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Home My WebLink About184-171 Ima~Project Well History File' e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. -~ ~) ~- -J- ~- L Well History File Identifier RESCAN DIGITAL DATA Color items: [] Diskettes No. [] Grayscale items: [] Other. No/Type [] Poor Quality Originals: [] Other: {- ~"~j NOTES: BY: BEVY BREN VINCENT SHERYL MARIA LOWELL Project Proofing BY: BEVERLY BREN V~T SHERYL MARIA LOWELl. OVERSIZED (Scannable) O Maps: Other items scannable by large scanner OVERSlZ. ED (Non-Scannable) Logs of various kinds [] Other Scanning Preparation BY: Production Scanning Stage I PAGE COUNT FROM SCANNED F~LE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: '~ YES NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES V~ERE FOUND: YES NO BY; ReScanned (individual page [special attention] scanmng completed) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanned.wpd STATE OF ALASKA ° RECEIVED • ALA....A OIL AND GAS CONSERVATION COMh..„SION REPORT OF SUNDRY WELL OPERATIONS 201 4 1.Operations Performed: Abandon r Repair w ell P. Rug Perforations r Perforate r Other rp OGG Alter Casing r Pull Tubing Stimulate-Frac r Waiver r Time Extension �!OG GC Approved Program r"`Operat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development rc,- Exploratory r • 184-171 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service I 50-029-21194-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25653 c ' 2D-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 • 6780 feet Plugs(measured) 6334' true vertical 6289 feet Junk(measured) 6495 Effective Depth measured ‘ 6678 feet Packer(measured) 6195,6326 true vertical 6200 feet (true vertical) 5791, 5899 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 117 117 SURFACE 2615 10.75 2650 2650 PRODUCTION 6741 7 6775 6285 SCANNED JUL 1 6 2014 134 Perforation depth: Measured depth: 6408-6410,6424-6438,6453-6493 RBDMS -MAY 1 4 2014 True Vertical Depth: 5968-5970, 5981-5993,6006-6040 Tubing(size,grade,MD,and ND) 3.5, L-80,6296 MD,5875 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER 3-1/2”4762 FHL PACKER @ 6195 MD and 5791 TVD PACKER-BAKER FHL PACKER @ 6326 MD and 5899 TVD LANDING NIPPLE-CAMCO'DS'@ 504 MD and 504 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run _ Exploratory r Development r Service r Stratigraphic r 16.Well Status after work: 'Oil F7 Gas r WDSPL r Daily Report of Well Operations )00( GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Ian Toomey aA 263-4773 Email Ian.A.Toomey@conocophillips.com Printed Name Ian Toomey Title Workover Engineer Signature --------- - Phone:263-4773 Date ,c/_) _ y <._..._ VLF 5J /J #- Form 10-404 Revised 10/2012 /"' 512, Submit Original Only • KUP PROD 2D-01 ConocoPhillips / Well Attributes Max Angle&MD TD AlaskahrWellbore API/UWField Name Wellbore Status ncl("1 MD(ftKB) Act Btm(ftKB) ,..„,..„..4,...,., 500292119400 KUPARUK RIVER UNIT PROD 40.42 5,500.00 6,760.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 20-01,4/1/20141.32.34 PM SSSV:NIPPLE _ 85 12/16/2012 Last WO: 2/17/2014 41.01 10/28/1984 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ------- ---------- - -- --- Last Tag:SLM 6,495.0 11/15/2013 Rev Reason:WORKOVER postojl 4/1/2014 HANGER;30.0 ' roil U Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(fIKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 35.0 117.0 117.0 62.50 H-40 WELDED y� �j Casing Description OD(in) 1D(In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...'Grade Top Thread {-MIL SURFACE 103/4 9.950 34.9 2,650.2 2,650.0 45.50 J-55 BTC ) Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len 11..-Grade Top Thread ■ • • PRODUCTION 7 6.276 34.0 6,774.9 6,284.9 26.00 J-55 BTC "n.AI CONDUCTOR;35.0-117.0 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD))...Wt(Ib/ft) Grade Top Connection 111 TUBING WO 2014 31/2 2.992 30.0 6,296.4 5,874.6 9.30 L-80 EUE 8RD NIPPLE;504.3 Completion Details 1. Nominal ID Top(ftKB) Top(TVD)(hKB) Top Incl(°) Item Des Com (in) I 30.0 30.0 0.03 HANGER FMC TUBING HANGER 2.992 504.3 504.3 0.22 NIPPLE CAMCO DS LANDING NIPPLE 2.875 6,165.0 5,766.7 35.60 LOCATOR BAKER LOCATER 2.992 GAS LIFT;2.582.2 6,165.3 5,766.9 35.60 SEAL ASSY SEAL ASSY-SPACE OUT 2.990 6,171.9 5,772.4 35.51 PBR BAKER 80-32 PBR 4.000 6,195.0 5,791.2 35.20 PACKER BAKER FHL PACKER 2.940 SURFACE;34.9-2,650.2 N ., 6,247.7 5,834.4 34.62 NIPPLE CAMCO DS NIPPLE 2.812 6,290.0 5,869.3 34.16 OVERSHOT BAKER OVERSHOT W/PACKING;SEE NOTE: 3.720 GAS LIFT;3,806.5 'Tubing Description String Me...ID(In) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ibnt) Grade Top Connection • TUBING 31/2 2.992 6,291.6 6,354.9 5,923.3 9.30 J-55 EUE8RD • • Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Ind(°1 Item Des Com (in) GAS LIFT;4,786.8 .[ 6,311.8' 5,887.4 33.89 PBR BAKER PBR 3.000 • 6,325.5 5,898.7 33.71 PACKER BAKER FHL PACKER 3.000 6,342.6 5,913.0 33.48 NIPPLE CAMCO D NIPPLE NO GO 2.750 GAS LIFT;5.647.0 - 6.354.1 5,922.6 33.33 SOS BAKER SHEAR OUT SUB,SEE NOTE: 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) 6,334.0 5,905.8 33.60 PLUG INTERWELL HEX 180-350 2.05"PLUG @ 6334 12/21/2013 0.000 GAS LIFT.6.108.7 00=1.80" • 6,342.6 5,913.0 33.48 NIPPLE 2.75"x2.25"NIPPLE REDUCER 9/3/1996 2.250 REDUCER LOCATOR;6,165.0 6,495.0 6,041.5 31.58 FISH 2.25"CA-2 PLUG FELL OUT OF D NIPPLE DOWN 11/15/2013 2.250 TO 6495' SEAL ASSY;6,165.3 PER;6,171.9 I Perforations&Slots PACKER;6,195.0 Shot Dens Top(TVD) atm(TVD) (shots/f Top(ftKB) Btm(ftKB) (MB) (ftKB) Zone Date t) Type Com �--- 6,408.0 6,410.0 5,967.8 5,969.5 UNIT B,2D- 11/20/1984 4.0 IPERF 4"Csg Gun;Squeezed 01 11-21-84 NIPPLE;6,247.6 6,424.0 6,438.0 5,981.3 5993.1 A-5,20-01 7/6/1988 4.0 RPERF 21/8"Big Hole Char; Zero deg Phasing 6,429.0 6,431.0 5,985.5 5,987.2 A-5,2D-01 1/13/1985 1.0 APERF 2 1/8"Enerjet Charg;45 deg.Phasing OVERSHOT.6,250.0 6,453.0 6,493.0 6,005.8 6,039.8 A-4,2D-01 7/6/1988 4.0 RPERF 2 1/8"Big Hole Char; Zero deg Phasing 6,457.0 6,467.0 6,009.2 6,017.7 A-4,2D-01 1/13/1985 1.0 APERF 2 1/8"Big Hole Char; • Zero deg Phasing PBR;6,311.8 6,475.0 6,477.0 6,024.5 6,026.2 A-4,2D-01 1/13/1985 1.0 APERF 2 1/8"Big Hole Char; PACKER;6,325.5 - Zero deg Phasing 6,480.0 6,481.0 6,028.7 6,029.6 A-3,2D-01 1/13/1985 1.0 APERF 2 1/8"Enerjet Charg;45 PLUG;6,334.0 i' deg.Phasing il 6,490.0 6,492.0 6,037.3 6,039.0 A-2,2D-01 1/13/1985 1.0 APERF 2 1/8"Enerjet Charg;45 NIPPLE;6,34251 i� deg. Phasing "' NIPPLE REDUCER;6,342.6Cement Squeezes Top(ND) Bim(ND) SOS;6.354.1 rte. Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn 6,408.0 6,410.0 5,967.8 5,969.5 Cement Squeeze 11/21/198 (PERF;6,408.0-6,410.0-® 4 Mandrel Inserts - St � ati _-. APERF;6,429.06.431.0-...- on Top(TVD) Valve Latch Port Size TRO Run RPERF;6,42406,438.0 N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1' 2,582.2 2,582.0 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 2/28/2014 - -- 2 3,806.5 3,800.6 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 2/28/2014 3 4,786.8 4,684.3 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/28/2014 ' 4 5,647.0 5,355.4 CAMCO MMG 1 1/2 GAS LIFT SOV RKP 0.000 0.0'2/28/2014 DCR-1 APERF;6,457.0-6.467.0--.-. = 5 6,108.7 5,721.2 jCAMCO MMG 11/2 GAS LIFT I DMY RK 0.000 0.0 2/28/2014 ] RPERF;6,453.06,493.0 Notes:General&Safety APERF;6,475.06,477.0 End Date Annotation 9/29/2010 NOTE:View Schematic w/Alaska Schematic9.0 APERF;6,480.0-6,4810-r . 2/15/2014 NOTE:Dump Bail 5 of Silica Sand on top of Hex Plug APERF;6,490.06,492.0-.a c 3/26/2014 NOTE:ELMD TTL @ 6340'during Ohs TEMP LOG on 03/15/85 '/26/2014 NOTE:Baker Poor Boy Overshot w/Packing will swallow 4.73' FISH;6,495.0 IPRODUCTION;34.0-6,774a-A 2D-01 PRE-RIG WELL WORK SUMMAf DATE ' SUMMARY 7/5/2013 Brush n' Flush &Tag top of Patch @ 6261' RKB; Make Multiple Holefinder Runs to Indicate leak Between 6261' &6253' RKB; Tag TD @ 6469'SLM (Est- 14' Rathole); Set 2.25"CA-2 Plug in Nipple Reducer @ 6343' RKB. Bleed 400 psi off Tbg & IA. Turned over to DHD for plan forward. (Called in for Jumper&Throttle valve install on IA) 7/10/2013 PULLED 2.25"CA-2 PLUG @ 6343' RKB. MEASURED BHP @ 6424' RKB: 3788 PSI. READY FOR E-LINE. 7/15/2013 SET BAKER INFLATABLE BRIDGE PLUG @ 6337', CCL TO MID-ELEMENT: 23.5', CCL STOP DEPTH @ 6313.5', TOOK 40 MINUTES TO SET PLUG, PLUG SET SUCCESSFULLY, POOH, TURN WELL BACK OVER TO DSO 7/26/2013 (AC EVAL) : CMIT-T x IA (FAILED)TO 2500 PSI. 7/30/2013 PULLED BAKER 2 1/8 IBP @ 6336' RKB; BRUSHED& FLUSHED TBG FROM 6336' RKB TO 6261' RKB. READY FOR E-LINE (IN PROGRESS) 8/2/2013 SET 2-1/8" BAKER RETRIEVABLE IBP WITH MID ELEMENT AT 6335'. SET PLUG AT A CCL STOP DEPTH OF 6311.3', WITH A CCL TO MID ELEMENT OFFSET OF 23.7'. COMING OUT OF THE WELL, BLED TUBING AND IA BACK TO 1500.WITHIN 15 MINUTES, CHECK PRESSURE AGAIN AND BOTH HAD CLIMBED BACK TO 2000 PSI. 8/13/2013 (AC EVAL): MIT OA, FOR SECURE (PASSED) 8/27/2013 PERFORMED A LEAK DETECTION LOG ON 2D-01. RIH TO IBP AT 6335'. BLED DOWN THE TUBING. WHILE PERFORMING A STOP CHECK ABOVE THE PLUG,A LEAK WAS DETECTED. WHEN PRESSURE HAD DROPPED 800 PSI, THE TOOLSTRING WAS SHOT UPHOLE AND SOMETHING WAS HOLDING IT STUCK IN THE PATCH AT 6281'. LITTLE RED WAS CALLED OUT TO PUMP DOWN THE TUBING TO TRY AND BREAK THE TOOL FREE. THE ATTEMPT WAS UNSUCCESSFUL, PULLED OUT OF ROPE SOCKET. TOOL STRING LENGTH =44.25', TOOL STRING WEIGHT=295 LBS, MAX OD =2.19", 1 3/8" FISHING NECK LOOKING UP. 8/31/2013 RECOVERED E-LINE TOOLSTRING FROM 6197'SLM (BOTTOM OF SPINNER SEVERLEY DAMAGED. POSSIBLY MISSING SMALL METAL PIECES). RAN KOT AND LIB TO 5760' RKB FOR DEPTH CORRELATION. TAGGED TOP OF PATCH W/2.78" LIB @ 6261' RKB, TO ENSURE PATCH WAS NOT MOVED. IN PROGRESS. 10/7/2013 BAILED FILL OFF IBP @ 6245' SLM, RECOVERING E-LINE SPINNER PART. FISHED BAKER 2- 1/8" IBP @ 6247' SLM; SEALING RUBBERS STILL IN HOLE. IN PROGRESS. 10/8/2013 TAGGED @ 6475' SLM. FISHED ALL OF IBP RUBBER SEALS. SET 2.25"CA-2 @ 6342' RKB. IN PROGRESS. 10/9/2013 SET AVA CATCHER ON PATCH @ 6261' RKB. PULLED DV @ 5759' RKB. WELL READY FOR BRINE. 10/10/2013 Pumped 211 bbls 9.8#brine followed by 10 diesel down tbg, up IA to F/L @ 1 bpm. Re-rigged jumper and allowed fluid to U-tube. Attempted CMIT; failed, slight linear leak. Note: See attached pump& MIT reports 11/15/2013 PULL CATCHER @ 6340' RKB; ATTEMPT TO DUMP BAIL;APPEARS 2.25"CA-2 PLUG & POSS. NIP REDUCER FELL OUT OF D-NIP @ 6342' RKB DOWN TO @ 6495'SLM (BELOW PERFS). READY FOR E-LINE. 11/16/2013 PERFORMED 24-ARM CALIPER FROM 6380'TO 6245'. LOG CORRELATED TO TUBING TALLY. JOB COMPLETE. 11/17/2013 SET INFLATABLE BRIDGE PLUG AT 6350'. LOG CORRELATED TO HALLIBURTON MULTIFINGER CALIPER LOG DATED 16-NOV-2013. READY FOR DHD. 11/18/2013 (PRE RWO) : CMIT TXIA FAILED TO 2800 PSI, LLR T/IA @ 1.81 GPM, POT-T PASSED, POT-IC PASSED, FUNCTION TESTED T& IC LDS (ALL GOOD). 11/20/2013 (PRE RWO): CMIT T X IA IN PROGRESS. T X IA DDT IN PROGRESS. T-POT PASSED. T-PPPOT PASSED. IC-POT PASSED. IC-PPPOT PASSED. 12/17/2013 PULLED 2.125" BAKER IBP @ 6343' RKB; BRUSH & FLUSHED TBG FROM 6250'-6305' RKB. READY FOR E/L. 12/21/2013 PERFORMED A SBHP. c' 'VEY @ 6424': TEMP=160F, PRESS=42' 31. GRADIENT CHECK @ 6301': TEMP=157F, PRE_ 4253PSI. CHANGES TO PROCEDURE: ',LADED A TEMPERATURE SENSOR AND PERFORMED GRADIENT CHECK 100'TVD ABOVE 6424'AS PER STEVE DRAKE. SET INTERWELL HEX 180-350 2.05" PLUG AT 6336', CCL TO MID ELEMENT=17.8', CCL STOP AT 6318.2'. LRS LEFT ON LOCATION TO PUMP 156 BBLS OF 11#CACL2 AND UTUBE WITH 70BBLS DIESEL. CMIT TO 2000 PSI FAILED. SEE ATTACHED PUMP REPORT. JOB IN PROGRESS 12/23/2013 SAT ABOVE PLUG AND PRESSURED UP TO 2500 PSI, THEN PERFORMED A DRAW DOWN TEST. DURING DRAW DOWN TEST,ABLE TO SEE CHANGE IN DENSITY AND SPINNER MOVEMENT, INDICATING LEAK A THE PLUG @ 6336'. 2/5/2014 DUMP BAILED 5' OF SILICA SAND ON TOP OF PLUG @ 6334' RKB. JOB COMPLETE (READY FOR BPV) Conoco hillips Time Log & Summary WelWiew Web Reporting Report Well Name: 2D-01 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 2/19/2014 6:00:00 AM Rig Release: 3/2/2014 11:59:00 PM Time Logs ' Date From To Dur S. Depth E. Death Phase"Code Subcode T Comment 02/17/2014 24 hr summary Completed 2T-23 Well Program. 00:00 06:00 6.00 0 0 MIRU MOVE MOB T Continue to clean Mud Pits and rig down miscellaneous equipment while waiting for Sows to move the Rig and Camp. 06:00 12:00 6.00 0 0 MIRU MOVE MOB P Blow down services lines. Disconnect electric lines and interconnects. Remove berming. Swap to Generator power. Continue to load out truck loads to 2D pad. 12:00 17:00 5.00 0 0 MIRU MOVE MOB P Continue to move loads to 2D. Break rig complexes apart. Prepare to move shop,satellite camp and pit complex to 2D-01. 17:00 21:00 4.00 0 0 MIRU MOVE MOB P Move 1st convoy of Pits complex, Downey(satellite)camp and shop to 2D pad. Set mats and spot Downey camp. 21:00 00:00 3.00 0 MIRU MOVE MOB P Begin move of sub to 2D pad. Crew change at midnight. Sub at 4 corners. 02/18/2014 Mobilize Rig and support modules to 2D-Pad. Move over 2D-01 Well Slot. Raise Derrick. Rig up Support Modules. 00:00 08:30 8.50 0 0 MIRU MOVE MOB P Continue move sub to 2D pad from 4 corners. 08:30 12:00 3.50 0 0 MIRU MOVE MOB P Set mats and herculite for Sub and pits complex. Hang new tree in cellar.Spot sub over 2D-01. 12:00 18:00 6.00 0 0 MIRU MOVE MOB P Continue to spot rig of 2D-01. Spot pit complex to sub. Raise Derrick. 18:00 00:00 6.00 0 0 MIRU MOVE MOB P Continue to spot rig and complexes. Berm herculite around rig and complexes. Continue to set up pad and support equipment on pad and around rig.Start to rig up hardline and tiger tank. 02/19/2014 Continue to Rig up on 2D-01. RIG ACCEPTED at 06:00.Take on mud to pits and water back to 14.2 ppg. Rig up to kill well and ensure lines are clear.Start well kill. Lines quickly blocked to tiger tank.Troubleshoot line blockage to tiger tank. 00:00 06:00 6.00 0 0 MIRU MOVE MOB P Continue to rig up. Rig up hardline, choke shack,tiger tank and tank berming. Thaw out suction lines in the Mud Pits. Accept Rig at 06:00 hrs. Page 1 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 08:00 2.00 0 0 MIRU MOVE RURD P Take on 14.2 lb/gal Mud in Pits. Test Gas Alarms in preparation for the initial BOPE test. 08:00 12:00 4.00 0 0 MIRU MOVE RURD P Continue to off-load 14.2 lb/gal Mud into the Rig Pits. Rig up Kill Manifold. Off-load FMC Lubricator and put in Plpe Shed. 12:00 17:30 5.50 0 0 MIRU MOVE RURD P Continue to build 14.2 lb/gal Mud volume in Rig Pits. Steam through circulating lines out to the Kill Tank and re-check all connections. Ensure Choke house and all choke paths are clear and open with steam and air. 17:30 19:00 1.50 0 0 MIRU WHDBO MPSP P Pick up lubricator and pull BPV per FMC rep.Well pressure 1500 psi IA and 1500 tubing. OA=440 psi. 19:00 20:30 1.50 0 0 MIRU WELCTL KLWL P Start well kill and vent gas out of IA. Pressure stabilized in choke house at 740 psi. Checked and had diesel in line to choke house. No movement of diesel/gas in lines from choke house to tiger tank. Investigate potential blockage in line to tiger tank from choke house. 20:30 00:00 3.50 0 0 MIRU WELCTL KLWL T Warm line to tiger tank. Crack line and have good diesel at base of lines at tiger tank. Pressure to 1500 psi on IA. Pressure line to tiger tank from well head with air and with wellbore pressure. No flow. Place gauge on line at tiger tank to see if blockage is at tiger tank or between tank and choke house. SIMOPS: offload new 3.5"tubing from trucks and begin loading into pipe shed. 02/20/2014 Continue to troubleshoot line blockage to tiger tank. Kill Well with 14.2 ppg mud. Monitor well(not static), circulate well again with 14.2 ppg mud(not static). Build mud to 14.4 ppg while circulating. Monitor(well out of balance). Circulate 14.4 ppg mud. Observe well(IA dead,tubing slight flow measured at 1/2 gal for 30 minutes and 6-8 psi for 30 minutes). Reverse circulate 14.4 ppg mud. 00:00 03:15 3.25 0 0 MIRU WELCTL KLWL T Investigate blockage in lines from choke house to tiger tank. Break hoses at connections and thaw hoses. Blockage of ice found in middle of both hoses. Once lines thawed in pipe shed run steam to tiger tank to ensure lines inside open. Reassemble lines to tiger tank. SIMOPS: load 3.5"tubing into pipe shed. 03:15 03:30 0.25 0 0 MIRU WELCTL SFTY P PJSM including all personnel involved in well kill operation. 03:30 05:30 2.00 0 0 MIRU WELCTL KLWL P Kill well by reverse circulating down IA and up the tubing with 14.2 ppg mud. Page 2 of 14 Time Logs Date From To- DUr$' S. Depth E.Depth Phase !'Code Subcode T Oomment E 05:30 06:30 1.00 0 0 MIRU WELCTL KLWL P Observe well for flow x 30 minutes. Well remains slightly heavy on the backside with a small flow from the tubing side. Reverse circulate with 14.2 lb/gal Mud. 06:30 12:30 6.00 0 0 MIRU WELCTL KLWL P Continue to reverse in with 14.2 lb/gal Mud at 3.0 bpm/760 psi. Observe 13.8-14.0 lb/gal in returns. Mud. Add de-foamer and continue to reverse. Continue to reverse circulate until 14.2 lb/gal returned at surface. Monitor Well. Now observe a slight flow from the IA. Continue to monitor for 30 minutes. No change in flow from the IA. 12:30 18:00 5.50 0 0 MIRU WELCTL KLWL P Decision made to weight up to 14.4 ppg with Town Engineer and Company Representative.While circulating weight up to 14.4 ppg mud. Initial Circulating Pressure at 1 bpm 300 psi,stage up to 2 bpm at 580 psi,stage up to 3 bpm at 670 psi. Final Circulating Pressure 680 psi. 18:00 19:30 1.50 0 0 MIRU WELCTL OWFF P Observe well,slight flow from tubing, IA static/vacuum SIMOPS: Blow down lines. Decision made to circulate due to out of balance mud. Rig up to circulate down tubing out IA. 19:30 21:45 2.25 0 0 MIRU WELCTL KLWL P Circulate hole with 14.4 ppg mud. Light spot found(in tubing when observing well previously)and heavy spot found(in IA when observing well previously)while circulating well. Circulate until consist 14.4 ppg mud out of well. 21:45 23:15 1.50 0 0 MIRU WELCTL OWFF P Observe well. IA dead,tubing has small but steady flow measured at 1/2 gallon over 30 minutes. Put gauge on tubing and observe IA for 30 minutes,tubing pressure builds to 6-8 psi with no flow from IA. 23:15 00:00 0.75 0 0 MIRU WELCTL KLWL P Call Town Engineer. Decision to reverse circulate 14.4 ppg mud. Rig up and circulate down IA and up tubing. OA pressure=880 psi at 23:20. 02/21/2014 Continue to reverse circulate 14.4 ppg mud. Observe well:tubing dead, IA slow flow to a drip over 5 hours. Circulate hole volume, observe well,slight flow to drip form tubing. Reverse circulate tubing volume, observe well for flow(STATIC). Set BPV. Nipple down tree. Nipple up BOPE 00:00 01:00 1.00 0 0 MIRU WELCTL KLWL P Continue to reverse circulate 14.4 ppg mud. Steady weight of 14.4 ppg mud weight in and out during circulation. Page 3of14 ' Time Logs Date From To Dur S. Depth E. Depth Phase Code I Subcode T bomment 01:00 06:00 5.00 0 0 MIRU WELCTL OWFF P Observe well for flow. (initial flow was 1 quart in 19:11 (19 min 11 sec), sequential readings following were: 22:50,27:29, 33:29,42:26,48:30, it continued to slow to between a drip and an extremely light stream. SIMOPS: Continue to load pipeshed, strap and drift 3.5"completion tubing. 06:00 08:00 2.00 0 0 MIRU WELCTL OWFF P Continue to monitor slight flow from the IA. Discuss options with Anchorage Engineer. Last flow back measurement 1 quart/1 hr and 7 minutes. 08:00 08:30 0.50 0 0 MIRU WELCTL KLWL P Received decision from the Anchorage Engineering Team to circulate again with 14.4 lb/gal mud and continue to work out any light spots in the mud column, most likely migrating up from the light fluids and some gas that could still be trapped below our circulating point at 5,760-ft (empty pocket in GLM#5)down to the top of the PBR at 6,311-ft. 08:30 11:30 3.00 0 0 MIRU WELCTL KLWL P Bring pump on line down the tubing taking returns from the IA back to Pits at 3.0 bpm/760 psi. Present mud weight in 14.4 lb/gals, mud weight out 14,4 lb/gal. Circulated a total of 235 bbls. Shut down to monitor. Observed a no-flow condition. However, after 20 minutes a small amount of flow began from the tubing side. 11:30 14:00 2.50 0 0 MIRU WELCTL OWFF P Continue to monitor. After observing for one hour-1/2 qt was returned. During the next hour, 5 sec to 20 sec drips were observed. The IA remains static. Discuss results with the Anchorage Engineering Team. 14:00 15:00 1.00 0 0 MIRU WELCTL KLWL P Rig back up to reverse circulate. Reverse a tubing volume back to surface with 14.4 lb/gal Mud at 3.0 bpm/845 psi. Total bbls reversed= 52. 14.4 lb/gal throughout the returns. 15:00 16:00 1.00 0 0 MIRU WELCTL OWFF P Shut down Pump. Observe no-flow. Continue to monitor. After 1 hour no flow no drips from the Tubing or the IA. 16:00 17:00 1.00 0 0 MIRU WHDBO NUND P Rig down circulating equipment. FMC install the BPV. 17:00 19:00 2.00 0 0 MIRU WHDBO NUND P Nipple down the FMC Gen III 3 1/8"x 5M Production Tree. 19:00 20:00 1.00 0 0 MIRU WHDBO MPSP P Install blanking plug in and get measurements. Inspect hanger threads(good). Page 4 of 14 ' Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 00:00 4.00 0 0 MIRU WHDBO NUND P Nipple up 13 5/8"5M BOPE. Get stack set and start tightening bolts. 02/22/2014 Continue to Nipple up BOPE. Perform body test on BOP stack. Stand-by for AOGCC state representative to witness test. Test BOPE,test witnessed by AOGCC representative Chuck Sheve(all pass). Pull 3.5" completion unsuccessfully. Mobilize HES E-Line. Rig Up E-Line,shoot string shot. 00:00 02:30 2.50 0 0 MIRU WHDBO NUND P Continue nipple up 13 5/8"5M BOPE. Get RKB measurements. Tighten bolts. Pick up test joint. 02:30 05:00 2.50 0 0 MIRU WHDBO PRTS P Check clearance of test joint for testing bottom VBRs in stack. Tighten bolts on stack. Rig up test equipment. Perform body test of BOP stack(good). 05:00 07:00 2.00 0 0 MIRU WHDBO BOPE P Notify AOGCC inspector Chuck Scheve and stand-by for test until his arrival as per his request. 07:00 11:15 4.25 0 0 MIRU WHDBO BOPE P Perform the initial BOPE test per ConocoPhillips/AOGCC requirements at 250/5,000 psi for the BOP Rams, Choke Manifold,and Floor Valves. Tested the Annular at 250/3,500 psi. BOP Tests were done with a 3 1/2"Test Joint. Tested all Gas Alarms. Perform Koomey draw down test. All pressure tests were recorded on a chart.All tests were witnessed by AOGCC Field Inspector Chuck Sheve. (actual test time 4hrs 5 minutes). 11:15 12:30 1.25 0 0 COMPZ WHDBO BOPE P Rig down test equipment. Suck out stack. FMC Rep pulled the Blanking Plug and the BPV with no problems. 12:30 14:30 2.00 0 0 COMPZ RPCOM PULL P Rig up GBR tubing handling equipment. Make-up 3 1/2"Pup Joints for the landing Joint. Screw into the tubing Hanger(12 turns). BOLDS. Saw the Tubing Hanger come off seat at 65K. Attempted to pull the Seal Assembly from the PBR at 6,311-ft several times at 140,000-144,000 lbs(includes Block weight of 30K). No-Joy. 14:30 18:00 3.50 0 0 COMPZ RPCOM ELNE P Call HES E-Line Unit to cut the 3 1/2"Tubing. (Rig up Schlumberger Spooling Unit while waiting for E-Line to arrive on location). E-Line arrives at 18:00 hrs. 18:00 20:00 2.00 0 0 COMPZ RPCOM RURD P PJSM. Pick up E-Line equipment. Rig up E-Line unit. 20:00 20:30 0.50 0 0 COMPZ RPCOM PULD P Pick up string shot assembly. Page 5of14 Time Logs Date From To Dur S. Death E.Death Phase Code Subcode T Comment 20:30 22:45 2.25 0 0 COMPZ RPCOM ELNE P RIH with E-Line string shot assembly. Correlate depths. Shoot string shot centered at 6292'MD (highest cut location available on target joint due to tubing patch above). POOH with String shot assembly. 22:45 23:30 0.75 0 0 COMPZ RPCOM PULD P Lay down string shot assembly. Pick up 2"Radial Cutting Tool assembly. 23:30 00:00 0.50 0 2,400 COMPZ RPCOM ELNE P RIH to 2400'with 2"Radial Cutting Torch cutting tool assembly. X2/23/2014 Perform E-Line cut of 3.5"tubing at 6292'MD. Lay down 3.5"completion to include: 1 SSSV(1874'control line,33 stainless steel bands),2 pup joints,6 GLMs, 199 joints, 1 cut joint(length 16.66'). Run in Hole with 3.5"tubing cleanout string. 00:00 02:00 2.00 2,400 6,292 COMPZ RPCOM ELNE P RIH form 2400'with HES E-Line 2" Radial Cutting Tool assembly. Cut 3.5"tubing with 2" RCT cutter at 6292'MD. Positive indication of cut in E-Line unit, also in movement of string and in collar shift of 4'down hole. POOH with RCT cutter. Positive indication of good cutter function. 02:00 02:45 0.75 6,292 6,292 COMPZ RPCOM RURD P Rig Down E-Line.SIMOPS: Rig up to Reverse Circulate, Pull on completion and pulls free without any indication of a partial cut.String weight: 72k. 02:45 04:30 1.75 6,292 6,292 COMPZ RPCOM CIRC P Reverse Circulate more than 2x tubing volume to clean hole. and get consistent 14.4 ppg. 04:30 05:00 0.50 6,292 6,292 COMPZ RPCOM SFTY P PJSM laying down 3.5"completion. 05:00 05:30 0.50 6,292 6,257 COMPZ RPCOM PULL P Lay down 3.5"completion hanger and 1 joint tubing. 05:30 06:30 1.00 6,257 6,257 COMPZ RPCOM CIRC P Circulate tubing volume of 14.4 mud, well out of balance. Pump @ 3 bpm, 1000 psi. 06:30 08:30 2.00 6,257 4,423 COMPZ RPCOM PULL P Pull and lay down to SSSV (recovered 33 Stainless Steel bands). Rig down SLB spooler. 08:30 08:45 0.25 4,423 4,423 COMPZ RPCOM SFTY P Kick while tripping drill.AAR. 08:45 12:00 3.25 4,423 2,550 COMPZ RPCOM PULL P Pull and lay down 3.5"completion. Total laid down for tour is 123 joints of tubing,2 GLMs 1 SSSV(with 33 Stainless Steel bands). 12:00 17:30 5.50 2,550 0 COMPZ RPCOM PULL P Pull and lay down 3.5"completion. Lay Down 76 joints of tubing,4 GLMs and cut joint(16.66'). Total lay down count of 3.5" completion hanger,tubing and jewelry(strapping and tallying). Lay down 1 SSSV(1874'control line,33 stainless steel bands),2 pup joints, 6 GLMs, 199 joints, 1 cut joint (length 16.66') Page 6 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 19:15 1.75 10 0 COMPZ RPCOM RURD P Clean and clear rig floor. Discuss cleanout run with Town Engineer. Decision made to run 3.5"tubing string to cleanout thick mud above tubing cut. SIMOPS: Prep pipe shed to run 3.5"tubing cleanout run. 19:15 21:00 1.75 0 0 COMPZ RPCOM RURD P Install 6-3/8"ID wear ring. SIMOPS: Prep pipe shed to run 3.5"tubing cleanout run. 21:00 00:00 3.00 0 2,123 COMPZ RPCOM RCST P RIH with 3.5"tubing string of 69 joints with muleshoe for cleanout circulation. 02/24/2014 Continue Run in hole with completion tubing(no jewelry)stopping to circulate hole at 3,072-ft 4,604-ft dpmd. Mud system has completely collapsed..."Play-Dough"like consistency.Wait on trucks for cuttings bin and mud deliverys. Start circulating again at 4604'MD to re-condition the 14.4 lb/gal mud system."Play Dough" consistency continues to emerge from hole. 00:00 01:00 1.00 2,123 3,072 COMPZ RPCOM RCST P Continue to RIH with 3.5"tubing cleanout string. Stop to circulate at 100 joints in. 01:00 01:45 0.75 3,072 3,072 COMPZ RPCOM CIRC P Circulate 14.4ppg mud. Initial Circulating at 3/4 bpm pressure 1100psi to establish circulation. Pressure at 6 bpm: 1400 psi. FCP once hole volume had been circulated 920 psi.circulate 1.5x volume to cleanout all thick mud from hole. 01:45 03:15 1.50 3,072 4,604 COMPZ RPCOM RCST P Continue to RIH with 3.5"tubing cleanout string. Stop to circulate at 150 joints in. Up wt=65k, Down wt= 40k. 03:15 03:30 0.25 4,604 4,604 COMPZ RPCOM SFTY P BOP drill and AAR with crew. SIMOPS rig up to circulate. 03:30 05:30 2.00 4,604 4,604 COMPZ RPCOM CIRC P Circulate 14.4ppg mud from 4,604-ft. Break circulation on up stroke. Initial Circulating pressure 1/2 bpm @ 2400 psi. Mud returning extremely thick, slow pumps to prevent possum belly from overflowing.Overboard"Play Dough"consistency mud while pumping. FCP 1100 psi. Order more mud from MI Mud Plant. Bad mud, very thick unloaded from hole in 2 parts with 10-15 minutes of liquid mud in between. Shut down circulation due to cuttings bin capacity and mud volume in the pits. 05:30 20:00 14.50 4,604 4,604 COMPZ RPCOM OTHR T Wait on mud from mud plant.Wait on Super Sucker and vac trucks to clean cuttings bin and pits. SIMOPS: Reciprocate pipe occasionally: Up wt =65k, Down wt=50k. Change out long bales to short bales,service rig. 20:00 22:30 2.50 4,604 4,604 COMPZ RPCOM COND P Load mud to pits and blend to 14.4 consistent weight. Clean cutting 9 bin and ready cuttings bin for further thick mud returns with water. Page 7 of 14 Time Logs Date From To Dur S.'Depth E. Depth Phase Code Subcode T Comment 22:30 23:00 0.50 4,604 4,604 COMPZ RPCOM SFTY P PJSM for circulating hole clean including all rig hands, 3rd party hands and truck drivers. 23:00 00:00 1.00 4,604 4,604 COMPZ RPCOM CIRC P Circulate well clean with 14.4 ppg mud. Hole immediately starts unloading more"Play Dough" consistency mud. Break Circulation in up stroke at 1.7 bpm @ 1745 psi. Pressure at end of tour is 1410 psi with 23 bbls pumped.All returns of thick consistency, unusable and offloaded. Samples taken by mud man. X2/25/2014 Continue to re-condition the 14.4 lb/gal mud system at 4604'MD. Once hole clean and balanced Run in hole with 20 more joints of 3.5"tubing to 5216'MD. Circulate hole clean until cutting bin full. Empty cutting bin, take on mud. Circulate hole clean. Run in hole with 17 more joints of 3.5"tubing to 5742'MD. Circulate well clean. Run in hole to 6282'MD with 3.5"tubing cleanout string. Circulate until cuttings bin and pit 1 are full. Stop circulation and wait on Super Sucker to empty cuttings bin while working on cleaning out pit 1. 00:00 02:30 2.50 4,604 4,604 COMPZ RPCOM CIRC P Continue to circulate 14.4PP9 mud in,"Play Dough"consistency mud coming out and cleaned up to usable mud after 75bbl offloaded.Stage pumps up to 8 bpm, Initial circulating pressure=2100 psi, Final circulating pressure=1800 psi. Pump hole volume x2 to ensure good mud around. 14.4 ppg mud in/out. 02:30 03:15 0.75 4,604 5,216 COMPZ RPCOM RCST P Run in hole with 3.5"cleanout string from 4,600'MD(Up wt=65k, Down wt =58k)to 5216'MD(Up wt=70k, Down wt=56k). 03:15 04:30 1.25 5,216 5,216 COMPZ RPCOM CIRC P Circulate 14.4 ppg mud. Break circulation at 2 bpm @ 700 psi, staging up to 6 bpm, Initial circulating pressure= 1700 psi,first 100 bbls returned are good mud returns, mud turns very thick and is sent to cuttings tank. Circulation stopped once cuttings tank at 80% capacity and 75 additional bbls of junk mud into pit 1. Mud thinning to flowing consistency before shutting down pumps. No additional trucks available to pump out or suck out cutting bin. 04:30 12:00 7.50 5,216 5,216 COMPZ RPCOM OTHR T Vac truck sent to G&I. Super Sucker sent to G&I.Additional mud ordered. SIMOPS:P :Truck sent to Mud plant for mud order. Rig Maintenance: Service top drive(replace lube pump motor), Clean rig. (OWFF: Static) 12:00 13:30 1.50 5,216 5,216 COMPZ RPCOM COND P Super Sucker sucks out 70 bbl from cuttings bin. SIMOPS: Mud checks, mud consistent 14.4 ppg in usable pits. 13:30 14:00 0.50 5,216 5,216 COMPZ RPCOM CIRC P Circulate hole until returns clean up. 5bpm @ 1820 psi. Page 8of14 Time Logs Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 14:00 15:00 1.00 5,216 5,742 COMPZ RPCOM RCST P Run in hole another 17 joints of 3.5" tubing cleanout string to 5742' MD. Up wt=65k, Down wt=55k. 15:00 16:30 1.50 5,742 5,742 COMPZ RPCOM CIRC P Circulate hole staging up to 4 bpm @ 1530 psi. 16:30 17:30 1.00 5,742 6,282 COMPZ RPCOM RCST P Run in hole 18 joints of 3.5"tubing cleanout string to 6282'MD. Up wt= 65k, Down wt=55k. Did not tag tubing stub. 17:30 20:00 2.50 6,282 6,282 COMPZ RPCOM CIRC P Circulate hole clean staging up to 3 bpm @ 1700 psi taking junk mud returns out to Cutting tank. Returns continued to be clabbered mud. Utilize excessive water to allow mud to flow into cuttings tanks,and pit 1. 20:00 21:00 1.00 6,282 6,282 COMPZ RPCOM CIRC P Set up to take returns to pit 1.Vac truck unable to keep up with rig pumps @ 1/2 bpm.Shut down pumps. 21:00 00:00 3.00 6,282 6,282 COMPZ RPCOM OTHR T Work on sucking out pit 1 with vac truck. Observed mud too thick to suck out with vac hose, utilize lots of water to thin.Wait on Super Sucker to return to suck cuttings bin down. Order 200 BBLS more mud and dispatch truck to mud plant. Circulate 4-5 bbls @ 1/2 bpm while reciprocating string every 30-45 minutes,taking returns to pit 1. (OWFF:Well static)OA= 1050 psi 02/26/2014 Cleanout cuttings bin and pit 1. Circulate 14.4 ppg mud to clean hole.exhaust pumpable mud, returns like peanut butter.Wait on mud orders and trucks. Cleanout out pit 1 and cuttings bin. Observed standpipe froze. Begin thawing standpipe. 00:00 01:00 1.00 6,282 6,282 COMPZ RPCOM OTHR T Continue work on sucking out pit 1 with vac truck.Wait on Super Sucker to return to suck cuttings bin down. Circulate 4-5 bbls @ 1/2 bpm while reciprocating string every 30-45 minutes,taking returns to pit 1. 01:00 02:00 1.00 6,282 6,282 COMPZ RPCOM OTHR T Super Sucker sucks out 70 bbls from solids side of cuttings bin.SIMOPS: Work continues to try and suck out pit 1 with vac truck. Circulate 4-5 bbls @ 1/2 bpm while reciprocating string every 30-45 minutes,taking returns to pit 1. 02:00 04:00 2.00 6,282 6,282 COMPZ RPCOM OTHR T Second Super Sucker dispatched to rig. Sucks out 70 bbls from full side of cuttings bin. Mud order from mud plant is being waited on by mud truck. SIMOPS:Work continues to try and suck out pit 1 with vac truck. Circulate 4-5 bbls @ 1/2 bpm while reciprocating string every 30-45 minutes,taking returns to pit 1. Page 9 of 14 Time Logs :,' 1I1Yi Date From To Dur S. Depth E.Depth Phase Code'+.: Subcode T ! Comment 04:00 06:00 2.00 6,282 6,282 COMPZ RPCOM CIRC P Circulate hole clean with 14.4 ppg mud.Take junk mud returns to cuttings bin and pit 1. 06:00 12:00 6.00 6,282 6,282 COMPZ RPCOM OTHR T Waiting on mud product to be delivered. Mud plant makes 3 batches of 14.4 polymer based mud but only have 1 truck to deliver. One 200 bbl load delivered @ 07:00. SIMOPS: Pump 5 bbls and reciprocate string every 60 minutes. Cleanout cuttings bin and pit 1 of junk returns from circulation. 12:00 00:00 12.00 6,282 6,282 COMPZ RPCOM OTHR T Waiting on mud product to be delivered. Mud plant makes 3 batches of 14.4 polymer based mud but only have 1 truck to deliver. One 200 bbl load delivered @ 19:00.Two loads total delivered by end of day. SIMOPS: Pump 5 bbls and reciprocate string every 60 minutes. Cleanout cuttings bin and pit 1 of junk returns from circulation. Rig Maintenance. Observed standpipe frozen. Begin thawing standpipe. 02/27/2014 Wait on mud to arrive at rig. bring on mud. Stand pipe frozen, break down stand pipe and kelly hose and thaw. Put stand pipe and kelly hose back together,test(good). Circulate hole clean taking junk returns to cuttings bin. Circulate hole at high rate and ensure uniform mud properties. 00:00 06:00 6.00 6,282 6,282 COMPZ RPCOM OTHR T Waiting on mud product to be delivered. Mud plant makes 3 batches of 14.4 polymer based mud but only have 1 truck to deliver. SIMOPS: Cleanout pit 4 and ready pits for additional new mud and upcoming circulation.Work thawing standpipe in Derrick. 06:00 12:00 6.00 6,282 6,282 COMPZ RPCOM OTHR T Take top section of stand pipe down and work on thawing out. 12:00 18:00 6.00 6,282 6,282 COMPZ RPCOM OTHR T Thaw out stand pipe. Replace Stand pipe and make up stand pipe and kelly hose. 18:00 18:30 0.50 6,282 6,282 COMPZ RPCOM PRTS T Pressure test stand pipe and Kelly Hose. (good) 18:30 19:00 0.50 6,282 6,282 COMPZ RPCOM RURD P PJSM, Pick up joint, make up with TIW valve to top drive and prepare to circulate hole clean. 19:00 19:30 0.50 6,282 6,282 COMPZ RPCOM SFTY P PJSM with all involved workers and 3rd party personnel for circulating well clean of thick junk mud. 19:30 20:30 1.00 6,282 6,282 COMPZ RPCOM CIRC P Circulating well with Polymer 14.4 mud system. Lead with 40 bbl low vis pill. Chase with 40 bbls high vis 14.4 ppg pill. 4 bpm @ 1750 psi. Send junk 14.4 gel mud and peanut butter returns to cuttings bin. SIMOPS:Take on final 70 bbls of new polymer mud once room in pits. Page 10 of 14 Timd Logs Date From To Dur S. Depth>E. Death Phase Code Subcode T Comment 20:30 00:00 3.50 6,282 6,282 COMPZ RPCOM CIRC P Displace well to 14.4 polymer based mud. Up wt=69k, Down wt=62k; 3 bpm @ 1325 psi;6 bpm @ 1850 psi; After cleaned up ICP at 6.5 bpm= 1100 psi; Stage pups up to 9 bpm @ 1650 psi. Reciprocating string 60' strokes. 02/28/2014 Monitor well.Trip out 3.5"tubing work string.Prepare to run Completion string.Attempt to pull wear bushing. Repeat attempts with no success and make up 6.220"spear and grapple. RIH retrieve wear bushing. Observe WB lipped over not allowing running tool to engage. Make up 3 1/2"completion string,as per detail. RIH to 6219'MD. 00:00 00:30 0.50 6,282 6,282 COMPZ RPCOM CIRC P Continue to circulate 14.4 ppg mud and get uniform properties. Take slow pump rates. 00:30 01:00 0.50 6,282 6,282 COMPZ RPCOM OWFF P Monitor well. (STATIC) 01:00 06:30 5.50 6,282 0 COMPZ RPCOM TRIP P Trip 3.5"completion tubing string out of hole. Lay down 10 joints, rack back 64 stands in Derrick, lay down final 3 joints. Lay down Mule shoe. 06:30 07:30 1.00 0 0 COMPZ RPCOM PULD P Clean&clear rig floor. Continue clean pits and prep for completion. Pull tools to rig floor. Make up stack washing tool and flush BOP stack. Function test rams. 07:30 14:00 6.50 0 0 COMPZ RPCOM PULD T Back out LDS.Attempt to pull wear bushing. Repeat attempts to pull wear bushing with no success. Observed pull tool would drop into slot but would not allow us to turn RH and engage. Called for Spear assembly. Make up BOT spear with 6.220"grapple and RIH. Engage wear bushing and POOH with no issues. Observed wear bushing on the top side had peeled over enough to not allow the tool or dogs to engage. Remove wear bushing from service. Breakout and lay down spear assembly. 14:00 14:30 0.50 0 0 COMPZ RPCOM PULD P Clean&clear rig floor. Rig up power tongs and prep for completion run. 14:30 14:45 0.25 0 0 COMPZ RPCOM SFTY P Held PJSM with crew, GBR and BOT reps. Discuss safety&hazard recognition issues. Discuss procedure to make up 3 1/2" _completion string and RIH. 14:45 00:00 9.25 0 6,219 COMPZ RPCOM RCST P Make up Poorboy overshot and FHL packer assembly as per detail,and continue TIH with 3 1/2"completion string from the derrick. Install Nipples and GLMs as planned in the detail. Observed proper displacement. Up wt=75k, Down wt=62k SIMOPS: Spot HES Slickline unit. Load lubricator in shed. Page 11 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/01/2014 24 hr Summary Continue to run in hole with 3.5"completion. Locate over stub with overshot. Spot Corrosion Inhibited mud. Run in hole with HES Slickline and set plug in nipple at 6248'MD. Set FHL packer. Shear out seal assembly. Space out completion. Circulate hole with 50 bbls 9.8 brine and 222 bbls diesel. Land hanger and RILDS. Pressure test tubing to 3000 psi, IA to 2500 psi. Shear SOV. 00:00 02:30 2.50 6,219 6,290 COMPZ RPCOM RCST P Pick up 3 single joints from shed to position Poorboy Overshot 1'off of the tbg stub,6292'. Verify&locate with 10K set down weight. Repeat to verify. Circulate down tbg and verify with pressure observing pressure increase wjhen NO-Go'd out on Overshot,from 225 PSI-290 PSI. 02:30 04:00 1.50 6,290 6,290 COMPZ RPCOM CIRC P Rig up and circulate to spot 25 bbls corrosion inhibited 14.4 ppg mud chased by 50 bbl of 14.4 ppg mud. Blow down top drive. 04:00 07:00 3.00 6,290 6,297 COMPZ RPCOM RURD P PJSM, Rig Up slickline. SIMOPS: Space out overshot 1'off of stump. Install 2'pup under joint 197 for proper spaceout of FHL packer, and allo Halliburton to rig up on tbg stump. 07:00 11:00 4.00 6,297 6,297 COMPZ RPCOM SLKL P Run in hole with slickline and 2.85" Gauge run to 6232'WLM.WLOH. Make up CA2 Plug and WLIH to set in 2.312"nipple at 6248'.WLOH, make up prong and WLIH to set same on CA2 plug.WLOH. 11:00 12:00 1.00 6,297 6,298 COMPZ RPCOM SLKL P Rig down Slickline lubricator assembly and set back same. 12:00 13:00 1.00 6,298 6,298 COMPZ RPCOM RURD P Make up pup joint and circualting valve assembly with hose,on tbg stump. Pull slips and locate packer and Poorboy overshot on depth. UP WT-76K, SOWT-67K. 13:00 14:15 1.25 6,298 6,172 COMPZ RPCOM PRTS P Pressure down tubing to 2500 PSI, observed packer set at 2000 PSI,set down 10K. Hold pressure and chart same for 10 minutes. Bled tbg to 1800 PSI. Line up, close uper rams, pressure don annulus to 1500 PSI-5 minutes. Observed tbg pressure increase to 2050 PSI. Observed no leaks. Bleed annulus pressure. Hold tbg pressure at 1800 PSI. Pull to 90K to observe PBR shear.Verify free movement in string. Bleed all pressures. 14:15 15:15 1.00 6,172 6,172 COMPZ RPCOM PULD P Continue rig down all of Halliburton Slickline equipment. remove lubricator and BOP's from pipe shed. Page 12 of 14 " Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:15 16:45 1.50 6,172 6,172 COMPZ RPCOM RCST P Pull and reland seals to verify space out. Pull and lay down first and second jnts of tbg. Install space out pups. Make up tubing jnts,and install tubing hanger and landing joint. Make up circulating hose and valves. UP WT=75k SO WT=66k. 16:45 19:30 2.75 6,172 6,172 COMPZ RPCOM CIRC P Position seal assembly above PBR. Line up and displace well pumping 50 bbls 9.6 PPG Brine wash, chasing with 222 bbls of diesel to displace well. 19:30 20:30 1.00 6,172 0 COMPZ RPCOM RCST P Hang off 3.5"completion. RILDS 20:30 21:30 1.00 0 0 COMPZ RPCOM RURD P Rig up to Pressure test Tubing and IA. 21:30 00:00 2.50 0 0 COMPZ RPCOM PRTS P Pressure Test Tubing to 3000 psi on chart for 30 minutes. (GOOD). Bleed tbg to 1500 psi and shut in. Pressure test IA to 2500 psi on chart for 30 minutes. (GOOD). Bleed off IA to 0 psi,bleed off tubing to 0 psi. Ramp up IA to Sheer SOV in GLM#4 at 2250 PSI. Pump 2 bbls down IA to tubing and 2 bbls tubing to IA to ensure flow path. Bleed all pressures and blow down lines. X3/02/2014 Set BPV. Clean Rotary table of clabbered mud returns. Clean pits and cuttings bin. Nipple Down BOPE. Nipple up tree. Pull BPV, install tree test plug,test tree. Pull tree test plug. Set'IS-A'BPV. Release rig. RIG RELEASED at 23:59 00:00 00:30 0.50 0 0 COMPZ RPCOM OWFF P Monitor well. SIMOPS: Rig down circulation equipment. Clean pits. 00:30 01:00 0.50 0 0 COMPZ WHDBOTHGR P Install BPV,with dry rod as per FMC II rep. 01:00 01:30 0.50 0 0 COMPZ WHDBO PRTS P Pressure test BPV to 1000 psi pumping down IA.(GOOD)Bleed pressure. 01:30 05:30 4.00 0 0 COMPZ WHDBO RURD P Clean out rotary table and under floor area of clabbered junk mud returns. Clean BOP stack and suck out prior to nippling down BOPE. Blow down Top drive SIMOPS: Clean pits and cutting bin. 05:30 09:30 4.00 0 0 COMPZ WHDBO NUND P Nipple down BOPE. 09:30 12:00 2.50 0 0 COMPZ WHDBO NUND P Clean hanger. Call DSO and agree on proper orientation. Nipple up tree. 12:00 15:00 3.00 0 0 COMPZ WHDBO NUND P Continue nippling up tree. Remove ported flange from old tree and install on new tree. Final pressures:tubing- 0 psi, IA-0 psi, OA-500 psi. 15:00 18:30 3.50 0 0 COMPZ WHDBO PRTS P Pull BPV. Install Tree test plug. Pressure test wellhead to 250/5000psi(GOOD). Pull tree test _ plug. 18:30 19:00 0.50 0 0 COMPZ WHDBO RURD P Set'IS-A'BPV. Page 13 of 14 Time'Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 19:00 19:30 0.50 0 0 DEMOB MOVE PULD P Lay down lubricator. 19:30 00:00 4.50 0 0 DEMOB MOVE RURD P Prep rig floor for Laying down derrick, bridal up, lower cattle chute clean pits, remove hydro service hose, work on Lay Down derrick checklist. Clean and secure cellar, remove gate valve and install old IA valves and new gauges. Load trucks with equipment to move to 2T-10. Release Rig @ 23:59. Page 14 of 14 ~ ~ • . ~onc~coPh~llips ,~as~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 3, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • a~~~ ~~~:.~ _~~~~ t~~~~ ~ ~ ~~~~~ ~~~~~~ ~~~~ ~ ~~~~ i~~~~~ . ~ ~,~~,~~s~~~ AnCts~~~g~ ~ ~~~ ~~~ Enclosed please find a spreadsheef with a list of wells from the Kuparuk field (KRLn. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped September 20th and October 13~' 2009. The corrosion inhibitor/sealant was pumped October 15~' and 31 St + November 1~ and 2"d 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. mcerely, ~ Perry Kle~ ~~w~~~;»~$~~~ ~~',j ~' ~ ~~~~ ConocoPhillips Well Integrity Projects Supervisor .. • ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 11/3/09 2C ~~_ 2z & 3K Pad Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor! sealant date ft bbls ft al 2C-01 50029209620000 1830830 17" NA 17" NA 2.12 10l15/2009 2C-02 50029209720000 1830930 72" NA 12" NA 2.97 10/15/2009 2C-03 50029209680000 1830890 10" NA 10" NA 3.82 10/15/2009 2C-04 50029209730000 1830940 17" NA 17" NA 2.12 10/15/2009 2C-05 50029209780000 1830990 18" NA 18" NA 3.4 10/31/2009 2C-06 50029209790000 1831000 28" NA 28" NA 7.65 10/15/2009 2C-08 50029209740000 1830950 27" NA 27" NA 6.8 10/15/2009 2C-09 50029212370000 1842210 22" NA 22" NA 5.1 10/15/2009 2C-10 50029212300000 1842140 54' 5.5 22" 10/13/2009 4.67 10/31/2009 2C-11 50029212310000 1842150 38' 5.3 26" 10/13/2009 5.52 10/3112009 2C-12 50029212220000 1842060 25' 4.5 26" 10/13/2009 6.8 10/31/2009 2C-13 50029212230000 1842070 20" NA 20" NA 3.4 10/15/2009 2D-01 50029211940000 1841710 38" NA 38" NA 6.8 10/31/2009 2D-07 50029211690000 1841430 20" NA 20" NA 2.12 10/31/2009 2D-09 50029211370000 1841030 28" NA 28" NA 4.67 10/31/2009 2D-10 50029211350000 1841010 21" NA 28" NA 2.97 11/172009 2D-11 50029211340000 1840990 19" NA 19" NA 2.55 11/1/2009 2D-12 50029211310000 1840940 18" NA 18" NA 2.55 11/1/2009 2D-15 50029211840000 1841600 NS NA NS NA 1.7 11/1/2009 2Z-01A 50029209530100 2071110 14" NA 14" NA 1.7 11/1/2009 2Z-02 50029209600000 1830800 18" NA 18" NA 5.1 11 /2/2009 2Z-03 50029209640000 1830850 24" NA 24" NA 5.5 11 /2/2009 2Z-06 50029209570000 1830770 10'9" 2.5 7" 9/20/2009 2.12 11/1/2009 2Z-14 50029213610000 1851070 24" NA 24" NA 3.4 11/1/2009 2Z-16 50029213630000 1851090 20" NA 20" NA 1.7 11/1/2009 2Z-18 50029218840000 1881330 37'6" 6.5 39" 9/20/2009 8.9 11/2/2009 2Z-22 50029225240000 1941470 16" NA 16" ~ NA 5.95 11/1/2009 2Z-23 50029225440000 1950100 17" NA 17" NA 3.4 11/1/2009 3K-103 50029233920000 2081150 29" NA 29" NA 11.9 11/2/2009 3K-108 50029233950000 2081300 24" NA 24" NA 4.25 11/2/2009 f' r-'\ ~ Tr;Á\'~' Œ [TfJ ~ç: //:.\ ~. /1,\\ (~) r vl /Ä\ u u, \ . ~~ \ -ù \ U\:1 ú=~~ '- II\.l L1 U @ ; ; I I j f ¡ f I { ¡ / FRANK H. MURKOWSKI, GOVERNOR , AI.ASIiA OIL AND GAS CONSERVATION COMMISSION' May 12,2004 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Mike Wheatall Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 ¡ØlP ~t 7 I Dear Mr. Wheatall: The Alaska Oil and Gas Conservation Commission ("Commission") performed an inspection of your well safety valve system (SVS) at Kuparuk River Unit 2D (KRU 2D) pad on May 6, 2004. Attached is a copy pf the Inspection Report. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. An SVS component failure rate of 12.5 percent was identified during the above-noted inspection. Commission policy, as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13, 2003, supported retention of the 10% failure threshold. Effective May 6, 2004, and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2D must be tested every 90 days. When testing is scheduled, you must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to witness the SVS test. Sincerely, '¡H ;{¿,¡el T. Seamount, Jr, Commissioner Attachment cc: AOGCC Inspectors (via email) Safety Valve & Well Pressures Test Report - Review Reviewed By: P.I. Suprv Comm Pad: KRU_20 Inspection Dt 5/6/2004 Inspected by Chuck Scheve Interval: InspectNo: svsCS040507072635 Src: Inspector Field Name KUP ARUK RIVER Operator CONOCOPHILLIPS ALASKA INC Operator Rep Bob Noble Reason 90-Day Well Number Permit Number Separ PSI Set PSI UP Trip Test Test Test Code Code Code Date SI Oil,WAG,GINJ, GAS,CYCLE, SI Inner PSI Outer PSI Tubing PSI YeslNo YeslNo L 20-13 1840120 98 70 60 P P I-OIL -- -- 20-12 1840940 98 70 65 P P I-OIL ¡-- 20-09 1841030 98 70 65 P P I-OIL I 20-08 1841270 98 70 65 P P I-OIL 20-068 1981760 98 70 65 P P I-OIL I 20-03 1841530 98 70 65 P P I-OIL I 20-15 1841600 98 70 50 P 4 I-OIL 1000 1000 150 Yes Yes IA x OA communication L 20-01 1841710 98 70 0 10 P I-OIL ) Comments Performance Pilot on well 20-01 failed to trip on initial test,was replaced and passed retest Surface Safety Valve on Well 20-15 had very slow leak when pressure tested. Valve to be repaired and retested by operator. Wells 8 Components 16 Failures 2 Failure Rate 12.5% ) Wednesday, May 12,2004 · rr MEMORANDUM TO: Julie Heusser, ~'~\~ THRU: FROM: State of Alaska Alaska Oil and Gas Conservation Commission Commissioner Tom Maunder, P. I. Supervisor Chuck Scheve; Petroleum Inspector DATE: January 28, 2001 SUBJECT: Safety Valve Tests Kuparuk River Unit 12D & 2E Pads Sunday, January 28, 2001: I traveled to the Kuparuk River Field and witnesSed the semi annual safety valve system testing on 2D & 2E Pads. As the attached AOGCC Safety Valve system Test Report indicates I witnessed the testing of 9 wells and 18 components with one failure on 2D Pad and 5 wells and 10 components with one failure on 2E Pad. The SUrface Safety Valve on Well 2E,16 had a slow leak when pressure tested. This valve will be serviced and retested by the operator. The Surface Safety Valve on well 2D-05, a WAG injector, could not be tested due to a leaking wing valve. This valve will be tested as soon as the wing . valve is repaired. Earnie Barndt conducted the testing today he demonstrated good test procedUre and was a pleasure to' work with All the wellhouses entered at these locations were Clean and all related eqUipment appeared to be in good condition. Summary: I witnessed the semi annual SVS testing at 2D & 2E pads in the Kuparuk River Field. KRU 2D Pad, 9 wells, 18 comPonents, KRU 2E Pad, 5 wells, 10 components, 24 wellhouse inspections I failure 5,56% failure rate I failure 10% failurerate Attachment: SVS KRU 2D & 2E Pads 1-28-01 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 2D & 2E Pads 1-28-01 CS~doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Prillips - Operator Rep: Eamie Barndt AOGCC Rep: Chuck Scheve Submitted By: Ch'u~k Scheye Date: Field/Unit/Pad: Kuparuk / KRU / 2D Pad Separator psi: 'LPS 99 lIPS 1/28/01 Well Pemit Separ Set ~ T~t T~t T~t Date ~ WAG, ~J, Number Number PSI PSI T~p Code Code Code Pass~. G~or 2D-01 1841710 99 70 65 P P OIL , , 2D-02 1841520 :2D-03 1841530 2D-05 184126qi 3750 20~ , 1750' P , 7 ' WAG 2D-06B 1981760~ 99 70 55~ P P OIL 2D-97 ' 1841436' , ~750 2000 .. 1'850 , P ,P ' . . ' wA-G 2D-08 1841270 99 70 60 p P OIL 2D-09 1841030 99 70 55 P P OIL , 2D. 0 , , , . , 2D-11 1840990 2D-12 1840940 99 70 60 ' p P ' 'OIL , ,, , 2D- 13 1840120 99 70 60 p P OIL ~ , , , , 2D-14 1841590 , 2D- 15 18~ 1600 99 70 60 'p P OIL ,~ . , , , , 2D-l~ 1841610 . Wells: 9 Components: 18 Failures: 1 Failure Rate: 5.56% [] 90 Day Remarks: Surface safety on 2D-05'not tested due a slow leaking wing valve Grove valve could be closed due to snow dd~s. RJF 1/16/01 Page 1 ofl SVS KRU 2D Pad 1-28-01 CS.xls Alaska Oil and Gas Conservation COmmission Safety Valve System Test RePort Operator: Phillips Operator Rep: Eamie Brandt AOGCC Rep: Chuck Scheve Submitted By: ,_Chuck Scheve Date: Field/Unit/Pad: Kupanxk / KRU / 2E Pad Separator psi: LPS 99 HPS 1/28/01 I I Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GmJ, Number Number PSI pSI , Trip · Code Code Code Passed GAS or CYCLE 2E-07 193104O , 2E-08 19318~0 99 70 . 6.0 ' P 'P . . 2E-09 1842400 - . . , 2E- 10 1842300 99 70 60 P P ,2E-11 1842260 99~ 70 50 - P .P ..... 2E-15 1841890 99 70 50 P P . . . 2E. 16 ' 1841900 99 70 50 P ,4 .... . , , Wells: 5 Components: 10 Failures: 1. . ~ Failure Rate: 10.00°/13 90 ~av Remarks: Surfa_ee saf,eW on 2E-16 had Slow leak when pressure tested. Valve will be serviced a retested by operator. -~ · RJF 1/16/01 page 1 ofl SVS KRU 2E Pad 1-28-01 CS.xls STATE OF ALASKA AL-A~KA OIL AND GAS CONSERVATION COMMIS'~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 153' FNL, 636' FEL, Sec. 26, At top of productive interval 1159' FSL, 1205' FEL, Sec. 23, T11N, At effective depth 1326' FSL, 1281' FEL, Sec. 23, T11N, At total depth 1371' FSL, 1301' FEL, Sec. 23, T11N, T11N, R9E, UM R9E, UM R9E, UM R9E, UM 12. Present well condition summary Total Depth: measured 6780 true vertical 6289 6. Datum elevation (DF or KB) RKB 1.27 7. Unit or Property name Kuparuk River Unit 8. Well number 2D-01 9. Permit number/approval number 84-171 10. APl number 50-029-21 1 94-00 11. Field/Pool Kuparuk River Field/Oil Pool feet Plugs (measured) None feet feet Effective depth: measured 6678 feet Junk (measured) None true vertical 6200 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6" 204 ex cs II 1 1 7' 1 1 7' Surface 261 5' 1 0-3/4" 800 ex AS III & .2650' 2650' Intermediate 300 Sx Class G . Production 6731' 7" 1280 Sx Class G & 6760' 6272' Liner 150 Sx AS I Perforation depth: measured ~i~'~: !~'~ ¢':" iii~ ': ~,' ~"~: 6424' - 6438', 6453' - 6493' '"'~ ~'': !: true vertical 5981' 5993', 6006' - 6040' -.':~:: ':';;- Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 6355' Packer: Baker FH @ 6325'; SSSV: Baker FVL @ 1880' (Locked out w/Camco WR DP'l) 13. Stimulation or cement squeeze summary Fracture Stimulate 'A' Sands on 9/13/96. ORIGINAL Intervals treated (measured) 6424' - 6438', 6453' - 6493' Treatment description including volumes used and final pressure Pumped 165 Mlbs of 20/40,12/18, & 10/14 ceramic proppant into formation, fp was 6800 psi ..... 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 6 2 1 395 918 1238 157 1197 829 1499 1245 174 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISigned ~~ ~'~}.,~ Title Wells Superintendent Form 1¢0'r4 If=ie~'//l~6/1~8 ~ -*' SUBMIT IN DUPLICATE STATE OF ALASKA ALASN~._..)IL AND GAS CONSERVATION COM~51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCFI Ala~lca; Tnt: :3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 153' FNL, 636' F§e, Sec. 26, TllN, RgE, UM At top of productive interval l15g' FSL, 1205' FEL, Sec. 23, TllN, R9E, UM At effective depth 1307' FSL, 1272' FEL, Sec. 23, T11N, RgE, UM At total depth 1371' FSL, 1301' FEL, Sec, 23, T11N, RgE, UM 11. Present well condition summary Total depth: measured true vertical 6780' feet 6289' feet Effective depth: measured 6678' feet true vertical 6200' feet Casing Length Size Structural Conductor 117' 16" Surface 2650' 10-3/4" Intermediate Production 6760' 7" Liner Perforation depth: measured 5. Datum elevation (DF or KB) 6200' SS 6. Unit or Property name KuDaruk River Unit 7. Well number 2D-II Producer Feet 8. Approval number 9, APl number 50-- 029-2119400 10. Pool true vertical Plugs (measured) Junk (measured) Cemented 204 Sx 800 Sx 300 Sx 1280 Sx Measured depth CS II AS III & AS I Class G & 117' 2650' 6760' 150 Sx AS I 6424'-6438', 6453'-6493' MD 5981'-5993', 6005'-6039' TVD Tubing (size, grade and measured depth) 3 1/2", J-55, 6355' 12. Stimulation or cement squeeze summar~Refracture A Sand with gelled diesel sand frac. 13. Intervals treated (measured) 6424' -6438', 6453' -6493' Treatment description including volumes used and final pressure 1360 bbls gelled diesel, 70,000 lbs 16/20 Carbo-Lite, 6800 psi Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 0 299 0 1200 125 1951 1577 0 1200 400 14. Attachments 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .//~gV~.. ~' ~~f' Title Form 10-404 Rev. 12-1-85 Daily Report of Well Operations Copies of Logs and Surveys Run [] Date %/,,,2 '/~ Submit in Duplicate Kuparuk River Oil Pool True Vertical depth 117' 2650' 6272' Packers and SSSV (type and measured depth) Baker PBR, 6325', Baker FVL, 1880' ARCO Alaska, In(' Subs'tdlary of Atlantic Richfield Compa._ .2D -I C, ONTRACTOR Oo~u e. II - td~,,, REMARKS WELL SERVICE REPOR'I IFIELD - DISTRICT- STATE DAYS /c,q~ ! 1 OPERATION-AT REPORT TIME ~ IDATE 0?30 I~oo l .'3/$ i 535 I ,:336 I 7'00 - ,~ O ~ 0 Z'., 7; ~_.. ; "/: / 'q ,,7.~ o ~ s . ['-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather [Temp' I Chill Fact°r Visibility IWInd Vel'Report 'F 'F miles ARCO Alaska, Inc. Post Office~_.., 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 .. DAT~: 10-22-85 TP, ANSMITTAL NO: 5410 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEEP,.ING k~CO~J3S CLEkK ATO-1115B ' '- -- P.O..uOX 100360 ANCHORAGE, AK 99510 TRANSMITTED hEReWITH A~{}~ T~ FOLLOWING ITEm, S. ' PLL.'AS~ ACKNOWLRDG~: RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. FINAL PRINTS/ SCHL/ ONE * OF EACH CEMENT. BOND LOG/ VA~IABLW. DENSITY "'"'3B- 8 '~ 42X- 15' ".'2X-13 "~ 2X- 12 '~'2X-11 '"~ 2X-9 ~' 2W-6 "" 2V-16 06-06-85 .RUN #1 5850-8369 11-07-.84 RUN ~1 5900-8258 11-17-84 RUN #1 5896-8410 12-08-84 RUN #1 3050-7215 12-08-84 RUN #1 3100-6370 12-21-84 kUN #l 3350-6973 12-20-84 PUN ~t 5100-8338 11-25-85 RUN ~1 5700-7290 06-06-85 .' kUN ~1 4550-7108 '~2V-15 06-07-85. RUN #1 4650-6428 ~'2V-13 06-03-85-' RUN #1 . 6590-8553 ~2U-8 ''.. 04-02-85 'RUN.%1 4970-6938 ~ 2U-6 r 03-31-85 'RUN ~1 :~ 5600-8107 '~2U-5 04-01-85 - ~UN %1.~ 5994-9161- ;'... . . '~2U-4' 03-02-85 ~UN %1 "' 6284-7850 ~'~ ~2D-16 12-19-84 kUN ,1 5200-74~9 2D-15 12-18-84 RUN ~1' - 3285-6454" ~W2D-1 11-03-84 ~N %1 5693-6652 -~lR-8 06-17-85 RUN ~1 5987-8324 -~lR-7 . 06-08-~5 RUN %1 4302-7028 .- '~R-5 06-08-85 RUN ~1 - 6950-8628 ,~lL-15 11-05-84 RUN %1 4883-6600 - . w lQ-15 05-27-85 RUN ~1 6490-7566~- '~1~3 04-17-85 . ~UN ~1 ~97~-10744 ' %CPF-1A 12-21-84 RUN ~1 2200-3856 · - c~ENT EV~UATION TOOL LUGS/. C~ENT ~V~UATION LOGS ~lF-'16 03-12-85 RUN %1- 8269-8712 - : '~-5 ' "06-26-85- RUN %1 6974-8~44 ~1~-5 06-27-85- RUN_%2 '. 8254-8532 .. . ~2U-2' '-:' 03-25-85' ~UN ~1' 5790-9450' ".. - ~_~. - - ..... '~2U-15 ·03-07-85 RUN %1'.. 6400-7002 '~3B-9 · - '06-30-85 RUN %1. 6000-8246 - - RUN #1 6500-8726 5400-7457 _ . .. . ' ~'3C-11 06-29-.85 -,,~3C~12 06-29-85- ' RUN ~1 . _. KECEIPT ACKNOWLEDGED: BPAE DRILLINg* BL B. CURRIER L. JOHNSTON. CHEVRON. ' mOBIL D & M "NSK CLE~K*DL ARCO Alaska. Inc. is a Subsidiary ot AtlanticRichfielgJCompany W. PASh~R EXXON PnILLIPS OIL J, RATHmELL" UNION . . ARCO Alaska, inc. Date: October 7, 1988 Transmittal #: 7314 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. 3Q-02 Kuparuk 3Q-02 Kuparuk 2 D - 01 Kuparuk '1 Y-1 6 Kuparuk $ A- 01 Kuparuk 3 A- 01 Kuparuk I F- 05 Kuparuk I F- 08 Kuparuk 1 F- 02 Kuparuk Please acknowledge receipt and return Fluid Level Report(4:20) Fluid Level Report(3:10) Fluid Level Report Fluid Level Report Fluid Level Report(3:55) Fluid Level Report(4:45) Fluid Level Report Fluid Level Report Well Pressure Report 10-02-88 10-02-88 10-02-88 10-02-88 10-02-88 10-02-88 10-04-88 10-04-88 9-30-88 Casing Casing Casing Casing Casing Casing Tubing Tubing Amerada Anchorage Receipt Acknowledged: ........................... Date: DISTRIBUTION: D&M State of Alaska ~ Chevron Unocal Mobil SAPC ARCO Alaska, ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 05-2 3-85 TRANSMITTAL NO: ~. 197 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-Ill5B 'P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HERE%[ITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. FINAL PRINTS OPEN HOLE/SCHLUMBERGER (ONE * OF EACH LISTED.) 2~9 5" DIL/SFL-GR 03-24-85 RUN %1 36!7-8089 2" DIL/SFL-GR 03-24-85 RUN ~1 3617-8089 5" DEN/NEU-GR (PORO) 03-24-85 RUN #1 5700-8064 2" DEN/NEU-GR (PORO) 03-24-85 RUN %1 5700-8064 5" DEN/NEU-GR (RAW) 03-24-85 RUN #1 5700-8064 2" DEN/NEU-GR (RAW) 03-24-85 RUN #1 5700-8064 CYBERLOOK 03-24-85 RUN #1 5700-8064 1L-15 ~' 5" DIL/SFL-GR 10-23-84 RUN #1 3477-6694 2" DIL/SFL-GR 10-23-84 RUN #1 3477-6694 5" FDC/CNL-GR (PORO) 10-23-84 RUN #1 600-0-6654 2" FDC/CNL-GR (PORO) 10-23-84 RUN #1 600D-6654 5" FDC/CNL-GR (RAW) 10-23-84 RUN #1 6000-6654 2" FDC/CNL-GR (RAW) 10-23-84 RUN #1 600 0-6654 5" BHC SONIC 10-23-84 RUN #1 6000-6684 2" BHC SONIC 10-23-84 RUN %1 6000-6684 CYBERLOOK 10-23-84 RUN #1 6000-6654 2U-8 2D-1 5" DIL/SFL-GR 03-28-85 RUN #1 3025-6934 2" DIL/SFL-GR 03-28-85 RUN #1 3025-6934 5" DEN/NEU PORO 03-28-85 RUN ~1 3025-6910 2" DEN/NEU PORO 03-28-85 RUN #1 3025-6910 5" DEN/NEU RAW 03-28-85 RUN #1 3025-6910 2" DEN/NEU RAW 03-28-85 RUN #1 3025-6910 CYBERLOOK 03-28-85 RUN #1 6590-6880 5" DIL/SFL-GR 10-27-85 RUN #2 2469-6748 2" DIL/SFL-GR 10-27-85 RUN #2 2469-6748 5" DEN/NEU PORO 10-27-85 RUN #2 2649-6722 2" DEN/NEU PORO 10-27-85 RUN #2 2649-6722 5" DEN/NEU RAW 10-2 2" DEN/NEU RAW 10-2 CYBERLOOK 10-2 RECEIPT ACKNOWLEDGED: BPAE *DRILLING-BL B. CURRIER L. JOHNSTON CHEVRON MOB I L D & M*-BL *NSK CLERK-BL * 7-85 RUN #2 264~-672~ 7-85 RUN #2 264~J~~ 7-84 RUN ~2 6109 DATE: W. PASHER *STk~E EXXON SOHEO PHILLIPS OIL UNTDN - T?,A~SE!TT-iD EE.~-~rfTE A2.E TEE FOLLO%~G: l~_a. SE ~OTE: BL- BLU=~--IR'E, $ - SE:Pi.&, F -FIL~, ,~- TAPE, PC- ?RoTOCOP~ PLEASE P~u-Tb~ R~CEI~T TO: 'ARCO ~ALASK.-'., iNS. ATTN: ?-.%TSy $. BAXiER P. O. BOX'!00360 AK 99510 NEW PROaECZS TRANSMITTAL m~o~: L. K. S~ITH/P. S. ~AXTEX WELL NAME: TRANSMITTED HEREWITH ARE THE FOLLOWING: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, PC - PHOTOCOPY RECEIPT ACKNOWLEDGED: PLEASE RETURN RECEIPT TO: ARCO ALASKA, INC. ~ 6~s Coos Commission ATTN: PATSY S. BAXTER ATO/507 '~°Chorage ' P. O. BOX 100360 ANCHORAGE, AK 99510 ARCO Alaska, Inc. Post Office B~.,~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 25, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2D-1 Dear Mr. Chatterton' Enclosed is an addendum to the 2D-1 Well History to include with the Well Completion Report, dated 01/10/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L52 Enclosure RECEIVED MAY 0 1 1985 Nmta (~ a ~ Cons. (;ommissk~ Anchorage ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany I ALASKA OIL AND 8AS CONSERYATION.~,OMMI$SION · Bill Sheffield, Governor 3001 PORCUPIHE DRIVE ANCHORAGE,ALAgKA gg6014-31g~ TEL EPHONE (901) 27g,-1433 DATE: ~ RE~ Well ~ Loc. ~ Permit No. ~ to your attention that the Co~ission has no~ We wish to bring following required items on_ the subject well yet received the Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled-well. Please submit the above missing m. aterial. ~~.e~~~~oc. V. Chatter Chairman lc:C.024 ARCO Alaska, Inc. ARCO Explor:a~T~n -Alaska Operations Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 277 5637 HAND CARRIED SAMPLE TRANSMITTAL To:ALASKA 0IL ~ GAS CONSERVATION SHIPPED COHMISSION 5001 P0.RCUPINE ·DRIVE ANCHORAGE, ALASKA 99501 ATTN: MIKE MINDER OPERATOR: ARCO DATE: _APRIL 11,1985 NAME: KUP-ARUK 2D-1 SAMPLE TYPE: PLUGS 1" NUMBER OF BOXES: 4 BOXES SAMPLES REQUESTED TO BE SEND BY RENEE C. BOYER ATO 1086 PLEASE· SEE ATTACHED LIST - // %>//_. SHIPPED UPON RECEIPT OF THESE sAmPLEs,~ PLEASE NOTE ANY DISCREPANCIES AND MAiL A SIGNED COPY OF THIS FORM TO: ARCO ALASKA, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99510 ATTN R. L. BROOKS RECEIVED BY'.- ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. 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[". ,.5 ~ ~.,;~ ,:::. ;.LJ_I;~ -: f'.~ I_-,-~ ,.,. c:, t-:~ ')(' 'I -~" · . . ...... ; li .O!'!ITIr']; [/~ ,- · " i .....~'-) I.f¢ f,? ]" ¥')?.J E '.'.( :,:' 0 i'-! ,;.;: t.J H I 0 :~'- ~ ....... f..-,; ~'.',,.. ,r..;.: ;[ I.....',,' -i F:' !.-I :[',... L.. ;I; F:' ,!-..7 r'~. .... T ,' ..... 9,_-. i'.J,?;": r"i lii:r;:i~' ,.i """"" :'""" ,t.:L. N/'¢¢'~'...JL.T · ..-.. ,. ......... .,.,-., I 1.1~ Il:: ..... I...-~,: 1 . ARCO &las~a. loc ,s a subs,diary of ~.PanllcR,cnhe;dCompany 'ARCO Alaska, Inc. Date: MARCH 18, 1985 InternsI correspom~..j-''e' : Subject: KUPARUK 2D-1 PLUGS ENDS FOR THE STATE OF ALASKA Fmm/LocaUon: ABV 100 .. EVA ANN ENDICOTT PALEO LAB · To/L~on: RENEE C' BOYER,. ATO 1086 SAMPLES ---"" -- ~ .DEPTHS OF :'2738 278'~ 2833 2877 -.. -2920 . 27.5 274 274 2.74 274 274 274 '274 ;: 2-7.4 :j 274 3.274 275 127S 27S 2 27S5 ~ 27S"4 127SS 7'2 75.6 275 .275 275 276 276 276 276 276 276 276 9 0 1 2 3 4 5. 6 7 8 ' . 9 0 1 .. 7 8. 9 0_ 1 2 3 4 5 6NOS 276 276 276 27~/0 2771 2772 2775 2774 2775 27'76 2777 2778 2779 :2780 2781 :"2782 -2783 7.0 8 9 2789 2790 2791 2792 2793 2794 2795N0 '2797 2798 2799 · 2.80-0 2801 2802 2803 280'4 2805 2806 · 2807 '2808 2809 2810 2811 2813 2814 2815 AMPL 2816 2817 2818 2819 2820 2821 2822 2823 2824 2825 2826 2827 2828 2829 2830 2831 _2832 2834 : ' 2835 2836 2837 2838 2839 SAMPLE CORE 2840 2841- ' 2842 2843 2845' '-2846 2847 2848 2849 2850 '2-8 S 1 2852 2853. 2854 2855 2856 2.85 7 2858 2859 - .NO SAMPLE' E CORE itl ENDS 2860 2'861 2862 2865 2864 2865 2866 2867 2868 2869 2870 2871 2872 2873 2874 2875 2876 .· 2889 2890 NO SAMPLE NO SAMPLE NO S~MP LE 289i 289.2 2895 · . ·2894 2895 2896 2897 289'8 2899 2900 2901 AT 2 2902 2903 2904 2905 2906 2907 2908 2909 '2910 2911 2912 2915 2914 2915 2916 291'7 2918 -. ' . '2919- · 2878 NO' SAMPLES a 287.9 2921 2880 2922 2.88 1 29 23 2882 2924 288-5 29.25 ENDS 2795 begins at 2926 2.884 2885 .2927 ~2886' ' 29128 95 ' DEPTH 2796 there isntt a 95' &.BEGINS AT -. 288.Z.Z~s :..:2929 2930. 2931 CORE #4 ENDS AT 2847 2932 - .- -2953 ' ' 2954 - · . . 295.5 - 2956 2917. _. 2938 - NOSAM~LES DUE 2959 2940 2941 2942 2943 765.3 CORE #2 STARTS 2944 2945 2945.5 TO RUBBLE' o,~ ' ..~ AT 2767.0 NO SAMPLE CORE ~'8 29'55.0. BEGINS CORE #9 2956 2957 2958 2959 2960 2961 2962 2963 2964 2965' 2966 2967 29'68 not enough .. to retrieve . cOre 2850 · . ENDS, -PKGE-#-2' ARCO KUPARUK n-1 SAMPLES DEPTHS' 'PERM PLUG ENDS · 2969 2970 PLUG ENDS NOT ENOUGH TO RETRIEVE 2971 2972 2975 2974 PLUG HAD TO BE PLUNGED NO PLUG END AVAILABLE 2975 . 2976 2977 2978 2979.~ ENO OF()CORE #9 2984 CORE #10 BEGINS 2985 2986 2987 2988 2989 2990 2991 299.2 2993 2994 2995 2996 2997 2998 2999 3000 3001 3002 3003 3004 3005 5006 5007 5008 5009 30~0 '.~ 3011 3012 5015 NOSAMPLE RUBBLE 3013.5 CORE #10 ENDS 3014 3015 3016 3017 3018 ' 3019 3020 3021 3022 3023 3024 3025 5026 3027 3028 3029 3030 3031 3032 3033 3034 3035 5036 3037 5038 3039 3040 3041 COR~fENTS/CORRE CTIONS ' .. THIS LIST EXCEPT AS' NOTED IN COI~B~EMTS AND coRREcTIONS, REPRESENTS A COMPLETE LIST OF S~fPLES DUE THE STATE OF ALASKA. · PLEASE SIGN AND RETURN THIS FOR~ TO~ '- 'E.A.. ENDICOTT, ABV-IO0 ARCO Alaska, Inc. Post Office Bit-x-100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 26, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2D-1 Dear Mr. Chatterton: Enclosed is an addendum to the 2D-1 Well History to include with the Well Completion Report dated 01/10/85. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU4/L193 Enclosure RECEIVED F E B 2 8 1985 'Nask~ ....... : ,;:~. ~mmissi0ri ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany SHALLOW SANDS ENGINEERING T~.NSMITTA~ ~ (03 TO: DATE: TRANSMITTED HEREWITH ARE THE FOLLOWING: FROM: L. K. SMITH/P. S. BAXTER WELL NAME: //--- ~- PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, PC - PHOTOCOPY 03 b I-~-ape. -~1~5' ~3~ RECEIPT AC~O~GED: /' / ~ DATE: P. O. BOX 100360 ~CHO~GE, ~ 99510 -~b~ 0il & ~as Cons. Commission AnChorage ARCO Alaska, Inc. Pos! Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 4, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Commi ss ion Attached in duplicate are subsequent notices on the following wells at the Kuparuk River Field: Well Action Date Performed 1E-15 Fracture 12/17/84 1F-6 Stressfrac 1/11/85 1L-4 Fracture 1/9/85 1L-5 Fracture 1/10/85 2C-5 Perforate 12/22/84 2C-6 Perforate 12/25/84 ~'~2'D--,t .......... Perforate 1/13/85 2D-2 Perforate 12/15/84 2D-3 Perforate 12/16/84 2D-8 Stressfrac 1/9/85 · If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) RECEIVED FEB 0 6 1 B5 Alaska 0il & Gas Cons. Gommissi°n Anchorage STATE OF ALASKA ALASKA (~FL AND GAS CONSERVATION cO'~)~M ISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL)~ OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. 0. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 153' FNL, 636' FEL, SEC. T11N, R9E, UM BOTTOMHOLE LOCATION- 23, T11N, R9E, 5. Elevation in feet (indicate KB, DF, etc.) 127' (RKB) 12. 7. Permit No. 84-171 8. APl Number 5o-029-21194 9. Unit or Lease Name 23, KUPARUK RIVER 10. Well Number 2D-1 1503' FSL, 1405' FEL, SEC. 11. Field and Pool UM KUPARUK 6. Lease Designation and Serial No. KU P A R U K ADL 25653 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data UNIT RIVER FIELD RIVER OIL NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [~] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing ' [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On January 13, 1985, the "A" sands of Kuparuk well 2D-1 were perforated for production. After testing the lubricator to the well was shot with a wireline conveyed gun. Interval (MD)' 6429-6431' (1 SPF) 6457-6467' 6490-6492' 6475' 6477' 6480' 3000 ps i, RECEIVED F E B 0 6 19 5 Alaska 0il & Gas Cons. commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed . . Title OPERATIONS The space below for Commission use COORDINATOR Date 2/4/85 Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office B~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 28, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2D-1 Dear Mr. Chatterton' Enclosed is a copy of the 2D-1 Well History (Completion Details) to include with the Well Completion Report, dated 01/10/85. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU3/L82 Enclosure xc' 2D-1 Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office B°1'-~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 10, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2D-1 Dear Mr. Chatterton: Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not received the portion of the 2D-1 Well History covering the completion details. .When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU3/L46 Enclosures RECEIVED JAN 1 5 1985 Alaska 0ii & Gas Cons. CommissiOn Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ¢,,...¢ AND GAS CONSERVATION CO,,,,.,fllSSlON WELL COMPLETION OR RECOMPLETION RI PORT AND LOG 1. Sta'tLJ~ of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-171 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-r7~-----~--~- 50- 029-21194 4. Location of well at surface I L?~/'"TJONSI 9. Unit or Lease Name 153' FNL, 636' FEL, 5ec.26, T11N, R9E, UN ~ V~R~F~ED i Kuparuk River Unit At Top Producing Interval I ~u.r!. ~--~¢~j 10. Well Number 1159' FSL, 1205' FEL, Sec.23, T11N, RgE, UM~ 2D-1 At Total Depth 11. Field and Pool 1371' FSL, 1301' FEL, Sec.23, T11N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 127' RKB ADL 25653 ALK 2579 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 10/1 6/84 10/28/84 11/23/84I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 6780'MD,6289'TVD 6678'MD,6200'TVD YES [] NO []I 1880 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run DI L/LSS/GR/SP, LDT/CNL/NGT, EPT/PCD, SHDT, GR/SP/DI L/SFL, Cal/FDC/CNL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 117' 24" 204 sx Cold Set II 10-3/4" 45.5# J-55 Surf 2650' 13-1/2" 800 sx AS Ill & 300 sx Class G 7" 26.0# J-55 Surf 6760' 8-1/2" 1280 sx Class G & 150 ,~x 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) None 3-1/2" 6355' 6325' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 6408' - 6410' 250 SX ClaSs 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 IGAS-OILRATIO TEST PERIOD I~ I OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See attached core description. £Cc iVED JAN] 5 ],985 .... Form 10-407 GRU3/WC04 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 6323' 5896' N/A Base Upper Sand 6332' 5904' Top Lower Sand 6413' 5972' Base Lower Sand 6551' 6089' 31. LIST OF ATTACHMENTS W¢.ll Hi_~t-.nry~ £nr~. D~..~m. ri,nf, lnn; Cyrnso. npie S. rv~y (2 o. opies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (/~o ~J~{,--/' ~}~~ Title Associate Engineer Date J~[O-'6~z'~-' 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". ADDENDUM WELL: 10128184 11105/84 3/18/85 2D-1 Arctic Pak w/25 bbls AS I, followed by 89 bbls Arctic Pak. RU & rn CBL/VDL/GR/CCL/gage ring f/6652'-5693'. RU & calibrate GCT. Rn GCT f/6660'-surf. Log well w/Temp & CCL f/6570'-6200'. Drilling~Superint endent ECEI VED MAY 0 1 I985 A/aska Oil & Gas Cons. Comm~lon Anchorage ' ~ate ADDENDUM WELL: 10/28/84 11/05/84 2D-1 Arctic Pak w/25 bbls AS I, followed by 89 bbls Arctic Pak. RU & rn CBL/VDL/GR/CCL/gage ring f/6652'-5693'. RU & calibrate GCT. Rn GCT f/6660'-surf. RECEIVED F £B ~ 8 Alaska ~,, ,., --,-~. ,,,~mmissior~ Ar~choruge DriZli~ -~pe~in~endent / Ddte ARCO Alaska, Inc. Date: Subject: Internal Correspond · December 12, 1984 Report of Kuparuk 2D-1 Core for State of Alaska From/Location: To/Location: S. Schreiber - ATO/1084 J. Gruber - ATO/1478 A total of 278' of core was recovered from the West Sak Sands interval out of 304' cored. Coring began at 2738' MD and ended at 3041' MD. The top of the West Sak interval is at 2715' MD, and the base of the interval coincides roughly with the K-12 marker at 3057' MD. The West Sak interval consists of moderate to thinly layered sands interbedded with siltstone and mudstone. CORE CUT RECOVERED 1 2738-2767 27/29 2 2767-2796 27.5/29 3 2796-2825 19/29 4 2825-2850 32/25 5 2850-2879 15/29 6 2879-2897 29/18 7 2897-2926 29/29 8 2926-2955 18/29 9 2955-2984 24/29 10 2984-3012 29.5/28 11 3012-3041 28/29 Sue Schreiber Geologist SAS/kb cc: M. R. Werner - ATO/1000 Wellfile - Shallow Sands KRU 2D-1 RECEIVED JAN I 5 1985 Alaska 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlleldCompany ARCO Oil and Gas Company Well History - Initial Report - Daily lallttlCllOnl: Prepare and submit the "lnlllll R~l~ort" on the first Wednesday after a well is spudded or workover operations are started. Dally work prtor to spudding should be summarized on the form giving inclusive dates only. District Alaska ICounty, parish or borough North Slope Borough Lease or Unit Title ADL #25653 Completion IState Field Kuparuk River Auth. or W.O. no. AFE 802921 Alaska Well no. 2D-1 Roll'n #4 Operator ARCO Alaska, Inc. Spudded or W.O, begun API 50-029-21194 ARCO W.I. Prior status 56.24% if a W.O. Complete Ioate 11/19/84 I'°ur Date and depth as o! 8:00 a.m. 11/20/84 11/21/84 Complete record for each day reported 0830 Hrs. 7" @ 6760' 6678' PBTD, Prep to cmt sqz 10.2 ppg NaC1/NaBr Accept rig @ 0830 hrs, 11/19/84. ND tree, NU & tst BOPE to 5000 psi. RU SOS, RIH w/4" csg gun @ 4 SPF/90° phasing & perf 6410'-6408', POH. PU CR, TIH, set retnr @ 6258', POH. TIH w/stinger & DP, prep to do sqz. 7" @ 6760' 6262', 6780' TD, Drl CR M&P 41 bbls Cl "G", sqz 21 bbls @ 3/4 BPM/300 psi. Stage cmt @ 1/4 BPM or less until achieving final press of 1750 psi w/27 bbls total to formation. Unsting, rev circ, POOH w/DP & stinger. TIH w/BHA, WOC, tag retnr @ 6256', DO retnr. RECEIVED AN 2. 9 1cj 5 Alaska Oit & Gas Cons, commission The above II correct For form preparation and dll~lbutlon, ~ee Proceduree Manual, Sectlon 10, Drilling, Pagea 86 end 87. IDate 1/15/85 ITM Drilling Superintendent ARCO Oil and Gas ComPly Daily Well History-Final Report Inalructlone: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Reperf" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final 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 Field Kuparuk River Auth. or W.O. no. AFE 802921 Lease or Unit ADL #25653 Title Completion Alaska IWell no. 2D-1 Roll' n #4 Operator ARCO Alaska, Inc. API 50-029-21194 A.R.Co. W.I. 56.24% Spudded or W.O. begun Date Complete 11 / 19/84 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 Dst center prior to plugging and bandonment of this well our I Prior status if a W.O. 0830 Hrs. [ 1000 Hrs. Old TD 11/22/84 thru 11/23/85 Released rig Classifications (oil, gas, etc.) Oil Producing method Flowing 7" @ 6760' 6653' PBTD, 6780' TD, RR DO CR &cmt, tst sqz perfs to 1500 psi; OK. Drl cmt stringers to 6653' PBTD, CBU, press tst csg to 1500 psi; OK, POOH w/bit & JB. PU csg scrpr, TIH to 6653', POOH, LD DP. Rn 3½" CA & lnd w/TT @ 6355', "D" Nipple @ 6343', FHL Pkr @ 6325', SSSV @ 1880'. Set BPV, ND BOPE, NU & tst tree to 5000 psi. Displ well w/30 bbls diesel, followed by crude. Drop ball, set pkr. Tst tbg to 2500 psi; OK. Tst ann to 2500 psi; OK. Tst SSSV; OK. RR @ 1000 hrs, 11/23/84. NewTD 6780' Date 11/23/84 I PB Depth 6653 ' Kind of rig Rotary IType completion (single, dual, etc.) Single Official rese~oir name(s) Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correcl Signatu re I Date [Title ~)~ ~,~f2~__~ j 1 / 15/85 Drilling Superintendent For form preparation and ~stribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AtlanticRichfieldCompany ~> Daily Well History-initial Report Prepare and sul~mlt the "la#M~ ~ o~ the first Wednesday after a walt is spudded or workover operations are st~led. Daily wor~ prior Io II~d~.N~ld be ~mmarlzed on the form giving inclusive datu only. Olalrtct County or Parl~ Alaska North Slope Borough Field Lease or Unit Kuparuk River ADL 25653 Auth. or W.O. no. Tit · AFE 802921 Drill Parker 191 API 50-029-21194 Alaska Ooeretor A.R.Co's W.I. ARCO Alaska, Inc. Spudd.dorW.O. bagUnspudded I°ate 10/17/84 I"°ur 2015 hrs Prioratatus,faW.O. JWell nO. 2D-1 Date and del~th el of 8:00 a.m. 10/18/84 10/19/84 10/20/84 thru 10/22/84 10/23/84 The ab .......... Ct Signature For form Orel:)aration and d~n~ution, see Procedures Manuel, Se~ion 10. Ortlling, Pagel 86 and 87. Complete record for each day reported AR38--459- f-8 56.24% 16" @ 117' _1(~ 1065', (948'), Drlg surf hole/IM' Wt. 9.8, PV 14, YP 14, PH_9/.~J~L 10, Sol 10 Accept rig @ 1600 hrs, 10~'~/~4. NU diverter sys. 2015 hfs, 10/~/84. Drl !3½" hole to 1065'. 10-3/4" @ 2650l~ 2665', (1600'), Wsh Cmt out of Div Stack Wt. 9.8+, PV 18, YP 15, PH 9.5, WL 12, Sol 12 Drl f/1065'-2665', MWD surv every 500'. Circ for sbt trip, 10 std. Pull 15,000# @ 1800'-1700' C&C hole to rn 10-3/4" csg. Drop SS surv. Pmp pill & blow dwn kelly. Trip out, LD MWD & BHA. RU to rn 10-3/4" csg. Rn 65 jts 10-3/4", 45.5 lb/ft, J-55, HF-ERW, BTC csg. Lnd csg w/Tanko fluted hgr. Shoe @ 2650', FC @ 2565' RU cmtg hd, circ 590 bbl @ 8 BPM. Mix & pmp 800 sx AS III @ 12.2 ppg followed by 300 sx Dowell Class "G" + 2% S1 + .2% D-46 tail slurry (15.8 ppg) @ 7 BPM. Displ w/10 BW @ 8 BPM. Displ cmt & wtr spacer w/237 bbl mud w/rig pmp @ 7 BPM. Bmp plug & press to 1500 psi. CIP @ 0554 hrs 10/19/84. 1473'MD 0.5° N1/2W 2461'MD 0.6° S86-1/2W 2595'MD 1/2° N22-1/2W Spud well @ 10-3/4" @ 2650' 3023', (126'), Coring w/Core #11 Wt. 9.2, PV 10, YP 7, PH 10, WL 12, Sol i ND diverter, perform top job w/100 sx AS I @ [6.0 ppg. NU & tst BOPE. Instl WB. PU BEA, GIH to 2564', C&C. Tst csg to 1500 psi;. OK. DO FC, FS + formation to 2675', C&C. Conduct formation tst to 12.5 ppg EMW. Drl 2675'-2738', trip f/coring assy. Core 2738'-3012' in 10 ms. GIH w/core assy #11, core 3012'-3023'. 10-3/4" @ 2650' 3200', (177'), Logging Wt. 9.3, PV 16, YP 19, PH 9.5, WL 9.4, Sol 5 Core 3023'-3041', POH, LD core assy. Total core rec'd = 92%. PU 9-7/8" bit/BHA & GIH. Drl 3041'-3200', C&C, short trip to 10-3/4" shoe, C&C, POH. RU Schl, log DIL/LSS/GR/GR/SP 3194'-2649'; LDT/CNL/NGT 3197'-2649'. Logging w/EPT-PCD. IOate I Title · .~, ~'f" ~ I1', . -- 10/31/84 ' JAN 5 985 Alaska Oil & Gas Cons. Commission Anchorage Drilling Superintendent Number all daily well history forms consecutively iPag~ no.. eS they are prepared for each well. .. · ARCO Oil and Gas Company Daily Well History--interim Insfrueflone: This form ~s used dunng drilling or workover oPera{ions. If lasting, coring, or po,fora{in§. Show :ormation name in describing work performed. Number a;I drill stem testa sequen a y Attach description of all cores. Work De,formed by Producing Section wil! be reported on "Interim" sheels until fmal completion. Report ollicial or reDrasentatiYe test on "Final" form. II Submit "Interim" sheets when fi led out but not less frequent y than eve~' 30 days. or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovera and following se!ting of oil string until completion. Oislrict ICounty or Parish IS!ate Alaska North Slope Borough I Field ILease or Unit Kuparuk River APL 25653 Alaska Well no. 29-1 Date and deP!h as of 8:00 a.m_ 10/24/84 10/25/84 [0/26/84 Signature ~ For form prepare.on and dls~ribu!lo see Procedures Manual SectiOn 10. Drilling. Pages 86 and 87 Complete record for each day while drllhng or workover in progress 10-3/4" @ 2650' 4054', (854'), Drlg Wt. 9.2, PV 11, YP 9, PH 10.5, WL 9.6, Sol 5 Log EPT/PCD 3181'-2649' Log w/SHDT f/3199'-2649'. Shot 30 SWC w/100% rec'd. PU 8½" bit, DD & BRA, GIH. Drl & DD 3200 -4054'. 3250 , Assumed vertical 3380 , 3.5°, NI6.5W, 3379.94 TVD, 3.93 VS, 3.81N, 1.12W 3503 , 6.7°, N16.5W, 3502.45 TVD, 14.74 VS, 14.29N, 4.23W 3658 , 11.7°, N16.5W, 3655.46 TVD, 39.26 VS, 38.05N, 11.27W 3841 , 16.5°, N18.5W, 3832.95 TVD, 83.47 VS, 80.57N, 24.68W 10-3/4" @ 2650' 5119', (1065'), Drlg Wt. 9.2, PV I1, YP 8, PH 10.5, WL 10.2, Sol 5 DD 4054'-4078', trip f/bit. DD 4078'-4173', trip f/bit. CO elec pkg in MWD. Drl & DD 4173'-5119'. 4023', 21.0°, N26.5W, 4004.93 TVD, 142.97 VS, 135.59N, 47.47W 4398', 26.8°, N27.5W, 4347.tl TVD, 296.14 VS, 274.12N, 112.83W 4774', 43.1°, N27.5W, 4668.96 TVD, 489.68 VS, 443.82N, 206.90W 10-3/4" @ 2650' 6332', (1213'), Drlg Wt. 9.8, PV 10, YP 4, PH 10, WL 8, Sol 8 Drl & DD 5119'-6266', CBU, POH & LD DD & MWD. GIH, drl 6266'-6332' 4962' 39.0~ N21.5W 4819 91TVD 601 63 V$ 545.70N, 253 33W , , ! · , · , 5397', 39.9°, N24.5W, 5157.34 TVD, 875.47 VS, 802.63N, 350.22W 5836', 37.0°, N25.5W, 5498.40 TVD, 1151.79 VS, 1051.47N, 470.42W 6211', 34.7°, N26.5W, 5800.53 TVD, 1373.23 VS, 1249.95N, 570.08W ITM 1o/31/8~ Drilling Superintendent RECEIVED JAN 1 5 1985 AR3B-459-2-B Alaska Oil & Gas Cons. Oo~,~mission Anchorage Number all dally well history .~orms consecutively as they are prepared lo, each well. ARCO Oil and Gas Company Daily Well History-Final Report Instructiona: Prepare and submit the "l~il~:~ml~" on thi lirst Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. · 'Final Rel3orr' should be submitted a~ el3erationa Im susoended !or an indefinite or anoreciable length of time. On workovers when an official test is not required upon completion, report coml~lIllll3W'-~l~l Ill;Ir~&entetlve test data in blocks provided. The "Final RII3ert" form may be used for reporting the entire operation ~t space ,s available. District ICounty or Parish Alaska I North Slope Borough F,md Lease or Unit Kuparuk River ADL 25653 Aufh. or W O. no. ~ TiUe AFE 802921 I Drill Accounting cost center code State Alaska IWell no. 2D-[ Parker 191 Operator ARCO Alaska, Inc. Spudded or W O. begun Spudded Date and cepth as of 8 00 a m API 50-029-21194 A.RCo. WI.56 24% [F°talnumber°fweils(actlve°riiaCtlvel°nthis cost center prior to plugging and I · abandonment of this well I Date Hour Prior status if a W.O. 10/17/84 2015 hfs Complete record for each day rel3orled [0/27/84 thru 10/29/84 7" @ 6760' 6678' PBTD, RR 10.2 ppg NaC1/NaBr Drl 6332'-6780', 44 std short trip, rm 6695'-6780', CBU, 6 std short trip, CBU, POH. RU & GIH w/DIL/SFL/GR/SP/CAL/FDC/CNL; could not pass 5142'~ POH, RD Schl. GIH, hit bridge @ 5142'. FIH, C&C, POH. RU Schl, log w/GR/SP/DIL/SFL 6780'-2650', CAL/FDC/CNL 6780'-6124' & 3200'-2649'. RD Schl. GIH, C&C, POH, LD DP. RU & rn 169 jts + 2 mkr jts, 7", 26#, J-55 HF-ERW BTC csg w/FS @ 6760', FC @ 6678'. RU Dowell, circ. Cmt w/45 bbls Spacer 3000, 620 sx C1 "G" + 1.5% D-79 + 1.2% D-112 + .5% D-65 + .2% D-46 + .25% D-13 @ 12.0 ppg, followed by 660 sx C1 "G" w/3% KC1 + .8% D-60 + .2% D-46 @ [5.8 ppg. Displ w/246 bbl 10.2 ppg brine. Bump plug w/2500 psi. CIP @ 1517 hfs, 10/28/84. Cut 7". ND BOPE NU tbg head & tst to 3000 psi; OK. Arctic Pak w/r50 sx AS I @ 15.7 ppg, followed by 89 bbls Arctic Pak. CIP @ 2130 hfs, 10/28/84. RR @ 2200 hfs, [0/28/84. Re[eased r,g Date Rotary Classlf,cat,ons ,od. gas. etcJ Type comc~et~on (s,ng~e. duai. etc.} Oil Single Producmg melhod Official reservoir name(s) Flowing Kuparuk Sands Potential :est data For f ...... p ......... d dis~',bution, ~0~5 seep .... d .... " .... ,.' ...... ,0, A i5 Drilling. Pages 86 and 87 /~ Atasl~,30i~ ~ Gas 6o~s. O0m~s¢on Anchof~e Well no Dale Reservoir Producing Interval Oil or gasTest t~me Production Oil on ;est Gas per clay Pumb s~ze. SPM X ;engtn Choke size T P. C.P. Water % GOR Gravity Allowable EfI~ective date corrected AR319-459-3-C Number all daily well history forms consecutively as they are prepared for each well. iPage no. 3 Oh~llI~a ~t Atllatk:RIchli~IdComPIny (: ll,.$'r 0 l~ 1~,: R 2D'l KUPARUK NORTH S[,ni'l~'', ALA$t',A (;CT ~)IF~:CTIONAL SU~V[':¥ C UST[][~EIR I, l,'q'I' l NC, AR('k.~ AI,ASKA~ INC, KUPARUK NORTH SbOPE, AI,ASAA SURVEY DA'It:i: 3-NOV,,B4 EN(;IN~]FR ~ I~CBR I, DF., uP,,TiqODS ['IF cr~,!PtJTATiF)t~ T[JOL LnCATIbNI TA~GEhTIAb- averaged (]evl,~]tion and azimuth I~7'~]RPOLAiTON: I,,[NEAR VERTICAl, SgC'll[))~l i,iflRlZ, DiST, PROjf]CTf, D [lmTO A TARGET AZIMUTH OF NORTH 24 D~G 55 MI~ WEST C{.} a P t} T Al' 1. {'l N ARCO ALASKA~ 2P-1 KUP/~RI~K INC. INTEhPiII,ATKD VAI,Uf<5 TR L.JF St. R-SEA HEA,51IRFD VERTICAl, YER'IICAI, DEPTN DF. PTa DEP'i H 0.O0 0,00 -127.O() 100. O0 10u. O0 -27. Ou 200.00 200,()n 73.Oo 300.00 30u.uo 1 -13.nO 400.00 400.00 273,00 500.00 bO0.00 600.00 bOO.OO 47.3.00 700,00 700.00 573.00 800.00 799,99 6'72.q9 900.00 899.99 772.99 1000 O0 999,99 R77.09 1100:00 1.009.98 q'l?,O~ 1200.00 1199,9R IOT~.Oa 1300, O0 1299.¥7 I 177.97 1400.00 1399,97 1~7~.97 1500 O0 1409,97 1372,97 1600~00 1599.97 147~.97 1700,00 1699,94 1572.94 1800.00 ~799,90 167~,90 1900,00 1899,B6 1779.~6 2000 00 1999. t~4 1R72.~4 2100:00 2099.t~1 t9'17.81 2200,00 2199,7q 20'12,79 2300,00 2209,79 217~.79 2400,00 2399.78 2272.78 2500.00 24.99.78 23'72.7~ 2600.00 2599,78 24'72.78 2700.00 269~.78 25'79.78 2800.00 2799,7~ 2672.78 2g00,O0 2809.7g 277?.78 3000,00 2999.'11S 3100,00 3009.78 3200,00 3199.'18 3077,78 3300.00 3299,77 3~72.77 3400.00 3309,09 32'72.69 3500.00 3499,37 3377.3'/ 3600, O0 3598,58 3471 , 58 3700.0(} 3690.94 3550,o4 3800,O0 3'/q4.24 3657,24 3900.00 3800.32 3753,32 DATE: 4-1)EC-~34 DATE UF SL, RVF. I/: 3-NOV-B4 KELLY BUSHING FLEVAIION{ ENG]NK["~R: MCBRIDE I-ON r, VI:::N 100 FEET OF MhASUI~FO L)FPTH CnUR,-E DEVIATION AZIMIJTh DEG MIN L')EG MTN VLRTTCAI, Di.IGLE~ RECTANGULAI~ 5ECTION SEVERITY' NOI.(TH/5OUTn FK~.T nE(il 1 O0 FEET C{qORD I NATES ~:AST/WEST Fi.'. E T DIST. FEET 0.00 O O0 O,oO N 0.00 K 0,00 -0.02 0:27 0,04 S 0,03 ~ 0.06 -O.01 0.22 0.15 S 0,28 W 0.32 -0,14 0,06 0.37 S 0.48 W 0.61 -0.18 0,12 0,51S U,b9 k' 0,06 -O.O7 0,17 0,55 S 1,02 W 1,16 0,03 0.29 0.05 S 1.47 W 1,bi '0.19 0.45 1,05 S 1,81 W 2.09 -O.g0 0~22 1.87 S l.~g W 2,66 -1,60 0.10 2.58 S 1,77 W 3.13 '2,29 0,13 3.34 S -2.R9 0,11 4,12 S -3.23 0,16 4.78 S -3,40 0.35 5,31 $ -3.52 U,3R 5,02 S '3.1.5 0.43 5,33 S -2.10 0,62 4.25 S -0.61 0,22 2,24 S 1.19 0,34 0.30 N 3,07 0,20 2,82 N 1,76 2,01 2,b3 3.38 ~,74 4.00 4,16 ~.39 2.19 1.22 PAGE 1 4.52 0,16 4,90 N 6.00 0,76 7,07 N 7,07 0,51 8,59 N 7,67 0,1,9 9,47 N 8.49 O,b2 10.'43 N q.41 0,05 11,12 N 9.79 0,17 11.30 N 9.89 0,12 11,29 N 9.79 0.09 11,17 N 9.66 0.20 Il.10 N 0,18 0,97 1,72 2,18 2.30 1,bl 1,08 0:Ul 0.96 127,00 FT q.7b 0,06 1.1,28 N q,93 0.21 11,49 N 10.01 0,13 11,5'1N 10,34 2,55 11,86 N 14'16 1,51 15,57 N 21 94 2,48 23 28 N 51.61 2.44 52.~9 N 74,37 2,88 75,01. N !02.01 3,19 100,'12 N 1.11 1.16 1.13 0.99 0,09 1,95 4.b6 8,65 ~5.05 25,32 DkPARTURE AZImUtH DEG ~IN N 0 0 E S 38 $ 62 29 1 8 W S 52 5 ~ $ 53 13 w S 61 50 ~, $66 6 w S 59 55 w $ 45 15 w (" S 34 23 w 11.33 N 5 36 E 11,55 ~ 5 46 E 11,b2 N 5 35 E 11,90 N 4 46 E 15,57 n 0 20 W 23,36 N 4 47 a 35,70 N 7 29 W 53,59 N 9 17 W 7~..50 N 11 20 w 103.85 ~ 14 6 w 4,90 N 2 2 * 7,14 N 7 50 g 8,77 N li 18 f 9.72 N 12 59 E 10,68 N1~ 26 E 11.24 N 15 g 11,35 N 5 28 E 11,32 N 4 12 E 11,20 )~ 4 9 E 11,14 N 4 56 E 3,78 S 27 48 * 4,59 b 25 59 W 5,46 $ 28 50 W 6.29 5 32 25 W b,75 S 33 38 , b,b6 S ]6 50 W b 95 S 44 2] ~ 3.07 N 2 * CnMPUTAT[III'., DATE: 4-I}FC-B4 ARCO ALASWA, 2D-1 K I.! P A RI1 Ix NORTH El. OPE, AbA~KA JN'It']RPtjI~ATED VAI,I~E5 F[]k EVEN 10o FEET bF MEA$UkFD PEPTH 4000.00 4100.00 4200,0O 4300,00 4400.00 4500.00 4600.O0 4700.00 4900,00 5000.00 5100.00 5200.00 5300.00 5400,00 5500.00 5600.00 5700,00 5800,00 5900,00 6100.00 620O 00 6300:00 6400,00 bEO0,O0 6600,00 6700.0O 6780.0(,) TRiIE StiR-SEA C(.'UPSF VERTICAL V~R]']CAt, DEVTATIRN AZIMUTH DEPTh DEPTH PEG M~N UKG MI~ 39R4,UO 3857.90 20 28 N 25 13 W 4077,U0 ~O5n,RU 22 24 ~ 72 7 w 4169.79 4042,79 23 42 N 22 ~6 ~ 4261.08 ~134.o~ 24 28 N ~b 3~ W 4351.o5 ,1724.65 26 11 N 29 44 w 4440 32 43~.~2 28 52 ~: 30 40 W 457~80 ~9~.RO 31 20 n 30 17 w 4~11,55 44u4.Eb 32 40 ~ 2u 54 ~ 4695.10 456R.10 34 11 N 23 33 W 4776.95 4649.95 ]6 6 N 19 14 W 4856.10 472q.10 39 5 N 1'7 6 W 4933.00 4806.60 39 q N 10 39 W 5011.14 4864,14 39 10 51 17 15 W 50~9,00 4962,00 39 q N 19 6 W 5166,39 5039.39 39 38 N 21 34 W 5~42,89 5115,89 40 25 N 24 36 W 5319.11 51.97,11 ]9 55 N ?4 bq W 5390,34 b~60,34 38 54 N ~5 21 W 5474,~0 5347.80 3'7 41. h ?b I W 5554,45 5427.45 30 bl N 20 5 W 50~3.06 5506.R~ 37 27 N 2~ ? W 5713.84 5586.84 30 29 N 2'1 37 W 5794,~ 5667.82 35 R N 27 35 W 5877,16 b750,1~ 34 3 N 20 13 W 5960,6.] 5833,63 32 4~ N ~4 55 W 6045,45 591R,45 31 31 N ~4 21 W 6131,52 6004'52 ~9 38 a 24 1 W 6219,05 O09?.Ob 2~ ~? N 23 44 W 6289,22 o102,22 ~U 42 ~i 23 44 W VERTICAL DOGLEG SECTION SEVER1T¥ FFkT DEG/IO0 134.73 2.77 1'1~.43 1.73 210.60 1.7~ 251.41 2.59 993.71 2.83 3~,72 2 62 389,64 2~01 442.58 2,27 497.51 1,95 554.84 615,40 1,78 678.05 0,73 740.52 2.04 802,87 1,17 865.96 3,21 930,34 1,51 995.07 1,12 1058.59 1,15 1120.5~ 1.07 11.~1.03 2,60 1241.74 1,24 1301,70 0.08 1ID0,]0 1,49 1416,99 1,57 1472.06 2,08 1525.02 2,10 1575,01 3.80 1624.?b 0,00 1662.66 0,00 DATE iJF SbRVEI: 3-NOV-B4 KELLY BUSHING ELFVAT1UN: M~ASURED RECTANGULAk COORDINATES HORIZ, NORTH/SOUTH EAST/WES~ DIST. FEET FEEl.' FEET 130.25 N 39,40 W 130.08 163.94 N 54.00 W 172,b0 200.32 N 68.65 W 211.'15 237.49 N 85.52 W 252.42 274.~8 N 105.84 W 294,37 314.b0 N 129.13 W 340,07 357.72 N 154.8! W 389,'78 404,19 N 180.41 W 442,63 455,87 N 203 ~6 W 497,55 507.33 N 224~86 W 554.93 565,40 N 243,79 W 015.72 625,91 N 262,03 W 67~,55 686,42 N 280,08 W 741.36 745,93 N 299,97 W 803.98 805.45 N 321,57 ~ 867,28 864,~1 N 347,03 W 931'~6 923.25 N 374 44 W 996.29 980.75 N 401~44 W ~059,73 1036,56 N 428.4P W 1121,bl 1090,94 h 454,87 W 1181,97 1144.92 N 982.77 W 1242,04 11q~,04 N 510,73 W 1302,36 ]250.01 N 537,95 W 1360,85 1300,52 N 563,77 ~ 1417,46 1350,29 N 587,35 ~ 1472.b0 1398,46 N 609.37 W 1525,46 1,444,92 N 630,16 ~ 1576,35 !989.20 N 649 55 W 162~.70 1524.38 N b65~01 W 1. b63,12 .. PAGE 2 127.00 FT DEPARTURE AZIMUTH DEG N 23 19 W N2 2 42 w N 22 11 ~ ~ 21 54 w N 21 45 w h 21 52 w ~ 22 4 w h 22 15 w n 22 27 ~ h 22 3u w h 22 51 w h 23 5 w I~ 23 17 W ~'~ 23 2t, w ~ 23 30 W N 23 32 w h 23 33 ~ N 23 34 ~ ARC~ AbASKA, Tr~C. 2P'1 KIJPARIIK DATE 4-DIFC-a4 51JMMAR¥ DATE UV SUPVEY: 3-NOV-84 ENGINEER/ PAGE 7 127.00 FT U, ARi~ER T[}P UPPER BASF IIPP~,R SANL) bA6F I,OWER SANO pE2'~ TOTAL I.)F PT ri FINAL Wr~I,L [,FICA'I.'IUN ;%'1' 1 D: Tf,' UE SbB,-SEA MEA,~bRED V I'iRT,[ OAI, VERTICAl.,, D E P l' tt tJ E P T H D E P T H MEASURt,:D DEPTH ORIGIN= 153' TV'D K~ SUR-$LA 6,323.0~ 6332.00 6~13,00 6551,00 6078,00 67~0,00 5896.2'~ 5903.72 5971.58 6080,12 6199.7o 6289,22 5769.24 577m,'12 5U44.58 5962.12 6072,76 6162,22 67~0,00 u?~9.22 6162,22 HONIZONTAI., i.~EpANTURE DISTANCE AZIMUTH FEET I.)EG MIN 1603.~2 !, 23 34 W SURFA 636' FEb, S RECTANGI] NORTH/S 1312.0 1316.5 1356 6 1422:4 1479.5 1524,3 CE LOCATION gC 26 TIlN R9E, OU'I'H igA&t/wK$'r 7 N 8 N 4 N 9 N ~ n 8 N 569 39 571 5b 590 ]0 620 to 645 29 665 01 ~.~ APKFI~ COMPUTATIf]N I..)A'J~E: 4-Dt<C-~4 IN'j.F'APL.)I,ATt~..I'~ VAI.,IJE.,5 ~'Ok CHO$[..~N HuRJjT..,UN,5 MF. ASURkD DEPTH PAG~ 6 DAT~ OF $ORV~i¥: 3-NuV-84 K~[,LY BUSttlNG FLEVATIUNI 127.00 F~ ENGINFik. R: ~icsRID~ 6323.00 5R90.24 5769.24 1312.07 6312.00 5903.72 577b.72 1316.58 6413.00 597~.58 5~44.58 1356,64 6651ouO b089.12 5962.1~ 1422,49 6678.00 6199,7~ 6072.76 i479.53 6780.00 02S9,22 6162,22 1524,38 569 ]9 , 571 56 . 590 ]0 . 620 1~ . 645 29 . 665 O1 w C(I~,~PtjTAT I F1N DATE: PAG~ 3 ARCO AbA~SKA, !h('o 2D-1 KUPARIIK NORTH ,SL[)PL., AIjA,.'SKA DATE [)F SUI~VE¥: 3-NOV-B4 KEL6Y BI)SitiNG ELEVAT]UN: ENGINELR; McBrIDE 127,00 IN'tI"'J-<POI,ATi":D VAI,,UF;:,S l..'f'lt-< J":VEN IOOU FELT OF ~F:A,SURLD DEPI ?RUE SUR-$b;A CDuRbF ~EASU~FD VKRTJCAI, VERTICAL DEVIATI{]N A~,I~UTH DEPTH DEPTH DE})I'H DEG MIN t)EG ~Im VLRTICAI., DOGLEG ~(ECTANGULAi~ COORDINATES ItORIZ, DEPARTURE ,SECTIIqi,~ SLVERITY NOHTH/5OUTb EA6T/WEST DIST, AZIMUTH FEET DEC/lO0 FEEI FEET FEET DEG ~IN 0,~0 u,O0 -127.00 0 0 1000,00 999,99 R'/2.o9 0 30 2000.Ou ]999.~4 1877.~4 ! 20 30OO.OO 2909.78 2~72,7g 0 8 4000 OO 39~4,~0 3857,R0 20 28 5000~00 4~5u,10 4729,{0 39 5 ~000.00 5~]3o86 6506,86 37 ~7 67~0,00 62R9,27 ~162.~2 28 42 0 0 E 0,00 o 56 W -2.29 29 12 ~: 4.52 22 R F '9.76 25 13 ~ 134,73 1'1 6 W 615.4B 2~ 2 W 1241,74 23 44 W 1662.6b 0,16 0.06 2,77 1.78 1,24 0,00 0,00 N 0.00 E O,O0 N 0 0 E j.34 S 1,76 W 3,78 $ 27 4u ~ 4,90 N U,18 W 4,90 N 2 2 w 11,28 N 1.11 E 11,33 N 5 36 E 130,25 N 39,40 W 136,08 N 16 49 W bbb,40 N 243.79 W ~,72 N 23 ~9 ~ 1144,92 N 482,77 W 1242,64 N 22 51 w 1524.38 N 665,01 W 1663,12 N 23 34 W (, CflMPUTATION ARCO Ai, ASKA, KIIP~RIlK NON'Ir'it SLOPE, IN] E~Pi]I,ATkl~ VA1,U~i5 'LROE SUB-Sr_.A ~EA~IIRFD VERTICAL VERTICAL DEPTH L)FPTH Di<PTU [)ATE: 0.00 O.OO 27.00 2'1.00 ]27.00 12'1 00 O.00 227,00 227~00 100,00 327.00 327.00 200,00 427,00 427'U0 300.00 527.00 527.0~ 400.00 627,00 ~27.uO 727.01 127.00 600.00 827'O1 827,00 DATE UF SURVEY: 3-NUV-84 KELLY BUSHING FLEVAIIUN: ENGII~EER: Mc~RID~ 927 01 92'1,U0 1027~01 102'1,uo gOO.no 1127.02 ~127.0o 1000.00 1227.O2 1227,00 1100.00 1327.03 1327,00 12Oo. Ou 1427,03 1477.00 ltO0,O0 1527.03 1527 00 1400,00 1627.O4 1~27~00 1500,00 1727,07 17~7.00 1600,00 1827.11 1827,00 1700,00 {"'OR F. VEN 100 F'~F]"I' OF SUB-SEA DEPTH 1927.14 192'1.O0 1800.00 2027 17 2027.00 ln00,OO 2127~20 2127,00 2000.00 2227.21 2227.00 2100,00 2327.21 2327,00 2200.00 2427.22 2427,u0 2300.00 2527.72 2527.00 2400.00 2627,~2 2b~7.00 2500.00 2727.22 2727,{)O 260n,00 2~27.72 2827,00 2700,00 C()URSE DEVIATION AZ]~UTt'i 2927 22 2927.00 2900. 3027:22 302'1.00 2qO0,o0 3127,22 3127.00 3000.00 3227.22 322'1,uo 3100,00 3327.24 1327,00 32u0,00 3427,3b 342'1.u0 3300.00 3527.g0 .3527,U0 340n.00 362~.78 309'!,00 3730,75 37~7,00 360o.o0 3833.~5 3827,00 .]7o0.00 0 4 $ 67 bO F 0 8 O 11 U 8 $ 45 24 w 0 10 $ 80 1) W 0 15 S. ~3 31. w 0 16 S 49 25 w 0 28 $ 1.1 2{7 W 026 S 10 PAGE 4 127,00 F~ VmR'I'ICAL DOGbEG NF:CTANGUuAN SECTION SEVERITj FF[<T PEG/100 FEFT COURDINA?E$ HOHI EAST/W£ST DI$T, FEE'~ FEET Z, DEPARTUi~E AZIMUTH DEG ~IN O,O0 0,00 0,00 N 0.00 1,13 0,00 N -0.03 0,18 0.08 S -0,03 0,16 0.20 S -0.1.7 0,12 0,43 $ -0.02 0,13 0,55 S -0,01 0,17 0,73 S -O,3b 0,31 1,25 S '1,11 0,24 2,08 S O,00 ~ O,00 0.00 F: 0.00 0,0~ W 0,11 0.35 W 0,40 0,52 W O,68 0,77 W 0,93 1.14 W 1.26 1,58 W 1,74 1,87 ~ 2,24 1.86 W 2.79 N 0 0 N 90 0 E 847 5b ~ $ 60 12 ~ S 50 50 $ 55 21 w $ 63 59 S 65 16 ~( ,556 $ 41 44 -1,76 0,38 2,75 S -2.49 0,30 3,58 S '3.01. 0,24 4,31 S -3,28 0.24 4.95 S -3.43 0,39 b,t2 S -3.49 0.45 5,b! S '2.93 0.59 5,13 $ -1.78 1,06 3,84 S '0,13 0,12 1,57 S 1,74 0,44 1,03 N 1,74 W 3,25 1.80 W 4,01 2,14 W 4,81 2,B5 W 5,'11 3,52 w b,46 3.80 W b,77 4,10 ~ b,57 4,05 ~ 5,59 3,07 W 3,45 ~,90 W 2,16 ].50 0.32 J.42 N 4.~0 0,21. 5,46 N 6.40 0,91 7,62 N 7,22 0,20 8,83 N 7.8'1 0,22 9'73 N 8.74 '0,34 10,b3 N 9.55 0,28 11.20 N 9 86 0,32 11,33 N 9:8b 0,04 11,26 N 9.74 0,14 11,13 N 0.95 W 3,55 0.14 £ 5,47 1,20 E 7,71. 1,86 F; 9,02 2.2~ E 10,00 2,15 £ 10,85 1,45 ~ 11,30 0,97 E 11,37 0.82 F: ll.2g 0.04 E 11,16 N 1 28 E 8 5~ E 11 55 £ 13 9 E 11 2b g 7 22 g 4 54 E 4 N 4 17 E ~ q,6b 0,20 11,12 N g. R1 0,06 1.1,34 N O.g7 0,1.1. 11,52 N 10.01 0,15 11,56 N 10.93 3,04 12,42 N 15.82 2,86 17,22 N 24.8B 2,58 26,21 N 38.49 3,47 39,83 N bR.O1 3,b0 59.20 N 83.23 3,b~ R3,39 N 1,01 E 11,17 1,13 F: 11,40 1.15 E 11,58 1.12 E 11,01 0,79 Fi 12,44 0,48 W 1"1,23 2.b4 W 26,34 5.60 W 40,23 10.27 W 60.U~ 1~.04 VI 8b,32 ARCFI AI, ASKA, KUPARIIK TRUF MEASIIRFI) DEPTH DFPT 3938.5R 397.7. 4045.91 40'27, ~153.]5 41'2.1. 4262.60 4227. 4372 6,2 437'1. 4484:~3 44?7. 4600.~3 4527, 47~8.37 46~7, 4RSR,7U 4797, 5091.48 4927. 5220.45 502'1. 5349.06 5127. 5479.25 5227, 6610.27 5739,79 ~42'l 5R65 69 5527~ 5q91:30 5027, b1.16.]0 5727, 6239.?3 582'7, 6359.O1 5927. 6478,35 6027. 6594.79 6127. 6709'06 6227, 6780,00 6289, CRMPIJTAT [ON ]NC. Al,ASEA L)A'rE: 4-L.)EC-84 IN'rFRPUI,ATEF) VAI,UE5 [.'OR LVEN 100 FEET SUR-.gt.A (:OURSE V~:R'rlCAL DOGLEG Al. VLR'I'ICAb DEVIATION AZIMUTH SECTION SEVERITY H [)l-:P'l'it bEG MIN DF, G ,~Ih FEET DEG/IO0 Oo ~HO¢),Ou ~8 48 N 25 27 W 0n 3OUO,O0 21 31 N 25 30 W 150.g4 O0 40oO,O0 23 7 ~ 21 46 W 197,06 uO ~()o.ou 24 10 t,~ ?,t 3q w ?36.00 O0 42u0.0() 25 27 ~ 29 21 W 281.82 00 4~00.06 28 27 ~' ]0 32 w 332.50 Uo 44uo.ou 3! 20 N 30 17 w 389.70 OO 4%0n.00 32 49 N 26 16 W 452.51 00 4600,n0 34 47 N 22 5 W 5t9.41 O0 47uO.OU 38 7 N 17 4g W 592.27 Un 4RUO.O{* ]9 q N 1. o 41 W 672,72 00 ~n0O.OO 38 56 N 17 55 W 753,33 O0 bO00.00 .?9 t2 N 19 45 W ~33.75 O0 51()o.n0 4u 18 N 24 6 w 916.83 OO 5200.00 39 48 N 25 I W 1001.64 OD 5~00,00 3~ 2a N ?b 45 ~ 1083.15 00 5400,00 37 4 N 25 54 W 1100.45 00 5SOO.aU .~'l 33 N 28 4 W 1~36,49 OO 5600.()0 36 21 N 27 36 W 1311,41 O0 5700,00 34 40 N 27 15 W 1382,70 O0 580n.00 33 i, 5 N 25 g w 1450.23 O0 bnO0.O0 31 38 N 24 24 W 1513.70 00 0000.00 29 46 h ?4 6 W 15'13.32 O0 6100.00 2~ 42 N 23 44 W 162~,60 22 olo2,22 2u 42 N 23 44 W 1662,66 4,12 2,30 1.33 1,46 2.71 2,77 2,00 1,39 3,30 4,29 1,43 1,94 1,16 1,52 0,99 1.27 0,~0 1,26 1,77 1.89 1.51 ,00 DATE OF SURVEY: 3-NOV-B4 KELLY BUSHING EGEVATIUN: ENGINFLR: ~.CBR IDE SUB-SEA DkPTH N[CTANGULAk COU NORTH/$OUTM FEET FE PAGE 5 111.56 N tO 145.02 N 45 1B3,12 N 61 223.58 N 78 264.31 N 99 308.35 N 125 357,U2 N 154 ~13.08 N 18~ 474.u6 N 212 543.05 h 236 127,00 FT 620,75 N 260 598 72 N 284 775:19 N 310 U52,31 N 341 929,21 N 377 1002,~1 N 412 1072,~2 N 445 1140,28 N 480 120b,05 N 515 1.269,91 N 548 RDINATES hORIZ, DEPARTURE T/WEST DIST, AZIMUTH E~' FEET DEG MIN ,38 w 115 63 ,10 k 152i17 .68 W 103 23 .89 w 237.09 ,96 W 282 58 ,45 W 332:89 ,87 W 389,90 ,~6 W 452,55 ,38 W 5~9,46 ,80 k 592,44 .4q W ~73.19 ,00 ~ 754.23 .26 W 834,98 .46 W 91U.16 .21 W 1002.86 03 W 1084.25 iU8 W 1161,q2 JO W 1237~31 ,24 ~ 1~12,b5 .28 W 1383,22 1330,50 N 5'18.13 W 1450,68 N 23 29 w 1388,14 N b04,70 W 1514,14 h 23 32 , 144.2,56 N 629.10 W 1573 76 N ~3 33 ~ 1.493,19 N 651.30 W 1629~05 h~3 33 w 1524,38 N 665,01 W 1663,12 N 23 34 W SCHLUMBERGER ARCO ALASKA, INC. 20- 1 KUPARUK NORTH SLOPE, ALASKA NOVEMBER 3, 1984 TVW PLOT FROM OCT DATA JOB REFERENCE 69802 WELL' 2D-1 SURFACE LOCATION' 153' FNL, 636' FEL, S26, T11N, R9E, UM SE VERTICAL PROJECTION -2000 - ] S~ - ! 000 -$DO 0 0 SOO 1000 1 SO0 2000 ........... ~.---.-.~ ......... ~-..,...Z._e. .,:../. .......... L._~ .......... ~.~..2..; ......... ,.._T_~ .............. ~ ............... : .................. , ................. ~ ................................................... L~.z...._.~...~ 2.. L.:...;...;..._..~..Z__...z...z...L&_Z ........ L.L...z...Z...LJ..L...=...z .._..;...._.;...L.......$ ........... ~ ....... i ............. . , , . ~ I .... ~ ....................................... ~ ........ ~ ............. r--~ ............... t ............... t ........... J .................................... "'* .............. * ................. t ............ ~ ....... ~'""-'"i ................. : ........... t ........... ~ .... ~6 ::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::: ::::::: : :' :::::: .... ';':::: r:-: ...... :'?--?----'- .......... f"-'"-'~ ....... ~ .... ; ..... t":'*'"- :'~ .......... :--- k,---: ....... ?'"'":":"' 't": ..... : .................. t ............ ............................................................................................. ] ............................... ~: ~: 8~ ............ ~ ' - I . I :i ~. ~:.ixi_.l i. :-1 ............... i_ i_. - ; ........... ~ ........:...[ ............ ~ ...... ~ ...... l ................. ; ............. ; ...... ~ ...... ~ .............. ~.: .......... + ......... t .... ~ ....... ~..-~:.-: ...... :.1 ....... ~ .......... ~ .... ; ................ '- ~_' ~.~p .... k't-~ ........... ~--~--: ......... ~ ............. f'-"7:?'~ ....... : ......... ~'"-":'* -i ............ -~*': ..... t"--": : :-- ~-'-:~: ' ~': t :- ...... ; 7"-'":'" ~ ....... * ~ ..... ~ ~-',. .......... ~: ....... 1 ....... : ............. ;7 .... ~ ....' "[ ...... : ~ : .... : .... [ ...... ; ........................... ; ....... ~ ..... ~ -4 .............. ~ .................... ~ ...... ~ ............. ~ ........ ~ ........................... , ........................... & ....., .............. .+..~.; ....... Li..._..z..;. '.~.1 ....... L.; ..... :...,..1 ..... ; ......... 1.--; ~ .... 1 .............. :-~ ............................ ~..; ............... · -:---,---:-- ]-. ~: .~-.-:- ~.-.: ........ :-~ ......... $--: .... ~ ...... :--~ 1 ..... ;...~: ................... :. ~ . . t , · . · . ~ , ~--t ....... : ..... f':' ~' :7'~'"7'"t .... ;":-7-:'~ ~ ........ :-'7'; ..... : ...... ~ .... : ..... ~ ...................... ........ 5 ........... ~.~ . : .......... t ........ ~ - . - ~ ............. .......... ; .... ~ ........; .......... ~ ... ..... ~' ...._..-_....._...._..._.._.,......-..,...__.....l ....... ~ ~ "1 ~ ....... . .......... ~ ...... ~ .............. L .....; .....~ .....~ ..... ........................... ' ....... ~ ................. ................................ ~ ............................................................. ~ :.::::: :: :: :: ::: .:::.:: :~ ::;. ::::::::::::::::::::::::::::: :.. ::::; :. ::::::: ~ /:: :: :' ':: :-: ::: · . ..................... ~ ................................................................ ;...: ............... : ............................................................. .... : ................. * ........... * .......... * .............. * ...... *'--*-------* .................................... ...................................... ; ............................... l sonn' PROJECTION ON VERTICAL PLANE OF AZIMUTH BBS SCALED IN VERTICAL OEPTHS HORIZ SCALE : l/SO0 [N/FT WELL' 2D-1 SURF2.CE LOCATION' 153' FNL, 636' FEL, S26, T11N, R9E, UM HORIZONTAL PROJECTIO?! ~T~ 1 ~00 1000 Soo -SOO - ! ooo -]SOO -2000 .................................................... ; ........................... ~ ............................................................ : .................. -3S00 -3000 -2500 -2000 - 1 SO0 - 1000 -SO0 0 SO0 WEST EAST Surgesi \ red'form to be inserted in each "ACtX~e'' well folder to dleck for timely ccmpliance 'with our regulations. or, WeliINam~ and Number . : ., Reports 'and Materials to be received by: /~ '~3--~ ' Date _RequiredDate Received Remarks _ . . ·. ~~on ~e~= ~es '~-/~-~- ~ Well History Yes /-- l~--g~ . . -. ~ . . _ Mud L~ , ~~~.-., ...... . . . wo-Pt ~ O ~ . Registered S~ey Plat ~ S 7-- t/L-g M ' ~i/ Inclina~on S~ey Dire~ional Drill St~ Test Re~s .~0,-~" " - ~ ~ --- . ... ~d~0n T~t Re~rts _ To.. DATE: IrltOM: L. K. SHITit/I~. I;. BAXTER -- TEAHSIdlTTED HEREI~ITIt AI~E THE FOLLOWING: PL~SE N~E: BL - BLU~IHE, S - SEPIA, F - FI~, T - T~E, PC - PH~OPY A!aska Oil & Gas Cons. Commission Anchorage DATE: p.F. CEIPT ACIQqOWI,EDGED: T~ i~LF, ASE ItETURN P, ECEII~ ATTN: I~ATS¥ S. I~AXTEI~ ATO/.~I.~ !'. O. BOX 100360 ANCHOI~GE, AX 99510 ARCO Alaska, Inc. ~ . Post Office B~xx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 12, 1984 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached are our notices of intention to following Kuparuk Field wells' 2D-1, 2D-2, 2D-3 If you have any questions, please call me at perforate the 263-4253. Mike L. Laue Kuparuk Operations Coord i nator MLL/kmc Attachment (In Triplicate) RECEIVED Alaska 0ii & Gas Co,~s. Commission Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA'0TL AND GAS CONSERVATION C~ISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~K OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84-171 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21].94 9. Unit or Lease Name KUPARUK RIVER UNIT 4. Location of Well SURFACE LOC T11N, ATION' 153' FNL, 636' FEL, SEC. 23, R9E, UM BOTTOMHOLE 23, T11N, R9E, 5. Elevation in feet (indicate KB, DF, etc.) 127' (RKB) LOCATION' 1503' FSL, 1405' FEL, SEC. UM 6. Lease Designation and Serial No. ADL 25653 10. Well Number 2D-1 11. Field and Pool KUPARUK KUPARUK POOL RIVER FIELD RIVER OIL 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [~( Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" sand in Kuparuk well 2D-1 be perforated for production. Procedures call for the well to be perforated with wireline conveyed gun under a lubricator. Proposed Intervals (MD)' 6457'-6467' (1SPF) 6475' 6477' 6480' ANTICIPATED START DATE' December 14, 1984 RECEIVED DEC I Alaska Oil & Gas Coils, Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _ Title OPERATIONS COORDINATOR Date The space below for Commission use 12/12/84 Conditions of Approval, if any: Approved by Approved Returned - By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, ~ ~ Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 21, 1984 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Monthly Reports Dear Mr. Chatterton: Enclosed are the Monthly State Reports for the following wells' 2G-14 1L-1 2D-3 2X-16 2G-15 1L-16 2D-2 2X-15 2G-16 1L-15 2D-1 2X-14 2E-16 2W-5 WSP #2 Sincerely, A~~g E~~ngtleer JBK/SH/tw. HILL/05 Enclosures RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary of AllantlcRichfieldCompany STATE OF ALASKA ALASK~--.~.~AND GAS CONSERVATION G.~r~441SSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~ X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-171 - 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21194 4. Location of Well atsurface 153' FNL, 636' FEL, 5ec.26, T11N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) 127' RKB, PAD 90' 6. Lease Designation and Serial No. ADL 25653 ALK 2579 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2D-1 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of October ,19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, s'pud date, remarks Spudded well @ 2015 hfs, 10/16/84. Drld 13-1/2" hole to 2665'. Ran, crated & tested 10-3/4" csg. Performed top jo6--w/lO0 sxs AS I. Drld 9-7/8" hole to 2738'. Core well. Continued drlg 9-7/8" hole to 3200'. Ran logs. Drld 8-1/2" hole to 6780'TD as of 10/28/84. Ran logs. Ran, cmtd & tstd 7" csg. Performed Arctic pack w/150 sxs AS I + 89 bbls Arctic pack. Secured well + RR @ 2200 hrs, 10/28/84. 13. Casing or liner rgn and quantities of cement, results of pressure tests 10-3/4", 45.5#, J-55 HF-ERW BTC csg w/shoe @ 2650'. Cmtd w/800 sxs AS II I + 300 sx Class "G" cmt. 7" 26#, J-55 HF-ERW BTC csg w/shoe @ 6760' Cmtd w/1280 sxs Class "G" 14. Coring resume and brief description 2738' - 3012' in 10 runs; 3012' - 3023' 3023' - 3041' 30 swc 15. Logs run and depth where run DIL/LSS/GR/SP f/3194' - 2649' LDT/CNL/NGT f/3197' - 2649' EPT/PCD f/3181' - 2649' 6. DST data, perforating data, shows of H2S, miscellaneous data SHDT f/3199' - 2649' GR/SP/DI L/SFL f/6780' - 2650' Cal/FDC/CNL f/6780' - 6124' + 3200' - 2649' ~,~s~ Ot~ & Gas 6o~S. N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. , //~ JJ~~'/~'" '/,//~/ ..... Area Drilling Engineer DA~-E'., __/~//~/% NO TE--Rep¢ on t~s~r~is required for each calendar month, regardless of the status of operations, and must be/~iled/J~ duplY6ate with the Alaska Oil and Gas (~onservat~n./Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 c.-' H I LL/MR30 Submit in duplicate ARCO*Alaska, Inc. Post Office 360 Anchorage?,.,~ska 99510 Telephone 907 277 5637 Date: 11/14/84 Transmittal No: 4849 RETURN TO: -. ARCO ALASKA, INC. ATTN: Records Clerk AT0-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one si~aed copy of this transmittal. OH LIS TAPES/Schlumberger f~B9730 2I)-16- 11/08/84 Run 1 ~9713 2~5 , 10/31/84 " /~69639 1L-16, 10/17/~ " ~~78 ~1' ~10/27/~ ~ 2 /~~ 2~15' 10/15/~ ~ 1 / ~0~71 ~-,-~u ~ ~ 6/~/~ ~ns /~9~~ 2~16' 10/30/~ ~ 1 /~9667 ~-15' ~0/23/~ " 3266.5 - 7855.5 3729 - 8112 400O - 7837.5 2638 - 6787 2717.5 - 6970 76.5 - 68O3 3391 -- 7693.5 3638 - 8396.5 Receipt Acknowledged: Date: DISTRIBUTION . B. Currier Drilling W. Pasher BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D & M NSK Ops. J. Rathmell Well Files _ . M EMORA- ,,I DU M Stare of Alaska TO: THRU Lonnie C Smith Commissioner FROM~ Doug Amos Petroleum !nspecror ALASK~OIL AI~D GAS CONSERVATION cC~ ~~.~on DATE: October 23 , 1984 a . , ....-' FILE NO: D, 4 I. 41 TELEPHONE NOi SU BJ ECT: Witness BOPE Test at ARCO's Mup. 2D-1 Well, Sec. 26,~zllN,R9E,U%~,~ Permit No. 84-171, Parker Rig No. 191. Friday, October 19, 1984: After witnessing the test at Doyon Rig ~o. 9, I travele¢ to ARCO's Kup. 2D-i well to witness the BOPE test there. The test commenced at 4:30 pm and was concluded at 6:00 pm. There was one failure which was repaired before drilling out the 10 3/4" casing shoe. I filled out an AOGCC BOPE test report which is attached. In summary, I witnessed the BOP test at ~RCO's Kup 2D-1 well. There was one failure during this test, please see attached report for details of this failure. Attachment 02-00IA(Rev. 10/79) O&G #4 4/80 ," ~.: . '~ ' . · . ~. ~ ~., '. ~T'. 'd(',-'zao~, p../%4; . - .: . , .~._..,.- - . STATE OF ALASKA' ALASKA OIL & GAS CONSERVATION COMMISSION B.0.P.E. Inspection RePort Inspector .., Operator Well k~,,o. ~,~ ~:)- / Location: Sec ~ T/1/~ Rc;~- M ~/A//, · . Drilling Contractnr ~:~t~/f~f~ '- Date VO//~/~ ~ Well ~-~p ~D_/ Representative ,,l~'. ,/~,,4.,,,,~-/F_. L.h PS rmi t # ~ ~ - / 7 / // ~_~Casing Set @ ~(~ 50 ft. Rig # /~/ Representative_' ?. /~Z~~O/( Location, General Well Sign General Housekeeping Reserve pit Rig & ' BOPE Stack Annular Preventer J ,,I,' · _ Pipe Rams ~'f- ~' Blind Rams ~w- j ~'~'0//Choke Line Valves . -' H.C.R. Valve / J · ~'~Kill Line Valves Check Valve J ACCUMULATOR SYSTEM Test Results: Failures Full Charge Pressure ~;0o. 0 psig Pressure After Closure J:~ ~;0 psig 200 psig Above Precharge Attain~: ~ min 5L sec. Full Charge Pressure Attained: 5 min ~9 sec~ N2 Controls: Master Remote ~. Blinds switch cow r . Kelly and Floor Safety Valves Upper Kelly j /Test Pressure_. Lower Kelly J ~'Test Pressure Ball Type.. J '-'(' Test Pressure Inside BOP J ~Test Pressure Choke Manifold [ Test Pressure No. Valves /_~ No. flanges ~7 ~ Test Pres sure II .. Adjustable Chokes Repair or Replacement of failed equipment, to be made within ~ days and Inspector/Commission office notified. Remarks~ ~D/%D I~/%~T~. V~.V~ 014 ~1%~.~ ~u~O~ ~~ ~ Distribution P~5~, ~, ~ [~(~ ~5~O , orig. - AO&~C' Test Time.. / hrs... Hydrauically operated choke ! ~' September 21, 1984 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re ,. Kuparuk River Unit 2D-1 ARCO Alaska, Inc. Permit No. 84-171 Sur. Loc. 153'FNL, 636'FEL, Sec. 26, T!!N, RgE, LrM. Btmhole Loc. 1503'FSL, !405'FEL, Sec. 23, TllM, RgE, Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samp_l~$ of well cuttings and a log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operation~ you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior ~o commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation, of the blowout prevention Mr. Jeffrey B. Kewin Kuparuk River Unit 2D-1 _. -2- september 21, 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~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. In. the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Ver~y__rtrulv vo~urs, ~/ ....//.,,:? ~____,~.~_,,~< : ..... ,l' C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY OP~ER OF THE COMMISSION be Enclosure cc: Department' of Fish & Game, M~bitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office B.,.~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 30, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 2D-1 Dear Mr. Chatterton' Enclosed are- An application for Permit to Drill Kuparuk 2D-1, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plat A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment Since we estimate spudding this well on October 20, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. S i~ere 1 y, /Area q~ril ling Engineer JBK/JG/tw GRU1/L15 Attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany STATE OF ALASKA ALASKA,-~IL AND GAS CONSERVATION C~=~MISSION P :RMIT TO DRILL 2O AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL I~X DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 '~.t':!;i!L; .,,'; .-~ ~'' ~':.::~ SERVICE [] STRATIGRAPHIC SINGLE ZONE [] MULTIPLE ZON E~[] 4. Location of well at surface 153' FNL, 636' FEL, Sec.26, T11N, RgE, UM At top of proposed producing interval 1247' FSL, 1286' FEL, Sec. 23, T11N~ R9E, UM At total depth 1503~ FSL, 1405' FEL, Sec. 23, T11N, R9E, UM 9. Unit or lease name Kupa ruk Riv~i'~:~ii!~ 10. Well number 2D-1 11. Field and pool Kuparuk River Field 5. Elevation in feet~ (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 127' PAD 90~ ADL 25653 ALK 2579 , 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewi de Surety and/or number #8088-26-27 13. Distance and direction from nearest town 30 mi. NW of Deadhorse miles 16. Prol~o~e~-depth (MD & TVD) 6849' MD, 6276' TVD fe~t 14. Distance to nearest property or lease line 153 feet 17. Number of acres in lease 2560 19. If deviated (see 20 AAC 25.050) Kuparuk River Oil Pool Amount $500,000 I15. Distance to nearest drilling or completed 2D-2 well 60' @ surface feet 18. Approximate spud date 10/20/84 2743 psig@ 80°F Surface 20. Anticipated pressures KICK OFF POINT 3247 feet. MAXIMUM HOLE ANGLE 37 o (see 20 AAC 25.035 (c) (2) 3149 Proposed Casing, Liner and Cementing Program 21 psig@ 6117 ft. TD (TVD) SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 124" 16" 62.5# H-40 I Weld 80' 37' I 37' 117'1 117' ~ 200 cf 12-1/4" 10-3/4" 45.5# J-55 I BTC 2613' 37' 37' 2650'1 2650' 450 sx AS Ill & HF-ERW I I I I 250 sx Class G .~8-1/2 7 26.0# J-SS I BTC 16813 36 , 36 6849 6276 550sxClass G Blend ',~'~\~j 22. Describe proposed program: .~)~\ ARCO Alaska, Inc., to dr~11 a Kuparuk River Field development well to approximately 6849' ND (6276' proposes . TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8 , 5000 p ', ' ' " s~ RSRRA BOPE stack w~ll be ~nstalled on the /0~/~'~' surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annuluar). The West Sak formation will be cored. Expected maximum surface pressure is 2743 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 2D-1 will be 60' away from 2D-2 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any (see attached sheet) 23. I hereby cerJ~ that the foregoing is true and correct to the best of my knowledge // SI_~GNE__~_D /'/~~)r~,~' TITLE Area Drilling Engineer The space ,~w tc~' UO~r~ssion use CONDITIONS OF APPROVAL Samples required []YES ~-.NO Permit number APPROVED BYL_____ Form 10401 ~l~r~PD1/O Mud log required I Directional Survey required I APl number []YES [~JXIO / ~;~LYES []NO I 50- Approval date SEE COVER LETTER FOR OTHER REQUIREMENTS ./--")/Q9/,~ 1/.8 4 I ,COMMISSIONER DATE September 21: 198/4 by order of the Commission Submit in triplicate PERMIT TO DRILL 2D-1 interruptions in the disposal process. The well will be completed by the workover rig using B-1/2", 9.2#/ft, J-55, 8rd tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. ARCOiAL^SK^.~-~Nc.-! .... - -- : ! .... i--- i./lr,,: - t -- ? -- ~ · . . ~ ~ ..... - i .... ..... ~ ; - . ~ ~ .. . - ..... ~ ...... ~ .... ; ........ ~ _ t ' ~ ...... ; ..... t ....... ~ - ..... ~ - . . ~ ~ .... , .... ~ ~ m i m ,~ m m . ~ASE2~AF~OST2~~02_' ............. ~. .~ ................. ... ...... ...... t . . . . . . . . , , , ~ . ,I . · , ~ · ~ , . ~ ......... ~ '' [ TOp W SA~ SNDS TVD=2F4Z ........... :_. ;.;-, ' KOP. TVD~3247 T,D=3247 DEP=0 { ' ' -~- AVERAGE ~NOLE _ .... : ...... 3Z__DE [;_._2.9:_J~Z N. ~. ,TOP UPPR SNDS TVD-590~' Tt'1D=S384J DEP= 54-4 ~, -~ ,,T~3P-L-OWR-SNDS~-6GOt--Tt'ID-6503-DEP--t-64-6 · \ TARGET CNTE TVD---6032. TtID=6517iDEP=1624 " BASE KUP BNDS- TVD-6 ~_TD.. ~ .(L 0 · . '- 000 -SECTION' ' ; - ; . 2000 , ,. i . · i PAD 2D. WELL NO) 1 REVISED'PROPOSAL KUPARUK FIELD..NORTH(SLOPE. AL~,SKA-, ; ~ ' i ' ' , ........ ~ WEST---4=^S ~4 2000 : ~000 O .... ~000 ~ , . :~000 -- ; - i - ~ ' TARG~.T LOCA'rZoN~ ' ' ' 1 ~20: F~9... ;1320' ~-g ' I i , ~oO ANNUI..-~ PR£¥ENI'~R 9 DIAGRAM ~1 !3-5/8" 5000 PSi RSRRA BOP STACK 1. 16' - 2000 psi Tanked s:a~ing head Z. ll' - 3000 psi casing head 3. I1" - 3000 psi x 13-5/8' - 5000 psi s~acer spool 4. 13-5/8" - 5000 psi x i3-5/8' - 5000 psi Oriiiing spool S. 13-5/8' - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke an~ kill lines 7. !3-5/8" - 5000 psi pipe ram~ 8. !3-5/8' - 5000 psi blind rams 9. 12-5/8" - SO00 psi annular BLIN~) R~ ~ 7 ~ORILLI~~ SPOOL CSG !:t:O ACCUMULATOR CAPACITY TEST '1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WiTH HYDRAULIC ~UID. 2. ASSURE THAT ACCUMULATOR PRESSURE !S 3000 PSi 1500 PSI DOWNSTRE~ OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ~J.L UNITS ARE CLOS~"D WiTH CHARGING PUMP OFF. 4. RECORD ON NAOC REPORT. THE ACCEPTABLE LOWER IS 45 SECONOS CLOSING TIH£ AND i200 PSi PR,.SUR.. !3-5/8" BOP STACX TEST .... !. FILL BOP STACX AND HANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- :~. PREDETERMINE DEP'rH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN iN LOCK DOWN SCR~S tN HEA~. 3. CLOSE ANNULAR PREVENTER AND ~A,L~S TLJ'I)~~ O~ ]30~T TIPSY AC~AINST CLOSES) CHOKES 4. TEST ALL COMPONENTS TO 250 PSl AND HOLD 'FOR l0 5. INCREASE PRESSURE TO iBOD PS! AND HOLE FOR !0 MINUTES. BLEED TO Z~RO PSi. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF RAHS. 7. iNCREASE PRESSURE TO 3000 PSi AND HOLD FOR i0 ~. ~~'PRaSSUR~ DOWNSTRt~ OF CHOKE ~SOLATION VAL%~']~S. 70 ZERO PSi 70 TEST VALVES. TEST REMAINING UNTESTED ,~N!FOLD.VALVES, It ANY, WITH- 3000 PSi UPSTRE,tM OF VALVE AND ZERO DOWNSTREAM. BLEED SYSTEH 70 ZERO PSl. 9. OPEN TOP S~7 OF PiPE RAJ~,S AND CLOSE BOTTDM SET OF PIPE RAHS. 10. INCRF_ASE PRESSURE TO 3000 PS] AND HOLD FOR iD MINUTES BLEE. D TO ZERO PSi. 11. OPEN BOTTOM SET OF PIPE P, AJ~.S. BACK OFF RUNNING jOINT AND PULL OUT OF HOLE. CLOSE BLIND RAHS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAHS AND RECOVER TEST PLUG. MAKE SURE I,tANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET iN DRiLLiNG POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSi. 14. TEST KELLY COCKS AND iNS!DE BOP TO 3000 PSi wiTH KOOHEY PUMP. )' ~'~ i] 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST '~ ........... FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFO~:U't COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPEP,.ATE BOPE DAILY. . _. - .. .~, ;.~ Surface Diverter System 16"-2000 psi Tankco starting head. lankco qu(ck connect assy. 16" X 20" 2000 psi double studded adapter. 20" 2000 psi drilling spool w/10" side outlets. 10" ball valves, hydraulically actuated~ w/lO" lines to reserve' pit. Valves to open automatically upon closure of annular preventer. 20" 2000 psi annular preventer. 20" bell nipple. Maintenance & Operation 1. Upon initial installation close annular preventer and verify Ghat bail valves have opened properly. 6. Close annular preventer and blow air through diverter line~ every ~ hours. Close annular preventer in the event that gas or fluid flow to surfmce is detected, If necessary~ manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor ARCO Alaska, Inc. Post Office BO'~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 5, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 2D Pad Wells 1-4, 13-16 Dear Elaine: Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU8/L25 Enclosure RECEIVED JUL ! 1 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany . DRILL . lt'E 2. D CONDUCTORS ' r 1~ ' A S' §'U I LT LOCATIONS II _ _,,_ .- . : _:.. . . i WELL I Y -- 5,95o,,0~I.5,15 Lot. 70°17'OT. 882. Z'' i! X = · _ 153' FNL, 636'FEL EL. 89.7',0.G. 8G.l' I WELL 2 Y · 5,954,o8g.~1 Lot. X = 529~08g, 24-onv.' ~ {49°~.5'52..468'' I 109' FNL~ 677'FEL EL, BcJ.6 ~O.G, 86.3' ,, I WELL 3 Y = 5,954, ts$.4z l_qt. 70o!7~08.75~8'' x= 5~9~048.58 Long. 149045'53,648'' ....... _ 65,', FNL) 7 WELL 4 Y = 5,954,177,42 Let. . X= 5Z9~008,~ L~. i49°45'54,8g2'' Z~2~ ,,.21',FNLz7~7'FEL .. EL. 89. e', 0, G. 86.3' '~ -~,~ ~'~ - ~6~25 ...... WELL 13Y=5,953,50e.~2 Lot. 70°17'O2.Se42'' D. g'Og ' ~ , , , B~ FNL, f44 FEL EL. ~ _. . , . , WELL 14 Y, 5~953~552.61 Lat. x= 52g~584.2A L~. 149045~,108'' 647' FNL~ I~' FEL EL. 89.8', O.G. 86 8' WELL 15 Y = 5,95~,596.~ Lot. 70017'03.4564'' X = 5~9~ 54~.57_ 603' FNL . ~-ELL--~6- Y-; 5,955,64o. sl X = ~9, 50~,~ L~g, i4~°45'40.4~" i 559'FNL~ 265'FEL EL. 89.5 ', 0.G.86.5' ....... · -- ~ ~ ..... Ji I I ' '- ' ....... ~ " ~oc~r~ ~ P~o~Ac~D s~C~O~ ~e JUL ~ ~ ]~, ~ TOWNSHIP i! N RANGE gE,, UMIAT MERiDAN. ' Alaska Oil & Gas Cons. ~ remission ~ ELEV. TAKEN AT TOE OF PAD,S.W. OF WELL. ~ , · , ~ ~ ·. ..... / ~m F~ '-- ~~D ~ ~ACTICE LAND SUEVEYING iN THE ~ATE OF --- , I ~CT A~ OF JANUARY '" ..... ARCO 2~ 2s ~ z~ ~ATIONS ,, O.S. Z-D LOCATION - " --- i .... CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee . (2) Loc' thru 8) (~/thru 11) (10 and 11) ~ (4) Cas~ .~ f-la (12 thru 20) thru 24) (6) Add: 1. Is the permit fee attached .......................................... s 2 I 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 well bore plat included .............. 7. Is operator the only affected party ............................... 8. Can permit be approved before ten-day wait,. ....................... e 10. 11. 12. 13. 14. i5. 16. 17. 18. 19. 20. 21. 22. 23. ' 24. YES NO REMARKS 25. Does operator have a bond in force .................... ~ ............. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is conductor string provided ................ Is enough cement used to circulate ~'c~duc~or an~ ~;;~''[[ ...... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... 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 well bore separation proposed ................ ' ........... Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached . ...... Does BOPE have sufficient pressure rating - Test to ~FZ) psig .. Does the choke manifold comply w/API RP-53 (Feb.78) ..... ....... Additional requirements Additional RemarkS:. , . GeolOgy: EngiBe~ering: HWK ~ LCS/~_ BEW ".'.( rev:.' 1~/08/83 ", '6.CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE . , Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 0 ¢) 0 0 0 0 0 0 uOO (:, t")ii 012 U6b O65 t) 6 b u65 O65 U6b i,, t 'iq ? ,, 0 o o 9 T u ? , 6 9 I 4 'f.Ij 2.4i4b 5.4: 4,. 0 0 (':' ,) 3.2070 1' L,'": 9,2 5 D 0 I'~,~ A 8, 3.7 9 ~ 0 2,4 ;ii 8 0 q, 3 5 q4:: 3. ~451 2.7 0 7 0 C) r) 7 (" 3 3. 7871 9.2 031 ,!. 567() 9. :,] 8 2 8 10.~93~ ,rl.0664 3,7'.,-)69 2. 1 'i~ 6 ~ '2.1 -q9a. 3.324, ~: 9. $ 'i ~ 1 - ':] ~ ":~. 250C, '~. 3359 '1. il). 09 3 b -qgq. ?Sn[: t:,,~ H ,j, -- 9 '9 r4. I:' b C' 'd '" C' b P '1 6 '~ r:, L;" (; h; . e 'f,.t - q !.:: t.? , 2 {~ f: (;"' 1,,: t.~ '.i _c~ .)q. 2f>n ...,, v'" "r 1_: 3.679 t ~ 14.3125 -- ": 90,250 .,) .! 56,. 2500 3..4 t'~ 2 9 1.7.4371% 3,, 5'13'! 117,5i!:,2b · -a9q, 2500 -q'~'h, 2500 ..ngg. 2bO j 2 . 3'Z 6 2 } <:J q. 2 $ (),) 3. ;:~ 4,. (7.'. 0 n 0 ,,, 9 t:,~ q. 25 *') , c>,~ q. 2bOu 3. 237.t - 9 9 g · 25 O .,,) _egQ 9%r~'.) 1 C, 2.2 .b O ,; . a c: c; 2 ~ ..' "i .~ C A L, ,L 3,724b 9,42 g 7 ,,, g ';..99'. 25 O (.) 4. !. 9.9 0 62 .-g99. 2500 t0.9219 .99,25 00 3,5 801 1 1.0.3 g l - 9 9 9,250 G 2,6289 o. 093 8 -999. 2509 9. q 375 - 9 "..J 9,2500 -999 o 250L, ~.~9~4 !',~. 5.859 -ggq. 250t) .~, 3 ,..; ~ b q. C, 7 ~; 1 -99q. ?DOt, .~. ,5t 7 t,. - 9 9 q. ~ 5 .s., 0 ."/· 3 '.-/4- b EP'I F',: P P H l E P T F H ,i, 95. ~- [57o (.l - c !9 <,~. ? 5 (',? t;~;',: '"" l _ c :.:; a ,. 2 b 0 ~.; F C < ~..., [').. 4- 2 3 ):! ": f.., _ o 9 o · ? 5 '~ ,.; F' C hi ~', - o ~i q o P 500 S;' C. rq t. 2 ,.. 4 5 7 0 95,t. d73 ',- 9 9 9, ? 5 0 0 .1 0 5,0 ~:5 ?.. 5 - 999.25 ',"~ 3 -999. ,.. o W '9.2 b ,:~ -qgq'. 2.~00 5,.,'..~ ,37 ~.3/?, 1 '25 '0 - <'~ 95,', 2 !:> 0 u . o '9 9., ? b o 0 2.3 .'3 n I 4.2~3 ! tf4.31.2) -()99, :~ 5 71 ', 3,767 ,.; ~.:: 6. (. '2 5 'o - <: "':' q .2. b ,9 't 9.1. 9 5,3 -9 9q. ?.50C. 2 ,, '? b 7 ~:~, - q 99.2 5 0 O 2. ,54:30 ~,9219 - 9 ,:)9.2 5 0 (.i 2,5 a: '! 0 a, 5 '85 9 ?. 3 ,b !. :3 ") 9 c.) 2 .) (. t., 9922 25o0 2.. 2 ~3 t.. (r) 8. ~b72 - q '9 g. 2.5 (! 0 2. '3 "13 t) 4.137: g. 72~o .. c., '9 g. 2 b O t) 6328 2 500 1 O, 4L:r~3 ..o 99.2. 500 .13 (,~ ,, I i'.'i 7 5 'f 72 7 ~!, n (,i ('; e, , I f". P. S ,, (,', {,~ 0 i 'F' ~..; .:...*' t 3.23 '? ":~ 97 ,, 0 'L~ 00 -999.75'30 - O 99. ? 59 3.95 '7 u -,999.2bO~) ~ 7 . 3750 -999,. 250<) 72.750 7 !. o, t':> ? 5 3.77 '7.3 -'~ b 7 ,, 0 (){'". 9 9, .t,.. 0 '? .,~, 2 4,04,7 bO() b5. n{:2 b 7 ?l. t 25 3. q 0 r-~,~ 1,11 ('" I,., I .f l., 5.1 Ci, i., i. 3, ! 5 8,2 - ,9 9 9.25 (',) o -" ii, ,,- 9 9 9.2 5 n f) 25.57 ~ 1 9.2260 4. 9. 'I 9 6 9 3. 892t~ ~. f~ '75 9 9.2031 4,. 21~.'7 9,~906 0938 ? ·., ~. 4.453 j, n. 320 3 '~,. ~? b 7 ~,,~ 2 O:) 0. O i)O t.~ 9.7.3q4 - r:~ 9 '::"'. 5' 500 0 6 5 ,;~ ,.~ 4 r.) r4 . t -'[ H a T U ?s'' F .v t?, C 'I ~' I C J, i' l': t .... ?'! L, [) (' I'; 5 'D CAb! ,[:' (j 'F ,/~ D T F 1,,:" H I C: A L i w t'.,, R A [*' L: "1 b ? C'. T A EPq ,[ [ L: C A 1.~ :'i, '? C '? A q, .[ :t; ~,." F,. i 9.7813 6 . 7500 65,. ! ~'~75 3p. . 593~ -g99.2hOt) -q99,25n0 595. b{.,nt; 38, RNRA POTA fi: P H i C;\ T, I F' C i',~ ,,,,, p U 'j) q -999,2b00 -999,2500 -999,2.5 (] (; -999. RECEIVED F E 8 1 4 ~185 Alaska Oil & Gas Cons. COn'.~missjpr~ b~$ TAPE VERIFICATION LVP OlO,HO~ VERIFICATION bISTING PAGE ** R~EL HEADER SERVICE NAME :SEP'VTC DATE :~5/01/14 ORIG~N : CONTINUATION PR,~VIOUS R~EL COmMeNTS : ** TA, PE ~E&DER SERVICE NA~{E :SE.VIC DAT'f :~5/01/~.4 ORIGIN :0000 TAPE NAME :987'1 CONTINUATION PREVIOUS T~P~ : CO~MFNTS : RECORD TYPE 137 ** FILE' NEADER FILE NA~F~ :$ERVIC,OOl SERVICF NA~E : VERSION ~ DATE : MAXIMUM t,E~IGTH : i024 FILE TYPE : PREVIOI!S FIDE INFORMATION REC(~RO~ ** ~NEM COMTENTS "NIT TYPE CATE SIZE CODE CN : ARCO ALASKa, INC, 000 000 018 065 WN : KUPA~UK 2D-! 000 000 012 065 FN : KUPA~UK ~IVE~ 000 000 014 065 RANG: gE 000 000 002 065 TOWN: llN 000 000 004 065 SECT: 96 OO0 000 002 065 COUN: NO~TH SLOPF 000 000 012 065 ST~T: ~LASKA 000 000 006 065 CT~Y: usa 000 000 003 065 ** COMMENTS ** ************************************************************************************ , $CHLUUB~RCER LVP O:I.O.HO~ VERIFICATION LISTING PAGE 2 ~SASKA CO~tPUTING CENTER COMPANY :. ATLANTIC RICHFIELD COMPANY WELD = 2D~1 FIELD = KUPARI, IK . ~'"N , COUNTY = NORTH 8LD~ E BOROUGH STAT~ : ALASKA RUN #1, DATE LOGGED: 22 OCT 84 EDIT LDP: T HALSTEAD JOB NU~B~R AT .~CC: 69664 TYD 5DP~ JR ' JOB NUNBER AT ACC: 6987'7 :::::::::::::::::::::::::::::::::::::::::::::::::::::: TTTTTTTTTTT V'~V VVV DDDDDDDDD TTT VVV VVV DDD ODD ~TT VVV VVV DDD DDD TTT VVYVV DOD DDD,. TTT VVV DDDDDDDDD..jR, ENTRY ~LOC~S TYPE SiZE REPR COD~ 4 1 66 8 4 73 9 4 65 !6 1 66 0 ! 66 DATUM SPFCIF!C~TION RLOCK$ ENTRY 0 1 60 ,lin 0 L¥p 010.N02 VERIFICATION LISTING PAC~E 3 SERVICE SERVICE I.!NYT API ~.PI APi AP! FibE sIZE SPL REPR ,ROCESS ~', L.G TYpE CLASS MOD NO. CODE (OCT~D) ORDER # FI 00 000 O0 0 0 4 ! 68 00000000000000 O~M~' 00 ~20 01 0 0 4 1 ~8 00000000000000 OHMM 0(} 120 46 0 0 4 I 68 00000000000000 OHM~ O0 1~0 4~ 0 0 4 I 68 00000000000000 ~v oo olo o~ 0 0 4 ~ 6~ oooooooooooooo ~ oo ~o o~ 0 0 4 ~ ~ 0000000o000000 ~ oo 00o oo 0 0 4 ~ ~s oooooooooooo, oo DATA DEPT SP ~T SP DEPT SP DEPT SP DEPT 3~20.0000 SFLU -999.2500 GR 3 ~ 00 0000 46:4063 3[oo oooo s~'r,u 2725000 GR 3000.0000 5FLU -36.5000 CR 2000.0000 -44.7188 oep? 2.o0 nooo sp -40: 4688 DEPT SP OE~T SP 2700.0000 -38.0000 261q,0000 SFLU -~90.7500 OR ** F!LF TR[ILE~ WILE NAME :SE~VIC,O0] SERVTC~ NA~E VERSIO~I ~ DATE : MAXI.UU LENGTH : 1024 FILE TYPE NEXT FILE MA.E : -999 2500 ILD -099.~500 ISM -999,2500 -g99:2500 MD 3~20,~217 6 6289 ILD 3 83~9 ]~M 6,~500 7~:,3125 ~[:) 3200:~1 7 6.~633 ILD 5,9687 ILM 5,9219 6~"3125 MD 3~00,~197 13,6797 ILD 9,8203 I. LM 9,8828 59,9375 ~[) 2~. 2344 lbD 24 53~3 I5~ ~3,703i 50:6250 ~D 200022197 4926250 "D 2000221 V o ~969 ILD 8.9207 IB~ 8,8672 77:06~5 ~D 2700.21~7 -999.2500 ?LB -999,~500 ]h~ -999,~500 -~99.2500 ~{D 2619.2197 ** RECO~D TYPE 137 ** TaPE TRAIt. EP ** SE~VYCF NA~E :$EPV!C DATE 285/01/~4 ORIGIN :OOOO [,,VP 010,N0~ VERIFICATION LISTING ]PAGE 4 TAPE NA~, :g877 CONTINUATION # NEXT TAP~ NAME COMmeNTS : ** REEl, TR~ILE~ SERVICE NAME :SE~V?C DATE ORIGIN : REEL NA~ CONTINUATION NEXT REEL MANE CO~FNTS : ** RECO~D TYPM ~,37 ** ** REC[]RO TYPE }37 ********** EOF ********** ********** EOF **********