278 -- 154 Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25 070,25.071,825 283) 15.Well Class after work: Daily Report of Well Operations 17 Exploratory r Development F. Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil I✓ Gas I— WDSPL r Printed and Bectronic Fracture Stimulation Data r" GSTOR r VVINJ r WAG - 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 none Contact Theresa Lee Cad 263-4837 Email Theresa.M.Lee@conocophiilips.com Printed Name eresa Lee Title Wells Engineer Signature Phone:263-4837 Date 4./ 1, ..i LTi- 575// 5- RBDMSV AUG - 2 1015 ''ts Form 10-404 Revised 5/2015 Submit Original Only 3K-01 PRE-RIG WELL WORK ' DATE' SUMMARY 2/22/2015 (PRE-RWO): T POT(PASSED), T PPPOT (PASSED), IC POT(PASSED), IC PPPOT(PASSED), FT LDS (ALL FUNCTIONED PROPERLY). 5/11/2015 ATTEMPT TO DRIFT TBG & NOTICED WET CONNECTION ON LUBRICATOR, DECISION MADE TO ABORT RUN, LAY DOWN EQUIPMENT TO INSPECT, AND REPLACE 0-RINGS. IN PROGRESS. 5/12/2015 BRUSHED, FLUSHED, GAUGED TBG TO 2.29"TO 8635' RKB; HEAVY SCALE BUILD UP FROM 4186'TO 6330' SLM. DRIFTED WITH 2.25" CA-2 DUMMY TO 8635' RKB. SET 2.25"CA-2 PLUG AND SPARTEK GAUGE @ SAME. ATTEMPTED SET BAITED P/T ON PLUG, LEFT @ 8624' RKB. PULLED GLV @ 7754' RKB. IN PROGRESS. 5/13/2015 RECOVERED GLV DROPPED 12/4/2002 IN GLM @ 6459' RKB. ATTEMPTED PULL GLV @ SAME, NO SUCCESS. REPLACED GLV @ 4670' RKB WITH DV. IN PROGRESS. 5/14/2015 SET DV @ 7754' RKB. PULLED OV @ 8552' RKB , LEFT GLM OPEN. ATTEMPTED EXERCISE FLOW TUBE: NO MOVEMENT, FLOW TUBE SEIZED. READY TO LOAD WELL. 5/15/2015 PUMPED 240 BBL INHIB SW DOWN TBG, UP IA TO PRODUCTION. PUMPED 72 BBL DSL& U- TUBE'd. READY FOR COMBO MIT. 5/16/2015 MIT TBG x IA 2500 PSI, PASSED. EXERCISED FLOW TUBE @ 1792' RKB. IN PROGRESS. 5/17/2015 EXERCISED FLOW TUBE WITH Z5 @1792' RKB. PULLED CATCHER @ 8582' SLM. BAILED SCALE OFF PLUG @ 8634' RKB. PULLED EQ PRONG @ 8635' RKB. IN PROGRESS. 5/18/2015 BAILED SCALE OFF LOCK @ 8635' RKB. ATTEMPTED PULL PLUG. IN PROGRESS. 5/19/2015 PULLED CA-2 LOCK& SPARTEK GAUGES FROM 8635' RKB. READY FOR CHEM CUT TBG. 5/22/2015 RAN STRING SHOT OVER INTERVAL FROM 8,569' RKB TO 8,579' RKB 5/23/2015 CUT TBG W/CHEM CUTTER @ 8,577' RKB SET COLLAR STOP @ 1,856' SLM LOCKED OUT TRDP-SSSV @ 1,792' RKB RAN FLAPPER CHECKER TO VERIFY TRDP LOCKED OUT PULLED F COLLAR STOP @ 1,856' SLM Conoco Phillips Time Log & Summary Wel!view Web Reporting Report Well Name: 3K-01 Rig Name: NABORS 9ES Job Type: RECOMPLETION Rig Accept: 7/5/2015 2:00:00 PM Rig Release: 7/13/2015 5:00:00 PM Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 37/05/2015 24 hr Summary Jack up pit system and pull away from sub base. Move sub base off 3K-32. Lay rig mats and herculite for new well. Spot in sub base, spot in pit system. Take on 8.9 ppg brine. Rig up tiger tank. Lubricate out BPV. Rig up manifold to kill well. Begin killing well with 8.9 ppg brine. 04:00 05:00 1.00 0 0 MIRU MOVE MOB P PJSM. Jack up pits and connect to sow. Move pit module away from sub base. 05:00 06:30 1.50 0 0 MIRU MOVE MOB P Jack up sub base. Move mats from underneath. Pull sub base off 3K-01. 06:30 08:00 1.50 0 0 MIRU MOVE RURD P Prep new well. Set rig mats and lay out herculite for cellar. Stage wellhead equipment behind well. Hang tree in cellar. 08:00 09:30 1.50 0 0 MIRU MOVE MOB P Pull sub base over 3K-01. 09:30 11:15 1.75 0 0 MIRU MOVE MOB P lay rig mats and herculate for pit module. Spot in pit module 11:15 14:00 2.75 0 0 MIRU MOVE RURD P Berm up pit module, cellar and sub base. Hook up interconnect. Spot cuttings tank and berm up. Rig accepted at 14:00 14:00 18:00 4.00 0 0 MIRU WELCTL RURD P Bring on 8.9 ppg brine into pits. Rig up handling tools on rig floor. Rig up secondary annulus valve. 18:00 19:00 1.00 0 0 MIRU WELCTL RURD P Rig up tiger tank. Blow air thorugh tank to look for leaks. Pick up lubricator. 19:00 19:30 0.50 0 0 MIRU WELCTL RURD P Pre-RWO meeting with Dan's crew 19:30 20:30 1.00 0 0 MIRU WELCTL MPSP P PT lubricator and lubricate out BPV. 20:30 22:30 2.00 0 0 MIRU WELCTL RURD P Rig up circulating manifold and hoses. PT lines to kill tank to 3000 psi-good. 22:30 00:00 1.50 0 0 MIRU WELCTL KLWL P PJSM kill well. Fluid pack tubing and IA. Shut in tubing pressure 290 psi. Shut in casing pressure 190 psi. Begin well kill with 8.9 ppg KWF. Hold casing pressure at 250 psi while bringing pumps up to rate, 2.5 bpm, pump pressure 710 psi. Continue holding back pressure as per schedule; 120 bbls into well kill 07/06/2015 Continue killing the well with 8.9 ppg brine. Monitor well,static. Set BPV. Nipple down tree and adapter, inspect hanger threads, install dart. Nipple up BOPE and test 250/3000 psi with 2-7/8"test joint. BOPE test witnessed by Jeff Jones. Make up BHA#1 Itco spear and engage tubing hanger. Pull hanger to the floor; PUW 80K. Circulate hole volume at 5 bpm 1290 psi. Rig up casing tongs, rig up spooler. POOH with decompletion spooling up control line. Page 1 of 11 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 0 0 MIRU WELCTL KLWL P Continue circulating 8.9 ppg kill weight fluid down tubing up the IA holding 250 psi back pressure at 2.5 bpm. Shut down after 360 bbls pumped 303 bbls returned-8.6 ppg fluid back. 01:30 02:45 1.25 0 0 MIRU WELCTL COND P Empty kill tank. Load pits with additional fluid. 02:45 03:45 1.00 0 0 MIRU WELCTL KLWL P Continue to kill well with 8.9 ppg fluid. Circulate an additional 50 bbls of brine(410 total)out to the kill tank,good 8.9 ppg fluid seen after 25 bbls. Initial shut in casing pressure 15 psi, shut in tubing pressure 40. Bleed off pressure; IA went on a vac; tubing 10 psi-appears out of balance. 03:45 04:15 0.50 0 0 MIRU WELCTL RURD P Rig up to take returns to the pits 04:15 04:45 0.50 0 0 MIRU WELCTL KLWL P Circulate 50 bbls through gas buster at 2.5 bpm 490 psi. Initial weight back 9.1 ppg. 04:45 05:00 0.25 0 0 MIRU WELCTL RURD P Install gauges on well and verify SITP =0 SICP=0 05:00 05:30 0.50 0 0 MIRU WELCTL OWFF P Monitor well for 30 minutes, static. 05:30 06:15 0.75 0 0 MIRU WHDBO MPSP P PJSM install 3"'HP' BPV 06:15 06:45 0.50 0 0 MIRU WHDBO SFTY P Pre-Spud meeting Jason's crew. 06:45 07:15 0.50 0 0 MIRU WHDBOOTHR P Rig down circulating equipment. 07:15 09:30 2.25 0 0 MIRU WHDBO NUND P Nipple down tree and adapter with top drive. Inspect hanger threads; in poor condition. Clean threads and work installing dart,6 turns achieved. 09:30 12:00 2.50 0 0 MIRU WHDBO NUND P Nipple up DSA, BOPE and riser. 12:00 13:00 1.00 0 0 MIRU WHDBO RURD P Rig up to test BOPE's. . Page 2 of 11 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 17:30 4.50 0 0 MIRU WHDBO BOPE P TestBOPE's 250/3000 psi with 2-7/8" test joint. Test witness by AOGCC inspector Jeff Jones. 1, Blinds; Kill Demco; Chokes 1,2, 3, 16-pass 2. HCR kill; chokes 4, 5, 6-pass 3. Manual kill; chokes 7, 8, 9-pass 4. manual and hydraulic choke 5. chokes 10, 11 -pass 6. Choke 12, 13, 14 low fail. Grease choke-pass 7.Annular with test joint, HCR kill, HT40 Dart valve;choke 15-pass 8. Top rams with test joint, HCR choke,TIW-pass 9. Manual choke-pass 10 LPR with test joint-pass 11 Hydraulic IBOP, outer test spool- pass 12. Manual IBOP, inner test spool- pass Accumulator test:starting pressure 2950 psi, final pressure 1800 psi. First 200 recharge 28 seconds, final recharge 124 seconds. 6 N2 bottles with 1998 psi average. Tested Upper&Lower VBR'S,& annular with 2 7/8"test joint.Two TIW ball type valves, HT-40 and 3 1/2 EUE Misc.=2-3 1/8 5K"Test Spool Valves. Fail/Passes-Choke valve#14 leaked on initial test,Greased valve retested good.LEL Audible in cellar failed, H2S Alarm failed to activate on rig floor. Repaired both, recalibrated and retested good. 17:30 18:30 1.00 0 0 MIRU WHDBO RURD P Rig down test tools, blow down lines. 18:30 19:00 0.50 0 0 MIRU WHDBOMPSP P Pull 3"'HP' BPV 19:00 20:30 1.50 0 0 COMPZ RPCOM PULL P Make up BHA#1 Itco spear dressed with 2.440"grapple. Engage tubing hanger. BOLDS. Pull hanger to the floor. Hanger free at 60K. Pulled up to 95K(35K blocks)sudden drop in weight to 80K. Lay down hanger. 20:30 21:00 0.50 0 0 COMPZ RPCOM RURD P Rig up Weatherford casing tongs 21:00 22:30 1.50 0 0 COMPZ RPCOM CIRC P Circulate hole volume at 5 bpm 1290 psi. Monitor well for 15 minutes. 22:30 23:00 0.50 0 0 COMPZ RPCOM RURD P Rig up Camco control line spooling unit. 23:00 00:00 1.00 8,577 8,073 COMPZ RPCOM PULL P POOH with 3-1/2"decompletion from 8,577 to 8073' PUW 75K SOW 65k; Spooling up control line. Page 3 of 11 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/07/2015 24 hr Summary Continue to POOH laying down 2-7/8"tubing to 2907'. PU, MU, RIH,and set storm packer at 98.5'; PT storm packer to 3000 psi for 15 minutes(good test). ND BOPE, ND DSA, and break bolts to RU Hydratight. Some of the bolts corroded needing to be cut off. ND tubing head using Hydratight to control the casing growth (casing growth= 1-3/4"). Spear the 7"casing and pull 100K(15K over string weight). Casing stretched an additional 6-1/4"for a total of 8"of casing growth. Set the 7"casing slips and cut off the excess casing with the Wachs cutter. Install casing pack off and NU new tubing head. PT void to 250/3000 psi (good test). NU DSA and NU BOPE. Shell test and test flange break between casing head and tubing head to 3000 psi against the storm packer(good test). Install test plug, MU HT-40 TIW to 4"test joint and test the annular, upper pipe rams, lower pipe rams to 250/3000 psi with 4"test joint(all test passed). 00:00 02:00 2.00 8,073 6,792 COMPZ RPCOM PULL P Continue to POOH with de-completion spooling up control line from 8073'to 6792'. 02:00 02:15 0.25 6,792 6,786 COMPZ RPCOM PULL P Lay down SCSSSV. Rig down spooling unit. 32 SS bands recovered. 02:15 05:00 2.75 6,786 3,994 COMPZ RPCOM PULL P Continue to POOH laying down 2-7/8"de completion to 3994'(PU= 69K, SO=56K). 05:00 05:45 0.75 3,994 3,994 COMPZ RPCOM BHAH P PJSM. PU and MU crossovers to storm packer assembly. Lay storm packer assembly down. 05:45 06:45 1.00 3,994 2,907 COMPZ RPCOM PULL P Continue to POOH laying down 2-7/8"with de completion to 3994'to 2907'(PU=53K, SO=47K). 06:45 07:30 0.75 2,907 2,907 COMPZ WELLPF BHAH P PU and MU to storm packer assembly. 07:30 08:30 1.00 2,907 0 COMPZ WELLPF MPSP P RIH and set storm packer at 98.5'. Release from storm packer, stand back 1 stand of DP, and PT storm packer to 3000 psi for 15 minutes (good test). Bleed pressure to 0 psi and blow down lines. 08:30 09:30 1.00 0 0 COMPZ WELLPF NUND P PJSM. Pull mouse hole and riser. ND BOP and ND DSA. 09:30 14:00 4.50 0 0 COMPZ WELLPF NUND P PJSM. ND secondary annulus valve. Break bolts to RU Hydratight. Some of the bolts corroded needing to be cut off. ND tubing head using Hydratight to control the casing growth(casing growth= 1-3/4"). RD Hydratight. 14:00 15:00 1.00 0 0 COMPZ WELLPF WWSP P Remove tubing head. MU Cameron pack off puller and pull pack off. 15:00 16:00 1.00 0 0 COMPZ WELLPF CUTP P PU and MU 7"casing spear. Spear the 7"casing and pull 100K(15K over string weight). Casing stretched an additional 6-1/4"for a total of 8"of casing growth. 16:00 17:00 1.00 0 0 COMPZ WELLPF CUTP P Set the 7"casing slips, release the spear and lay down the spear. Cut off the excess casing with the Wachs cutter. 17:00 18:00 1.00 0 0 COMPZ WELLPF WWSP P Prep the casing head, install casing pack off, and NU new tubing head. Page 4 of 11 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 19:00 1.00 0 0 COMPZ WELLPF PRTS P Plastic pack the NX bushing to 4000 psi. PT void to 250/3000 psi(good test). 19:00 21:30 2.50 0 0 COMPZ WELLPF NUND P NU DSA, NU secondary annulus valve, and NU BOPE. Install riser and mouse hole. 21:30 22:00 0.50 0 0 COMPZ WELLPF BOPE P Shell test and test flange break between casing head and tubing head to 3000 psi against the storm packer(good test). 22:00 00:00 2.00 0 0 COMPZ WELLPF BOPE P Install test plug, MU HT-40 TIW to 4" test joint and test the annular, upper pipe rams, lower pipe rams to 250/3000 psi with 4"test joint(all test passed) 07/08/2015 Test the annular, upper pipe rams, lower pipe rams to 250/3000 psi with 3-1/2"test joint(all test passed). RIH, equalize the storm packer, release the storm packer, POOH, and lay down storm packer. POOH laying down 2-7/8"tubing from 2907'to tubing cut(cut joint= 13.34'). PU, MU, and single in the hole with 5-3/4" overshot assembly for 2-7/8"tubing on 4" DP to 8554' RKB. Unable to get the top drive to rotate; call out the electrician to trouble shoot and fix the issue. 00:00 01:45 1.75 0 0 COMPZ WELLPF BOPE P MU HT-40 TIW to 3-1/2"test joint and test the annular, upper pipe rams, lower pipe rams to 250/3000 psi with 3-1/2"test joint(all test passed). 01:45 02:15 0.50 0 0 COMPZ WELLPF BOPE P RD BOPE testing equipment, lay down 3-1/2"test joint, pull test plug, install wear ring,and blow down lines. 02:15 02:45 0.50 0 3,005 COMPZ WELLPF MPSP P PU and MU storm packer retrieval tool. RIH, equalize the storm packer, and release the storm packer. 02:45 03:00 0.25 0 3,005 COMPZ WELLPF OWFF P Observe the well for flow for 10 minutes;well static. 03:00 03:30 0.50 3,005 2,907 COMPZ WELLPF BHAH P Lay down 3 joints of DP and lay down storm packer with retrieval tool. 03:30 03:45 0.25 2,907 2,907 COMPZ RPCOM RURD P Change elevators to 2-7/8"and RU Weatherford tongs. 03:45 07:45 4.00 2,907 0 COMPZ RPCOM PULL P POOH laying down 2-7/8"tubing from 2907'to tubing cut(cut joint= 13.34'). 07:45 09:45 2.00 0 0 COMPZ RPCOM RURD P RD Weatherford tubing equipment, Clean and clear rig floor, Offload pipe shed, SimOps: Load the pipe shed with bumper sub/jars and load 4-3/4" DC's. 09:45 10:15 0.50 0 0 COMPZ RPCOM SVRG P Service the top drive and draw works. 10:15 11:15 1.00 0 1 COMPZ RPCOM RURD P Bring overshot tools to the rig floor. Lay down crossovers that are not needed on the rig floor. Page 5 of 11 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:15 14:30 3.25 0 225 COMPZ RPCOM BHAH P PJSM. RU manual tongs and 3-1/2" elevators. PU and MU BHA#1 - 5-3/4"overshot assembly with six 4-3/4" DC's. 14:30 22:00 7.50 225 8,554 COMPZ RPCOM PULD P Change elevators to 4"DP and single in the hole with BHA#1 on 4"HT-40 DP to 8554'RKB 22:00 22:30 0.50 8,554 8,554 COMPZ RPCOM FISH P Install blower hose. Obtain fishing parameters: PU= 160K, SO= 115K,4 BPM=400 psi.. 22:30 23:00 0.50 8,554 8,554 COMPZ RPCOM SVRG T Service TD and draw works. 23:00 00:00 1.00 8,554 8,554 COMPZ RPCOM RGRP T Unable to get the top drive to rotate. Call out the electrician to trouble shoot and fix the issue. 07/09/2015 Continue to trouble shoot and fix the issue with the top drive not being able to rotate. Tag to of tubing stub at 8567', SO to 8572', and engage overshot with 15K down. PU 20K over string weight and OEJ seal barrel pulled free. TOOH standing back DP from 8572'to 215'. 00:00 17:00 17.00 8,554 8,554 COMPZ RPCOM RGRP T Continue to trouble shoot and fix the issue with the top drive not being able to rotate. SimOps: Load, strap, and tally 3-1/2"tubing. Clean the rig and equipment/tools. Inventory crossover subs and lifting subs. 17:00 17:30 0.50 8,554 8,554 COMPZ RPCOM SVRG T Service the rig 17:30 18:45 1.25 8,554 8,572 COMPZ RPCOM FISH P Obtain fishing parameters: PU= 160K, SO= 115K,40 RPM, rotating weight= 130K,4 BPM =380 psi. SO,tagged tubing stub at 8567', continued down to 8572'with 15K down (observed pressure increase as overshot went over tubing stub), PU to 180K(20K overpull)and OEJ seal barrel pulled free. Turn the pumps on at 4 BPM, SO, and saw pressure increase 10' indicating seal barrel going over slick stick. 18:45 19:00 0.25 8,572 8,572 COMPZ RPCOM OWFF P Observe the well for flow;well is on a slight vac. 19:00 19:15 0.25 8,572 8,572 COMPZ RPCOM RURD P Remove blower hose and blow down the top drive. 19:15 23:45 4.50 8,572 215 COMPZ RPCOM TRIP P TOOH from 8572' BHA#1 -5-3/4" overshot assembly for 2-7/8"tubing with fish. 23:45 00:00 0.25 215 215 COMPZ RPCOM OWFF P Observe the well for flow prior to pulling DC's;well on a slight vac. 07/10/2015 Lay down 5-3/4"overshot assembly for 2-7/8"tubing and lay down cut joint and lay down OEJ seal barrel. PU, MU, and TIH with 5-3/4"overshot assembly for OEJ slick stick to 8592' RKB. Engage overshot with 15K down, PU 15K to verify overshot is engaged, PU to 200K to set the jar, PU to 240K, and packer released. Circulate bottoms up at 4.5 BPM=525 psi; seen minimal packer gas just past bottoms up. TOOH with overshot assembly and lay down packer with 2-7/8"tail pipe fish. PU, MU, and TIH with cleanout assembly to 8824', circulate 1.5 hole volumes at 6 BPM=865 psi,and POOH laying down DP to 7447'RKB at midnight. Page 6 of 11 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 215 0 COMPZ RPCOM BHAH P PJSM. Lay down BHA#1 -5-3/4" overshot assembly for 2-7/8"tubing and lay down cut joint and lay down OEJ seal barrel. Clean the floor. 02:00 02:45 0.75 0 216 COMPZ RPCOM BHAH P PU and MU BHA#2-5-3/4"overshot assembly for OEJ slick stick and 2 stands of 4-3/4"DC's. 02:45 05:30 2.75 216 8,587 COMPZ RPCOM TRIP P TIH with BHA#2 to 8587' RKB(PU= 170K, SO= 105K). 05:30 05:45 0.25 8,587 8,592 COMPZ RPCOM FISH P Tag top of OEJ slick stick at 8592' RKB, set down 15K, PU 15K to verify overshot is engaged, PU to 200K to set the jar, PU to 240K, and packer released (PU= 175K, SO= 106K). 05:45 07:00 1.25 8,592 8,592 COMPZ RPCOM CIRC P Circulate bottoms up at 4.5 BPM 525 psi; seen minimal packer gas just past bottoms up. 07:00 07:15 0.25 8,592 8,592 COMPZ RPCOM OWFF P Observe the well for flow for 10 minutes,well is on a slight vac. 07:15 11:30 4.25 8,592 216 COMPZ RPCOM TRIP P TOOH with BHA#2 and packer fish 11:30 11:45 0.25 216 216 COMPZ RPCOM OWFF P Observe the well for flow prior to pulling DC's;well on a slight vac. 11:45 14:00 2.25 216 0 COMPZ RPCOM BHAH P Stand back 2 stands of DC's and lay down BHA#2 14:00 14:15 0.25 0 0 COMPZ RPCOM RURD P RU Weatherford tongs. 14:15 15:00 0.75 0 0 COMPZ RPCOM PULL P Lay down packer and 2-7/8"tail pipe. 15:00 15:30 0.50 0 220 COMPZ WELLPF BHAH P Clean and clear the floor. Change elevators to 3-1/2"and bring cleanout tools to the rig floor. PU and MU BHA#3-cleanout assembly and 2 stands of 4-3/4" DC's. 15:30 17:00 1.50 220 3,737 COMPZ WELLPF TRIP P TIH with BHA#3 to 3737' RKB 17:00 17:30 0.50 3,737 3,737 COMPZ WELLPF SVRG P Service rig. 17:30 20:00 2.50 3,737 8,590 COMPZ WELLPF TRIP P Continue toTIH with BHA#3 to 8590' RKB. 20:00 20:30 0.50 8,590 8,824 COMPZ WELLPF PULD P PU DP from the pipe shed to 8824' (PU = 180K, SO= 105K). 20:30 22:15 1.75 8,824 8,817 COMPZ WELLPF CIRC P PU to 8818' RKB and circulate 1.5 hole volumes at 6 BPM=865 psi. Shut down the pumps. 22:15 22:30 0.25 8,817 8,817 COMPZ WELLPF OWFF P Observe the well for flow for 10 minutes,well on a slight vac. Blow down the TD. 22:30 00:00 1.50 8,817 7,447 COMPZ WELLPF PULD P POOH with BHA#3-clean out assembly laying down DP from 8817' to 7447' RKB. 07/11/2015 Continue to POOH with cleanout assembly laying down DP from 7447'to BHA. Lay down six 4-3/4"DC's and BHA. PU and MU 2 wearsoxs, nipple assembly, packer assembly, and RIH with 3-1/2"tubing per tally to 4730' RKB. RU two Halliburton control line spoolers and sheave. PU and MU Orbit Barrier Valve. Continue to RIH with 3-1/2"tubing per tally from 4730'to 6997' RKB installing a cross coupling cannon clamp on every connection. 00:00 06:00 6.00 7,447 220 COMPZ WELLPF PULD P Continue to POOH with BHA#3- cleanout assembly laying down DP from 7447'to 220' RKB. Page 7 of 11 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 08:00 2.00 220 0 COMPZ WELLPF BHAH P Lay down six 4-3/4" DC's and BHA #3-cleanout assembly. Clean and clear the floor. 08:00 08:30 0.50 0 0 COMPZ RPCOM RURD P Pump out the BOP stack, MU wear ring pulling tool, and pull the wear ring. 08:30 09:15 0.75 0 0 COMPZ RPCOM RURD P RU Weatherford tubing running tongs and change elevators to 3-1/2"tubing 09:15 10:30 1.25 0 0 COMPZ RPCOM RURD P Finish loading the pipe shed with completion jewelry and organizing in _ running order. 10:30 17:00 6.50 0 4,730 COMPZ RPCOM PUTB P PJSM. PU and MU 2 wearsoxs, nipple assembly, packer assembly, and RIH with 3-1/2"tubing per tally to 4730' RKB. 17:00 18:00 1.00 4,730 4,730 COMPZ RPCOM RURD P RU two Halliburton control line spoolers and sheave. 18:00 18:15 0.25 4,730 4,730 COMPZ RPCOM PUTB P PU and MU Orbit Barrier Valve. 18:15 20:15 2.00 4,730 4,730 COMPZ RPCOM PRTS P MU the control lines to the open and closed ports, PT both lines to 3000 psi, and function test Orbit Barrier Valve. 20:15 00:00 3.75 4,730 6,997 COMPZ RPCOM PUTB P Continue to RIH with 3-1/2"tubing per tally from 4730'to 6997' RKB installing a cross coupling cannon clamp on every connection. Note: Installed 1 stainless steel band above the Orbit valve, 1 stainless steel band on GLM above the Orbit valve, and a cannon clamp across each control line splice on joint#189. 07/12/2015 Continue to RIH with 3-1/2"tubing per tally from 6997'to 8774' RKB installing a cross coupling cannon clamp on every connection. RU SLB DSL with lubricator, correlate completion to the K-1 at 8356', set'XX'plug in'X' nipple, and RD SLB DSL. Spot 10 bbl CI pill, set FHL packer per Baker rep at 8589', shear the PBR, space out with pups, MU the tubing hanger, MU the control lines to the tubing hanger, circulate 234 bbl of CI brine followed by 72 bbls of brine, land the tubing hanger, and RILDS. PT the tubing to 3000 psi for 15 minutes (good test), bleed the tubing to 2000 psi, and PT the IA to 3000 psi for 30 minutes(good test)(both charted). Bleed the IA to 0 psi, bleed the tubing to 0 psi, and pressure up on the IA to shear the SOV at 1900 psi. 00:00 00:15 0.25 6,997 7,028 COMPZ RPCOM PUTB P Continue to RIH with 3-1/2"tubing per tally from 6997'to 7028' RKB installing a cross coupling cannon clamp on every connection. 00:15 00:30 0.25 7,028 7,028 COMPZ RPCOM PUTB T Connection between joint#214 and #215 did not make up properly. Backed out joint,the threads galled, and the pin on#215 was missing a small chunk of thread(appears to be a manufacturing issue on the pin thread of joint#215). Replaced the collar on joint#214 and MU spare joint from outside to replace joint #215. Page 8 of 11 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 04:00 3.50 7,028 8,774 COMPZ RPCOM PUTB P Continue to RIH with 3-1/2"tubing per tally from 7028'to 8774' RKB installing a cross coupling cannon clamp on every connection. 04:00 06:45 2.75 8,774 8,774 COMPZ RPCOM ELOG P PJSM. RU SLB DSL to perform E-line correlation log. RU lubricator with 20'extension and PT to 1000 psi. 06:45 09:00 2.25 8,774 8,774 COMPZ RPCOM ELOG P RIH with gamma ray and CCL(tool length 47')and correlate to the K-1 marker at 8356'. POOH with gamma ray and CCL. 09:00 10:00 1.00 8,774 8,774 COMPZ RPCOM ELOG P RD lubricator, lay down lubricator in the pipe shed, and set tools off to the side. 10:00 10:30 0.50 8,774 8,768 COMPZ RPCOM HOSO P Lay down joint#270 and space out with two 10'pup joints to 8768' RKB (PU = 105K, SO=75K) 10:30 12:00 1.50 8,768 8,768 COMPZ RPCOM CRIH P Spot 8.9 ppg corrosion inhibited brine pill around the PBR/FHL packer by pumping 10 bbls of CI brine followed by 74 bbls of 8.9 ppg brine at 2 BPM = 165 psi. 12:00 14:30 2.50 8,768 8,768 COMPZ RPCOM SLKL P RU lubricator, MU'XX'plug with gamma ray/CCL, and RIH. Confirm correlation depth with gamma ray/CCI and set'XX'plug in'X' nipple. POOH. 14:30 15:45 1.25 8,768 8,768 COMPZ RPCOM SLKL P Break down slickline tools and RD lubricator. 15:45 16:15 0.50 8,768 8,768 COMPZ RPCOM PACK P Set FHL packer per Baker rep: pressure up on the tubing to 2000 psi, hold for 5 minutes, and continue to pressure up to 3000 psi(PBR sheared at 3000 psi). 16:15 16:30 0.25 8,768 8,768 COMPZ RPCOM PRTS P PT the tubing to 3000 psi for 15 minutes(good test). 16:30 17:00 0.50 8,768 8,768 COMPZ RPCOM SLKL P Lay down DSL lubricator and remove DSL tools from the rig floor. 17:00 17:30 0.50 8,768 8,768 COMPZ RPCOM RURD P RD circulating equipment. 17:30 18:30 1.00 8,768 8,553 COMPZ RPCOM HOSO P PU to confirm PBR sheared, SO, locate out, mark the pipe, PU,and space out. Lay down two 10'pups, joint#269, and#268. MU 6.11'pup and joint#268. 18:30 19:00 0.50 8,553 8,553 COMPZ RPCOM THGR P MU tubing hanger to landing joint, MU TIW, and MU circulation hose. 19:00 19:30 0.50 8,553 8,553 COMPZ RPCOM RURD P RD Halliburton control line sheave. Page 9 of 11 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 20:15 0.75 8,553 8,553 COMPZ RPCOM THGR P MU both control lines to the bottom of the tubing hanger, install a stainless steel band on tubing hanger pup joint, MU both control lines to the top of the tubing hanger. PU,control lines still had some slack therefore attempted to place a stainless steel band in the middle of the joint below of tubing hanger pup, banding tool broke,so installed a cannon clamp. 20:15 21:45 1.50 8,553 8,564 COMPZ RPCOM CRIH P Roll the pump, locate the top seal in the PBR, PU 2'and circulate 234 bbls of 8.9 ppg corrosion inhibited brine followed by 72 bbls of brine at 4 BPM =483 psi. 21:45 22:30 0.75 8,564 8,582 COMPZ RPCOM THGR P Drain the BOP stack, land the tubing hanger, and RILDS. 22:30 23:30 1.00 8,582 8,582 COMPZ RPCOM PRTS P PT the tubing to 3000 psi for 15 minutes(good test), bleed the tubing to 2000 psi, and PT the IA to 3000 psi for 30 minutes(good test)(both charted). Bleed the IA to 0 psi and bleed the tubing to 0 psi. 23:30 00:00 0.50 8,582 8,582 COMPZ RPCOM CIRC P Pressure up on the IA to shear the SOV at 1900 psi. Pump 1 bbl down the IA to ensure the SOV is open and pump 1 bbl down the tubing to ensure the SOV is open at 1 BPM= 70 psi. X7/13/2015 Close the Orbit Barrier Valve. PT the Orbit valve from above to 1000 psi for 5 minutes(good test)and PT the Orbit valve from below in the direction of flow to 1000 psi for 5 minutes(good test). Install the 3"'H' BPV. ND the BOP stack, set back on the stump, installed test dart, NU the tubing head adapter,and NU the tree. Function tested the Orbit Barrier Valve, PT the tubing hanger void to 250/5000 psi, and PT the tree to 250/5000 psi (all good tests). Pulled the test dart/BPV with dry rod and freeze protect the well with diesel by pumping 78 bbls of diesel down the IA taking return out the tubing. Place the tubing and IA in communication, allow to u-tube, and pressures equalized at 150 psi. Bleed off remaining pressure to zero and install the 3" 'H' BPV with dry rod. Secure tree and cellar. Install valves and gauges. Clean and clear the cellar. Released the rig at 17:00 hours. 00:00 00:30 0.50 8,582 8,582 COMPZ RPCOM PRTS P Close the Orbit Barrier Valve. PT the Orbit valve from above to 1000 psi for 5 minutes(good test), bleed tubing to 0 psi, PT the Orbit valve from below in the direction of flow to 1000 psi for 5 minutes(good test), and bleed the IA to 0 psi. 00:30 01:00 0.50 8,582 0 COMPZ RPCOM RURD P RD circulating equipment and lay down landing joint. 01:00 01:15 0.25 0 0 COMPZ WHDBO MPSP P Pump out the BOP stack and install the 3"'H' BPV. Page 10 of 11 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 02:30 1.25 0 0 COMPZ WHDBO OTHR P RD Weatherford tong and Halliburton control line spoolers. Clear the floor of the Weatherford tongs, slips, elevators, and dog collar. Clear the floor of both Halliburton control line spoolers and tool boxes. SimOps: Blow down choke line, kill line,TD, and mud pumps. 02:30 07:30 5.00 0 0 COMPZ WHDBO NUND P Break bolts on the BOP stack. Disconnect the kommey hoses and cap all ends, Pull riser. Pull mouse hole and lay down in the pipe shed. ND the BOP stack and set back on the stump. 07:30 08:30 1.00 0 0 COMPZ WHDBO NUND P Prepare cellar and ND 13-5/8"5M x 11"5M DSA, Install test dart and NU tubing head adapter. 08:30 10:00 1.50 0 0 COMPZ WHDBO NUND P NU tree to adapter, break at the actuator and orient the for proper install as per previous photo. 10:00 11:15 1.25 0 0 COMPZ WHDBO PRTS P Prep cellar and well head. Built the manifold for Baker Orbit valve while testing hanger void to 250/5000 psi. Function test orbit valve-good test. 11:15 12:00 0.75 0 0 COMPZ WHDBO PRTS P Test tree at 250/5000 psi for 5 minutes. 12:00 12:30 0.50 0 0 COMPZ WHDBO MPSP P Pull test dart and BPV with dry rod 12:30 14:30 2.00 0 0 COMPZ WHDBO FRZP P RU Little Red Services and freeze protect the well with diesel by pumping 78 bbls of diesel down the IA taking return out the tubing (ICP= 100 psi and FCP=700 psi). RD LRS. 14:30 15:30 1.00 0 0 COMPZ WHDBO FRZP P ISIP=250. Place the tubing and IA in communication,allow to u-tube, and pressures equalized at 150 psi. Bleed off remaining pressure to zero. 15:30 16:00 0.50 0 0 COMPZ WHDBO MPSP P Dry rod in 3"'H' BPV. 16:00 17:00 1.00 0 0 DEMOB MOVE RURD P Secure tree and cellar. Install valves and gauges. Clean and clear the cellar. Final well pressures: Tubing=0 psi, IA=0 psi, and OA=0 psi. Release rig Nabors 9ES at 17:00 hrs on 7-13-15 Page 11 of 11 e 9- 7 KUP PROD 3K-01 ConocoPhillips ® }Well Attributes Max Angle&MD TD AlaskaINCWellbore APIUWI Field Name Wellbore Status Ingle) MD(kKB) Act Btm(ftKB) L- m.,,, / 500292160000 KUPARUK RIVER UNIT PROD 47.53 3,800.009.150.0 ••• Comment 1125(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3K-01,7232015 5 53 27 PM SSW:TRDP LOCKED OUT 130 3/9/2014 Last WO: 7/512015 40.78 8,27/1986 Vertical schematic(a:lu,, I • Annotation Depth(kK8) End Dale Annotation Last Mod By End Date Last Tag:SLM 8,841.0 2/162015 Rev Reason:WORKOVER smsmith 7123/2015 HANGER:35.0 ;Cff)0 Casing Strings ' Caning Descrlpkan OD(In) ID(In) Top(888) Set Depth(888) Sat Depth(1V0)...Wt/Len(1...Grade Top Thread CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELDED J • Casing Description OD(in) •ID(In) Top(MB) •Set Depth(MB) Set Depth(TVD)...WVLen(1...Grwle Top Thread 1 SURFACE 95!8 8.921 37.0 4,919.2 3,852.4 36.00 7-55 BTC Casing Description OD(In) ID(In) Top(1589) Set Depth(kKB) Set Depth(160)...WVlen(1...Grade Top Thread ,r PRODUCTION 7 6.276 25.4 9.139.7 6,870.9 26.00 J-55 BTC Tubing Strings CONDUCTOR,78.0-115.0 .. Tubing Description [String Ma...I ID(In) [Top(IIKB) [Set Depth((1..,861 Depth(TVD)(...[WI(IbM) (Grade [Top Connection TUBING-WO 2015 II 3 1.2 2.992 35.0 8.768 OI 6,605.311 9.30 L-BO EUE Brd Moo Completion Details GAS LIFT;2,962.5 al Nominal ID ! Top(kKB) Top(TVD)(kKB) Top Incl(•) Item Des Com (In) I 35.0 4,020.5 35.0 0.09 HANGER CAMERON CXS TUBING HANGER 2.950 3,236.5 47.29 BARRIER VLV BAKER ORBIT BARRIER VALVE W.2 CONTROL LINES 2.890 BARRIER VLV;4,020.5 II 8,559.8 6,453.9 42.85 LOCATOR BAKER GBH-22 LOCATOR SUB 2.980 in 8,560.8 6,454.7 42.85 SEAL ASSY BAKER 80-40 GBH-22 SEAL ASSEMBLY 2.980 III 8,566.4 6,458.8 42.85 PBR BAKER 80-40 PBR 4.000 GAS LIFT;4,766.9 a 8,589.5 6,475.7 42.84 PACKER BAKER 47B2 FHL RETRIEVABLE PACKER 2.920 III I 8,642.9 6,514.8 43.27'NIPPLE HALLIBURTON X NIPPLE 2.813 8,684.6 6,545.0 43.69 XO Enlarging Ported Crossover,3-1/2'EUE 8-rd Mod Box x 5-1/2"STC 2.992 Pin SURFACE;37.0.4,9193 0 s.. 8,685.6 6,545.7 43.70 WEARSOX 6"OD Wearsox,5-1/2".149.7-55,STC Boxx Pin 5.012 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD[ Top Intl GAS LIFT.8.175.8 Top(NKB[ (kKB) I') Des Com Run Date ID(In)8,642.9 6.514.8 43.27 'XX'Plug 'XX'Plug 7/12/2015 0.000 -8,977.0 6.755.1 44.60 FISH DMY 1 L2'DMY Dropped In Rathole 10/17/1986 10/17/1986 0.000 GAS LIFT.7,229.4 Perforations&Slots Shot ' I Dene Top(TVD) atm(TVD) (shotsn Top(ftK8) Btm(kKB) (kKB) (1188) Zone Date 1) Type Com 8.818.0 8,850.0 6.611.4 6,664.4 Ate,A-3,3K- 6/6/1990 6.0 RPERF 2 1/8"Dyna Ship;0 deg. GAS LIFT.8,005.9 ■ 01 ph I 8.824.0 8,844.0 6.6(5.7 6,660.1 A-0,A-3,3K- 5/161996 - 4.0-RPERF 21/8"67:180 deg ph: 01 Orient♦1-90 deg F/ lowside GAS LIFT,6.505.2 a 8.830.0 8,831.0 6,650.0 6,650.7 A-3,3K-01 8/25/1986 1.0 IPERF 4"Csg Gun;120 deg.ph 8.834.0 8,835.0 6,652.9 6.653.6 A-3,3K-01 8/2511986 1.0 IPERF 4"Csg Gun;120 deg.ph LOCATOR.8,559.8 _ 8,836.0 8,837.0 6,654.3- 6,655.0 A-3,38-01 8/25'1986 1.0 IPERF 4"Csg Gun;120 deg.ph SEAL ASSY;8,500,8 PBR,8,568.4 i___,l 8,850.0 8,895.0 6,664.4 6,697.3 A-3,A-2,3K- 6/61990 6.0 RPERF 2 1/8"DynaStrip;0 deg ph PACKER;9.189.0 01 8.858.0 8,859.0 6,670.1 6,670.9 A-2,3K-01 8/2511986 - 1.0 IPERF 4"Csg Gun;120 deg.ph '88'Plug;9,642 0 8.865.0 8,866.0 6,675.2 6.675.9 A-2,38-01 8125/1986 1.0 IPERF 4"Csg Gun;120 deg.ph NIPPLE;0,642,0, 8,869.0 8,870.0 6,678.0 6,678.7 A-2 3K-01 8/25'1986 1.0 IPERF 4"Csg Gun;120 deg.ph x0 Enlarging;8.684.5 I 8.873.0 8,874.0 6,680.9 6,681.6 A-2,3K-01 8125;1986 1.0 IPERF 4"Csg Gun;120 deg.ph WEARBO)C 8,685.5 I E 8,876.0 8,877.0 6,6883.0. 6,683.8 A-2,3K-01 8/25:1986 1.0 IPERF 4"Csg Gun;120 deg.ph' 8,881.0 8,893.0 6886.6' 6,695.2 A-2,3K-01 82501986 4.0 IPERF 4"Csg Gun;120 deg.ph- - Mandrel Inserts IPERF a 830.04.831.0-. RPERF:9.824.0-0,044.0 - St RPERF-8818.0-8.950.0 aft IPERF;8,634.0-8,035.0 N Top(TVD) Valve Latch Poll Size TRO Run Top(ftKB) (kKB) Make Model OD(In) Sets Type Type tin) (psi) Run Date Com 1 2,962.5 2,508.7 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 7/122015 IPERF.8.636.46837.0 f. 2 4,766.9 3,746.1 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 7/12/2015 3 6,175.6 4,740.1 CAMCO MMG 112 GAS LIFT DMY RK 0.000 0.0 7/12/2015 - 4 7,229.4 5,491.9 CAMCO MMG 1 1:2 GAS LIFT SOV RKP 0.000 0.0 7/12/2015 5 8,005.6 6,052.4 CAMCO MMG 1 112 GAS LIFT DMY RK 0.000 0.0 7/12:2015 6 8,503.2 6,412.4 CAMCO MMG 1 112 GAS LIFT DMY RK 0.000 0.0 7/122015 PERF.a.esa.aa.e5s.a- Notes:General&Safety IPERF,8,965.0.8.099.0 End Date Annotation 8/26/2002 'NOTE:Mandrel#7 should be left alone,severe deflector damage,see WSRs IPERF'9869.0.8.870.0 8/30/2004 NOTE:WAIVERED WELL:IA x OA COMMUNICATION RPERF,6.650.48,958.0 112/2010 NOTE:View Schematic v.,/Alaska Schematic9.0-BAD PROD CSG RKB IPERF'9 67304.674.0 IPERF'8 0760.8677.0 IPERF 8 881.04893.0 FISH;8,977.0 7 I PRODUCTION;25.44139.7 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. l _~_~ _./'_~) Z/ Well History File Identifier Organization (done) RESCAN Color items: Grayscale items: DIGITAL DATA [] Diskettes, No. [] Other, No/Type [] Poor Quality Originals: ..~"Other:~~-~ ~ ~ TOTAL PAGES: ~ <~ NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL 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: Is~ PAGES:~" (at the time of scanning) SCANNED BY; BEVERLY BRE~SHERYL MARIA LOWELL ReScanned (done) RESCANNED BY.' BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /si General Notes or Comments about this file: PAGES: ~' Quality Checked (done) ScblUmbel'ger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well Job# 1 R-27 31-08 2M-19 3G-26 1R-18 1Y-01 2C-08 3H-32 1Y-10 3G·08 1A-06 2N-337B 2U-08 1G-12 2N-343 2N-327 2N-327 3K·01 2X-04 2Z-29 2X-19 1A-20 1F-13 1H-10 1Q-10 2U-05 2D-12 2H-06 11850425 11839638 11813070 11813071 11837482 11813072 11813073 11837483 11837485 11813075 11837486 11837489 11813076 11837490 11745232 11837491 11837491 11632749 11846430 11850419 11850420 11850421 11850422 11846432 11846431 11846433 11846434 11846435 2 '7 ZOG7 cmnrn\ss\Qf1 d, sç~a:> ¡;'\JG :I 11(\(\1 Log Description FPIT ¡q / - 10;).. LDL ¡'>r/A-rM\ INJECTION PROFILE lIT" ,A 1-12-::'1 LDL 1~'7-n-:}K SBHP/DDL JC) 1 -' ^ 15'9- INJECTION PROFILE U'1J'l. - J1íf3-öSó INJECTION PROFILE' (JTf\ l'fr~ -reA.""" LDL ..:JNJ - Ñ) I INJECTION PROFILE . V~ I~~ -a!:;'"" ) PRODUCTION PROFILE' 1~^ .()G:,fi- INJECTION PROFILE ÍY-rC' 1"lr1-11l- PRODUCTION PROFILE . ,t:)tV ~ -II A -=<\ LDL W17t , 1r<.,- -;-.,/=)..I PRODUCTION PROFILE 1153. - I~d. MEM INJECTION PROFILE . ()T(' ,0]'1("- rA:J SONIC SCANNER 6b ~ -0<00:, SONIC SCANNER-FMI ......"-" .r ..... PRODUCTION PROFILE . IffCt, ~ I";' INJECTION PROFILE I ,-'r.f\ )<;,~ -11 *' SBHP SURVEY /1f1r":')(:JCJ SBHPSURVEY I~~-/~,~- SBHP SURVEY I ~() - IC:J. SBHP SURVEY l) 'J:f' 1St:?" -IL/(J SBHP SURVEY je¡:,-~ SBHP SURVEY J'1fL.t - ICVx INJECTION PROFILE I ~ -r.(\. Hr..ç- - tJl~ PRODUCTION PROFILE 1111./ - /"A4 LDL 1¿¡ç,t:; -'IA~ NO. 4384 Company: Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Date BL 08118/07 1 07/28/07 1 07/29/07 1 07/30/07 1 07/31/07 1 07/31/07 1 08/01/07 1 08/01/07 1 08/03/07 1 08/04/07 1 08/04/07 1 08/06/07 1 08/06/07 1 08/07/07 1 08/08/07 1 08/08/07 08/08/07 08/12/07 1 08/13/07 1 08/13/07 1 08/13/07 1 08/14/07 1 08/14/07 1 08/14/07 1 08/14/07 1 08/15/07 1 08/16/07 1 08/17/07 1 Kuparuk Color CD 1 1 'd?1' Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 08/22/07 . . . . ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 .JUL .5) ~ ;., ..) ~ ~" 6! ~Jrnr(;ì July 28, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK. 99501 \ <6"Cu- fD' SCANNED AUG 0 1 2007 Dear Mr. Maunder: EnclDsed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ) ----(- 7 /1- 'illo?- Perry KI . ConocoPhillips Well Integrity Supervisor . . JUL 3 l 2007 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/28/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft na gal 3K-1 186-101 19' 2.6 19" 7/7/2007 7 7/27/2007 3K-2 186-102 53' 7.2 9" 7/7/2007 3.7 7/22/2007 3K-3 186-103 43' 5.8 11 " 7/7/2007 4.2 7/27/2007 3K-5 186-123 66' 9.0 26" 7/7/2007 9.6 7/22/2007 3K-6 186-124 58' 7.9 13" 7/10/2007 4.8 7/22/2007 3K-7 186-125 70' 10.5 35" 7/7/2007 13.2 7/22/2007 3K-8 186-126 54' 4.0 9" 7/10/2007 3.6 7/22/2007 3K-9 186-174 26' 9.0 16" 7/10/2007 6 7/22/2007 3K~11 186-164 43'- 6.5 21" . .. 7/10/2007 ... .. 7.8 7/16/2007 3K-13 186-136 8" none 8" 7/10/2007 3.1 7/16/2007 .. 3K-14 186-137 8" none 8" 7/10/2007 3.1 7/16/2007 3K-15 186-138 50' 6.0 22" 7/10/2007 8.4 7/22/2007 3K-16 186-139 46' 7.0 27" 7/10/2007 9.6 7/22/2007 3K-17 186-152 56' 8.0 30" 7/10/2007 10.7 7/22/2007 3K-18 186-151 38' 5.5 23" 7/10/2007 . 8.4 7/22/2007 MEMORANDUM- State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner Tom Maunder, P. i. Supervisor DATE: May 18, 2001 FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit 3K Pad May 18,2001' I traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, SSV on 3K-27 would not pass the DP test. The valve was serviced & passed the re-test The AOGCC test report is attached for reference. I inspected 14 well houses on lQ Pad w/no problems witnessed. 'SUMMARY: I witnessed SVS testing in Kuparuk River Field. 14 wells, 28 components tested. 1 failure witnessed. 3.57% failure rate. 14 well houses inspected. Attachments: SVS KRU 3K 5-18-01jc CC; NON-CONF.IDENTIAL SVS KRU 3K 5-18-01jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Operator Rep: Emie Barndt AOGCC Rep: John Crisp Submitted By: Date: Field/Unit/Pad: Kuparuk River Unit 3K Pad Separator psi: LPS 65 HPS 5/18/01 We~ Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI T~p Code Code Code Passed GAS or CYCLE 13K-01 1861010 65 70 50 P P OIL 3K-03 1861030 65 70 55 P P OIL :~k-06 1861240 65 70 50 P P OIL 3K-09A 1861740 65 60 54 P P OIL 3K-10 1861630 65: 70 52 P P OIL 3K-11 1861640' 65 70 50 P P OIL ,, , 3K-14 1861370 65 60 58 P P OIL 3K-16 1861390 65 70 70 P P OIL 3K-17 1861520 65 60 35 P P oIL , , 3K-23 1970970 65 70 58 P P OIL 3K-24 1982490 65 70 50 P P OIL ,, 3K-27 1970460 65 70 52 P 4 OIL 3K-32 1970760 65 70 55 P P OIL 3K-35 1971090 65 70 50 P P OIL _ Wells: 14 Components: 28 Failures: I Failure Rate: 3.57% 1-39o ~av .. Remarks: RJF 1/16/01 Page 1 ofl SVS KRU 3K 5-18-01jc MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIAL .UNDER THIS PAGE ARCO Alaska, Inc. T-'-~!ephohe 907 27~ 12i 5 August 24, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in duplicate is a Report of Sundry Well Operations for the well listed below. WELL ACTION 3K-01 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer CC: J. R. Brandstetter ATe 1120 L. L. Perini ATe 1130 KeEl .4-9 w/o attachments A U 6 2 9 1998 Alaska Oil & Gas Cons, Commissio[~ Anchorage ARL:Q ,'"'.iss:,;a, lnc, is a Subsidiary of ,'..tl,'_,'i;[i,:,~ic;iii.i. ..... !.~ ,, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing 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 Location of well at surface 1434' FSL, 318' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1329' FSL, 804' FEL, Sec. 27, T13N, R9E, UM At effective depth 1622' FSL, 749' FEL, Sec. 27, T13N, R9E, UM At total depth 1687' FSL, 733' FEL, Sec. 27, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 9 1 5 0' feet 6877' feet 9055' feet 6809' feet 6. Datum elevation (DF or KB) 69' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number ,,3K-01 9. Permit number/approval number 86-101 / 90-564 10. APl number 50-029-21600 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) None Junk (measured) None Casing Length Structural Conductor 115' Surface 4 91 9' Intermediate Production 91 4 0' Liner Size Cemented 1 6" 1540 Poleset 9 5/8" 1400 Sx AS III & 350 Sx Class G 7" 270 Sx Class G 175 Sx AS I Measured depth True vertical depth 115' 115' 4919' 3851' 9140' 6870' 13. Perforation depth: measured 8818'-8896' true vertical 6640'-6696' 6 SPF 0 degree phasing 6 SPF 0 degree phasing Tubing (size, grade, and measured depth) 2 7/8" J-55 tbg w/ tail @ 8646' Packers and SSSV (type and measured depth) Camco HR-I-sp @ 8619', Camco TRDP-1A-SSA @ 1792' Stimulation or cement squeeze summary Refer to attached Well Service Report Intervals treated (measured) Refer to attached Well Service Report Treatment description including volumes used and final pressure Refer to attached Well Service Report REEEIVED ¸14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation (Producing) 245 60 -0- 1150 Subsequent to operation (Producing) 300 60 -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 17. I hereby certify that the foregoing is true and correct to the best of my kno¢ledge. 1150 Service Tubing Pressure 8O 8O Form 10-404 Rev 05/17/89 Title Sr. Operations Engineer Date SUBMIT IN DUPLICATE ARCO AlaSKa, Inc. Sul~sidiary of Atlantic Richfield Company WELL CONTRACTOR ir-~OT _MARKS IFIELD - DISTRICT-STATE IOPERATI~.~AT REPORT TIME WELL SERVICE REPORT IDAYS I DATE , "- ~, ~..L. I V EL) Alaska Oil & P~ COn,c,. r,,....,..,= .... Anchorage [--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeatherReport .]Temp' °F Chill Factor0F I Visibility miles IWind Vel. knots~[~x,~~/ STATE OF ALASKA APPLIL ATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _~_ Pull tubing _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic 4. Location of well at surface 1434' FSL, 318' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1329' FSL, 804' FEL, ,Sec. 27, T12N, R9E, UM At effective depth 1622' FSL,749' FEL, Sec.27, T13N, R8E, UM At total depth 1687' FSL, 733' FEL, Sec. 27, T13N~ R9E~ UM 12. Present well condition summary Total Depth: RKB 69 7. Unit or Property name feet measured 91 50' feet Plugs (measured) true vertical 6877' feet Nolle Effective depth: measured 9055' feet Junk (measured) true vertical 6 8 0 9' feet None 13. Kuparuk River Unit Tubing (size, grade, and measured depth 2 7/8" J-55 w/tubg tail at 8646' Packers and SSSV (type and measured depth) Camco HR-I-sp ~ 8619, Camco TRDP-1A-SSA @ 1792' Attachments 8. Well number 3K-01 g. Permit number 86-101 10. APl number so-029-21 600 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Lengl~ Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6" 1540# Poleset 1 1 5' I 1 5' Surface 4391 9' 9 5/8" 1400 Sx AS III & 491 9' 3851' Intermediate 350 Sx Class G Production 91 4 0' 7" 270 Sx Class G 91 4 0' 91 4 0' Liner 175 Sx AS I Perforation depth: measured 8818'-8896' 6 SPF 0 degree phasing · true vertical 6640'-6696' 6 SPF 0 degree phasing Description summary of proposal ~ Detailed operation program _ BOP sketch _ 14. Estimated date for commencing operation July, 1~90 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ;x; Gas __ Suspended Service 17. I hererg~ certify tha~,the foregoing is true and correct to the best of my knowledge. Signed~')~~ ° i~ Title Senior Operations Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10- IApprov. aJ No...-, , / Approved by the order Commission Original Signed By David W. Johnston Commissioner Form 10-403 Rev 5/03/89 Approved Copy Returned SUBMIT IN TRIPLICATE Well 3K-01 Solvent Stimulation Treatment Arco Alaska, Inc requests permission to perform an A Sand solvent stimulation treatment on KRU Well 3K-01. The treatment will consist of pumping a 67 bbls xylene pill displaced into the perforations by 56 bbls of diesel. The purpose of this stimulation is to remove reservoir damage incurred during the recent reperforation of the A2 and A3 intervals. The expected reservoir pressure is 2200 psi and no BOP equipment will be necessary. ARCO Alaska, Ir Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 7, 1987 Transmittal f! 5931 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. Please acknowledge receipt and return one signed copy of this transmittal. 3I-2 CET 2/86 7100-8526 3J-13. CET 2-12-86 6065-7507 3K-1 CET 7-2-86 7100-9052 3K-2 CET 7-2-86 6950-9694 2T-12 CET 7-7-86 3862-6080 3N-1 CET 2-14-86 7582-9421 3J-i2 CET 2-12-86 6054- 8150 3J-14 CET 2-13-86 6435-7987 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC ~~'~ k-"ZBPAE Chevron Unocal Vault (film) ARCO Alaska, Inc. is a Subsidiary of AllanticRIchfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CL~MMISSION ~:/¢:, WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-101 3. Address 8. APl Number P, 0, Box 100360, Anchorage, AK 99510-0360 50- 029-21600 4. Location of well at surface 9. Unit or Lease Name 1434' FSL, 318' FWL, Sec.35, T13N, R9E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1329' FSL, 804' FEL, Sec.27, T13N, R9E, UN 3K-1 At Total Depth 1 1. Field and Pool 1687' FSL, 733' FEL, 5ec.27, T13N, R9E, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Oi 1 Pool 69' RKBI ADL 25520 ALK 2556 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 06/04/86 06/10/86 11/1 7/86* "I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. PIug Back Depth (MD+TVD} 19. DirectionaISurvey I 20. Depth where SSSV set 21. Thickness of Permafrost 9150'MD,6877'TVD 9055'MD,6809'TVD YESY~ NO []I 1792 feetMD 1700' (approx) 22. Type Electric or Other Logs Run D IL/GR/SP/SFL, FDC/CNL, Cal, CET, 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;~ ~z.b¢~ H-~U Surf 115' 24" 1540# Pol eset 9-5/8" 36.0# J-55 Surf 4919' 12-1/4'' 1400 sx AS Ill & 350 sx Class G 7" 26.0# J-55 Surf 9140' 8-1/2" 270 sx Class G & 175 sx AS I 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) See Attached 2-7/8" ~' ~ ' °"~ O' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ........................ ,.,,., u,..,., , ,i ,.,i,.,u, for fi-ouuul~ data 8750' - 8752' 150 sx Ciass G 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 GAS-OIL RATIO TEST PERIOD e Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL' OILGRAVITY-API (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 RECEIVED I3E(.:: I ? 1986 Alaska Oil & Gas C;ons, Comrnission Ar~churafje Form 10-407 * NOTE: Drilled RR 06/11/86. Well was perforated and tubing run 8/26/86. Rev. 7-1-80 CONTINUED ON REVERSE SIDE (DAM) WC1:166 Submit in duplicate GEOLOGIC-MARK~:-R~ ~"'"" ": ........ 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 8627~ 6502~ Base Kuparuk C 8~03' 6557~ Top Kuparuk A 8807' 6632' Base Kuparuk A 89.54' 6737' 31. LIST OF ATTACHMENTS Addendum (dated 11/19/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~~ ~~ / TitleAs socia te Engi neer 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. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached.supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 Drill Site 3K-1 Well Completion or Recompletion Report and Log Item 24. Perforations: MD 8830 8834 8836 8858 8865 8869 8873 8876 8881 -8893' TVD 6649 6651 6653 6669 6674 6677 6680 6682 6685'-6694' Perforated w/1 spf, 120° phasing WC1:166 1 2-17-86 !.l) i:' .. ( i,: J. 9 1986 ~aska Oil & ('},as ([;:'~,~r~, Conn'mssior~ 12".,!'[": ,; ,:, ~' i~: ADDENDUM WELL: 6/20/86 3K-1 Arctic Pak w/175 sx AS I, followed by 64.7 bbls Arctic Pak. Frac'd "A" sand perfs 8830', 8834', 8836', 8858', 8865', 8873', 8876' & 8881'-8893' in 8 stages per 10/06/86 procedure using gelled diesel, 100 mesh & 20/40 mesh sand. Press'd ann to 2380 psi w/diesel. Tst lines to 8100 psi; OK. Stage #1: Pmp'd 97 bbls gelled diesel pre-pad @ 20 BPM, 5300 - 5450 psi Stage #2: Pmp'd 20 bbls gelled diesel pad @ 20 BPM, 1970 to 5300 psi Stage #3: 31 bbls gelled diesel w/1 ppg 100 mesh @ 20 BPM, 5300 - 5200 psi Stage #4: 278 bbls gelled diesel pad @ 20 BPM, 5200 - 5210 psi Stage #5: 48 bbls gelled diesel w/3 ppg 20/40 sand @ 20 BPM, 5210 - 5320 psi Stage #6: 65 bbls gelled diesel w/6 ppg 20/40 sand @ 20 BPM, 5320 - 5450 psi Stage #7: 22 bls gelled diesel w/8 ppg 20/40 @ 20 BPM, 5450 - 6000 psi Stage #8: 54 bbls gelled diesel flush @ 20 BPM, 6080 - 6100 psi Pmp'd 1300# 100 mesh & 29,085# 20/40 in formation leaving 735# 20/40 in csg above top perf. Bled ann to 500# & turn well over to Production Load to recover 615 bbls of gelled diesel. Job complete @ 1600 hrs, 11/17/86. Drilling Supervis~or -/ D~te $ UB-$ URFA CE DIRECTIONAL SURVEY [-~] UIDANCE 1'~'10NTINUOUS r'~"! COL Company Well Name Field/Location ARCO ALASKA, INC. 3K-1 (1434'FSL, 318'FWL, SEC.35,T13N,R9E,UM) KUPARUK, NORTH SLOPE, ALASKA · · Job Reference No.; 7'1606 SARBER Date ,. 7/2/86 Computed By: KRUWELL C, CT CI'RECT.TJNfiL SURVEY C, USTOM~R LZ STZ~!,) ,~qC,] AL.~SK&~ iNC. ~,UF'~UK S:JRV:-Y L~TS: OZ-JbL-$5 r,1 £ T :-t .] C. S C~- T33L LSC,~'FZ 3h: ZNT-RP'Z' ~TZ'~: V~RTZCAL S-CTIL].~: '--iG,qlZ. ]TST. &Z]]MUTm PRGJ=-TE,O g, NTO ~ TSRG-T AZZMUTm NSRTH 12 D-G ~ M Z N N=ST,. ARCO nL~SK,I, INC. 3K-1 NORTH SLOPE,ALASKA iNTERPCLATEC, TRUE SUB-SEA MEASURED VERTICAL 'VERTICAL DEPTH DEPTH CE~TH DEVIAT D=G MI 0,00 0,00 -69,00 100,00 100,00 31,00 200,00 200,00 131,00 300,00 300,00 231,00 400,00 399,99 330,99 500,00 4'99,96 430,96 600,00 599,09 530,69 700,00 698,96 629,96 800.00 797.34 729.34 900.00 8:94,55 825,55 0 0 015 0 20 0 Z 2 0 4O 2 34 5 30 8 34 11 50 1000,00 990,a2 '921,42 1100,00 1084,~2 1015,42 1200,00 1176,79 1107,79 1300,00 1267,22 11:)3,22 1400,00 1355.58 1256.53 1500,00 1441,73 1372.75 1600,00 1523,49 1~5C,49 1700,00 1606,95 1537.95 1800,00 1686.C7 1017.07 1900,00 1762,81 1593.31 18 2! 21 13 23 53 26 33 '~9 1~ 31 45 36 29 41 1 2000,00 1536,72 1767,72 ZiO0,O0 1907.80 183o.~0 2200,00 1978,07 i~09,07 2300,00 2048,26 1579,26 °400 O0 211q 1~ 2045 ~ 2500,00 21~7,56 21i3.50 2600,00 2256,70 21~7,73 2700,00 2325,75 225C.7~ 2300.00 239~.95 2325.9~ 2900,00 2464,51 23'95.5! C CMPU T 4. T i ON 3000.00 2534.6~ 2455.C3 310O.OO 2603.B~ 2534.36 3200.00 2573.5~ 2504.59 3300.00 2743.~ !57~,49 3400.00 2~12.99 27~3.9~ 3500,00 2801.75 3600,00 2~50,~2 2~3!.42 3700.00 301~.76 3200.00 3086.50 3017.50 3900.00 3154.01 30~5.01 'VALU:':S FOq C .3 U R S 5 i {] ;q A Z N D- I M U T d G M!N ~,5 51 47 47 25 DAT~=: ~ ~-JUL- ~=~ " "0 FEET OF =VcN I'~ MEASUR~ V~RTiC~L .,.=mn:GLEG < = CTAN S~"ZTISN SEV~'RiTY NORTh/ FEET DEG/iOC, FEE 0.00 0.00 0.03 0.20 0.23 0.19 0.54 0.21 0.77 1.25 ~,00 2,45 5.85 2,79 21.75 3,53 3').47 3.26 52,42 3.78 C . O. O. C,. 1. 3. 10. 22. 40. 53. 91,12 3,62 90, 115,1:3 2,57 123, !.53,3 S 2,77 lSh. ZOE 04 ~ 71 202 ~.~.>~ 2.Z~ 24~ 30~.~0 '2.~f 297. 35:£.19 2.37 351. 4!6.1d 2.55 407. 477.33 2.3~ 457. 541.4~ '~ 5& 5~,~ 50~.7g 2,84 596, 579,07 0.99 665. 750,14 0,15 7'35, 32!.~4 0.51 ~0.5. ~,~2,~1 0,54 ~76, 954.~ 0,32 547. i636.6!, 0.26, 1019. i i S :~. 7,{ O. 15 1 'S 9 O · 1!~0.77 0.3'{ 1162. ~2.41 9.3~ 1233. 1324,00 O,Cc, 1304, 135E,34 0.22 1375, !466,6~ C.lO 1446, 1537,97 0,~4 151~, 150~.64 2.34 1589. 1532.!~ 0.2~ i560. i754.~2 0,37 1732. I~27.73 0,64 ig.21.lg J,22 !~77. I~74.77 0,44 !~50. P&GE ,1 gT~:_ OF ...,cURV=Y:- 02-JUL-~6 ELLY BUSHING ELEVATION: 69.-0.0 PT EN,iir.,,IEER: S. SAR3ER BS tq 10.77 W 91.53 N 6 05 W 73 N 19.8:3 W 125.30 N ) 6 a 88 "{ 29.02 W 163.48 N lO 13 a 43 hi 3B,72 W 205,10 N 10 49 N 05 N 49.11 ~' 252.87 N 11 11 W 56 N 59.89 W 303.53 N 11 22 N 05 N 71.31 ,4 358.22 N 11 23 a 7:~ N ~3.31 N 416.21 N 11 32 W 71 N 95.,8 W 477,35 N 11 32 N 43 N 10~,72 W 541,45 N 11 35 '.~ 42,.~ ~' 12P.07~ W 608.79 N 11 3~ .50 N 13~.$1 W 679.11 N 11 27 76 N 145,60 ~ 750,23 N 11 15 N 04 N 158,16 W ~21.41 N 11 6 70 N 189.32 W 892.91 N 10 55 86 N 1~0,17 W 964.3~ N 10 45 ~.~ 34 N 190,59 W 1037,01 N 97 N 200,70 w 1109,27 N 10 25 45 iq 210,72 W 1181,39 64 N 220,44 W 1253,1~ N 10 7 W S;5 il 229.57 v, 1324.94 9'~ N 235.57 ~ 1395.47 99 N Z 47,43 W 1467, r'~ I~ C7 N 2f6,08 N 1539,52 33 N 265,56 d 1~11,37 ~9 N 277,$4 '.~ 1663. ~7 ~4 N 290, 1~ W 1756. 67 57 :q 302.:}1 w la29,67 29 N 3i3.09 W 1~03.~)2 29 N 323.79 ',', 1975.98 O0 N 0.00 E 0.00 N 0 0 E 0:3 N 0.21 E 0.23 N 69 32 E 3,5 N 0.81 E 0.71 N 59 1'9 E 79 N 1,11 E 1,36 N 5~ 27 Z 17 N 1 78 = ,~ 12 N 56 4~ ": 5S ,q 2.39 z 4.30 N 33 40 58 N 2.32 E 10.83 N 12 23 5~ q 1.51 E 22.54 !'1 3 50 : 38 N 0.34 E 40. 38 N 0 3 E 03 N 3.:~1 ~i 6,3.15 N 3 27 ;~ SULAR CCOR,DiNATES HORIZ. OEP~RTURE SC?TM =,gST/'~'EST CIST. AZ'iMU'Fh T FEET FEET DEG MIN O 3EPTH ARCO ALASKA, INC. 3K-1 KUPARUK NORTm SLOPE,ALASKA M J TRUE ASUREO VERTIC.~L DEPTH DEPTH 000,00 3221,7, 100.00 3289,59 200.00 3357.76 300.00 3425.22 400.00 3494.45 500,00 3562.31 600.00 3630,35 700.00 36'98.93 800.00 3768.17 900.03 3837.93 000.00 3908.58 100.00 3979.32 200.00 4050.17 300,00 4120.93 400.00 %191.77 500.00 4262.57 600.00 4333.32 700.00 4403.91 800,00 4474.45 900.00 ~544.75 O00.O0 4613.17 iO0.OO 4685.71 200.00 4755.42 300.00 4827.12 400.00 4897.,~3 500, O0 4968.~6 600,00 5C39,%3 700,03 5110.~5 900,00 5253,26 O00.Oj 5325.11 iO0.O0 5397.35 200.00 5459.63 300.00 55~1.94 400. $J 5614.25 500.00 ~085.59 60O.OO 5759.09 700.00 5831.34 800. O0 5903.41 900, O0 5975,37 2'ATc: 23-JUL-B,5 :NT&R?CLATEL3 V,~LIJ;S F'2'?, :v"N 100 FE:-T OF 3U'3-S; ~ C 3dRSf: V'~RTiCaL 93GL -' ':.~ VERTICAL OEViAT!S',~ '~ZI'4'jTd S:~CTI3N S~V=RITY ZEPTH 9EG Mlh 51{',$ '4i',~ FE:--T OES/IO0 3152.74 47 20 N 7 40 W 20a!~,.14 0.4-j ~3 5~ 47 9 " C, ,~' ' I, . 3288.76 46 52 N 6 26 W 2!94.20 0.71 3357.22 46 48 ~ 6 35 ~.,~ 2266.7i !.36 3425.45 47 10 N 6 !6 ~ 2~39.55 0.71 3493.31 47 17 N il 7 W 2412.95 ~56i.35 46 5 p ~,~ !! = W 2,43A 21 0 73 3529.98 46 28 k 10 3~ ,J 2558.93 0.55 3768.9~ 45 22 h 9 46 ,N E702.6A 1.31 *05i.9°~ 4a 5.'5 h 11 5~ W 29~3.~..,,"~ 0.~2 ~t22.77 ~ 57 N ~2 il ,~ 3355.8g 0.21 4193.57 4~ 55 N 12 24 w 3!26.52 0.15 426~._P2 45 i W 12 3P_, w J197.1~,~ 0.43 4334.91 45 5 N 12 5;{ W 326~.01 0.55 4~05 45 45 ~ 3 ~,.j i.~ .~ o , 3~- .. : ...... ,', -,~:~. ~ ~ 0.29 ~47~.75 45 19 N 13 5,3 W 3~09.97 0.55 45'~6.17 45 '9 N !w £2 W 3430.92 0.31 4616.71 45 5 N l~ 3b W D551.75 0.39 45~7. 42 ~ 59 "~ .~4 53 X ~A;2~_ . 3a. ~'~.33 4758.12 45 0 F; 15 19 ,.4 3.592.01 0.33 482,~:.~3 45 O U !5 ~5 W 37,53.59 0.~5 ~G99.56 43 0 r,~ 16 'W ',.! 3~3~.13 0.42 ,970.,3 ~ 45 ~ 16 20 ~,., ~904.50 0.22 504!.46 ,4 39 h 15 36 ',~ 3~7~.69 0.32 5112.70 a4 27 N i~. ~.~7 W 4544.63 ~t~4.25 44 9 N !7 !I ,~ ~1i~.22 3256.11 ~3 55 N !7 £0 ~.~ ~1~3.49' 0,4'9 532{,35 43 40 N 17 3.5 '~ 4252,35 0,29 540i3.63 43 .6 ;, 13 ! '.,~ ~32!.11 ~47 - 54 4~ ~,'~ ' _ . . 5~17.69 ~% g5 h 1~ 55 w ~26.~7 ;Y3~.41 43 54 ~ 2'J 22 'w 4732.55 ,3.26 590~.37 44 5 h 23 39 w ~0!.27 0.6~ M m ,h :~ IJ R E R ::CTAN NSRT,~/ 232~. 2 ;395. 2168 . 2:241. ~- _~1.3 · 23.{ $. 2457. 2529. 2 60:3. 2670. 2740. 230 ~. 2~ 78. 294 i. 3317, 3085. 31~5. 3~24 3293. 3362 · 3431. 34.99. 3568. 3636. 3704. 3772. 3640. 39'37 · 3974. 40u!. AT~ 3¢ SURVEY: 02-JUL-S6 :LLY BUSHING EL=VATION: 67,~00 FT ENGIN:L.R: G. S&R~.ER 9 j r- p T H GUL,iR COSOr'IN~,TeS HORiZ 2, EPARTURF ~,UTH :'A£T/~EST DIST. AZfMUTY T FE"T FEET 15 N 333.95 W 2050,53 N O0 N 343.42 W 2123.95 N 64 N '35Z.17 ;4 2197,05 N · 39 !,l 3~0,13 W 2269.84 N 55 N 369.78 W 2342,92 N 9~ N 351.97 W 2416.3.5 N ~O r,J 396.45 i-i 2~9.57 N 2~ N 410.11 W 2562.28 N 29 N 422.95 W 2534.46 N ~1 N ~35.13 W 2706.12 N 55 !4 447.71 W 2775.88 %7 N 461.49 W 2847.51 96 N 475.77 W 2'918.02 07 N 490.31 W 2983.57 13 N 505.10 ~ 3059.12 14 N 520.16 '. 3129.67 13 N 535,47 W 3200.24 21 N 551,14 w 3270,98 20 N 567,40 W 3341,72 31 N 584.18 N 3412,~8 2:2 W 13 w 7 N 4. W 5 ' 9 1 £ N 14 W 15 W 16 N 501.&9 W 3483.48 79 N 619.21 N 3554.15 17 N 637.24 W 3624.53 44 N 655.72 W 3695,0~ 56 N 674.65 ~ 3765.49 53 N 6,94.10 W 3535.~5 25 N 713.~5 W J906.04 76 N 733.$1 W 3976.0~ 94 N 754.07 W 4045.8~ 71 N 77%.60 ~ 4115.26 ~ i 6 W '9 19 W ~ 23 w 9 26 W 9 30 w 9 34 W 9 37 W 9 46 W 9 51 ;~ ~103.13 N 7'95.23 4174.10 N 815.97 4239.~9 N 837.13 ~305.50 k 853.71 4371.06 N ~60.46 4501 .52 N 925.20 45o6.59 N 'Ba'{. c 2 4631.62 N 972.58 4696.65 ~J 996.91 N 9 55 W N 10 2 w N 10 7 W N 10 13 W N 10 19 W N 10 25 w N lO 31 N 10 38 N 1 O 44 ~,~ ~'J 10 50 '.,~ 4134.39 h 10 57 ~ 4253.10 N 11 3 W 4321.74 N 11 I~ 4 ~3'90.30 ~.l 11 16 ~ a527.25 !~ 11 29 ~ 4595.61 N 11 36 ~ 4~64,06 X ll 44 w ~732.63 N I1 5i W 4801.29 N 11 39 ~ 6'*¢',!PuTAT]2~I ,l'A] E: 2}-J',JL-35 ARCO ALASKA, ZNC. 3K-1 KUPARUK NJRTH SLOPE,AL,&SK~ iNTERPCL&TE3 VALd2S FJR EVfN 100 FEET TRU~ SUS-Sk~ MEASURED VERTiCaL VERTICAL DEPTH DEPTH DEPTH C. (-: IJ ~. S ~" V2.qTIC~L 2GGLEG DEVTATZ~DN A ZZ;.IU TH SECTZON S~!VERITY DEG i,,I I N DiG 8000.00 6367.18 5973.18 8100.00 6119.34 0050.34 d200,O0 6191,57 6122.57 8300,00 .5253,52 5194,82 a400,00 5335,7~ 5256,78 5500.00 6~0B.54 ~339.54 8600.00 6481.95 6412.95 8700. ~0 6554.75 648~.75 8800.00 6626.d4 6557.84 ~900.00 5698.68 6629.6b 43 53 I.l 21 4 ~.i ~+ 70.,J.], 1.31 · 43 45 ~i ,.1 33 W ~.93'_4,40 0,87 43 39 N Z2 7 W 5006, 58 1, 43 49 N 1'~ ~i W 5074.72 43 45 N I1 25 ',.~ 5!43.9~ 42 53 N 2 ii ~ 5112.15 42 50 N 4.~=. a'" ..;~P76,17... 3.77 43 ~1 N O ~3 ~i' ::;342.03 2.19 43 44 N lO 13 ~ 5407.43 !. 29 44 27 N !C 56 ~ 5471 .54 1.01 9000.00 6759.91 ~70'0.91 9100.00 6~41.05 o77£.C5 9150.00 ,5876.62 6807.62 44 39 N 14 5 ,:_ -535.45 1.B1 ~4 3'9 N 14 5 ,: 5~9:{..50 O.O0 44 39 N 14 5 f' 5530.02 0.00 ~EASURE FEE 4761. 4 ,~ 26 · 4890. 4954. 5021. 5157. 5225. 5361. PgG'_= '3 ATE O~ SURVEY: 02-JUL-B5 ELLY BUSHING ELEVATZOH: 59~00 FT ENGIhEER: G. SARBER 5430.50 N 1076.54 W 5536.18 N I1 12 w 5~96.66 N 1059.44 W 5599.80 N 10 54 W 5532.75 iq 1050.6~ W 5631.67 N 10 45 W 6~ N 1021.70 %N ~70.06 N 12 ~ W 16 N !046.B8 W 4938.40 N 12 1~ W 37 N 1072.60 W 5006.62 N 12 22 W 55 N 1098.2e W 5074.82 N 12 29 ~ ~1 N 1117.15 W ~144.08 N 12 32 W 30 N 1125.33 ~ 5212.23 N 12 28 16 N !123.83 W 5278.19 N 12 17 23 N 1115.:~1 W 5343.05 N 12 3 w 57 N 1104.33 W 5~07.53 N 11 47 W 92 N 1091.44 W 5471.87 N 11 30 W GULAR CDCROINAT£S HGRIZ, OEPARIURE SOUTH EAST/WEST DIST, AZIMUTh T FE~T FEET DEG MiN O ,2EPTH CO".I;.~UTA]"i3!',~ D,AT,~: 23-JUL-85 PAGE ARCO ~ILASKA, INC. 3K-1 KUP~RUK NORTH S L"Z' PF;, A LA SK A INTfR.','°'SLATt!'', VALU":S F'J:! 2V~N 1000 FEiT 3F TRUE Sd.5-S EA MEASURED V'::~RT!CAL VERTICAL DEPTrt O.~ PTH DEPTH 0.03 0.00 -5:9.00 1003.00 990.42 921.42 ZO00.O0 1835.72 1757.72 3000.00 2534.08 2465.08 ~O00.OC 3221.74 3152.74 5000.00 3'908.58 3S3'~.58 6000.00 4615.17 ~546.17 7000. CO 53°5~ . 11 5056~ .11 8000.00 6047.1~ 5975.15 9000.00 6'769.91 6700.91 0 O ¢,; C O :; O.OC 3.00 18 21 N i~ 20 ,,~ 91.12 3.52 43 43 "q !1 1 W 60P..76 2.84 45 51 N 7 !2 ',~ 132~.00 0.06 47 20 N 7 40 W 2548.1~ 0.43 4~ 2 N I0 4~ w 277 '~ 4! 0 :~b 65 9 N 1' 20 W 3&~0.92 O. 31 43 55 N 17 20 ~ -i,~3.4~ 0.49 43 53 N ~°i ~ ,~ 4~ 70.Ob 1 3~ L, e 44 39 q 14 5 ( 3~35.45 RECTAN NePTH/ F- E '.F 90. 595. 1304. 2023. 2740. 3431. .133. a761. 5430. ATE ,OF SURVEY: 02-JUL-B6 ELLY 'BUSdlNG ELEVATION: EhGZNEER: G. SAREER ED D~-PT ,'59 .-.O, 0 F T GUL&R CO3~.DINATE$ HORIZ. D~PaRTURE SO'JTH EaST/WEST DIST. AZIMUTH T FEET FEET DEG O0 !'.~ 0.00 E 0.00 N 0 0 ~9 N 10.77 W 91.53 N 6 45 ~2, f,,l 122.0'7 W 608.79 N 11 34 W ~ N 22~.6'7 W 1324.94 N 9 !5 N 333.95 ~ 2050.53 N 55 iN 4~7.71 W '2776.88 N 9 16 N 601 49 W ~4~3 4~ N 9 55 I~ iq 795,~"3 N 41~4, 39 N 10 57 69 N 1021.70 W 4870.05 N 12 6 W 50 N 1076.54 W 5536.18 N 9150.00 5876.62 m$07.52 44 39 N !4 5 E 5530.02 0.00 5532.75 N 1050.39 W 5,531.67 N 10 45 W ~RCC ALASKA, INC. 3K-1 KUPARUK NORTH SLSP~,ALAS~ C 2 !'q PUT AT i':~T=. ?~-JijL--2= .[NTERPULATE;..3 VALU"-'$ FOR "YE",! 100 TRUE SbS-SaA ME.&SUREa VERTZCAL V;::RTICAL DEPTH D~PTH DEPTH O.O0 0.00 -5~.00 69.00 59.00 0.00 1~.00 159.00 100.00 20'9.00 269.00 200.00 369.0i 369.00 330.00 4~9.0Z 469.00 400.00 56'9.17 569.00 500.00 669.T% 569.00 771,09 769.00 700.00 873.53 869.00 977.47 9,59.00 900.OO 1083.~7 1069.00 1000.00 1191.51 1169.00 !130.00 1301.99 1259.00 1200.00 1415.~2 1359.00 1300.0~ 1532.19 1~5'9.00 1400.03 1653.15 1569.00 15'30.00 1778.15 1669.00 !600.00 190S.23 1769.00 1700.00 2045.12 1869.30 l~OS.OC 2187.09 1969.00 1900.00 2329.64 2069.00 2300.0'3 2473.22 2169.00 2!00.33 2617.81 2269.00 2200.00 2762.53 2359.00 2306.00 2906.45 2469.00 3050.09 2559.00 2~00.20 3193.29 2,55~.00 2500.03 3335.60 2759.00 2700.00 3~31.~4 2369.00 2800.00 COURSE Vl~qT ,"~'ALu OEG MI!',I DES MiN ~-~ET 0 0 ,": 0 0 ,: 0.30 0 1~_ 1t t=,_, 53 ~: 0. O 17 f',.~ .~9 42 E 0.13 0 23 N 54 19 :2 0.43 0 27 N 5') 14 f 0.52 1 ~6 N 10 5'3 ~ 1.89 4 38 N 0 57 W 7.14 7 27 ~ 3 54 W 17.57 1i 0 N ~ ii ~', 33.7'3 I* 1 N lO 53 w 17 34 N 14 50 ~ 34.16 20 47 N IF 4 W 1i9.!~ 2~ ~ ~ w 1.50 Ol 39 h t~ ~ 25 35 N 13 0 W 205.93 29 3~ N 12 2~ W 260.4~ 32 40 N 12 4 ~ 320.6~ 35 32 N 11 $6 W 388.71 3~ i7 N 11 26 ~ 463.~7 4! 14 N !1 ~0 w 5~,5.85 44 3~ N 10 32 ~ 6~0.27 ~5 ~> i,~ ~ 27 ~ !774.53 ~7 22 ~', .- ~ w 1~9!.33 ~6 50 k T £0 ;~ 2205.13 a7 i .': 7 Jo 2 . ~ 23~ · ~7 -~.~ :, ~; __~ ' i~_ "~,. =~22,. 1~' ~fi 37 ;. lO 47 w 2527.!7 44 £~ i': !? 3 ,~ 27~3.'55 3527.11 2959.00 L~O3.OO 3774.07 305~.C0 3000.00 3922.15 3169.00 3100.05 4069.70 326~.00 3200.rJ~ 4216.43 33~9.00 3}OO.CO -, 4362.~0 3-59.C0 ~C.CC ~509.~6 3559.00 4656.3~ 3559.00 3~30.0J 4801.1:~ 3759.20 37J0.00 4944.03 386'9.00 3808.08 F~:T OF DOGLEG SEVERITY SEG/IO0 0.00 '3 * '~ · ¢_ 0.26 0.49 2.75 J.61 2 · 97 3.4d 3.55 2.39 2.73 2.35 1.76 2.17 2.72 1.70 0.15 0.4.3 3 · 32 0.27 0.35 0.35 1.25 O .43 0.60 C'. 41 0.45 ! .26 0.48 C · 9: ?AG~ 5 DATE OF SUaVelY: C2-JdL-86 K~LLY BUSHING ELEVATION: 69.0'9 FI EN'GINE~R: G. SARBER SUB-S=~ O:PTH ~ECTANGULAR COORDINATES MOR!Z. DEPARTURE NO2Th/SOJTH EAST/WEST DIST. AZZMUTM FEET FEET FEET DEG MIN 0.0O N 0.00 E 0.00 N 0 0 i 0.02 N 0.13 E 0.10 N 76 45 E 0.24 N 0.49 E 0.55 N 5, 11 ':~ 0.70 N 0.'93 E !.16 N 52 43 ~ 0.9'7 N 1.57 ~ 1.34 N 58 19 ~ 2.42 N 2.26 E 3.31 N 43 1 7.83 N 2.42 ~ 8.19 N 17 12 1~.36 N 1.79 ~ 13.45 N 5 33 ~ 34.69 N 0.62 ~ 34.70 N 1 i ~ 56.6°~ N 2. 51 W 55.68 N =~ 32 W 84.16 N 8.'92 W 84.64 N 5 2. W 117.97 N 18.30 W 119.36 N ,5 49 k 157.60 N 28.24 W 160.11 N 10 9 w 203.29 N 33.92 W 206.98 N 10 50 W °55 48 N 50 76 w ?60 47 N 11 14 N 314.~5 ~ 63.4'9 ~' 320.70 N 11 25 W 3~0.90 N 77.65 W 383.73 N 11 31 W 454.32 !q 92.78 W 463.70 N 11 32 W 535.73 N 109.~4 w 546.87 N 11 35 W 627.3~ N 127.99 W 640.31 N 1i 31 W 72c.70 N 145.09 W 741.04 N 11 17 W 826.95 N 161.52 W 842.58 N 11 3 i~ 923.77 :q 177.29 W 945.54 N iO 4B W 1032.10 N 192.39 W 10~9.$8 N 10 33 N 1135.70 N 205.99 N 1154.40 N 10 19 W 1238.24 N 221.05 'W 1257.81 N 10 7 w 1340.52 N 234.16 W 1360.81 N ~ 54 1442.22 'q 246.31 Vi 1~63.1~ ;i 9 42 1544.11 N 259.25 W 1565.73 N 9 31 ~ 1547.61 N 275.52 W 1670.49 N 9 29 iq 1752.00 N 2'~3.43 W 177~.40 ,'.~ $ 30 W 185~.35 N 310.29 W 1324.09 N ~ 2B W 1955.43 N 325.10 W 1393.2~ N ~ 24 w 2973.9~ N 240.62 W 2101.72 N 9 19 tq 21~0_.. 55 I,; ~_.~ 49 ','~ 2~0~ .07_ ~i ~ Iv- W 2200.42 N 365.'~2 W 2315.52 N 9 5 W £393.0E r; 3£3.39 k 2423.60 N 9 6 W 2468.13 N 40~.22 W 2530.52 i~ 9 ll ~ 2fi,Sl.l? ~,J ~23.i0 'W 2535.32 N ~ 1~ ,~ 2701.63 N 4~0.51 W 2737.31 N ~ 15 ~ u.:~PUTATIu 2, ATd: 23 JUL 36 PAGE 3K-1 KUPARUK NSRTH SLCPE,ALASKA iNTERD:3L:~TCD V&Ldr':S FSR E\,'=~.; 100 F '~T 0~: TRd: SUf,-SEA MEASIJREO VERTICAL V~,TiCAL D~PT~ 3=PTM DEPTH 5085.41 3969.00 39JO.OJ 5226.54 4069.00 4000.00 5367.81 4169.00 4100.00 5509.0~ 4269.00 4200.00 5650.54 4369.00 4300.00 5792.2'? 4~69o00 4400.00 5934.45 ~569.0~ 4500.00 6076.3i 4669.30 4500.00 6217.79 4769.00 ~700.00 635~.23 4869.00 4800.00 6500.62 ~96'9.00 4900.00 6641.65 506'9.00 5000.00 6752.20 5169.0.3 ~100.00 ,5921.93 5269.00 5200.00 7060.81 5369.00 5300.00 7199.12 5469.C0 5400.00 7337.40 5569.00 5500.00 7475.5~ 566'9.00 5600.$3 7613.71 576~.00 5700.OJ 7752.21 5869.00 5~O0.O0 7891.14 5969.00 5000.00 8030.1~ 6059.00 6000.00 8168.77 61,59.00 610C'.00 8307.17 6269.00 6200.00 ~445.86 5369.00 3582.36 646'R.$0 g~O0.O0 8719.83 6569.00 ~500.00 3998.72 0769.30 913'9.29 6369.00 6{OC.JO CC, uRSi V'-PTZC&L ",3 G L E,.? D E V I A T ! 0 N A Z "?.'~ U T .'~, S ,~" T 13 !,] S (~ V ;:: 4 I T Y 9EG MIN C=3 ;'41N FE:_'T O~G/100 44 55 N 11 27 W 2;'33.77 0.50 44 50 i',;,~ 1 5', W 2'933 · _,~5 0 · 2~, 44 56 ?~ !£ 7 ',' 5333.13 0.24 44 56 N i2 25 N 3132.93 0.22 45 6 N 12 46 W 3232.97 0.16 45 13 N 13 26 W 3333.39 0.31 45 15 N 14 2 :d 3434. 43 O. 45 45 7 N 14 32 d 3534.97 0.29 45 0 N !5 2 W 3o3a.gL 0.27 44 59 N 1'5 J3 W 373~.52 0.35 4a 4 N 20 37 ~i ~7~5.18 0.53 43 ~7 ~,i 21 14 ~,~ 4-']90.,56 0.63 43 47 ?'~ 2! 35 w 49'~5.31 0.75 4'3 ~0 N 1~ ~'1 ',~' 5079.62 5.3'9 43 i~ r'~ 7 12 ~ 5175.50 5.37 :~ 5 )5.~ · - ~ ~c 1.21 4. 9 R IJ ~ : ~a4a.7~ 1.2'~ 44 36: ~,~ lw 6 z ~J3~.6~ 1.31 ~4 39 h i~ 5 ~ 5523.27 O.OC OAT~ OF SU;~VzY: 02-JUL-86 KELLY ~%USrilNG ELEVATION: b9.D'0 PT :NGINEER: G. SARE,~R cU:~-S~:¢' O PTtt R:CTAD"- C, . ,~oUL~R C ORDINATES HORIZ DEPARTUN~ 'lOST'miS,'~ . · ~'JT~ E, 4ST/N~ST DIST AZIP.tUT~ FEET FEET FEET D~G MIN 27S9.7 Z :3 ') 7 · 2 2S9~'.8 3092.4 3190.0 3287.3 3380.0 34~3.5 35 ~ 0.3 3675.~, 6 N 459.43 W 2837.21 N 9 19 W B N 479.60 W 2'936.71 N 9 23 W 9 Fi 5,00.32 W 3036.39 N 9 29 W 1 N 521.53 W 3136.08 N 9 34 W 4 N 5~3.35 W 3235.98 N '.9 39 w 6 N 565.12 W 3336.25 N 9 46" 6 N 5~0.07 N 3437.09 N 9 53 4 N 614.99 W 3537.41 N 10 0 w 2 N 640.50 W 3637.16 N 10 3 W 1 N 566.87 W 3736.79 N 10 16 W 3772. '9 3868.4 3953.0 4056.2 ~148.3 4239 ..3 4333.0 45!0.4 694.23 W 3835.29 N 10 25 W 722.13 W 3935.22 N 10 ?4 iq 750.44 W 4033.44 N 10 43 W 77).12 ~,';4130.4~ N 10 52 W 807.80 W 4226.22 N 11 1 W _~36.91 W 4321.13 N 11 lO W 866.34 W 4415.92 N 11 19 W 897.03 W 4510.56 i'j 11 2C~ W 92.3.37 W 4504.99 N 11 37 W 961.07 W 4699.84 N 11 47 N 4690.39 N :994.75 W 4795.20 N 11 5S 47ai.14 N 1029.22 W a890.66 N 12 ~ W ~70.J6 N 1064.51 W 4'9~5.33 N 12 19 W 495'~.20 N 109'~.:J7 W 5079.73 N 12 30 W 505'~.46 N 1122.~'~0 W 5175.62 N 12 31 5145.21 N 1124.52 ;~ 5266.60 N 12 19 523~,.84 N 1113.54 iN 5355.90 N 12 0 ,. =4?9 §~ N 1075 76 W 5535 5525.45 P,] 10~2.72 W 552~.'~4 N lO 47 9150.00 5676.52 6807.62 44 3F N 1~ 5 £ 5530.C2 O.CO 5532.75 H 1050.,99 W 5631.57 N 1J 45 W ARC3 ALASKA, 1!~C. 3K-1 KUPARUK NSRTm SL~Pi,ALASK"~ TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A PBTD TD CC!',iPUTAT'ON: , ZNTERPCL&TEC VALUES FSR J ' 27.0 C' 3733.00 8507.00 9150.0C CATE: 23-JUL-36 CmOS!~; H3ql ZL,~,S FR~ K~ OFO1.72 555~.91 6531.90 ,5737.1~ 6309.04 5~76.52 3RI.SIN= 1434 TV3 SU~-S~A 6z. B2.7£ 5 ~+ !57.91 6,,5, 6 :~ . 15 6740.04 e5o7.52 PAGE 2ATE OF SURVEY: 02-JUL-8.5 KELLY ~USHiNG EL~.VATZ3N: ENGINEER: G. SARB_.,ER O 9.5'0 SURFA :SL, 318 ~WL, SE RECTANGU NORT"/S 5175.4 5227.2 5298.3 5399.0 54,57.9 5532.7 C~ LJCATION AT C 35, T13N, RgB, LAR COORDINaTeS OUTH EAST/NEST 1122.27 1115.4E? 1103.~ 1083.92 1067.13 1050.B9 FT ARCO ALASKa, INC. :K-1 KUP~RUK NORTH 2. 3-JC L-',:3 6 P DATE OF SURVEY: 02-JUL-3.5 KELLY BUSHING ELE¥,A'rioN: ENGiN'-ER: 3. S~RBER ',' ',' '1' °,' 69 TOP KUPARUK iS BASE KUPARUK C TOP KUPARUK A 5~SE KUPARUK A P6TD TO 85!7 a 703. 960T.00 9055.00 ~150.00 F R 2 M < 5 5501 7~ 0556.91 6531.90 6737.15 SURFACE LGCATiON AT O~!~ZN: 1~4 FSL~ 31~ FWL, S~C '35, T13N~ R$E, TVD RECTANGULAR COORDiNATeS SU:-SEA NORTh/SOUTH EAST/W~ST 6432.7? 5175.48 N 1122.27 ~4c'7.91,. 5227.29 N 1115.43 6562.90 529~.32 N 1103.46 e665.15 53'99.05 N 1083.92 6740.04 5467.99 N 1067.13 6~07.62 5532.75 N 1050.~9 FINAL W-LL L3CS. 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' ....... · : : 1 "?"?" ~" ?" ~'":'"?"?'"~ ...... ~'?" ?"?" ~"?'"~" ~'"~'-r-'?"?"-~'"~'", "?'?'"~'"~-'*'"~"?'"~--e--! --e---~'--~-'?-'-~-.'~ ....... ~--?.-.~..-:---~ ....... ~--~..e---~---~..-~--e--.~--.~---~ ........ : ....... ~---~--+---~-'-~---~---:---r ..................... >--.--- ~---- --] · ..h-;...h.?.-h.-~ ....... h.-;..[..~ ....... ~"~'"~'"~ ............. 'r"-~'--;-'-~ ....... ~---h..~.-.~-.-~---~---~--.~.--h--~--.h.-;---~.--:---~.-~---~-.~...~.`.~...~...~...~...~...~...[...~...L..;...~...L..L..~...t...~..L.t...t...h..L.;...t...u.~...L..k..~...t...:...: ......... L.~...t..~ .... ~"?";'-"~"'~'"~'"~'"?' ~ ..... ~' '~"?'"~"?'"~'"~'"~'"~ ..... :'"'~'"~'"~"-~"-?'~"-~'"~ ...... ~'"~"t'"?'i"'~"~'-'k-~-'-,-'-~'"~'+'-~"'~'"?'-~"-~'"~" --~---~---~---~--~...~...~._.~..~.._~...~...~...~...~...~...~...~...~...~._.,...::....~...:...u ~.. ~....~...~._.~...~ ~ VERTICAL PROJECTION SOO0 £C32 72.33 847, PROJECTION ON VERT]CRL PLANE 34?. - 167. SCI:ILEB IN VERT16J:~ OEPTHS HOR]7 SCALE WELL: 3K-1 (1434'FSL,318'FWL, SEC.35,T13N,R9E,UM) HORIZONTAL PROJECTION NORTM ?OOO 6,000 .SO00 4OOO 3OOO 2000 1000 REF 00007160S SCA~E = 1/1000 IN/FT SC~.JTH -IOOO -4O00 WEST -3000 -2000 -1000 0 1000 2000 4000 E2~T Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR, WELL NAME AND NUMBER Reports and Materials to be received by: ~,/ ,.~.~-_,, /~" ' Date Required Date Received Remarks Comp 1 e t ion Re p o r t ..... Well History Samples Mud Log Core Ch~ps Core Description Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test Reports ~ .' , ....... Log Run , , , ,, , Digitized Data ~., , , , ARCO Alaska, Inc Post Office E~,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 17, 1986 RETURN TO: ARCO ALASKA, INC. ATTN' Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #5831 Transmitted herewith are the following receipt and return one signed copy of this Open Hole Final Logs: 3K--2-.2" DIL-SFL-GR 6-19-86 1000-9952 -5" DIL-SFL-GR 6-19-86 1000-9952 _~._-2" FDC Porosity 6-19-86 8950-9926 5" FDC Porosity 6-19-86 8950-9926 --2" FDC Raw 6-19-86 8950-9928 '- 5" FDC Raw 6-19-86 8950-9928 ~-Cyberl ook 6-19-86 9100-9700 3K-1~2" DIL-SFL-GR 6-10-86 4920-8988 '5" DIL-SFL-GR 6-10-86 4920-8988 .~~2" FDC Porosity 6-10-86 4920-8991 ~5" FDC Porosity 6-10-86 4920-8991 '-2" FDC Raw 6-10-86 4920-8991 '- 5" FDC Raw 6-10-86 4920-8991 --Cyberl ook 6-10-86 8400-8970 2T-11'~2" DIL-SFL-GR 6-5-86 6187-6783 "5",DIL-SFL-GR 6-5-86 6187-6783 ~2" FDC Porosity 6-5-86 6187-6757 ~' ~5" FDC Porosity 6-5-86 6187-6757 ~2" FDC Raw 6-5-86 6187-6757 '-5" FDC Raw 6-5-86 6187-6757 -~ Cyberl ook 6-5-86 6187-6783 items. Please acknowl'edge transmittal.. Receipt Acknowledged' Distribution' NSK Dri 11 ing Rathmel 1 Vault (1 film) D & M State Date' of Alaska(1 bl + 1 se) ARCO Alaska. Inc. is a Subsidiary of AHanticRJchfieldCompany STATE OF ALASKA ., ~:'~' t ALAg..-~ OIL AND GAS CONSERVATION COk ,.,,~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate © Plugging ~ Perforate~ Pull tubing Alter Casing L~ Other ~. Complete 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.0. Box 100360 Anchorage, AK 99510 4. Location of well at surface 1434'FSL, 318'FWL, Sec.35, T13N, R9E, UM At top of productive interval 1329'FSL, 804'FEL, Sec.27, T13N, R9E, UM At effective depth 1622'FSL, 749'FEL, Sec.27, T13N, R9E, UM At total depth 1687'FSL, 733'FEL, Sec.27, T13N, R9E, UM 5. Datum elevation (DF or KB) / RKB 69 ' Feet 6. Unit or Property name Kuparuk River Unit 7. Well number 3K-1 8. Approval number 220 9. APl number 50-- 029-21600 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Length 80' 4882 ' 9140' Producti on 9150'MD 6877'TVD 9055'MD 6809'TVD Size 16" 9-5/8" feet feet feet feet Plugs (measured)None Junk (measured) None Cemented 1540# Poleset 1400 sx AS III & 350 sx Class G 270 sx Class G & 175 sx AS I Measured depth 115'MD 4919'MD 9140 'MD True Vertical depth 115'TVD 3851 'TVD 6869 ' TVD Perforation depth: measured true vertical 8830'MD 8834'MD 6649'TVD 6651 ' TVD Tubing (size, grade and measured depth) 2~7/8", J-55, tbg w/tail @ 8646' Packers and SSSV (type and measured depth) HR-1-SP pkr @ 8619' & TRDP-1A-SSA SSSV ~ 1792' 8836 'MD 8865 'MD 8873 'MD 8858 'MD 8869 'MD 8876 'MD 6653'TVD 6674'TVD 6680'TVD 6669'TVD 6677'TVD 6682'TVD 8881 '-8893 'MD 6685 ' -6694 'TVD 12. Stimulation or cement squeeze summary Intervals treated (measured) 8750' - 8752' ~eatment description including volumes used and final pressure 150 sx Class G 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well History) Daily Report of Well Operations Copies of Logs and Surveys Run Y-~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Title Associate Enqineer (DAM) SW0/095 Submit in Duplicate' ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" oq 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 I County. parish or borough I State I Alaska Alaska North Slope Borough Kuparuk River 3K-1 Auth. or W.O. no. ~Title AFE AK1339 I Completion Nordic #1 API 50-029-21600 Operator I I ]ARCO W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun IDate [Hour Prior status if a W.O. Complete 8/23/86 1130 hrs. Date and depth as of 8:00 a.m. 8/23/86 thru 8/25/86 8/26/86 Complete record for each day reported 7" @ 9140' 9055', C&C hole 10.0 ppg NaC1/NaBr Accept ri~ @ 1130 hrs, 8/23/86. ND tbg head, NU & tst BOPE. RU GO, perf for sqz f/8750'-8752', RD GO. RIH w/sqz pkr, set @ 8500'. Pmp & sqz 150 sx C1 "G" w/.85% D-60, .2% D-46 & 5% KC1, POH w/3½" DP & sqz pkr. TIH w/6-1/8" bit, tag cmt @ 8502', drl cmt to 9020'. Tst sqz & csg to 2000 psi; OK, C&C hole, POH, LD DP. 7" @ 9140' 9055', RIH w/CA 9.9 ppg NaC1/NaBr POH w/3½" DP, bit & scrpr. RU, perf 8830', 8834', 8836', 8858', 8865', 8869', 8873' & 8876' (limited entry), & 8881'-8893' w/1SPF, 120° phasing. RD Gearhart. RIH w/CA. The above is correct , For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date Title Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday utter 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 required upon completion, report completion and representative test data in blocks provided. The "Final Reporl' form may be used for reporting ~he entire operation if space is available. District Alaska Field Kuparuk River Accounting cost center code ICounty or Parish State North Slope Borough Alaska Jhease or Unit Well no. ADL 25520 3K-1 ITitle Auth. or W.O. no. AFE AK1339 Completion Nordic 1 API 50-029-21600 Operator I A.R.Co. W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun ~Date Complete J 8/23/86 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 bandonrnent of this well our J Prior status if a W,O, I 1130 hrs. 8/27/86 Did TD New TD Released rig Date 1730 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing 7" @ 9140' 9055', RR 7.5 ppg Diesel Rn 272 jts, 6.5#, J-55 AB Mod 8RD EUE tbg w/SSSV @ 1792', HR-1-SP Pkr @ 8619', TT @ 8646'. Set pkr, shear SBR. ND BOPE, NU & tst tree. Displ well to diesel. RR @ 1730 hrs, 8/26/86. PB Depth IK nd of rig 8/26/86 I IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Rotary 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 For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ARCO AlasKa. In Pos! Office Box 100360 Anchorage. AlasKa 99510-0360 Telel~t~one 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. DATE 07-~2-86 TRANSMI ~"~fAL # 5702 Please acknowledge receipt and Open Hole LIS Tapes: Schl: One tape plus listing for each 0067.0-2023.5 0995.0-8314.5 1441.5-6812.0 2992.5-9025.0 0994.0-9974.0 ~2T-9 Edit LIS 06-22-86 Run #1 ~2T-10 Edit LIS 06-18-86 Run ~1 ~2T-11 Open Hole 06-05-86 Run #2 ~ 3K-1 Open Hole 06-10-86 Run #1 ~ 3K-2 Edit LIS 06-19-86 Run #1 Receipt Acknowledged: State of AK Date: ARCO Alili[I. lng tS ~ Subs,chary O! Alll~lm¢l~hcl~ftel(~CoI11DImy ~ ~, OIL AND GAS CONSERVATION COMk 4ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK Operation Shutdown _ Re-enter suspended well_ _ Plugging _ Time extension _ Stimulate X Pull tubing _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) 99510 5. Type of Well: Development .~_ Exploratory _ Stratigraphic _ Service -- 4. Location of well at surface 1434' FSL, 318' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1329' FSL, 804' FEL, Sec. 27, T12N, RgE, UM At effective depth 1622' FSL,749' FEL, Sec.27, T13N, RSE, UM At total depth 1687' FSL, 733' FEL, Sec. 27, T13N, RgE~ UM 12. Present well condition summary Total Depth: measured 91 5 0' true vertical Effective depth: measured true vertical Casing Length Structural Conductor 8 0' Surface 4391 9' Intermediate Production 91 4 0' Liner Perforation depth: measured 13. Attachments feet 6877'-feet 9055' feet 6 8 0 9' feet Size RKB 69 7. Unit or Property name Kuparuk River Unit 8. Well number 3K-01 9. Permit number 86-101 10. APl number so-029-21 600 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth 1540# Poleset 115' 115' 1400 Sx AS III & 491 9' 3851' 350 Sx Class G 270 Sx Class G 91 4 0' 91 4 0' 175 Sx AS I 16" 9 5/8" 7" 8818'-8896' 6 SPF 0 degree phasing ,.. ~ true vertical " 6640'-6696' 6 sPF' 0 degree phasing Tubing (size, grade, and measured depth 2 7/8" J-55 w/tubg tail at 8646' Packers and SSSV (type and measured depth) Camco HR-I-sp ~ 8619, Camco TRDP-1A-SSA @ 1792' Description summary of proposal ~ Detailed operation program _ BOP sketch 14. Estimated date for commencing operation July. 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas __ Suspended Service 17. I here[~ certify thaJkthe foregoing is true and correct to the best of my knowledge. Si~lned~'/)~~ · l~ Title Senior Operations Engineer FOR COMMISSION USE ONLY Conditions of approval' Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test _ Subsequent form require Orlgln~l ~Ji~ed l~y David W, John~t~ Approved by the order Commission Commissioner Form 10-403 Rev 5/03/89 Approved Copy i~eturne,d IApproval SUBMIT IN TRIPLICATE Well 3K-01 Solvent Stimulation Treatment Arco Alaska, Inc requests permission to perform an A Sand solvent stimulation treatment on KRU Well 3K-01. The treatment will consist of pumping a 67 bbls xylene pill displaced into the perforations by 56 bbls of diesel. The purpose of this stimulation is to remove reservoir damage incurred during the recent reperforation of the A2 and A3 intervals. The expected reservoir pressure is 2200 psi and no BOP equipment will be necessary. STATE Of ALASKA ALASKA ,.,il AND GAS CONSERVATION COMMIL_.ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~.' Operation Shutdown .~ Re-enter suspended well -- Alter casing Time extension '.~ Change approved program ~ Plugging % Stimulate r- Pull tubing- Amend order ~- Perforate Other ' 2. Name of Operator ARCO Alaska, Inco 3. Address P. 0. Box 100360 Anchorage, AK 4. Location of well at surface 1434'FSL, 318'FWL, Sec.35, T13N, 5. Datum elevation (DF or KB) 69' RKB 99510 Kuparuk River 7. Well number R9E, UH 3K-1 6. Unit or Property name Unii; At top of productive interval 8. Permit number 1267'FSL, 781'FEL, Sec.27, T13N, R9E~ UM (approx.) 86-101 At effective depth 9. APl number 1633'FSL, 714'FEL, Sec.27, T13N~ R9E, UM (approx.) 50_029-21600 At lt~ot¢~ ~1~ 10. Pool , 716'FEL, Sec.27, T13N, R9E, UM (approx.) Ku'paruk River Oil Pool feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Length 80' 4882 ' 9140' Production 91 50 feet Plugs (measured) None 687 7 feet 9055 feet Junk (measured) None feet 6809 Size Cemented Measured depth 16" 1540# Poleset 115'MD 9-5/8" 1400 sx AS Ill & 4919'MD 350 sx Class G 7" 270 sx Class G~ 9140'MD ~ue Verticaldepth 115'TVD 3861'TVD 6870'TVD Perforation depth: measured N one true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) N on e 12.At.tacl~m~Dts. Description ,summary of ~oroposal [] 13. Estimated date for commenc~g operation September, 1986 14. If proposal was verbally approved Detailed operations program ~ BOP sketch Name of approver Date approved 15. I hereby certify t.hat the foregoin¢ is true and correct to the best of my knowledge Signed(~~ ~ Title Associ ate Engi neet , Commission Use Only ( DAM ) SA/069 Date Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity i~, BOP Test ~ Location clearance ............ . :..~ :r.; :~ :/ Commissioner IApproval No. ~ ~ by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "lnitisl 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 Alaska Field Kuparuk River Auth. or W.O. no. AFE AK1339 ICounty. parish or boroug~ North Slope Borough ILease or Unit ADL 25520 ITitle Drill IState Alaska IWell no. 3K-1 Doyon 9 AP1 50-029-21600 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded 6/4/86 IHour 1930 hrs. Date and depth as of 8:00 a.m. 6/05/86 Complete record for each day reported 16" @ 115' 1250', (1135'), DD Wt. 9.4· PV 19, YP 14, PH 9.0, WL 12.8, Sol 8 IARCO W I Prior status if a W.O. 56.24% 6/06/86 6/07/86 thru 6/09/86 6/10/86 Accept rig @ 1400 hfs, 6/4/86. NU diverter sys. Spud well @ 1930 hrs, 6/4/86. Drl to 423' DD to 1250' · · 16" @ 115' 4204', (2954'), Drlg Wt. 9.6, PV 19, YP 13, PH 8.5, WL 13.2, Sol 10 Drl & surv 12¼" hole to 4204'. 559', 3.9°, N 1.4E, 558.85 TVD, 5.62 VS, 6.40N, 3.01E 923', 15.4°, N13W, 917.16 TVD, 65.61VS, 66.50N, 2.82W 1481', 30.9°, N13W, 1427.62 TVD, 286.68 VS, 281.12N, 56.35W 1856', 39.7°, N13.4W, 1732.25 TVD, 504.70 VS, 493.49N, 105.79W 2327', 45.6°, N 7.6W, 2073.07 TVD, 829.26 VS, 812.65N, 165.38W 9-5/8" @ 4919' 8459', (4255'), Drlg Wt. 10.1, PV 15, YP 7, PH 9.5, WL 6.4, Sol 10 Drl 12¼" hole to 4940', short trip, C&C, POOH. RU & rn'123 jts, 9-5/8", 36#, J-55 BTC csg w/FC @ 4836', FS @ 4919'. Cmt w/1400 sx AS III w/10#/sx Gilsonite. Tailed w/350 sx C1 "G" w/2% S-1 & .2% D-46. Displ & bump plug. ND 20", NU & tst BOPE. TIH w/8½" BHA to FC, tst csg to 2000 psi. DO flts & cmt + 10' new formation. Conduct formation tst to 12.5 ppg EMW. Drl & surv 8½" hole to 6343'. 2638', 46.2°, N7.5W, 2289.50 TVD, 1051.88 VS, 1034.05N,194.72W 3454', 46.4°, N9.7W, 2856.45 TVD, 1634.37 VS, 1616.77N, 263.46W 4240', 46.5°, N5.7W, 3393.29 TVD, 2205.37 VS, 2186.08N, 336.37W 4880', 45.6°, NSW, 3833.44 TVD, 2671.33 VS, 2644.52N, 408.48W 5681', 45.4°, Nll.7W, 4398.34 TVD, 3239.30 VS, 3202.83N, 513.87W 6185', 45.0°, N13.9W, 4753.47 TVD, 3596.88 VS, 3551.55N, 593.09W 6688', 44.8°, N15.9W, 5109.77 TVD, 3951.50 VS, 3894.64N, 684.38W 7698', 44.1°, N18.9W, 5834.76 TVD, 4651.79 VS, 4566.12N, 892.87W 8193', 43.9°, N21.1W, 6190.83 TVD, 4992.39 VS, 4889.22N, 1010.47W 9-5/8" @ 4919' 8995', (536'), Logging · Wt. 10.1, PV 17, YP 9, PH 9.5, WL 4.8, Sol 12 Drl 8½" hole f/8459'-8995', short trip, C&C, POOH. RU Schl, rn DIL/GR/SP/SFL f/8994'-4920', FDC/CNL f/8994'-7800', CAL f/8994'-4920'. The ab.~'~ co rrect ~, For form preparati~l/aj~d'distributiOn, see Procedures M(I~I,~I, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructiona: 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 abpreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Fir)al Reporl" form may be used for reporting the entire operation if space is available. Accounting cost center code District :County or Parish State Alaska North Slope Borough Alaska Field Kuparuk River Auth. or W.O. no. Title AFE AK1339 Drill Lease or Unit I Well no. ADL 25520 { 3K-I Doyon 9 Operator ARCO Alaska, Inc. A.R.Co. W.I. 56.24% Spudded or W.O, begun Date Spudded 6/4/86 Date and depth Complete record for each day reported as of 8:00 a.m. Old TD 6/11/86 6/12/86 API 50-029-21600 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our ~Prior status if a W.O. 1930 hrs. I 9-5/8" @ 4919' 9150' TD, 9055' PBTD, (155'), Rn'g 7" Wt. 10.1, PV 16, YP 8, PH 9.5, WL 4.6, Sol 12 RD Schl. TIH, drl & surv 8½" hole to 9150', C&C, POOH, LD DP. Chg top rams to 7". RU & rn 223 jts + 1 mkr jr, 7", 26#, SR-2 & set @ 9140'. 9103'' 44.5°, N17E, 6843.22 TVD, 5605.57 VS, 5511.61N, 1032.75W 7" @ 9140' 9150.' TD, 9055' PBTD, (0'), RR 10.0 Brine Cmt 7" w/lO0 sx 50/50 Pozz w/4% D-20, .5% D-65 & .2% D-46, followed by 270 sx Cl "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Displ cmt w/10.0 brine, bump plug. ND BOPE, Instl pack-off & tbg head. Tst flange to 3000 psi. RR @ 1600 hrs, 6/11/86. New TD IPB Depth Kind of rig 9150' TD 9055' PBTD Released rig Date 1600 hrs ' 6/11/86 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single 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 Th~:FO~ is correct Drilling, Pages 86 and 87. Drilling Supervisor ADDENDUM WELL: 6/20/86 3K-1 Arctic Pak w/175 sx AS I, followed by 64.7 bbls Arctic Pak. MEMORANt JM Stat6 3f Alaska Ai~,.SKA OIL A~.~ GAS CONSERVATION CO~.R.~ISSi.,d TO: C.V. ~/~.~&on DATE' June 10, 1986 Chairm~.~' FILE NO.' D. JFB. 1 TH RU: FROM: Lonnie C. Smith Commissioner John F. Boyi~~ C ~_ Petroleum Engineer Asst. TELEPHONE NO.: SUBJECT: BOP Test ARCO KRU 3K-1 Permit No, 86-101 Kuparuk River Field Friday, June 6, 198.6: I traveled this date from Anchorage to K~Paru~%d to witness the BOP test on ARCO's KRU 3K-1 well. Saturday_, June 7, 1986: The BOP test commenced at 2:06 p.m. and ~6ncluded at 3:06 p.m. There were no failures. I filled out an AOGCC report which is attached. In summary, I witnessed the BOP test on ARCO Kuparuk 3K-l, Doyon Rig 9. -001 A(Rev 10-84) . . Drilling Contractor Ri Location- General ~ ~ Well Sign ~ ~_ General H°uSekeePing~Rig'~. Ad. ~ >. - it.. Reserve Pit Mud Systems Visual · ~-'~-~.~ Trip Tank Pit Gauge Audio Date Flow Monitor . . · --'.:: :~ G~s' Detectors -::.-~,~;~_ :q <.~i:'!_~~ ' 'Bl~.nd Rams.X~ H.C.R. Valve ' ~ L~e Valves'O ' Check Valve ... ~ ~. . r, .. . . ~ .. - . . ~:- ... . Well . ~ ~ Z / Representative_ Permit # ~~Casing Set. . · Representative ACC~ATOR SYST~ ft. / Full Charge Pressure ~.c~O ~ Pressure After Closure_' l,q,~'0 Pump incr. c~os. pres. 200 psig Full C~arge Pressure Attained: psig. psig · Omin ~/3se=- Controls: Master__ ~/,~d vt*t ~ ' Remote T~ Blinds switch cover ' "~" ~' Kelly and Floor Safety Valves LoW~'"Kelly~7:~· ~'~Test Pressure '" Ball Z '(9~.' / Test Pressure.. Choke Manifold ~ ~est Pressure No. Valves $~ <'-~~ ~~ ~ No. flanges ~'~ ~ ~' Adjustable Chokes Hvdrauicall¥ ooerated choke Test' Results: Failures ~ Test Time -Z_~.. hrs. ~OO Repair or. Replacement of failed equipment to' be made within days and Inspector/ Commission office notified. Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector May 21, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box !00360 A~nchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: 3K-i ARCO Alaska, inc. Permit No. 86-101 Sur. Loc. 1434'FSL, 318'F~-~, Sec. 35, T13N, R9E, Btmttole Loc. 1509'FSL, 833'FEL, Sec. 27, T13N, R9E, 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, t~,q~ere 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. Cha~er. to~ Chai~an of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COI-~ISSION jo Eric io sure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION C,. .'1MISSION PERMIT TO DRILL 20 AAC 25.OO5 I la. Type of work Drill ~ Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test © Development Oil ~ Re-Entry ~ Deepen ~1 Service [] Developement Gas ~ Single Zone ~ Multiple Zone I~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 69', PAD 35' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk Ri vet Oi 1 Pool P.0. Box 100360 Anchorage, AK 99510 ADL 25520 ALK 2556 4. Location of well at surface 7. Unit or property Name 11. Type Borld(see 20AAC25.025) 1434'FSL, 318'FWL, 5ec.35, T13N, R9E, UN Kuparuk River Unit Statewide At top of productive interval 8. Well nu ,mber Number 1267'FSL, 781 'FEL, Sec.27~ T13N, R9E, UN 3K-1 #8088-26-27 At total depth 9. Approximate spud date Amount 1509'FSL, 833'FEL, Sec.27, T13N, R9E, UM 06/10/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line 8932 ' MD 318' ¢ surface feet 3N-15 5280'f~ TI~ feet 2_560 (6776'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 Kickoff depth 400 feet Maximum hole angle44 0 Maximum surface 2287 psig At total depth (TVD) 3385 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 6" 2.5# H-40 Weld 80' 5' 35' 115' 115' +200 cf 12:~" -5/8" 6.0# J-55 BTC 4822' 5' 35' ~857' 3864' 1385 sx AS I I I & HF-ER 325 sx Class G blend 8½" " 6.0# J-55 BTC 8898' 4' 4' B932' 6776' 200 sx Class G(minimum) HI--bK' TUC 500' above top of Kuparuk. 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface : ' Intermediate , · Production " Liner ~.. , Perforation depth: measured " :',:.~;~ true vertical ' 20. Attachments Filing fee ~ Property plat C BOP Sketch ~ DiverterSketch :~ Drilling program ~ Drilling fluid program ~ Timevs depth plot ~ Refraction analysis ~ Seabed report ~ 20AAC 25.050 requirements 21. I hereby certif~cthat the foregoing is true and correct to the best of my knowledge _ Signed TitleRegional Drilling Engineer Date.%--~¢ ~. ;/~ ~/¢, /? .... /' Commission Use Only " ,/ ' / (HRF) P ',~/PD?~9 I API number I Approvl~.~el_ See cover letter Permit Numb'er ,~'~- -' [O! 50-- O ~L~,- [~--[ ('~- C;© /86 for other requirements Conditions of approval Samples required [] Yes "~.No Mud log required ~ Yes ,'~ No Hydrogen sulfide measures ~ Yes ~ No DirectiOnal survey required ~.Yes ~ No' in ~ · , · ½ · ~ 10M; Required work ~~~5M, 15M e~/,~ Other: by order of Approved by Commissioner the commission Dat Form 10-401 Rev. 12~5 / Sul triplicate I _. ....... ~ - ~ J t ~ ...... t -'r ......... :":'i '~ ....... ' ' -- ! " ~ I '~ I ...... ~ ........ t ..... ,'--:-~'f .... ~-' , T / - ' j - .' r ..... l ''- r ...... T ..... r .... · i - -- ' - _.~ .... r _ I ~ j ~ [ ', ~ ::_._~&::-:~,: -j ........ ~ ...... ~ ...... ~ .... ~_._i. -; ..... ~ ~ ..... ~..: .... =... ........... T/ZONE A ~ TVO-~S5~' T~-8~-~--~O~N ......~ · · ~ - - , _ ~ _ ."_ ~ _~_ i'. , . | O0 '0 6 S :3. 2 KUP/~RUK R I VER UN I T 20" O I VERTER SCHEM/~T I C DE SC R I PT I ON 1. 16" CONDUCTOR. 2. TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LOWER QUICK-CONNECT ASSY. S. TANKO UPPER QUICK-CONNECT ASSY. 6. 20" 2000 PSI DRILLINQ SPOOL W/lO" OUTLETS. 7. 10" HCR BALL VALVES W/lO" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 8, 20" 2000 PSI'ANNULAR PREVENTER. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC2S.03S ( b ) MAI NTENANCE & OPERAT I ON 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW A 1R THROUGH O I VERTER L I NES EVERY !2 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE OOHNWINO OIVERSION. DO NOT SHUT IN HELL UNOER ANY C I RCUMSTANCES. 0084002 R 1.__._.~( < J 1 6 J 4 I3 2 13. ~. ~" - ~ FSI X ~-S/8" - ~C~ PSI S~AC~ SPCa_ ,4. ~8" - ~ ~ P~ ~ K~ LZ~ 6. 1~8" - ~ ~I ~ ~ W~I~ ~ ~ T~, 7. 1~8" - ~ ~I ~ AC~ATCR CAPACITY TgST 1. Q-ECX AAD FILL ACCZM..LATCR RF~OIR TO PRC~ LEVEL WITH HYDRAULIC FLUID. 2__.~ 'R-{AT A~TC~ ~ IS ~ PSI WITH 3. CBSE~VE TI~, T~ CLOSE ALL UNITS SI~IJLTAt~CUSLY ALL UNITS ARE CLOSEI) WITH CHARGIN~ PUVP CFF. 4. RECORD ON NArC RE, CRT, ll-E ACTABLE LC:~4~ LIMIT IS 45 SEO:lq~ CLOSING TINE AhD 1200 PSI RgMAI~NG 13-5/8" BOP STACK TEST 1. FILL BOP STACX AhO CHCI<E IV~NIFOI.D WITH ARCTIC DIESEL. Q-ECX THAT ALL LOCI4 EO~ SCRLc'Y~ IN Y~ AR~ Flay RETRAC~. SEAT TEST PLUG IN Y~E1.L~F_AD WITH RUNNING J'~ AhO RUN IN LO(~ SC~. LIhE VALVES ADJA~ TO BOP STAC~ ALL 4. PRES..qJRE UP TO ~ ~Z_A~NCLD FOR I0 MIN. IN- CREAS~ PRE~ TO ~3~.___~ AND H~LD FCR lO MIN. B~ I::h~~ TO O-PSI. 6; TEST TO 250 AS IN STEP 4. ?. ODVTIhI.E TESTING ALL VALVES, LIb, ES, AND CHO<ES WITH A ~ PSI LC~ A/,,D 3000 PSI HIGH. TEST AS IN STE~ 4. DO NOT Pt:~~ TEST ANY O-.K]KE THAT IS NDT A FULL CLOSe.Kg POSITIVE SEAL CHCKE. CN_Y ~ICN TEST CHO(ES THA'T DO NOT FLLLY CLCSE. 8.(:PEN TOP PIPE P, AN~ ~ CL__r6E_ BOTTC34 PIPE TEST BOTTCI~ PIPE RAMS TO ~ PSI AND 30C0 PSI. 9. (:PEN BOTTCI~ PIPE RAMS, t~AQ( OUT RMNNING JT AhD .10. CLOSE BLIhD RAMS AND TEST TO 250 PSI AND PSI; II. CPEN BLIt,,D RAJv~ AND RETRIEVE TEST PLLK~. MAKE .SURE MANIFOLD AND LINES ARE FULL. CF hl31N-FRFF'TING FLUID, SET ALL VALVES IN DRILLING POSITI61% 12. TEST STAN~IPE VALVES, KEJIY, KF31Y CCX:XS, DRILL' PIPE SAFETY VALVE, AND INSIDE BOP TO 2.50 PSI AND 3000 PSI. RE~ TEST INF~TION CIN BL~ PC~'VE~T1D~ TEST FO~4, SIGN, AhD ,SEND TO DRILLING SUPERVI~, PF_.RFCI~ O3,4M_ETE BCPE TEST AF'FE~ NIPPLIN2 UP AND YC_EKLY THEREAF'FER ~ICI'4ALLY ~TE BCPE DAILY. 5 i O084O01 REV. 2 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in, 21. Secure well and release rig. 22. Fracture stimulate. -~ DEOASSERt SHALE SHAKERS CLEANER STIR ~ STIR STIR CLEANER TYPICAL MUD SYSTEM SCHEMATIC LWK4/ih DRILLING FLUID PROGRAM Density PV YP viscosity Initial Gel 10 Minute Gel Filtrate API pH % Solids Spud to ~ 9-5/8" SUrface Casing 9.6-9.8 15-30 20.40 50-100 5-15 15-30 2O 9-10 10_+ Drill out to Weight Up 5-15 8-12 35-40 2-4 4-8 10-20 9.5-10.5 · 4-7 Weight Up to TD 10.3 9-I3 8-12 35-45 3-5 5-12 9.5-10.5 9-12 Drilling Fluid System: Triple Tandem Shale Shaker 2 Mud Cleaners Centrifuge Degasser Pit Level Indicator (Visual & Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Drilling fluid Practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated sUrface pressure is calculated using a,-:':/ surface casing leak~off of 13.5 ppg EMW (Kuparuk average)"and a gas gradient of .11 psi/ft. This shows that formation breakdown-would occur"before~a ~surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. - After 200' of departure, there are no well bores within 200' of this proPosed well.. LWK5/ih ARCO Alaska, Inc. Post Office L~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 7, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3K Pad (Wells 1 - 18) 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 GRU1/12 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ;TION 35, T. 13N., R. gE.,U A.S.P. North T.~,.~ , ~ ~';' ~ , , .' LOCATED IN PROTRACTED LOCATED IN PROTRACTED [ - Y = 6,008,4Z8.74 ~T. 70~26'02.7804" 10 - Y - 6,008,153.79 LAT. 70~26'00.076Z" X - 529,~06.[8 LON~. [49~45'39.9297" X - 529,305.69 LONG. [49~45'39.9756~ 14~' FSL, 3[8' ~ 0~ - ~.2 P~ - 34.5 ~ 1160' FSL, 3[6' F~L 0~ - 29.8 P~ - 34.5 ~ - Y - 6,0~8,405.66 ~T. 70°26'02.53~8' ~ t[ - Y - 6,008,[Z8.19 ~T. 70~25'59.8~' X · 5~9,306.[9 LON~. 149~45'39.9~22" ~ X - 529,305.73 L0~. [49~45'~9.9774" 1~9~ FSL, ~[8~ ~L 0~ - 28.~ PA0 ~ 34.5~ 1135' FSL, ~ - Y ' 6,0~,378,66 ~T. 70~6'02.Z879" [2 - Y ' 6,008,103.63 ~T, 70~25'59.5828 X - 529,306.14 L~G. 149~45'39,9366" X" 529,~5.72 L~G. t49~45'39.9805" ~' FSL, 318' ~ OG ~ ~.5 P~ ' 34.5 ~109' FSL, 3~6' F~ ~ · 30.0 P~ - 34.5 13 - Y - 6,008,078.67 ~T. 70025'59.3373 Y 6,~8,353.~ ~T, 70~26'02.0414" X- 529,3~.11 L~G. 149~5'39.9~3" X- 529,~5.7Z L~G. 149'45'~.9835" 1359' FSL, 318' ~L 0G - 28.7 PAD - 34.5 1084' FSL, 316' 5 - Y - 6,008,3~.58 ~T, 70~26'01.7953' 14 - Y · 6,008,053.76 ~T. 70'25'59.0923" X- 529,306.07 LONG. 149045'39.9~5" X- 529,~5.8~ LONG. 149'45'39.98~" 1334' FSL, 317' ~ ~ - 28.8 PAD ~.5 ~060' FSL, 316' F~L 0G - ~.0 PAD - 34.5 6 - Y - 6,008,303.64 ~T, 70°26'01.5~1" 15 - Y - 6,008,0~.63 ~T. 70°25'58.8451· X- 529,306.05 LONG. 149°45'39.9478" X- 529,305.75 LONG, 149045'39.9884" 1309' FSL, 317' ~L 0G ~ ~.9 P~ - 34.5 1034' FSL, 316' ~ ~ - 30.0 PAD - 34.5 7 - Y - 6,008,E78.~ ~T. 70"26'01.3037" 16 - Y - 6,008,003.64 ~T. 70~25'58.5994" X- 529,~5.~ LONG. 149"45'39.9529" X- 529,305.78 LONG. 149'45'39.9905' 1~4~ FSL, 317' ~ 0G ~ 29.0 P~ - 34.5 1009' FSL, 315' F~L OG - 30.0 PAD - 34.5 8 - Y - 6,0~,253.70 ~T. 70~26'01.0589" 17 - Y = 6,007,978.81 ~T. 70~25'58.3551" X - 529,305.94 LONG. 149045'39.95~' X - 529,305.77 LONG. 149°45'39.9935" 1259' FSL, 317' ~ 0G - 29.0 P~ - 34.5 985' FSL, 315' ~L OG - 30.0 PAD - 34.5 9 - Y = 6,008,2~.65 ~T. 70~26'00.81~4" 18 - Y - 6,007,953.69 LAT. 70°25'58.1081" X - 529,305.92 LONG. 149°45'39.9604' X = 529,305.73 LONG. 149~45'39.9977 1234' FSL, 317' ~L 0G ~ 29.1 PAD - 34.5 959' FSL, 315' F~L 0G NOTES I. ALL COOROINATES ARE A,S.R, ZONE4. 2. ALL DISTANCES SHOWN ARE TRUE. 3. HORIZONTAL POSITIONS BASED ON 3K CONTROL MONUMENTS PER LHD A ASSOC. 4. VERTICAL POSITIONS BASED ON 3K TBM NO. 4 ~ TBM NO. 5 PER LHD &ASSOC. 5.0.G. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED-RIXX-3070 rev. . . . CERTIFICATE OF SURVEYOR; I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE ~AND I S THIS PLAT RE~RESENTS A LOCATION SURVEY .. M~DE BY ME OR UNDER MY SUPERVISION, ~: THAT ALL DIMENSIONS AND OTHER DETAILS ., ~w~~ DRILL SITE 3K CONDUCTOR ~ECKED ~,T. ~~, ~,~ ~ ~,.~.~o~ AS-BUILT LOCATIONS ,,~,,,, .... ,,, ,,,,,,, t ' I~DWG. No. NSK 86-31 ' ~5 Arctic Bouleva~, Suite 201, Anchorage, Alaska 99503IIiis~LE NOT TO SCALE .. ilaoa i i i i i (1) Fee (2) Loc FOR NEW AP~_~OVE DATE ! (2" t~hr& 8) 7 '(9 thru 13) / (4) Casg~~,~ 5c-~-~g (14 thru 22) (23 thru 28) (6) Add: (29 thru 31) YES · NO REMARKS, 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 .......................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... 10. 11. 12. 13. Is conductor string provided ........................................ Will surface casing protect, fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie. in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... 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 ............................ 14. 15. 16. 17. 18. 19. 20. 21. 22. Is a diverter system required ....................................... ~ Is the drilling fluid program, schematic and list of equipment adequate//~/ Are necessary diagrams and descriptions of diverter and BOPE attached.~.Ffz_ Does BOPE have sufficient pressure rating - Test to ~<P~D. psig .. Does the choke manifold comply w/API RP-53 (~eb.78~..f~.~ d~ ........ Is the presence of H2S gas probable ................................. 23. 24. 25. 26. 27. 28. For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ............ 31. If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. · Geology: Engineering: HWK~ LCS ?~'~'BEW(~~ JAL rev: 04/03/86 6.011 POOL ol oo INITIAL CLASS STATUS ~cw { -o;I GEO. AREA ?qo UNIT { 0N!OFF N0./ SHORE Additional Remarks: 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. · LIS T~PE ~ERI~ICATI2N LISTIN$ ;:EDIT 065 065 ooo.'-~ Oo0 000 ' '-.300 · 0o0~0 ' OOO ,000 , ~ O0 ' 000 ~00 -000 ~-00 006 000 0 5 LVP OIO.H02 VERIFiCATI2~ LISTIN~ = ~RCD- ~.L~SKA- INC ' . COMPANY WELL~ : FIELD : KUP~.2UK - = ~DRT~i'SLOPE BOROUGH _~D~NTY JOB NUMSER .AT A.C.~ ' 71529 RUN.#ONE~ DATE LOGGED: IO JJN BS- LDP:~ HALSTEAD CASING : TYPE FLgID - : LSND WT. POLYMER DENSITY -' : IO.1).LB/G. VISCOSITY = PH~ : ~FLgID LOSS = ~ -RMF " RMC RM ~T~ BHT S NOT-BEEY DEPTH SHI LYP- OiO.HOZ YERIFIC~TI3~ LI$~IN~ ' : ' IO L S~HLUMBE~SER LOGS. INCLUDED WITH T~IS MAGNETIC :F3~USED LD~.(DIL) DdAL IND~:TIB~'SPtERICALL¥ ~ S N) ABLE: TO- 920 .~g ~ TYPE SIZE REPR CODE · 66 8 ¢' 73 9 4 _ 65' ! $ I 66 3~ 1 66 ~PI FILE API R_ ~ ,LOG-TYPE FI. O0 000' 39MM O0 220 D~MM D~MM M~' O0 O0 "310 EN1 I 68 1 LVP OIO.HO2 VER[FICATI3q LISTiN3 PAGE SR FDN GAPI CALI FDN RH3B :DN G/C3 DRH5 FDN G/C3 NRAT FDN RNRA FDN NPdI ~DN NCIL F2N CBS 'FCNL FgN GR CNL GAPI O0 310 01 0 O0 280 01 0 0.0 350 ~Z 9 O0 356 01 2 O0 898 DD 3 O0 330 31 ~ O0 330 30 0 O0 310 01 0 0000- 0000 0000 DEPT SP RH3B NP~ I DEPT: SP RHDB NP~I DEPT SP RH3B NPH'I 2EP~ SP RH2B 4PdI D~PT SP RH3B NP~I DE.PT SP RH3B NP~4I DEPT SP NP~qI SP R HDB' NP~I AT~ ~ 9025.0000 SFLd -25~5107 SR 2.2932 D~.q] 51,2207 NCNL gO00.O000' SFLJ -16.495! GR 2.2~32 DRq3 52.3~38 NC~L 8900.0000 SFLJ -27.9)5! GR 2.4104 DRq3 35.400~ MCi_ 8800.0000 SFLJ -51.4883 GR 2.4592 DRH3 36.816~ NCNL 8?00.0000 SFLJ -~7.9883 SR 2.$$0~ DRY3 32.3730' NCtC; 8500.0000 SFLJ -42.4883 GR 2;4~05 DRY] 31,5~18 'NC~L_ 8500,0000 SFLJ -7.9980 GR 2.3596 DRi2 63.359~ NCNL 8400.0000 SFLJ -52.488} GR 2.2893 DRH3 ~3,-7D12 NCNL ILD 0.t55 1732.681 2:.7073 I.L~~ ~5.8398 :GR .. 0.1558 1795.6875 FCNL ~5o8398 ' 0o0801 NR~T F ~988.6875 C~ ~.5523 GR 0;0645 NR~T 18~8.6875 FCtL 3.5~59 ~LD 79.2173 0.0)18 NRAT 2027.5000 FCNL 3.0~15 ILO 137.8398 SR . 0.0293 NRAT 2073~.5000 FC~L 3.994¢ ILO ~g.52~3 GR 0o0~73 NR~T 1757.-6-875- FC~L 2.252-0 0.02?3 NR~ 1580.'6.875 38 98~3 ~33.1 ~06 2.55 g8,8~ 3~; 9 405.'1~ 3.8~:06 ~5.8 RNRA GR . I RNR & ;R 672.8!2~ ! GR tLM':' CALI ILM~ 430.1~06 ~R 5 02 5 ¢ 2500 -99 -99 1, 3~6i -999'. 2! LVP OlO.H02 VERIFICATID4 8300.0000 SFLJ -48.9883 GR 2.3555 DR93 51.5502 NCNL 82,00.0000 SFLJ -59.9883 GR 2.3443 DRq3 39.8925 NCN_ BlO0.O000 SFLJ -56.7383 ER 2.6377 DR93 29.3657 NC~L 8000.0000 SFLJ -50.4883 GR 2.~534 DRH3 42.3340 NC~L; 7gO0.O0.O0 SFLJ -50.2383 ER 2.~07 DRY3 34.4727 NC~_; 7800.0000 SFLJ -51.9883 2.6338 DRH3 38.9548 7700.0000 SFLJ -56.9883 ~R -999.2500 DRq3 -999.2500 NCNL 7600.0000 SFLJ -59.~883 ~ GR -999.2500 DRq3 -999.2500 NCqL 7500.0000 SFLJ' '65.2227 SR -999.2500 DRq3 -999,2500 NC~-~ 7~00.0000 SFLJ -69.2227 ' ER -999,2500 DRY3 -999.2500 NCNb, 7300,0000 SFLJ -$6.7227 ER -999,2500 DRd3 -999.2500 NC4L LISTIN~ Z.~358 IL~ 135.2148 GR 0.0~35 NRA~ 1690.5~75 FCNL 2.9202 135.3125 GR 16~8.6875 FC~L 3.1467 ~LD 331.3906 O.0308NR~T 2015.5875 FCqL 3.05.88 ILD 15t.9375 'GR 0.0~39 NRAT 1853.6875 FCNL 2.5881 !L~ 1!4.5~98 GR 0,1152 NR~ F 2107.5D00 ~NL 1.$321 90.2773 GR 0.0361 NR~T 2081.5000 FC4L 2.2288 99.1523 GR -999.2590 'NR~T -9~9.2500 FCNL 2.2424 IL3 96.7773 GR -999,2500 NR~ -999,2500 FCNL, 2.8909 IL3 135.7!~8 ER -999,2500 NR~T -999.2500 FC4L 2.9~_02 ILD 100.1523 ER -999.2500 NR~lr ,9~9.2500 FC4.' 1.9639' ILO 97.4548 GR -999.2500 NRAT -999.2500 FCNL 2.2~34 IL4 106.2148 CALI 4,0710 RNR~ 351.3906 GR 2.7327 I35.3125 3.5100 432. B)06 2~ 3 30I~ 572,.3 Z, 7522 15 49 IL4 C~L.I R~R~ ILM RN.R~ GR IL RNR~ ;98 CALl )99 RN'R~ z5 GR ,2366 ILM · -99~. ER .500 RNR -999.2500 GR I lLM CALI '9( -999.2~ '9 -999,2500 LI RNR~ GR '.2'.3342 IL4 -999,250-0 CALI -999.2500 RNR~ -999.2500 GR PAGE -2~3~55 9 8301 -4.8093 -999.2500 2,2578 9.3'B~8 01 5O0 -99 3 .999 '999 '999 -3.·0~9I -999,2500 -999.2500 -ggg.-ZSO0 2~3889 -999,Z500 -999.2500 -999.2500 LVP 010.H02 VERIFICtTI2N LISTIN~ PAGE 6 DEPT 7200.0000 SFLJ SP -66.2227 SR RH]B -999.2500 DRY3 NPHI -999.2500 NC4~ DEmT: ?100.0000 -.SFL. J SP -72.722? ~. 'RH2B -999.2500 DRH3. NP~I -999.2500 NCNL DEPT 7000.0000 SFLJ SP -54o?$95 GR RH3B -999,2500 9R~O NPMI -999.2500 NC~L 3EPT- 6900.0000 SFLJ SP -61;9B83- GR RH3B -999.2500 DRHg NP~I -999.2500 NCNZ DEPT SP 'RH3B NPqI DEPT SP~ RH3B 'NPHI DEPT SP RH3B NPHI 3EPT SP RHDB NP~I DE~T SP : ~P~I DEP~: SP RHDB NPHI DEPT SP RH2B 6BO0.OOO0 SFLJ -73.7227 GR -999~250D DR93 -999.2500 6700.0000 -7~.9727 -999.2500 -999.2500 6600.0000 -17.2~51 -999.2500 -999.2500 6500,0000 ~5,2~93 -999,.2500 -999.2500- 5%00.0000 -12.2715 2¢99.2500 999o250~ 6300.0000 -12.5215 -999.Z500 -999.2500 6200.0000~ -15.193~ -999.2500 NCNL SFLJ GR DRH2 NC~L SFL2 DRg] NCN_ SFLJ ~R DRH2 NC4. SFLJ ~R DR93 NCNL SFLJ GR NC~L SFLj ~R DRt] 2.5508 IL3 ~9.~148 GR -9~9.zsoo N~r -939°2500 FC~L 2.9299 -ILD ~7.714B GR -999.2500 ]NR~T -999.2500 FCNL 3.I~87 ILD 2.93'19 IL3 88.5273 GR~ -9~9. z~oO ~NR~ -9~9.2500 FC~,, 2.5393 ILD -999.2500 NR~ -999.2500 FC~L 266389 ILD ~6.7148 GR -9~9,2500 . NR~T -9)9.Z500 FCYL 2.8225 iLD )1.2148 -999.2500 NR~T. -9~9..2500 FCNL 2.'B596 IL9 ~2.2773 GR -9~9.2500 NR~T -9~.~'.2500 FC~L 2.701~ ILD 39.'2773 GR - -9)9.2~00 NR~T -9~9.2500 FCNL 2.~202 I-LD )~.'~5~8 GR ,9)9.2500 NRAT -999,2500 FCqL 2,B206 ILD ~1.5898 GR -999.2500 NR~T 2.7151 ILM -999~2500 CALl -~99.2500 RNRA' -999.2500' GR -999,2500 GR ILM' C~LI RNR~ GR 3.153t' ILM CALI ~NR~ -99~ ;R -99.9.'2500 '999.2500 2,8 -999.2 RNR~ -999.2500 -9-99.2500 -999.,2500 -999.2500]. R~R~ ~ .-9~9.2500 G - 3o2776 IlM -999'.25~0-CALI ~.999.z~00 )N~ -999.2S00 GR 2.6~87 'ILM -999.2500 CALl -999.2500 RNR~ -999.2500 GR 2.9~17 ILM -999J2500 CALI -999.2500 RNR~ 3.-0901' -999.2500 2, 9807 -999.2500 -999. 500 -' -99 -999, O0 2 ,999 -999 -999 2.~33B -999.2500 -9~9.2500 LVP OlD.H02 VERIFIC~TIDN LISTINS NPHI -999.2500 NC~L DE~T 5100.0000: SFLJ SP -17.~682 GR RH3B' -999.2500 DRH2 NPHI . -999.2500 NC~L. ~EPT 6000'0000 SFLJ 'SP -20.4795 GR RH3B -999.2500 DRY3 NPHI -999,2500 DEPT 5900.0000 ~FL~ ~3B -20,953, SR -999°2300 DRY3 DEP~ 5800.0000 SFLJ SP -38.95T0 RH3B- 2,33~2 NPH~I 38.8572 NCNL DEPT 5700.0000 ~FLJ SP '33,7270 ~R RH2B 2.3Z64 DRH] NPHI 37.6665 . NCNL 3EPT 5500.0000 SFLJ SP -22.1~70 RH35 2.326~ DRH2 NPHI 39.~1~ ' NCNL DEPT' 5~00.0000 SFLJ SP -3B.1755 ' 2R NP~tI 41.9636 NCNL DE~T 5~00.0000 SFL'J SP -38.2070 GR RH3B 2,2~52 DRt2 .ERT 5300.0000 'SFLJ RHSB 2'2345 DRY3 NPHI DEPT 5200.0000 SFLJ SP -19o~3Z'$ GR .RH3~ 2.2683 DRH3 NPHI 46.3'867 NCN~ D'EPT 5100.0000 SFLJ SP -39.3533 -999.2500 FC'4L 2.4768 ILD ?9.5273 GR -999,2500 NR~T -999.2500 FCNL 2.8147 ILD 81:3398 GR -9~9 2500 NR~T -999.2500 FCNL 2.80'69 ILD B2.027~ GR -9~9.2500 9 ~9.25:00' FCNL 2.9299 ILO ~1.71~8 ~R 0.0117 19~9. 5875 FC~L 3. 0061 IL9 ~0.0273 GR 0.0t37 N-R~T 2153.5000 FC~L 3.1311 IL3 ~5.0'z73 ~R 0.0068 NR~T ' 2127.5300 FCNL 3~393 87.9548 GR -0.0015 NRA? 1958.6875 FCNL 3.1311 ILD 30. t5.23 GR 0,0D49 NRAT 19%6.$B75 FCNL 0.0034- NRAT 2151.5000 mCNL 2.4~84 ILD ~5.¢548 GR -0.0005 NRAT - . 1878.5875 FC~L 2-.8B50 IL2 ~6.7773 GR -9~9. ~.00 GR 2.,8~30 ILM -999.2500 CALI -999.2.500' RNR~ ~999.250~ SR 3.1760 IL~ IL4. CALI ~NRAR 3~ 3'~5100 ILM 80.9548' C~LI 3.3069 RN~ 571.3125 GR 453.6605 GR PASE, -999.2500 500 ~9~9.2'500 O! 3 -9gg 2.77!7 9.8513' -999.2500 3.832~ 9.955 LV)' OlO.H02 VERiFIC~TI3N LISTIN3 PAGE 8 RH]B NPHI DEmT: SP NPflI 'DEPT SP RH3B DEPT SP DEP? NP~I DEPT: SP NPHI RH3B NP~I SP RHgB ~PHI DEPT SP NPHI DEPT SP RHOB NP~I DE~[ SP RH~5 NP~I DEPT 2.2581 39,2090 NCNL 5000.0000 SFLJ -52.8533 GR 2.2500 DRH3 ~.3359 NCNC ~900,0000 SFLJ -999.2500 SR -999.2500 -999.2500 NCNL ~800.0000 SFLJ -999.2500 GR -999.2500 DR~2 -999.2500 NC~_ 4700.0009 SFLJ -999.2503 ~R -999,2500 DRq2 -999.2500 NCNL 4500.0000 SFLJ -999.2500 ~R -999.2500 DRH3 m999.2500 NC~ 500.0000 SFLJ 9'99.2500 GR -999.2500 DR92 -999,2500 NCNL. ~O0.O000 SFLJ -99~2500 GR -999,2500 DR93 -999.2500 NCAi. ~300,0000 SFLJ -999.2500 SR -999.2502 DR93 -993.2500 NC~L ~200.0000 SFLJ -999.2500 GR -999.2~00 DR 3 -999.2~00~ NCNL ~100.0000 SFL~ -999.2500 -999.2500 D-R93 -999.2500 NC~ ~000.0000 SFLJ 0.0015 NR~T 1871.5875 FCNL Iw53~8 IL~ 97.8398 GR 0~0122 NR~T 17/6.$875 FC~_ -999.2500 'IL) -999.2500 GR -999.2500 NR~T -939,2500 FC~L. -9~9,2500 NR&T -939.2500 FCAL-, -999.2500 -999.2500 GR -999'250'0 NR~T -9~9.2500 FCNL -939.2500 -999.2500 ~9~9.2500 NRAT -9~9.2500 FCNL -999.2500 -999.2500 GR -999.25O0 NR~ -9~9.2500 FCqL -999.2500 ILD -939.2500 GR -999.2500 ,NR~T -999.Z~00 F'CAL' -9~9.2500 ILD -9~9.2500 GR -999.2500 NR~T -9~9.2500 FC~L -9~9,2500 ILD -999.2~00 GR -9~9,2500 NR~T -9~9.2500 FC~C~ -9~9.2500 IL) -999,2500 GR -9~9.2~00 NR~T -9~9.2500 FCNL -9~9,.2500 IL) 3.4006 RNR~ ~99.6~06 GR 2.235~ ~LM 3,72~9 RNR~ ~$2o1~06 GR -~99,2500 ILM -999.25100 CALI -999.2500 RNRR -999.2500 GRi -999,2500 -999~2500 -99'9.2500 -999.2500 RNR~ -999.2500 GR 9 -99 .2~00 -999,2500 CALI -99-9.2500 ~NR~~ -9.99.2500' -999,2500 IL) -999.2500 CALI -999.2500 -999.2500, GR -999.2500 ILM -999.25'00 CALI -999.2500" RNRA -999.2500 GR -999.2500 -999,2500 -999.2500 -999,2500~ -999.2500 -999.2500 -999,2500 RNR~ -999,2500::'..G.R -999.2500 -999-.Z~00 CALI -9~'9.2~00 RNR4 -999.2500 GR -~99.2500 tLM -999.2-500. 2.2600 1 -999 2500. '999. 2500- 54.1580 -999.2500 --( -999.2500~ ~999.2500 999.250.0 :500 0 -999,2'500 5'3.1055 ~999.2500 99'9w2500 -999.2500 32..0742 ~999.2500 LVP OlO.H02 VERtFIC~TI2~ LISTIN~ SP -999.2500 GR RH3B -999,2500 DRH] NPHI -999.2500 NC~L DEPT' 3900.0000 SFL'J SP -999.2500 GR RHDB -999.2500' DRq3 ~PHI -999.2500 NCNL- DEPT 3800.0000 -SFLJ SP -999.2500 GR RH23 -999,2500 DRD] NPHI -999.2500 NC~L. DEPT- 3700.0000 SFLJ SP -999.2500 RH3B. -999.250-0 DR92 NPHI - -999.2500 DEPT -3~O0.OgO0 SFLJ SP -999w2500 GR RHgB -99'9.2500 DRq3 NPiI -999.2500 NCNL DEPT ~500o0000 SFLJ SP .9.99°2500 ER RHDB ~999.2500 DRq3 9 ' ~HI - 99.2~00 N~ EPT . 3600.0000 SFLJ P -999.2~00 ~R RHDB -999.2500 DR53 NPMI -999.2500 NC~L DEP~ 3300°0000 SFL2 SP' -999.2500 GR RH3B -999.2500 NPqI -999.2500 NCNL DEPT 3~00.0000 S'FLJ SP - 99.2500 GR RHD5 -999.2500 DRH3 NP~I -999.2'500 'NC~. DEPT 3100.0000 SFL~ SP RHDB ~PHI -999.2500 GR -999,2500 DRM3 -999.2~00 NCNL DEPT 3000.0000 SFLJ SP -999.2500 ER RHDB -999,2500 DRY3 NPqI -999.2500 NC~L -999.2500 ER -9~9.2500 NR&T -9~9.2500 FCNL -999.2500 ILO -9~9.2500 GR ' -9~9.2500/ NRAT' -9~9.2500 cNL ,9}9.2500 ILD -9~9.2500GR -9)9.2~00 NRAT -999.2500 FC~L -9-}9.2500. ILD -999.2500 GR -999.2500 NRAT -9~9.2500 FC~L -9~9.2500' ILD -999.250'0 GR ~-9}9,2500 NRAT -999.250.0 FCNL -999.2500 ILD ~9~9.2500 ER -9~9.2500 NR~T -9~9.2500 F.CNL -999.2500 IL3 -9~9.2500 GR -999.2500 NRAT -9~9.2500 FC~L: -9~9.'2500 IL~ -9~9.2500 GR -999.2~00 NR~T -999.2500 FCNL -999.250'0 -999.2500 G'R .999.'2500 N~T -9~9.2500 FC4L -999.2500 -999.2500 ER '9~9.2500 NRA~ -9~9.2~00 FC~- --9~9.2500 IL9 -999.2500 GR -9~9.250'0 -NRAT -999.2500 FCAL -999.2500 -999.2500 -999~2500 CA:LI RNR~ GR -999.2500 IL-M ~999.2500 CALI -999.2500 RNR~ -999.2500 GR I ER CALl ' RNR~ GR -99 -99 '999. -9.99.2500 -999.~500 -9~9. 500 ~9~9.2~00, PAGE -9' ~999, -99'9, -999 ~99 20.62 '9! -9 -999. 2500 - 99,9.2500 -9 RNR~ CAL. 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