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Con©coPhillips TRANSMITTAL FROM: Sandra D. Lemke, ATO -704 TO: Abby Bell ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 222 W. Th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 2K-15 DATE: 02/11/2019 Transmitted: Kuparuk River Ziebel Cased Hole Mechanical logs - raw data reports (production profile characterization) instructions: please promptly sign, scan, and e-mail to CC: 2K-15 - e -transmittal well folder Receipt: Date: L Alaska/lT--GGRE i Co c Phillips Alaska i Office: 907.265.6947, Mobile 907.440.4512 30 35 9 RE EvEn FEB 11 2019 A(7GC; c • • ConocoPhillips RECEIVEC Alaska OCT 13 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGC October 11, 2015 5����E� ,SAN 2 0 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7t'Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement 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 attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, /17"/-7:7/;761 /6> MJ Loveland 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) Sir 411, 0g9 Kuparuk Field Date 10/11/2015 2N&2K PAD Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# of cement pumped cement date inhibitor sealant date ft bbls ft gal 2N-312 50103207060000 2150280 Surface N/A 11" N/A 3 10/9/2015 2K-15 50103201130000 1890890 Surface NA 10" NA 3.7 10/4/2015 • STATE OF ALASKA , ALA, A OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed' Abandon r Repair w ell J Rug Perforations r Perforate rOther CTD Set-Up Alter Casing r Pull Tubing J Stimulate- Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4 Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r 189-089 - 3.Address: 6.API Number: P O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20113-00 7.Property Designation(Lease Number): 8.Well Name and Number. ADL 25588 KRU 2K-15 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Gyro, RCBL, caliper, GR, CCL Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary Total Depth measured 8304 feet Plugs(measured) 7742' true vertical 6495 feet Junk(measured) none Effective Depth measured 8202 feet Packer(measured) 7598 true vertical 6417 feet (true vertical) 5965 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 SURFACE 3285 9.625 3320 2947 PRODUCTION 8253 7 8286 6481 RECEIVED JAN 23 2015 Perforation depth Measured depth: 7824-7832, 7934-7974 True Vertical Depth: 6134-6140,6217-6247 suttee i AOGCC; Tubing(size,grade,MD,and ND) 3.5, L-80, 7754 MD,6082 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL PACKER @ 7598 MD and 5965 TVD NIPPLE-CAMCO'DS' NIPPLE @ 519 MD and 518 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this workover Treatment descriptions including volumes used and final pressure. 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 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 r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ 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- 314-594 Contact Janelle Nesvold @ 263-4641 Email Janelle.R.Nesvold@conocophillips.com Printed Name Janelle Nesvold Title Sr. Wells Engineer Signature -n,tc.P Phone:263-4641 Date v J/15 k-r-i, 1/731 1 S Form 10-404 Revised 10/2012 Submit OriginAl Only RBDMS J JAN 2 6 2015 KUP PROD 2K-15 ConocoPhillips o Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(') MD(ftKB) Act Btm(ftKB) [ .r.;fldwr^ 501032011300 KUPARUK RIVER UNIT PROD 46.42 6,500.00 8,304.0 ,,. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2K-15,1/22/20152:0606 PM SSSV:TRDP 73 12/30/2012 Last WO: 11/28/2014 40.191 10/16/1989 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,904.0 10/27/2014 Rev Reason:WORKOVER smsmith 1/16/2015 HANGER;31.1- 1.=.41 LJ_ Casing Sings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread r. CONDUCTOR 16 15.062 360 115.0 115.0 62.50 H-40 WELDED .*:r./:..', Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ...•1 SURFACE 9 5/8 8.921 35.0 3,319.7 2,946.5 36.00 J-55 BTC 41i Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread `/` ` PRODUCTION 7" 7 6.276 33.0 2,107.4 2,053.2 26.00 L-80 TC II ; .Tieback Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I.,.Grade Top Thread 'Original 1989 7"" 7 6.276 2,107.4 8,285.6 6,480.7 26.00 J-55 BTC PRODUCTION • Tubing Strings -M/CONDUCTOR;36.4175.0 _ :, �'Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TAD)(...Wt(Ibltt) Grade Top Connection TUBING-WO 31/2x 31/21 2992 31.1 7,916.0 6,203.2 9.30 L-80 IEUE 8Rd 5 12 @7785.13 NIPPLE:519.0 Completion Details ■ is' Nominal ID Top(ftKB) Top)TVD)(ftKB) Top Incl(') Item Des Corn (in) 31.1 31.1 0.05 HANGER FMC GEN V HANGER 2.992 � 519.0 519.0 0.38 NIPPLE CAMCO"DS"NIPPLE 2.875 )c 3,719.6 3,227.1 45.48 BARRIER VLV HES LUBRICATOR ORBIT VALVE(BARRIER VLV) 2.894 PRODUCTION T.Tieback;33.0- 2.707.4 7,567.9 5,942.4 41.52 LOCATOR BAKER LOCATOR 2.900 il 1 7,568.9 5,943.1 41.52 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY(SPACED OUT 7.13') 3.000 GAS LIFT;2,6W 6 7,575.4 5,948.0 41.51 PBR BAKER 80-40 20'PBR 2.980 7,598.5 5.965.2 41.51 PACKER BAKER 4782 FHL PACKER 2.900 7,742.8 6,073.4 41.42 NIPPLE HES"X"NIPPLE 2.813 7,785.1 6,105.2 41.40 XO Enlarging 3 12"to 5 12"PORTED CROSSOVER 2.992 Perforations&Slots SURFACE;35.03.319.7 Shot Den • Top(TVD) Btrn(TVD) (shotsll Top(ftKB) Beer(ftKB) (ftKB) (ftKB) Zone Date 1) Type Com _ 7,824.0 7,832.0 6,134.3 6,140.3 C-4,2K-15 5/25/1997 6.0 IPERF 2.5"HSD,60 deg. BARRIER VLV;3,719.6 '> I Phasing 7,934.0 7,974.0 6,216.7 6,246.7 A-4,2K-15 4/19/1990 4.0 IPERF 4.5"HSC,180 deg. Phasing Mandrel Inserts St MI GAS LIFT;4,261.1 - on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Com 1 2,660.6 2,487.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/24/2014 2 4,261.1 3,609.0 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 12/24/2014 GAS LIFT.5,469.2 3 5,469.2 4,459.6 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 12/24/2014 4 6,384.6 5,105.1 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 12/24/2014 GAS LIFT,6,394 6 5 7,084.2 5,593.2 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12242014 6 7,511.8 5,900.4 CAMCO MMG 1 1/2 GAS LIFT SOV RKP 0.000 i 0.0 12/242014 OCR- I 1 al Notes:General&Safety GAS LIFT;7,084.2 End Date Annotation 9/3/2000 NOTE:E-LINE IDENTIFIED LEAKS @ 2425',6765',7235'MD al 11/3/2010 NOTE:View Schematic w/Alaska Schematic9.0 1/20/2015 NOTE:BARRIER VLV control lines/system @Wellhead marked Open/Close GAS LIFT;7,511.e v.. 1/20/2015 NOTE:BARRIER VLV is NOT a safety valve,it does not fail to dosed position I El LOCATOR;7,567.9 SEAL ASSY;7,568.9 . KIR PBR;7,575.4 PACKER;7,598.5 NIPPLE;7,742.8 U 1111t !PERF;7,824.0.7,832.0- • IPERF.7.934.0-7.974.0 I 1 'Original 1969 T' PRODUCTION;2,107.4-8,2856 --15 PRE-RIG WELL WORK SUMMARY DATE SUMMARY 10/27/2014 (PRE-RWO): T POT-PASSED. T PPPOT-PASSED. IC POT-FAILED. IC PPPOT-FAILED. LDS-ALL FUNCTIIONED PROPERLY. 10/27/2014 DRIFTED TO TOP OF PATCH WITH 2.78" SWAGE; DRIFTED THRU PATCH WITH 5'x 1.5" BAILER &TAGGED @ 7904' SLM. IN PROGRESS. 10/28/2014 MEASURED BHP @ 7899' RKB: 3431 PSI. PULLED UPPER 12" OF FLOWCUT ECLIPSE PKR @ 6766' RKB. RAN 2.75" LIB TO SAME. IN PROGRESS. 10/29/2014 SET CATCHER ON PATCH @ 6766' RKB. PULLED OV @ 6026', GLVs @ 4674', 2440' RKB. SET DVs @ SAME. PULLED CATCHER. ATTEMPTED DRIFT 11'x 1.70"THRU PATCH, STICKY. DRIFTED THRU PATCH TO 7748' RKB WITH 10'x 1.5". IN PROGRESS. 10/30/2014 BRUSHED SSSV @ 1812' RKB. CYCLED CONTROL LINE, UNABLE TO CATCH FLAPPER: FLOW TUBE SEIZED. BRUSHED PATCH @ 6766' RKB. GAUGED PATCH WITH 1.69"AND 1.73" SWAGES. ATTEMPTED DRIFT 11'x 1.70"THRU PATCH, STICKS IN BOTTOM PKR. READY FOR E-LINE. 11/1/2014 CORRELATED LOG TO WELL JEWELRY TO PACKER AT 7693'AND PBR AT 7679'. FIRED TUBING PUNCH GUN FROM 7660'-7665'. FIRED 5' GUN WITH 4 SPF AND 0 DEG PHASING. IA AND TUBING WERE ALREADY EQUAL, NO CHANGE WAS OBSERVED. ConocoPhiIIips Time Log & Summary Wel/view Web Reporting Report Well Name: 2K-15 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 11/29/2014 3 00 00 PM Rig Release: 12/25/2014 3:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11/28/2014 24 hr Summary Moved Pits complex, shop, camp and equipment to 2K pad form 1C pad. Spot all on pad. Berm up. Moved Sub from 1C pad to CPF-2. 06:00 12:00 6.00 0 0 MIRU MOVE MOB P Rig Down from well 1C-109. Pull Pits of Rig. Break down Berming. Prepare Shop, Camp and Pits to move to 2K pad. 12:00 18:00 6.00 0 0 MIRU MOVE MOB P Move Pits Complex, Shop and Camp to 2K pad Move Rig sub from 1C pad to KOC.. 18:00 00:00 6.00 0 0 MIRU MOVE MOB P Move Rig sub from KOC to CPF-2. Spot up Camp and Shop on 2K pad. Berm up Camp.. 11/29/2014 Move Sub to 2K. Spot up on 2K-15. Spot pits. Berm Up. Raise Derrick.Accept Rig. Rig Up kill tank and hardline Pull BPV RIG ACCEPTED @ 15:00 00:00 06:00 6.00 0 0 MIRU MOVE MOB P Move Rig sub from CPF-2 to 2K access road. Prepare cellar and Herculite for Sub. Put well head equipment in cellar area prior to rig arrival 06:00 09:00 3.00 0 0 MIRU MOVE RURD P Secure Rig floor and tools. SPool tuggers, Tighten Kelly hose, Raise Cattle chute. Bridle Down. Hook up Top Drive lines and ready for service SIMOPS: Take on 11.0 ppg to pits 09:00 14:00 5.00 0 0 MIRU MOVE MOB P Move Rig to 2K pad. Hang tree in cellar. Spot up Rig sub on 2K-15. Lay Rig mats and herculite. Spot pits up to sub, Lay herculite for pits and cuttings tank. Spot cuttings tank. . 14:00 16:00 2.00 0 0 MIRU MOVE RURD P Continue taking on 11.0 ppg mud to pits. Rig up Hard Line, Choke House and begin berming tank area.. 16:00 18:30 2.50 0 0 MIRU MOVE RURD P Berm Up entire rig, mud elevator and cuttings tank. Hook up interconnects.. 18 30 19:30 1.00 0 0 MIRU MOVE SFTY P Inspect derrick. PJSM for raising derrick.. 19:30 20:00 0.50 0 0 MIRU MOVE RURD P Raise Derrick and pin in place. RIG ACCEPTED @ 15 00 20 00 22:30 2.50 0 0 MIRU WELCTL RURD P Rig Up Tiger Tank, open top tank and manifold in bermed area. Complete berming of tanks and manifold.Test hard line for leaks.. Page 1 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00 00 1.50 0 0 MIRU WELCTL MPSP P Bleed off tree and evacuate fluid from same. Rig Up lubricator and PT to 1500 psi. Pull BPV. Rig Down Lubricator. Pressure Tbg= 1000 psi, IA=860 psi, OA=300 psi... 11/30/2014 Kill Well. Monitor Well. Reverse Circulate tubing volume. Monitor well Shut in well.Weight up mud system to 11.5 ppg. Kill well with 11 5 ppg mud. Losses for the day: 0000 01:00 1.00 0 0 MIRU WELCTL RURD P Rig up lines for well kill operations PT lines 01.00 06:00 5.00 0 0 MIRU WELCTL OWFF T Shut in Well. Observe shut-in Tbg press at 58 psi. Discussed any recent 2K-Pad injection well changes with the CPF-2 Prod Engineer. Nothing appears to have been changed that would cause increase in BHP. Discussed the need to increase KWM with Anchorage Engineer. Continue to monitor shut in Tbg pressure until stabilized.Tbg press stabilized @ 42 psi. SIMOPS: Weight Up Mud system in the pits to 11.5 ppg.. 06 00 06:15 0.25 0 0 MIRU WELCTL SFTY P PJSM for Well Kill. . 06:15 09.30 3.25 0 0 MIRU WELCTL KLWL P Kill well. Lead with 25 bbl water spacer. Pump 11.0 ppg mud down tubing taking return out IA to choke shack and tiger tank following Kill sheet step down back pressure schedule. Once good returns at surface shut in IA and bullhead 20 bbl of mud down tubing. 299 bbls returned to tiger tank during Kill operations after pumping total of 329 bbl(21 bbl spacer and 308 bbl 11.0 ppg mud). Kill circulating pressures at 3 bpm, ICP= 1180 psi, FCP= 250 psi. Bullhead circulating pressure at 1 bpm @ 830 psi 09:30 13:30 4 00 0 0 MIRU WELCTL KLWL T Circulate down tubing out IA with 11 5 ppg mud through gas buster @ 2 bpm Treat pits to maintain 11.5 ppg during circulation. Mud weight out prior to BU 10.8 ppg. Once hole volume complete with 11 5 ppg out continue to circulate.Weights come back @ 11.2 and 11.3 after an addition 50-100 bbls circulated. Continue circulating maintaining pits at 11 5 ppg.2 bpm @ 440 psi Page 2 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13.30 18:00 4.50 0 0 MIRU WELCTL OWFF P Monitor well. Shut in and allow formation to bleed down pressure from bull heading. Pressure bled from 830 psi to 120 psi over 35 min. Bleed down pressure and observe well for flow. Recovered 12 bbls back from the bull heading. Tubing continues to flow(5 gal in 40 seconds avg). Casing on a very slight vacuum.. 18:00 19:30 1.50 0 0 MIRU WELCTL CIRC P Reverse circulate 1.5 x the tubing volume routing returns through the Gas Buster back to the Pits(100 bbls)at 1.0 bpm/286 psi Increase rate to 1.9 bpm/715 psi. Mud weight in 11 1 lb/gal. Present mud weight returned 10 4 lb/gal...ah ha...! Bottoms up. 11 1 lb/gal in...8.5 lb/gal gas cut out. Continue reversing at 1.9 bbls/792 psi. Mud weight returns now 10.9 lb/gal. 100 bbls pumped (1.5 x tbg vol)at 1 9 bpm/845 psi. Mud weight in 11.1 lb/gal Mud weight out 11.0 lb/gal. Continue to condition hole. End pumping with 2 tubing volumes reversed. Final rate was 1.9 bpm/812 psi Mud weight in 11.1 lb/gal. Mud weight out 11.1 lb/gal. Blow down lines.. 19.30 20:00 0.50 0 0 MIRU WELCTL OWFF P Monitor Well. Tubing dead However, steady stream from the 3 1/2"x 7"Annulus at 1.6 bbls in 20 minutes.. 20.00 21:00 1.00 0 0 MIRU WELCTL CIRC P Resume reverse circulating at 2 0 bpm/803 psi. Complete reversing the remainder of the hole volume 11.1 lb/gal in. 11 1 lb/gal out.. 21:00 21:30 0 50 0 0 MIRU WELCTL OWFF P Monitor Well Tubing dead. Still have a steady 1/2"stream from the IA. Shut in well 21:30 23:30 2 00 0 0 MIRU WELCTL CIRC P Circulate the Well the long way...down the tubing .returns up the IA through the Gas Buster to the Pits at 2.7 bpm/375 psi. Circulated 300 bbls. Final: 4 0 bpm/644 psi. 11.1 lb/gal in. 11 1 lb/gal out. Total fluid loss 22 bbls(?).. 23:30 00:00 0.50 0 0 MIRU WELCTL SFTY T PJSM Circulate to kill well. check lines and line up.. 12/01/2014 Continue Circulation. Monitor well Set BPV Nipple Down tree. Nipple Up BOPE. Test BOPE. (Test with 3.5" and 7"test joints, 2 7/8"x 5"VBR on top and 7"solids body rams on bottom; 1 F/P on annular, all other tests pass; Koomey 5 bottle avg 1925 psi, 200 psi recovered 16 sec,full pressure 92 sec) Page 3 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 0 0 MIRU WELCTL KLWL T Continue Circulating 11.5 ppg mud into well. Once returns consistently 11.5 ppg stage up pumps to 3 bpm. Consistent 11.5 ppg mud returning from hole. 3 bpm @ 590 psi. Losses during entire circulation 28 bbls. OA Pressure at beginning of Circulation 340 psi. OA pressure at end of circulation 340 psi 01:00 07:00 6.00 0 0 MIRU WELCTL OWFF T Monitor well. Steady stream to slow drip to dead. 07:00 07:30 0.50 0 0 MIRU WHDBO MPSP P Set BPV. 07:30 11:00 3.50 0 0 MIRU WHDBO NUND P Nipple down the Production Tree. Install Blanking Plug. (Check IA. on slight Vacuum). 11:00 16:00 5.00 0 0 MIRU WHDBO NUND P Nipple up BOP Stack. Remove VBR Pipe Rams and install 7"Pipe Rams in the lower gate. Set blanking plug 16:00 1700 1 00 0 0 MIRU WHDBO RURD P Rig Up test equipment Ready test joints and floor valves. 17:00 00:00 7.00 0 0 MIRU WHDBO BOPE P Perform the initial BOPE test per ConocoPhillips/AOGCC requirements at 250/3,000 psi.The witness of test was waived by AOGCC Field Rep,Johnnie Hill. Test with 3 1/2"and 7"test joints. Test H2S and Gas Alarms. 16 choke valves, manual and HCR Kill and Choke valves,2" DEMCO @ manifold, Upper and Lower IBOP, TIW, 8rd floor valve, Dart,test spool valves,Top Pipe Rams(2 7/8"x 5" VBR), Lower Pipe Rams(7"solid body), Blinds,Annular(F/P). Accumulator test. Koomey test: Initial system Pressure 2950 psi,5 bottle average 1925 psi 200 psi build in 16 sec,full pressure 92 sec. Note: the next BOPE test will be performed 12/8/2014 or after the 7"tieback and diverter status of the Stack. 12/02/2014 Pull BPV Attempt to pull 3.5"completion, seals did not pull free. Rig Up SLB Digital Slickline Shoot Stringshot at 6754.8'in first full joint above GLM#3 Chemical cut at 6754.8'. Rig down SLB Digital Slickline. Pull completion, not free.Work pipe to attempt to free 00 00 01 30 1 50 0 0 MIRU WHDBO RURD P Rig Down Test equipment. Rig Down and blow down lines. Ready equipment to pull BPV. 01:30 01:45 0.25 0 MIRU WHDBO SFTY P PJSM for puling BPV. Mobilize SLB spooling unit and GBR to rig. 01:45 02 15 0 50 0 0 MIRU WHDBO MPSP P Pull BPV.Well dead 02:15 03 30 1 25 0 0 COMPZ RPCOM PULL P BOLDS. Pull Hanger free and attempt to pull completion free Pull to max pull 144k(104k plus blocks) and work to free seals Set String in tension in slips and mobilize SLB Digital Slickline Page 4 of 29 7 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 04:30 1.00 0 0 COMPZ RPCOM RURD P Lay Down top pups of landing joint. Bring SLB spooler onto rig and GBR power tongs onto rig. 04:30 13 00 8.50 0 0 COMPZ RPCOM+ELNE P Spot in and Rig Up SLB Digital Slickline. Make Up Lubricator. Pick up 8 ft long string shot Test lubricator to 1000 psi. Good test. RIH with String Shot, correlate and shoot centered on 6754.8'. POOH. 13 00 15:30 2.50 0 0 COMPZ RPCOM ELNE T 300'of damaged line observed at the 2500'mark in line. Cut and line _reheaded. 15:30 19:00 3 50 0 0 COMPZ RPCOM ELNE P MU 2 3/8"chemical cutter. RIH, correlate and fire cutter at 6754.8'. No indication at surface of cut. Observed minimal tension difference and no difference in CCL.WLOH Rig Down Lubricator. Rig up and pull on tubing, observing tubing is not free pulling up to 150K. Lay Down cutter assembly. Cutter has good indication of firing. Rig SLB Digital Slickline equipment off to side of derrick and out of way. SLB crew timed out. 19:00 00:00 5.00 0 COMPZ RPCOM OTHR T Due to no cut and crew timing out decision to work the tubing string repeatedly from string weight to 165K. Continue with repeated attempts to free the tbg. No Sucess 12/03/2014 Continue to work pipe to free. Rig Up SLB Digital Slickline. Shoot Stringshot at 6724'in first full joint above GLM#3.Attempt to RIH with Chem Cutter, trigger failure and crew timed out. Rig down SLB Digital Slickline Circulate hole to consistent 11.5 ppg. 00:00 05:00 5.00 0 0 COMPZ RPCOM OTHR T Continue to work string repeatedly from string weight to max pull to 165K. Continue with repeated attempts to free the tbg No Success. 05:00 1700 12 00 0 0 COMPZ RPCOM ELNE T Slickline crew on location at 0500 HRS. Rig Up SLB Digital Slickline. Pick up 8 ft long string shot.Test lubricator to 1000 psi. Good test. RIH with String Shot, correlate and attempt to shoot centered on 6724.0'. Tool failure POOH. Lay down string shot assembly and change out drum line on unit. Restring line. Pick up 8 ft long string shot. Test lubricator to 1000 psi Good test. RIH with String Shot, pump down tubing to assist at 2 bpm @ 300 psi, correlate and shoot centered on 6724.0' Indication of 6' shift of collars. POOH. Lay Down assembly and set Lubricator off to side to pull on completion. Page 5 of 29 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 17:00 17:30 0.50 0 0 COMPZ RPCOM OTHR T Make Up Crossover. Make up to Top Drive.Attempt to pull free to 150k twice. No free movement Set in slips with 125k. 17:30 22:00 4 50 0 0 COMPZ RPCOM ELNE T Rig Up lubricator. Pick up 2 3/8" Chem Cutter.Triggers will not test. Troubleshoot. Lay down cutter. Troubleshoot No trigger firing. Discover line without coating above head, likely was shorting out trigger signal Due to not SLB crew timing out again,decision made to rig down and mobilize HES E-Line for cut. Rig down SLB Digital Slickline and move trucks on pad so HES will be able to spot up. 22 00 22:30 0 50 0 0 COMPZ RPCOM RURD T Rig Up Circulating Equipment SIMOPS while getting circulating equipment ready slack off pull on string until hanger about 1'above tubing head. Measure pipe stretch to calculate free point. Then pull 130k and set in slips. Complete rigging up Circulating equipment. 22:30 00:00 1 50 0 0 COMPZ RPCOM CIRC T Circulate hole volume at 2 bpm @ 370 psi. Consistent 11.5 ppg in and out during circulation. No gas or light mud observed. 12/04/2014 Continue circulating hole to consistent 11 5 ppg Rig Up HES E-Line. Cut at 6725'. POOH and RD HES E-Line Circulate hole. Pull and Lay Down old 3.5"completion. 00:00 02 00 2.00 0 0 COMPZ RPCOM CIRC T Continue circulating at 2 bpm @ 370 psi. Consistent 11.5 ppg in and out during circulation. Circulate total of 364 bbls. 02:00 10:30 8.50 0 6,725 COMPZ RPCOM ELNE T Spot unit and rig up HES E-Line. Rig Up lubricator, Pick up 2" RCT cutter. Pressure Test Lubricator to 1000 psi. RIH and cut at 6725'WLM. Positive indications at surface and in unit of successful cut POOH, Lay Down cutter assembly, Set Lubricator off to side. 10:30 11:00 0.50 6,725 6,725 COMPZ RPCOM PULL P Pull on completion Up Wt=80k; Dn Wt=60k 11.00 11:30 0.50 6,725 6,725 COMPZ RPCOM RURD P Rig up to Circulate 11 30 14:00 2.50 6,725 6,725 COMPZ RPCOM CIRC P Reverse Circulate 2 tubing volumes.at 2 bpm @ 500 psi Hole out of balance. Circulate hole volume down tubing at 4 bpm @ 450 psi. SIMOPS: Rig Down HES E-Line. 14 00 14:30 0.50 6,725 6,725 COMPZ RPCOM OWFF P Monitor well. Slow flow to static. 14 30 15:00 0.50 6,725 6,725 COMPZ RPCOM RURD P Rig Down Circulating Equipment. 15 00 18:30 3.50 6,725 5,083 COMPZ RPCOM PULL P Pull 3.5"completion. Up Wt=67k, Dn Wt=50k. Page 6 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 18 45 0.25 5,083 5,083 COMPZrRPCOM SFTY P Well Control Drill and AAR with crew. Well secure in 42 sec, all crew in place 71 sec 18:45 19:45 1.00 5,083 4,950 COMPZ RPCOM PULL P Continue to pull 3.5"completion to SSSV Control line was broken—2 feet above SSSV Looking down control line was observed in riser. 25'of control line removed from stack and completion. Recovered 23 SS bands. 19:45 20:00 0.25 4,950 4,950 COMPZ RPCOM RURD P Rig Down SLB Spooling Unit. 20:00 23:00 3.00 4,950 0 COMPZ RPCOM PULL P Continue to pull 3 5"completion. Lay down total of 209 joints, 1 SSSV, 3 GLMs, 1 cut joint(9.67'). 23:00 00:00 1.00 0 0 COMPZ RPCOM RURD P Rig Down power tongs. Clean and Clear Rig Floor. 12/05/2014 Set Wear Ring. PU BHA#1 (7"casing scraper)and SIH. Criculate well.TOOH and LD BHA#1. Rig Up HES E-Line. Rig on High-Line @ 13:00 0000 01:45 1.75 0 0 COMPZ RPCOM RURD P While running wear ring pieces of control line observed at bottom of stack. Remove 3 pieces of control line and ensure stack clear. Set Wear Ring. 01:45 02:00 0 25 0 0 COMPZ WELLPF SFTY P PJSM picking up BHA#1 02:00 03:30 1 50 0 41 COMPZ WELLPF PULD P Pick Up BHA#1 (7"Casing Scraper). Total length-40.88' 03:30 11 00 7 50 41 5,088 COMPZ WELLPF PULD P Single in hole with Drill Pipe from Pipe Shed. Stand back first ten stands in derrick. 11:00 11:30 0.50 5,088 5,088 COMPZ WELLPF SFTY P Well Control Drill with all hands. MR following. Shut in 41 sec, Crew Response Time=91 sec 11:30 14:30 3 00 5,088 6,708 COMPZ WELLPF PULD P Continue to single in the hole from pipe shed. Lightly tag the tubing cut joint at 6708' DPMD. Parameters: Up Wt= 135k, Dn Wt=85k, Rot Wt= 102k, 15 RPM, TQ=6k. RIG on High-Line Power at 13:00 14:30 15:00 0.50 6,708 6,708 COMPZ WELLPF CIRC P Circulate hole volume at 4-7 bpm. 960-1520 psi. 15:00 15:30 0.50 6,708 6,708 COMPZ WELLPF OWFF P Monitor well. Static. 15:30 19:30 4.00 6,708 140 COMPZ WELLPF TRIP P Trip 2 stands. Check for swabbing. Pump Dry Job. Install stripping Rubbers and air slips. Continue trip out of hole. 19:30 20 00 0.50 140 140 COMPZ WELLPF OWFF P Monitor Well Static. SIMOPS Spot E-Line unit and ready for Rig Up. 2000 21 00 1.00 140 0 COMPZ WELLPF PULD P Stand back last stand and lay down BHA#1 per Baker Hughes Rep. 21 00 00:00 3.00 0 0 COMPZ WELLPF ELOG P Rig Up E-Line, Rig Up Dutch Riser. Test Lubricator to 250 psi. Good. Page 7 of 29 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 12/06/2014 24 hr summary E-Line Gyro Log RCBL and Caliper log. Set WRBP @ 5900' Pressure test Plug String Shot across collar @ 2085'. Rig Down HES E-Line. PU and TIH with RBP. 00 00 1530 15.50 0 0 COMPZ WELLPF ELOG P Make up Gyro assembly and perform cased hole logging. Gyro Log, RCBL and Caliper Log from tubing stump at 6708' to surface No Fluid losses /gains 15:30 23:00 7.50 0 0 COMPZ WELLPF ELNE P Make Up RBP. RIH and set @ 5900' (center of element)wlmd. POOH and Change out sheave. Pressure test plug to 1000 psi for 10 minutes (charted). RIH with String shot and shoot in collar at 2086'wlmd. POOH and Rig Down HES E-Line. No Fluid losses/gains. 23:00 23 30 0.50 0 22 COMPZ WELLPF PULD P Pick Up RBP as per Baker Rep. (22.5') 23 30 00.00 0.50 22 117 COMPZ WELLPF TRIP P Trip in hole with stands from derrick. 12/07/2014 TIH and set RBP on DP at—2500'. Pressure test plug to 1000 PSI Displace well to 8.5 ppg seawater TOOH and LD RBP running tool. PU Muleshoe and TIH. Dump sand on plug TOOH and LD mule shoe Nipple Down BOP Grow 7"casing 7 5",stretch same 10". Nipple Up BOP stack. 0000 02 00 2.00 117 2,640 COMPZ WELLPF TRIP P Continue to trip in hole from derrick 02 00 02:15 0.25 2,640 2,640 COMPZ WELLPF MPSP P Set RBP at 2640'dpmd per Baker Rep. 02:15 02:45 0.50 2,630 2,630 COMPZ WELLPF RURD P Rig up circulation equipment to test plug and to circulate well over to 8.6 ppg seawater. 02:45 03 00 0 25 2,630 2,630 COMPZ WELLPF PRTS P Test plug to 1000 psi for 10 min (charted). 03 00 05.00 2.00 2,630 2,630 COMPZ WELLPF DISP P Circulate 1+ hole volume followed by 50 bbl spacer pill followed by 8.6 ppg seawater. returns taken to pits and cuttings bin SIMOPS: Pits 1 and 2 loaded onto truck. Clean Trip Tank and prep for seawater. 05:00 05:30 0 50 2,630 2,483 COMPZ WELLPF TRIP P Pull 2 stands. 05:30 06:00 0.50 2,483 2,483 COMPZ WELLPF RURD P Rig down circulating equipment. Fill Trip Tank with seawater. 06:00 07:00 1.00 2,483 2,483 COMPZ WELLPF SVRG P Service top drive and daily inspection. 07:00 08:00 1 00 2,483 15 COMPZ WELLPF TRIP P Trip out of hole with RBP running tool 08:00 0830 0.50 15 7 COMPZ WELLPF PULD P Lay down Baker RBP running tool. Pick up Muleshoe. 08.30 10 30 2.00 7 2,467 COMPZ WELLPF TRIP P Trip in hole to 180'above RBP 10 30 13.30 3.00 2,467 2,467 COMPZ WELLPF CIRC P Dump 50 sacks of 20-40 sand on plug 13 30 14:30 1.00 2,467 0 COMPZ WELLPF TRIP P Tag top of sand @ 2511'dpmd Trip out of hole. 14:30 15:00 0.50 0 0 COMPZ WELLPF RURD P Clean rig floor Remove wear ring with running tool 15:00 16:30 1.50 0 0 COMPZ WELLPF NUND P Nipple Down BOP stack. Page 8 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16 30 20:30 4.00 0 0 COMPZ WELLPF CUTP P Rig Up Hydratight and grow 7" casing. Casing grew 7.5" Nipple Down Tubing Head. Remove casing packoff. Spear 7"stub and pull into tension with 30k at cut location, 110k indicated Additional pull had 10"of stretch Land 7"back in slips. 20:30 00:00 3.50 0 0 COMPZ WELLPF NUND P Nipple Up Working Spool, DSA, BOP stack. 12/08/2014 Nipple Up BOP stack PU BHA#3(7"cutter)and TIH. Cut 7"casing at 2076'dpmd TOOH and LD BHA#3 PU BHA#4(7"spear w/packoff) Spear 7". Circulate out Arctic pack with heated diesel and heated seawater. Lay Down BHA#4 and 7"Casing. 00:00 02:30 2.50 0 0 COMPZ WELLPF NUND P Continue Nipple Up BOP Stack. Install secondary Annulus Valve Install riser and get new RKB measurements for BOP stack components. 02 30 03:30 1.00 0 0 COMPZ WELLPF PRTS P Attempt to pressure test break Without packoff no pressure build. 03:30 04:00 0.50 0 8 COMPZ WELLPF PULD P Pick Up BHA#3(7"Cutter). 04:00 06:00 2.00 8 2,066 COMPZ WELLPF TRIP P TIH with BHA#3. 06.00 07:00 1.00 2,066 2,076 COMPZ WELLPF CPBO P Obtain parameters. Locate 3 casing collars with cutter knives to confirm location of pipe for cut Cut Pipe at 2076'dpmd. Up Wt=57k, Dn Wt= 55k. Cut casing at 80 rpm,TQ= 1.5-2.0k, ICP 4.7 bpm @ 800 psi, FCP 4.7 bpm @ 250 psi. Pick up to confirm cut,good cut indicaiton 07:00 08:30 1.50 2,076 8 COMPZ WELLPF TRIP P Trip out of hole with BHA#3. 08:30 09:15 0.75 8 14 COMPZ WELLPF PULD P Lay Down BHA#3. Pick Up BHA#4 (7 in spear with packoff) 09:15 09:30 0.25 14 2,076 COMPZ WELLPF FISH P Engage 7"casing stub with spear. Pick up a foot to confirm cut is free. 09:30 11:30 2.00 2,076 2,076 COMPZ WELLPF NUND P Drain stack. Nipple down BOP, break bolts at adapter and lift stack. Remove emergency slips, pulled 97k to get slips out. Nipple Up BOP, set stack back down and tighten bolts. 11:30 12.00 0.50 2,076 2,076 COMPZ WELLPF RURD P Rig Up Circulation Equipment for Little Red and hot seawater. Pressure test lines to 2500 psi. 12.00 16:30 4 50 2,076 2,076 COMPZ WELLPF DISP P Displace well with 160 bbls of 150 degree diesel, 2 bpm @ 600 psi. Let diesel soak for 45 minutes. Circulate 200 bbls of 170 degree seawater,2 bpm @ 500 psi.until cleaned up 16:30 17:15 0 75 2,076 2,076 COMPZ WELLPF RURD P Rig Down Circulating equipment and Blow down lines,while monitor the well. Static. 17:15 18:00 0.75 2,076 2,030 COMPZ WELLPF PULL P Pull Spear and top cut joint(37.90') to floor and break out joint with spear (BHA#4)and Lay Down. Up Wt= 80k Pulled tight once to 150k Worked up and down to ensure free Page 9 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 21 30 3.50 2,030 2,030 COMPZ WELLPF CIRC T When breaking out first full joint well observed to be out of balance Circulate well to ensure balanced.At bottoms Up gas alarms in pits sound and gas breaking out at table. Stop pumps and close annular to prevent further migration of gas to pits/rig. (Gas breaking out of Arctic pack and diesel as comes to surface.) No pressure build observed on gauges Notify CPAI Engineer,Workover Superintendent and AOGCC of Annular usage Take returns out to open top tank and continue circulation. Once 1.5 hole circulations complete, stop Line up to take returns to pits. Circulate 1 hole volume, no gas or breakout during circulation. Fluid weight in/ out 8.6 PPG 21.30 22:00 0.50 2,030 2,030 COMPZ WELLPF OWFF T Monitor well. STATIC 22.00 00 00 2.00 2,030 1,015 COMPZ WELLPF PULL P Pull and Lay down 7"casing Up Wt =80 k. Observed overpull every 40' with overpull to 150K initially and lessening with each joint to joint 33 pulling out of hole.Average overpull 50K 12/09/2014 Lay Down 7"Casing Rig Down Casing equipment. Rig up to test BOPS Test BOPE. M/U BHA#5&RIH. Mill thru tight spots from 739 to 808' . Con't to RIH to 2076'. Circ hole clean. POOH. 00:00 02.00 2.00 1,015 0 COMPZ WELLPF PULL P Continue Pull and Lay Down 7" casing and partial cut joint(19.10'). Last cut joint might have centering guide centralizer on lower half of joint still in hole. 16 centering guides centralizers recovered Joints 18-32 had bowing/bending(but not corkscrewed), Pictures taken, posted on the S drive 51 full joints laid down, 2 cut joints 37.90' Upper Cut joint, 19.10' Lower Cut joint 02:00 03:15 1.25 0 0 COMPZ WELLPF RURD P Rig Down Power Tongs. Clean and clear rig floor. Pictures of bottom cut joint taken. 03:15 05:30 2.25 0 0 COMPZ WHDBO RURD P Install test equipment and Rig Up for BOP test. Set test plug. Fill stack. Prepare Test joints Notify AOGCC Inspector 0530 08:30 3.00 0 0 COMPZ WHDBO BOPE T Shell test prior to BOP test Lower Ram Cavity leaking. Tighten up same. Still leaking Open Ram Door. Change out door seal Retest&held pressure.. Page 10 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 14:00 5.50 0 0 COMPZ WHDBO BOPE P Perform initial BOPE test.Test witnessed by John Crisp w/AOGCC. Tested LP 250 psi, HP 3000 psi Used 3 1/2"&7"test jts. Tested 16 valves on choke manifold, Man& Hyd Choke valves, 2"Demco @ manifold, 2-TIW valves, Dart, Upper &lowwer IBOP,Top&lower Pipe Rams,Annular, Blind Rams& Koomey, Had 1 Fail/Pass-Lower Door Seal.Tested Gas Alarms. 14 00 14:30 0.50 0 0 COMPZ WHDBO RURD P Pull Test Plug, R/D testing equip.B/D lines&drain stack. 14 30 15:00 0.50 0 0 COMPZ WELLPF RURD P P/U Running tool&install Wear Bushing. UD running tool. 15.00 15:30 0.50 0 0 COMPZ WELLPF SVRG P Service rig. Clear&clean rig floor. 1530 18:00 2.50 0 241 COMPZ WELLPF PULD P P/U BHA#5 as follows: Bull Nose, Flex Jt, 8.5"Mill, Flex Jt, 8 75"Mill, Bumper Sub, Jars,X0, 6-6 25" DCs,X0,XO. TL=240.51'. 18:00 18:30 0.50 241 739 COMPZ WELLPF TRIP P Trip in hole w/BHA#5 from 241 to 739'. 18:30 19:30 1.00 739 808 COMPZ WELLPF MILL P Tag up @ 739'. P/U&break circulation. Mill&clean out casing from 739 to 808' P/U, S/O&Rot Wts-50K. Pump 8 BPM @ 140 psi. WOM-4-7K. 100 RPMs. Free TQ- 1 K Ft-lbs.TQ-3-8K Ft-lbs Rotate thru interval several times 19:30 21:00 1 50 808 2,076 COMPZ WELLPF TRIP P Cont to RIH to 2076'. Tagged up on 7"stump @ 2076'. P/U&S/O Wts- 70K 21:00 22.00 1 00 2,076 2,070 COMPZ WELLPF CIRC P Circulate&clean hole Pump 8 BPM @ 400 psi. Obtain SPRs @ 2070'. #1 2BPM @ 65 psi, 3BPM© 105 psi,#2 2 BPM @ 65 psi, 3BPM @ 100 psi..MW-8.6 ppg. Monitor well Well Static After circulation cleaned ditch magnets&recovered 25#of metal. 22:00 00:00 2.00 2,070 241 COMPZ WELLPF TRIP P POOH w/stands to 808'. Back ream thru tight interval to 739'. No problems. Con't to POOH to 241' Hole taking correct fill. 12/10/2014 UD BHA#5. Hold Rig Evac. Drill.Wash out stack. M/U&RIH w/BHA#6. Mill out casing tight areas. POOH & L/D BHA#6. M/U 7"casing drift Assy. RIH&drift casing Circulate hole clean. POOH&L/D same. 00:00 02:00 2.00 241 0 COMPZ WELLPF PULD P Stand back DCs&break out&L/D BHA#5 02:00 02:30 0 50 0 0 COMPZ WELLPF SFTY P Hold Rig Evacuation Drill w/all hands.All personnel evacuated& mustered in safe area in 210 sec. Held AAR&discuss drill&individual responsibilities. Page 11 of 29 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 04:00 1 50 0 0 COMPZ WELLPF WWWH P P/U running tool&pull Wear Bushing. M/U Swizzle stick&Jet out BOP stack. UD same. Re-run Wear Bushing & UD running tool. Recovered 11#of metal from Wear Bushing&jetting operation. 04 00 05 00 1.00 0 231 COMPZ WELLPF PULD P M/U BHA#6 as follows: Bull Nose, Flex Jt, 8.5"Mill, 8.75"mill, Bumper Sub, Jars,XO, 6-6 1/4"DCs,XO, XO. TL=231.48'. 05:00 06:00 1 00 231 700 COMPZ WELLPF TRIP P RIH w/BHA#6 06 00 06 30 0.50 700 700 COMPZ WELLPF SFTY P Held Well Control Drill w/all hands. Well Shut in 43 sec Complete response in 82 sec Held AAR& discussed drill. 06:30 11:00 4 50 700 760 COMPZ WELLPF MILL P Tag up @ 728' DPM w/5K wt. Establish parameters&mill thru tight spots from 728 to 760' P/U Wt- 50K, S/O wt-52K, Rot Wt-52K 60 -80 RPMs. Free TQ-1/5 K ft-lbs Rot TQ-2-5.2K ft-lbs.WOM 1-5K 11:00 12:00 1.00 760 2,056 COMPZ WELLPF TRIP P Con't to RIH to 2056' P/U Wt-66K, S/0 Wt-68K 12:00 12:30 0.50 2,056 2,054 COMPZ WELLPF CIRC P Circulate hole volume w/Hot 8 6 ppg Brine. Pumped 6 BPM @ 220 psi Recovered Arctic Pac&metal to surface Total weight of metal recovered in buckets-76# 12:30 13:00 0.50 2,054 231 COMPZ WELLPF TRIP P POOH&stand back DP. P/U Wt 66K, 5/0 Wt-68K. Hole took correct fill. 13:00 15.00 2.00 231 0 COMPZ WELLPF PULD P Stand back DCs&UD BHA#6. 15:00 18:00 3.00 0 270 COMPZ WELLPF PULD P M/U BHA#7 as follows Triple Connect, 7"Csg Pup, ES Cementer, 1 Jt of 7"casing, X-over,X-over, 2- Magnets,X-over,X-over, 6-6 1/4" DCs,X-over,X-over. TL=270.46' P/U Wt-40K S/O Wt-45K. 18:00 19:00 1.00 270 2,068 COMPZ WELLPF TRIP P RIH w/Drift Assy from 270 to 2068'. P/U Wt- 67K, S/O Wt-65K. Observed no issues getting through milled spots from 736'-753' 1900 21.00 2.00 2,068 2,068 COMPZ WELLPF CIRC P Circulate hole clean w/hot 8.6 ppg Brine. Pump 5 BPM @ 235 psi. Recovered 5#of metal. Monitor well Blow down lines 21:00 21.30 0.50 2,068 2,068 COMPZ WELLPF SVRG P Service rig&Top Drive. 21:30 22:30 1 00 2,068 270 COMPZ WELLPF TRIP P POOH from 2068 to 270' P/U Wt- 67K. Hole took correct fill. 22:30 22:45 0.25 270 270 COMPZ WELLPF SFTY P Held Man Down Drill. Reaction time 93 sec Reviewed drill procedure w/ all hands 22:45 00.00 1.25 270 150 COMPZ WELLPF PULD P UD 6 1/4"DCs. Page 12 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/11/2014 24 hr Summary Finish L/D drift Assy. P/U BHA#8. RIH&clean out inside of 7"casing stub. Circulate hole clean POOH & L/D BHA#8 RIH&Back off 7"csg stub &recover same. 00:00 02 30 2 50 150 0 COMPZ WELLPF PULD P Con't to L/D 6 1/4"DCs&BHA#7. Recovered 11 lbs of metal from magnets Clear&clean rig floor. 02:30 03 30 1.00 0 0 COMPZ WELLPF WWWH P P/U running tool&pull Wear Bushing. RIH w/Swizzle Stick&jet out BOP stack Re-run Wear Bushing& L/D running tool. 03:30 06:30 3.00 0 334 COMPZ WELLPF PULD P M/U BHA#8 as follows. 6 1/8" Tapered Mill, Double Pin Sub, 2- Boot Baskets, Bit Sub, 2-String Magnets, Bumper Sub, Oil Jars, 9- 4 3/4"DCs,X-Over. TL=334.26'. 06:30 08:00 1.50 334 2,414 COMPZ WELLPF TRIP P RIH w/BHA#8 to top of 7"cut jt @ 2076'.entered top of 7"&con't to RIH to 2414'. P/U Wt-68K, S/O Wt -67K. No problems entering or running inside of csg 08.00 09:00 1.00 2,414 2,414 COMPZ WELLPF CIRC P Circulate hot 8.6 ppg brine Pump 4 BPM @ 250 psi. 09:00 10:00 1.00 2,414 334 COMPZ WELLPF TRIP P POOH w/BHA#8. Hole taking correct fill. P/U Wt-68K, S/O Wt- 67 K. 10 00 11:30 1.50 334 0 COMPZ WELLPF PULD P Stand back DCs. Break out&L/D remainder of BHA#8 11 30 12:30 1.00 0 314 COMPZ WELLPF PULD P M/U BHA#9 as follows:6 125" Tapered Mill, 6-4 3/4"DCs, Drain Sub, Blank Sub, Lower Anchor, Power Sub, Upper Anchor, Pump Out Sub, 3-4 3/4"DCs,X-Over. TL =314 44'. 12:30 14:30 2.00 314 2,298 COMPZ WELLPF TRIP P RIH w/Back Off Assy.fill DP w/ diesel on every stand Locate& space out Back Off Tool&2298'. P/U Wt-68K, S/O Wt-66K. 14 30 15:30 1.00 2,298 2,298 COMPZ WELLPF CPBO P Set Lower Anchor w/1000 psi&S/O w/20K. Set Upper Anchor w/3000 psi&S/O all wt. Pressure up& cycle tool 6 times.observed 3 full rotations. R/D&blow down lines. 15:30 17:00 1.50 2,298 2,298 COMPZ WELLPF CIRC P Drop dart pressure up&open circulating sub w/2200 psi. SI annular&reverse out diesel from DP.Pumped 20 bbls&lost circ @ 3 BPM. S/D&confirm no leak in lines etc. Open annular&pump long way 1 hole volume.to clear diesel. Hole clean. Blow down top drive&kill lines. Monitor well.Well static. 17:00 18:00 1.00 2,298 314 COMPZ WELLPF TRIP P POOH&stand back 3 1/2"DP Hole taking correct fill. P/U Wt-68K, S/O Wt 66K 18 00 19:00 1.00 314 0 COMPZ WELLPF PULD P Stand back DCs, &L/D remainder of BHA#9 Page 13 of 29 M Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 19 00 20 00 1.00 0 24 COMPZ WELLPF PULD P M/U BHA#10 as follows to spear cut off jt. Smooth Taper Mill, ITCO Spear, Spear Extension, Stop Sub, XO, Bumper Sub,X0. TL=23.63' 20 00 21:30 1.50 24 2,086 COMPZ WELLPF TRIP P RIH w/Spear Assy. Engage stub @ 2076'&bottomed out @ 2086'w/5K down wt. Rotate assy to the left for 14 turns. Max TQ 3.5K ft-lbs. P/U jt free 21 30 00:00 2.50 2,086 0 COMPZ WELLPF TRIP P POOH w/fish. No overpull noted P/U Wt-60K Recovered 19.75'Cut off jt. Threads looked good, have a 7" collar looking up No centering guide recovered(no indication on cut jt) Remove cut jt from spear. 12/12/2014 Pull Wear Bushing. R/U&run 7"Tie Back string. Cmt same. N/D BOP. Set Slips&cut csg. N/U&test new tbg head. Reset BOP, change out 7"rams for VBRs.&test BOP breaks. 00:00 01:30 1.50 0 0 COMPZ WELLPF RURD P P/U running tool&pull Wear Bushing. L/D same L/D short bail& install long bails on Top Drive. 01:30 03:00 1.50 0 0 COMPZ WELLPF RURD P R/U floor&power tongs to run casing. 03:00 06:00 3.00 0 800 COMPZ WELLPF PUTB P Hold PJSM w/all hands. Run 7"26#, L-80,TCII Tie Back string as follows: Triple Connect Sub 7"pup jt, ES Cementer,2-7"pups, 51 jts 7"csg. Installed 1 straight bladed centralizer per jt. M/U Torq= 10K ft-lbs. 06:00 08 30 2 50 800 2,096 COMPZ WELLPF PUTB P Con't to Run 7"csg Tie back string. RIH to 2096'. Ran total of 51 jts P/U Wt-73K, S/O Wt-70k. 08:30 10.00 1 50 2,096 2,096 COMPZ WELLPF PRTS P M/U Top Drive. Slowly circulate down on csg stub. Engage Triple Connect into csg stub&torq up to 10k ft-lbs. P/U w/75K over string wt&pull test S/O&pressure up on csg to 2000 psi for 5 min. Increase pressure to 2500 psi&hold for 15 min Test Good. Charted test. Increased pressure to 3180 psi&opened the ES cementer. Pump 5 BBLS to verify good flow. 10.00 11:00 1.00 2,096 2,096 COMPZ WELLPF RURD P R/u cementing lines M/U X-Over& cementing head. Install Wiper plug in head 11:00 12:00 1.00 2,096 2,096 COMPZ WELLPF SFTY P Hold PJSM w/all hands&review complete cementing procedure& assign specific tasks Page 14 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 15:00 3.00 2,096 2,096 COMPZ WELLPF CMNT P Cement 7"Tie Back as follows: Pump 5 bbls of Fresh water. Pressure test lines to 4000 psi, OK Pump 140 bbls of heated fresh water ahead of cement, 5 BPM-450 psi Pump 10 bbls of Neat AS-1 @ 15 7 ppg Swap to silo&pump 91.8 bbls of AS-1 blend Cemnet @ 3 BPM- 400 psi Chase w/10 bbls of Neat AS-1 @ 15.7 ppg. S/D&drop cement plug and close lower 7" rams. Pump 3.0 bbls of neat AS-1 cement Displace w/5 bbls of Fresh Water followed by 73.4 bbls of seawater 3 BPM.After—28 bbls of displacement slowed pump to 1.5 BPM&slowly close the outer annular valve for back pressure& squeezed away—20 bbls of cement holding 900 psi pump pressure Bumped plug. increased pressure to 2850&ES cementer closed. Bled back&checked for flow Had 3/4 bbl flow back&cementer held. CIP @ 14:40 hrs. Had—35 bbls of cement to surface. 15:00 18:00 3.00 2,096 2,096 COMPZ WHDBO NUND P Blow down&R/D cementing lines. Open rams and Flush BOP stack. R/D Cementing head. Drain stack& 7"csg. P/U BOP stack. Observed no cement at the surface,water only. Mixed 4 ea-7 Gallon buckets of dry cement and pour into OA Still no cement at surface. Discuss options with Well Integrity group. Decision to move ahead. P/U&set emergency slips w/100K over weight. 18:00 21:00 3.00 2,096 2,096 COMPZ WHDBO WWSP P Reset stack. Break nuts on DSA& Spool. Remove same&set back stack. Install Pack Off&new Tbg Spool. Test Pack off 250/3000, 10 min each. 21:00 00:00 3.00 2,096 2,096 COMPZ WHDBO NUND P Set BOP stack& DSA on new Tbg spool&tighten up bolts. 12/13/2014 P/U BHA#11, RIH&clean out shoe track. Circ hole clean. POOH. RIH w/BHA#12 Concave mill&break up any debris. 00 00 01 30 1 50 0 0 COMPZ WHDBO NUND P Con't to N/U BOPE. Install Riser& center up stack 01:30 03:00 1.50 0 0 COMPZ WHDBO NUND P Change out lower 7"pipe rams to 2 7/8"x 5"VBRs. Tighten up bolts 03:00 03'30 0 50 0 0 COMPZ WELLPF BOPE P Set Test Plug&P/U Test Jt. 0330 04:30 1.00 0 0 COMPZ WELLPF BOPE P Fill stack. Pressure test BOP breaks,VBRs& Ram Doors LP 250 psi, HP 3000 psi 5 min each Tested good. Charted test. L/D test jt &pull Test Plug.. Page 15 of 29 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 04 30 05:00 0 50 0 0 COMPZ WELLPF RURD P P/U running tool&install Wear Bushing. RILDS. L/D running tool 05:00 0600 1.00 0 308 COMPZ WELLPF PULD P M/U BHA#11 as follows:6 1/8"Bit, 2-Boot Baskets, Bit Sub, Bumper Sub, Jars, Pump Out Sub, 9-4 3/4" DCs, XO TL=308.42'. RIH w/ same. 06 00 07:30 1.50 308 1,950 COMPZ WELLPF TRIP P RIH w/BHA#11 to 1950'.Tagged up on cement. P/U Wt-63K, S/O Wt- 63K. 07 30 12:00 4.50 1,950 2,081 COMPZ WELLPF DRLG P Wash&ream thru cement stringers from 1950 to 2081' Pump 7BPM @ 500 psi 90 RPMs, 1K Free TQ, Drill ES cementer&plug from 2081 to 2085'.TQ 1-1.5K ft-lbs, 90 RPMs, 2-5K WOB, 7 BPM @ 550 psi. P/U Wt-60K, S/O Wt-60K. 12:00 13:00 1.00 2,081 2,400 COMPZ WELLPF WASH P Wash down to Top of Sand from 2081 to 2511'. Pump 2BPM @ 150 psi. P/U to 2400'Circulate out 173 blls to clean out Arctic Pac. P/U Wt -70K, S/O Wt-65K. Observed 96 Units of gas at bottoms up, and about 20 BBLS of mixed up arctic pak returns. Circulate until returns cleaned up 13 00 13:30 0.50 2,400 2,400 COMPZ WELLPF OWFF P Monitor well 30 min.Well Static Blow down Top Drive. 13:30 15:00 1 50 2,400 308 COMPZ WELLPF TRIP P POOH&stand back 3 1/2"DP Hole took correct fill. P/U Wt-40K, S/O Wt-40K. 15:00 16:00 1.00 308 0 COMPZ WELLPF PULD P Break out&L/D BHA#11. 16:00 17:00 1.00 0 0 COMPZ WELLPF PRTS P R/U&pressure test 7"casing LP 250 psi, 5 min. HP 3000 psi, 30 min. Test Good. Charted same. R/D test equip 17:00 19:00 2 00 0 0 COMPZ WELLPF WWWH P Pull Wear Bushing. P/U Swizzle stick&jet&flush out stack. L/D Swizzle stick. Reset Wear Bushing &RILDs. 19 00 20:00 1.00 0 311 COMPZ WELLPF PULD P P/U BHA#12 as follows: 6 1/8" ConCave Mill, 2-Boot Baskets, Bit Sub, Bumper Sub, Oil Jars, Pump Out Sub, 9-4 3/4"DCs,X-Over. TL =310.90' 20:00 21:30 1.50 311 2,511 COMPZ WELLPF TRIP P RIH w/BHA#12.Tag up @ 2511' 21:30 00:00 2.50 2,511 2,516 COMPZ WELLPF MILL P Dry drill&work concave mill to break up junk from 2511 to 2516' Observed max overpull of 50K&max TQ of 9K, after grinding on junk 90 RPMs, 2-4K WOM, Free TQ-2K,TQ- 2.4-3K, P/U Wt-75K, S/0 Wt-75K, Rot Wt-74K 12/14/2014 Finish Milling up junk Circ bottoms up. POOH&L/D Mill Assy. M/U RCJB&clean out junk&sand to Top of RBP. Monitor well. Clean pits. Cond&wt up to 11.7 ppg. Mix push pill. Page 16 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 2,516 2,521 COMPZ WELLPF MILL P Con't to dry drill&mill junk from 2516 to 2521'. Had max overpull of 15K&max Tq of 3.2K Attempt to circ&wash @ 2521' Mill plugged 90 RPMs 2-4K WOM, Free TQ-2K ft-lbs,TQ-2.4-3K ft-lbs. P/U Wt- 75K, S/O Wt-75K, Rot Wt-74K. 02 00 04:00 2.00 2,521 2,521 COMPZ WELLPF CIRC P Drop dart&open pump out sub. Circulate bottoms up. Pump 5 BPM @ 440 psi. Had 192 units of CO2 gas when bottoms came up. Reduced circ rate to 2 BPM& circulated gas out. Monitor well,very slight flow.After 20 min circulated 2 bottoms up 5 BPM @ 380 psi. Monitor well.Well static 0400 05:30 1.50 2,521 311 COMPZ WELLPF TRIP P POOH&stand back DP. 05.30 07:00 1.50 311 0 COMPZ WELLPF PULD P Break out&L/D BHA#12. Inspect mill&clean out Boot Baskets Recovered 1/2 cup of metal pieces consisting of centralizer slips, aluminum&milled metal. Largest piece was 1.5"x 1.5" 07:00 07:30 0.50 0 145 COMPZ WELLPF PULD P M/U BHA#13 as follows: RCJB, 2- String magnets, Bunper Sub, Oil Jars, Pump Out Sub, 3-4 3/4"DCs 07:30 08:30 1.00 145 145 COMPZ WELLPF SVRG P Service rig. Check&tighten hoses on Iron Roughneck. 08:30 09:00 0.50 145 325 COMPZ WELLPF PULD P Finish M/U BHA#13 as follows RCJB,2-String magnets, Bunper Sub, Oil Jars, Pump Out Sub, 9-4 3/4"DCs,X-Over. TL=324 78 09 00 10:30 1.50 325 2,502 COMPZ WELLPF TRIP P RIH w/BHA#13 to 2502' P/U Wt- 73K, S/O Wt-70K, Rot Wt-73K. 10 30 11:30 1.00 2,502 2,515 COMPZ WELLPF CIRC P Ream down to 2518'Break circulation 8 BPM, 1800 psi, 50 RPMs, Free TQ-1 5K ft-lbs. Rotate down to 2520'.Work down thru junk. Saw TQ increase to 9K Ft-lbs& pump pressure increased to 1900 psi. P/U 10'&work string back down to 2530'. P/U 15'to 2515' Circulate bottoms up 11:30 13:00 1.50 2,515 325 COMPZ WELLPF TRIP P Blow down Top Drive Monitor well. Well Static. POOH w/BHA#13. Hole took correct fill P/U Wt-73K. 13:00 13:30 0 50 325 0 COMPZ WELLPF PULD P Break out&LID BHA#13. Recovered• ????? 13:30 14:30 1.00 0 325 COMPZ WELLPF PULD P M/U BHA#14 as follows. RCJB,2- String magnets, Bunper Sub, Oil Jars, Pump Out Sub, 9-4 3/4"DCs, X-Over. TL=324.78 14:30 14:45 0.25 325 1,365 COMPZ WELLPF TRIP P Trip in hole w/BHA#14 to 1365'. 1445 15:00 0.25 1,365 1,365 COMPZ WELLPF SFTY P Hold D-1 Kick while tripping drill Well secure in 45 sec.All personnel in position in 91 sec Page 17 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 15:30 0.50 1,365 2,535 COMPZ WELLPF TRIP P Con't to RIH from 1365 to 2535' Tagged sand 15:30 1600 0.50 2,535 2,585 COMPZ WELLPF WASH P Dry drill 2'. Pump 8 BPM @ 1800 psi.Wash down 10'. P/U 10'&cycle pumps. Pump 6 BPM @ 1100 psi. & wash down 40'to 2585'. P/U&circ out sand. 16:00 16:30 0.50 2,495 2,495 COMPZ WELLPF OWFF P Pull 1 stand Blow down Top Drive& monitor well.Well static. 16 30 17 30 1.00 2,495 325 COMPZ WELLPF TRIP P POOH&stand back DP. Hole took correct fill 17:30 19:00 1.50 325 0 COMPZ WELLPF PULD P Break out&UD BHA#14 No recovery in JBs. 19:00 19:45 0.75 0 13 COMPZ WELLPF PULD P Load Tally&M/U RBP retrieving tool as per Baker Rep. RIH w/same. 19:45 22 00 2.25 13 2,583 COMPZ WELLPF TRIP P RIH w/RBP retrieving assy. Tagged up on sand @ 2582 5'. 22:00 23:00 1.00 2,583 2,626 COMPZ WELLPF CIRC P Circulate out sand from 2582.5 to 2626'. Pump 7 BPM @ 520 psi 23:00 00:00 1 00 2,626 2,626 COMPZ WELLPF COND P Clean pits. &flush lines.Take on mud, condition&weight up to 11.7 ppg. Monitor well.Well static. 12/15/2014 Displace well to 11.7 ppg fluid. Retrieve RBP. POOH&L/D same RIH to 5900'&condition mud to 11.7 ppg Retrieve RBP. Circ&POOH. completion. 00 00 10.30 10.50 2,626 2,626 COMPZ WELLPF COND P Clean pits. &flush lines.Take on mud, Condition&weight up to 11.7 ppg. Mix&Weight up Push Pill.. 10:30 11:00 0.50 2,626 2,626 COMPZ WELLPF DISP P Displace 8.6 ppg brine to 11.7 ppg mud. Pump 3 BPM @ 220 psi. SPRs.#1 2 BPM @ 170 psi, 3BPM 2 230 psi #2 2 BPM @ 160 psi, 3BPM @ 220 psi. 11:00 12:00 1.00 2,626 2,626 COMPZ WELLPF MPSP P Pull RBP.as follows Pump 3 BPM @ 220 psi. Lower down over fishing neck, set down 5K, P/U 20K over& open equalizer valve. S/O to neutral wt 64K. Circulate bottoms up. P/U 5K over&rotate DP&release RBP Work pipe up&down to insure free Monitor well.Well static 1200 14:00 2.00 2,626 13 COMPZ WELLPF TRIP P POOH &stand back DP. Hole took correct fill. P/U Wt-65K. Hole took correct fill. 14:00 14:30 0 50 13 0 COMPZ WELLPF PULD P UD RBP. Clear&clean floor. 14:30 18:00 3 50 0 5,866 COMPZ WELLPF TRIP P Trip in hole w/RBP retrieving tool on 3 1/2" DP to 5866'. P/U Wt-115K, S/O Wt-80K. 18:00 2030 2.50 5,866 5,866 COMPZ WELLPF CIRC P Circulate&condition mud to 11.7 ppg. Cut&slipped 96'of drilling line while circulating Page 18 of 29 I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 22:30 2.00 5,866 5,908 COMPZ WELLPF MPSP P Slowly RIH to 5908'w/10K down& engage RBP Open equalizer port Observe well no flow. P/U 3K& circulate bottoms up. Pump 4 BPM @ 890 psi. P/U 115K, S/O-80k 22:30 23:00 0.50 5,908 5,909 COMPZ WELLPF OWFF P P/U 10'to insure RBP unset. 5/0 15'. Observe well for 30 min.Well static 23:00 00 00 1.00 5,909 3,950 COMPZ WELLPF TRIP P Pump slug&blow down Top Drive. POOH w/RBP. Hole took correct fill. 12/16/2014 Finish POOH& L/D RBP M/U Overshot assy. RIH&fish Chemical cut Joint POOH LID same. Perform Weekly BOPE test. BOPE test witnessing waived by Chuck Sheve w/AOGCC @ 0644 Hrs, 12-15-2014. 00:00 03 00 3.00 3,950 13 COMPZ WELLPF TRIP P Con't to POOH w/RBP&stand back DP. Hole took correct fill. 03:00 03:30 0.50 13 0 COMPZ WELLPF PULD P Break out&L/D RBP&running tool. Clear&clean rig floor. 03:30 04:30 1.00 0 314 COMPZ RPCOM PULD P M/U BHA#15 as follows: Cut Lip Guide, Overshot, Overshot Ext, Drive Sub, Bumper Sub, Oil Jars, Pump Out Sub, 9-4 3/4"DCs,X-Over. TL =313.55 04:30 09:00 4.50 314 6,704 COMPZ RPCOM TRIP P RIH w/BHA#15 to 6704'. P/U Wt- 65K, S/O Wt-60K. 09:00 10:30 1.50 6,704 6,704 COMPZ RPCOM CIRC P Circulate bottoms up. Obtain SPRs: #1 2 BPM @ 400 psi, 3 BPM @ 500 psi. #2 2BPM @390 psi 4BPM@ 475 psi. 10 30 11:00 0.50 6,704 6,707 COMPZ RPCOM JAR P Slowly engage fish @ 6707& swallow overshot to 6713'w/10K down wt. P/U to 175K&blled of jars. S/O to 93K,then P/U to 235K Set down w/10K& P/U to 185K Fire jars. P/U to 240K&fish came free. Work up&down 10'to insure free movement 11:00 12:30 1.50 6,707 6,707 COMPZ RPCOM CIRC P Circulate bottoms up no gas. Monitor well.Well Static. Blow down lines& Top Drive. 12:30 16 00 3 50 6,707 314 COMPZ RPCOM TRIP P POOH from 6707 to 314'&stand back DP. Hole took correct fill. P/U Wt- 138K, S/O Wt-93K 16:00 17:30 1.50 314 0 COMPZ RPCOM PULD P Break out&L/D BHA. Recovered Cut Off Jt TL=29 34'. Clear&clean rig floor. 17 30 18:00 0.50 0 0 COMPZ RPCOM SVRG P Service rig&top drive 1800 19:00 1.00 0 0 COMPZ RPCOM RURD P P/U running tool&pull Wear Bushing L/D same. P/U swizzle stick&jet out stack Cycle rams. 19:00 20 45 1 75 0 0 COMPZ WHDBO RURD P R/U test equip. M/U 3 1/2"test jt Fill stack 20:45 21 00 0 25 0 0 COMPZ WHDBO SFTY P Hold Man Down Drill. Crew Response 122 sec. Hold AAR. Page 19 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 00:00 3.00 0 0 COMPZ WHDBO BOPE P Perform weekly BOPE test as follows: LP-250 psi, HP-3000 psi 3 1/2"testa Test Blind rams, CK Valves#1, 2, 3,4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15& 16. Rig floor Kill, Outer Test Spool Valve, IBOP, Blind rams, Inner Test Spool Valve, Manual IBOP, Blind Rams, Manual Kill, HT38 Dart, Super Choke, Manual Choke, HT-38 TIW,Annular, EUE TIW valve, Upper Pipe Rams, Lower Pipe Rams, Choke HCR, Koomey test. failures.Test witnessing waived by Chuck Sheve w/AOGCC 12/17/2014 Finish BOPE test Install WR. P/U Overshot Assy, RIH&Jar No success. Perform Blind Back Off. CBU Monitor well POOH checking connections. 00:00 03 00 3.00 0 0 COMPZ WHDBO BOPE P Perform weekly BOPE test as follows: LP-250 psi, HP-3000 psi. 3 1/2"testjt. Test Blind rams, CK Valves#1,2, 3, 4, 5,6, 7, 8, 9, 10, 11, 12, 13, 14, 15&16. Rig floor Kill, Outer Test Spool Valve, IBOP, Blind rams, Inner Test Spool Valve, Manual IBOP, Blind Rams, Manual Kill, HT38 Dart, Super Choke, Manual Choke, HT-38 TIW,Annular, EUE TIW valve, Upper Pipe Rams, Lower Pipe Rams, Choke HCR, Koomey test. 1 Fail/Pass-Manual Kill.Test witnessing waived by Chuck Sheve w/AOGCC 03 00 04:00 1 00 0 0 COMPZ WHDBO RURD P L/D testjt, R/D test equip. Blow down lines. Drain stack. Pull Test plug.. 04:00 04:30 0.50 0 0 COMPZ RPCOM RURD P P/U running tool&install Wear Bushing. RILDS. L/D running tool.. 04:30 06:30 2.00 0 314 COMPZ RPCOM PULD P M/U BHA#16 as follows: Cut Lip Guide, Overshot, Overshot Ext, Drive Sub, Bumper Sub, Oil Jars, Pump Out Sub, 9-4 3/4"DCs, Intensifier, XO. TL=313.55'. RIH w/same.. 06:30 08:30 2.00 314 1,921 COMPZ RPCOM TRIP P RIH w/BHA#16 from 312 to 1921'. P/U Wt-50K. S/O Wt-50K. 0830 09.00 0.50 1,921 2,890 COMPZ RPCOM SVRG P Service Rig&Inspect Top Drive. 09.00 10:00 1.00 2,890 2,890 COMPZ RPCOM TRIP P Con't to RIH from 1921 to 2890'. 10 00 11 00 1.00 2,890 2,890 COMPZ RPCOM RGRP T Rig Repair. Clean Top Drive Look for Leak. 11 00 12.00 1.00 2,890 4,550 COMPZ RPCOM TRIP P Can't to RIH from 2890 to 4550'. P/U Wt-90K, S/O Wt-75K. 12 00 1400 2.00 4,550 4,550 COMPZ RPCOM RGRP T Repair leaking hose on Top Drive. 14.00 15 00 1.00 4,550 5,990 COMPZ RPCOM TRIP P Con't to RIH from 4550 to 5990'. P/U Wt- 125K, S/O Wt-85K. Page 20 of 29 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 15:15 0.25 5,990 5,990 COMPZ RPCOM SFTY P Hold D-1 drill; Kick while Tripping Well secure in 55 sec All crew in position in 97 sec. Hold AAR. 15:15 1630 1.25 5,990 6,652 COMPZ RPCOM TRIP P Con't to RIH from 5990 to 6652'. P/U Wt-140K, S/O Wt-95K. Obtain SPRs. #1 2 BPM @ 420 psi, 3 BPM @ 540 psi #2 2 BPM @ 440 psi, 3 BPM @ 530 psi 16:30 20 30 4 00 6,652 6,743 COMPZ RPCOM JAR P P/U Wt-135K, S/O Wt-90K, Rot Wt- 105K. Free TQ-6K ft-lbs Slowly RIH&engage fish @ 6737. Set down w/20K Swallow to 6743'. P/U to 175K&confirm latched on. Beging jarring&work pipe @ 175K. Worked up to 2250K. Pulled to 250K No Movement Jarred on fish total of 86 times. 20 30 21:00 0.50 6,743 6,743 COMPZ RPCOM CPBO P Perform a Blind Back Off. Max TQ- 8.3K ft-lbs Backed out 12 turns& String came free. P/U w/138K. 3K more then before Back Off. 21:00 22:30 1.50 6,743 6,743 COMPZ RPCOM CIRC P Circulate hole volume. Pump 4 BPM @ 850 psi. No Losses. Blow down lines. Perform Derrick inspection after jarring operations.. 22:30 23:00 0.50 6,743 6,743 COMPZ RPCOM OWFF P Monitor well.Well Static. Service Top Drive. 23:00 00:00 1.00 6,743 6,000 COMPZ RPCOM TRIP P POOH&stand back 3 1/2"DP. Check all connections for Torq after Backing Off operation. Hole took correct fill. 12/18/2014 Finish POOH&L/D recovered 661'of fish. Redress Overshot Assy& RIH on DP Rig repair-Work on Top Drve leak. Finish RIH &engage fish @ 7394'. 00:00 05:00 5.00 6,000 314 COMPZ RPCOM TRIP P POOH&stand back 3 1/2"DP. Check all connections for Torq after Backing Off. Hole took correct fill. 05:00 0600 1 00 314 0 COMPZ RPCOM PULD P BHA#16 at surface. Lay down same. 06:00 06 30 0.50 0 0 COMPZ RPCOM SFTY P PJSM. Discuss options to lay down the GLM Assemble with a Straddle Patch inside, safely. 06:30 11 00 4.50 0 0 COMPZ RPCOM PULL P Lay down recovered fish as follows: 3 1/2"Cut-Off Joint, Merla GLM#3 with w/Straddle Patch, 14 Joints of 3 1/2"Tubing, Camco GLM Assembly #2, 5 Joints of 3 1/2"Tubing. Total length recovered=661-ft. Clear and clean Floor. (new fish top is at 7,397-ft+/-...with a 3 1/2"collar looking up). 11:00 11:30 0.50 0 5 COMPZ RPCOM PULD P Pick up BHA#17 as follows: Cut Lip Guide, 5 3/4"Overshot(w/4 1/2" Spiral Grapple), Overshot Sub. 11:30 16:30 5.00 5 6,156 COMPZ RPCOM TRIP P Trip in with BHA#17 on 3 1/2"Drill Pipe from the Derrick. Page 21 of 29 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 22:30 6 00 6,156 6,156 COMPZ RPCOM RGRP T Repair leaking Top Drive. 22:30 23:45 1.25 6,156 7,394 COMPZ RPCOM TRIP P Con't to RIH&tag up on top of fish @ 7394'. 23:45 00:00 0 25 7,394 7,397 COMPZ RPCOM FISH P Slowly go over&engage fish to 7397' 5/0 w/2K. P/U&overpull to 160K,then S/0 to 150K(8K Over) P/U Wt- 142K, S/O 87K. 12/19/2014 CBU. R/U E-line. Fire string shot. Cut Tbg @ 7667'. R/D E-line. CBU. POOH&UD fish. Recovered 259'. 7 jts +2 pups+GLM+Cut Jt. M/U BHA#18, 0/S&RIH 00:00 01:00 1.00 7,397 7,397 COMPZ RPCOM CIRC P Break circulation&Pump bottoms up. Pump 4 BPM © 1010 psi . 01.00 04 00 3.00 7,397 7,397 COMPZ RPCOM ELNE P Hold PJSM w/all hands R/U HES E-line equip&lubricator 04:00 07:00 3.00 7,397 7,397 COMPZ RPCOM ELNE P RIH w/ 5'of 160 Gr/ft String shot to 7665'. Correlate spacing. Middle of shot @ 7665'. Fire shot POOH. 07.00 07:30 0.50 7,397 7,397 COMPZ RPCOM SFTY P PJSM and operations meeting with E-Line Crew that just came on tower. 07:30 11:00 3 50 7,397 7,397 COMPZ RPCOM ELNE P Run in with the 2"Radial Cutting Torch Cutter tool string. Set down on top of the Packer. Pick-up, sticky. Had to tie into the GLM Assembly at 7634-ft. Made a(+) 25-ft correction. Drop back and log RCT Cutter into place. (CCL to the Cutter= 15-ft). Odometer at 7,652 2-fURCT Cutter at 7,667 2-ft Set Anchor Arms(7,656-ft). Good Fire Cutter. Good. Release Arms (took one jar hit) Arms free. Log off. Observe a line tension decrease of—300 lbs and a 2-ft collar shift Good. POOH. 11:00 12:30 1.50 7,397 7,397 COMPZ RPCOM ELNE P Break down E-Line tools. Rig Lubricator off of the well and lay down in sections. Rig down Pump-in-Sub. Pull on Tubing...tubing is free. Complete E-Line rig down and release the Unit. 12:30 14:00 1.50 7,397 7,397 COMPZ RPCOM CIRC P Circulate Well Monitor x 30 minutes, static. 14:00 18:30 4.50 7,397 5 COMPZ RPCOM TRIP P Trip out with BHA#17, standing back 3 1/2"Drill Pipe in the Derrick Hole took correct fill. 18:30 20:00 1.50 5 0 COMPZ RPCOM PULL P Break out Overshot&UD same. POOH &UD fish Recovered 7 its tbg+2 pups+GLM+Cut Off Jt. Tallied fish, 258.69'. Cut Off Jt= 21.47'. Clear Clean rig floor. 20:00 20 30 0 50 0 0 COMPZ RPCOM SVRG P Service rig&inspect Top Drive 20:30 22 00 1.50 0 314 COMPZ RPCOM PULD P M/U BHA#18 as follows: Cut Lip Guide, Overshot, Overshot Ext, Drive Sub, Bumper Sub, Oil Jars, Pump Out Sub, 9-4 3/4"DCs, Intensifier, XO. TL=313.61'. RIH w/same Page 22 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22.00 00:00 2.00 314 3,806 COMPZ RPCOM TRIP P RIH w/BHA#18 from 314 to 3806' 12/20/2014 RIH&CBU. Engage fish&Jar free. Con't to Pull&work fish out of hole.Above 6000'started to come smoothely. Circ @ 5000'. Con't to POOH&recover fish. Recovered 100%of remaining fish. 00:00 02:30 2.50 3,806 7,630 COMPZ RPCOM TRIP P Con't to RIH w/BHA#18 from 3806 to 7630'. 02:30 03 30 1 00 7,630 7,630 COMPZ RPCOM CIRC P Break circulation&pump bottoms up. Pump 4 BPM ©950 psi. Had very fine sand in returns to surface. 03 30 06:00 2.50 7,630 7,655 COMPZ RPCOM FISH P Slowly RIH&found top of fish @ 7650 dpmd'. Go over fish to 7655 dpmd' P/U to 225K&confirm latched up.Jar on fish to 250K. Pull to 270K. P/U 155K, S/O Wt-95K. Estimate 7'of movement. 06:00 10 30 4.50 7,655 7,645 COMPZ RPCOM CIRC P Continue to make very slow progress Fish is pack-off with sand. Establish a steady circulation rate at 1.0 bpm/540 psi. Working pipe to gain progress...jarring seems to pack the sand and stop progress at present time....continue washing and working pipe. Now packed off no circulations. Blow down Top Drive. Discussed our plan forward with Anchorage Engineer. Order out 6" Washpipe. Continue to work pipe. Now have some movement down hole Establish circulations at 0.5 bpm/580 psi. Work pipe Making slow progress out of the hole again. Bottoms up. Now observe gas cut mud. Continue to pump at 0.6 bpm/480 psi Stop working pipe. Continue to observe returns 10:30 11 00 0 50 7,645 7,643 COMPZ RPCOM CIRC P Increase pump rate to 0.75 bpm/560 psi. Continue to monitor gas cut mud returns 11:00 11 45 0 75 7,643 7,600 COMPZ RPCOM CIRC P Begin making progress once again (POOH). Packer dragging and hanging up. Continue to make very slow steady progress. Continue to Pump at 0 6 bpm. Continue to observe gas cut mud. Set back Stand#1. Drop Dart to open Pump-Out Sub. 11:45 13:00 1.25 7,600 7,600 COMPZ RPCOM CIRC P Pump-Out-Sub open. Increase pump rate to 2 5 bpm/550 psi. Circulate and condition well. Increase rate to 3 5 bpm/740 psi. Increase rate to 5.0 bpm/1,230 psi. Circulate hole volume x 2. Shut down pump to monitor well. Static. Page 23 of 29 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 16:30 3.50 7,600 6,900 COMPZ RPCOM TRIP P Bring pump back on line at 1.0 bpm/385 psi. Continue to pull out slowly while pumping.. Packer continues to drag and pull tight at 220K. Continue to work pipe to free. Once the fish got to 6,900-ft it started to pull easier. End pumping 16:30 18 30 2.00 6,900 5,045 COMPZ RPCOM TRIP P Continue to Trip out standing back 3 1/2"Drill Pipe in the Derrick from 6900 to 5045'. Hole taking correct fill Pulling wt smoothed out @ 115K Last several stands. 18:30 19 30 1.00 5,045 5,045 COMPZ RPCOM CIRC P Circulate bottoms up Pump 4 BPM @ 670 psi. No losses..No gains No gas. MW in&out-11.7 ppg. 19:30 00 00 4.50 5,045 125 COMPZ RPCOM TRIP P Con't to POOH&stand back DP from 5045 to 125'. Stood Back DCs &accelerator. Hole took Correct fill. 12/21/2014 L/D Fish&BHA#18 M/U BHA#19. RIH&clean out casing to 8008'. Circ hole clean. POOH &LDDP. 00:00 01:00 1 00 125 0 COMPZ RPCOM PULD P Con't to POOH&stand back DCs. Break out&L/D BHA#18. Recovered 100%of remaining fish as follows. Cut Jt, Baker PBR Assy, Baker HB Pkr, 1 jt Tbg, "XN"Nipple, Pup Jt&Baker SOS. L/D same. TL =78.07'. 01:00 01:30 0.50 0 0 COMPZ RPCOM SVRG P Clear&clean rig floor Service rig& Top Drive. Perform Derrick inspection after Jarring ops. 01:30 03:30 2 00 0 533 COMPZ RPCOM PULD P Hold PJSM. M/U Clean out Assy BHA#19 as follows Concave Junk Mill, Bit Sub,XO,6 its DP,XO, PxP Sub, 7"Csg Scraper, 2-Boot Baskets, Bit Sub, 2 String Magnets, Bumper Sub, Oil Jars, Pump Out Sub, 9-4 3/4"DCs,XO TL= 533.08'. 03:30 08.30 5.00 533 7,819 COMPZ RPCOM TRIP P RIH w/BHA#19 from 533'to 7,820' Short trip the Completion Packer setting area x 3 with the Casing Scraper...Note the Scraper is positioned in the BHA 202-ft above the present depth of the Junk Mill...area short tripped 7,620- 7,580'. Expected packer setting depth=7,598-ft. Up weight= 165K. Down weight=95K. 08 30 1000 1.50 7,819 7,819 COMPZ RPCOM SLPC P Stop to slip and cut drilling line (69-ft). Page 24 of 29 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 12:00 2.00 7,819 8,008 COMPZ RPCOM WASH P Bring Pump on line at 2.0 bpm/682 psi and break circulations. Continue to trip in washing down at 3.0 bpm/830 psi with Stand#78, looking for the top of fill. Washed through a bridge at 7,887-ft. Continue on in. Found the top of sand at 7,895-ft dpmd Rotate at 10 rpms/torque 6K -7K. Continue to wash through sand down to 7,913-ft Make up Stand #79. Bring pump on line at 3.0 bpm/985 psi. Rotate at 20 rpm/torque 6K-7K. Continue to wash through sand down to 8,008-ft dpmd at 4-5 ft/min with no problems. Note. maintained full returns while washing through the sand covered lower perforated interval at 7,934'-7,974'. 12:00 13.30 1.50 8,008 8,008 COMPZ RPCOM CIRC P Increase pump rate to 6.0 bpm/2,380 psi to clean up the well. Continue to slowly rotate and reciprocate pipe from 8,008'-7,960'. 13:30 15 00 1.50 8,008 8,008 COMPZ RPCOM CIRC P Close in Rams R/U&reverse circulate well. Pumped 111 bbls.3 BPM @ 890 psi 15:00 16:00 1.00 8,008 7,787 COMPZ RPCOM PULD P Open ram. Blow down lines POOH &UD 7 jts of DP to be above perfs. 16:00 17:00 1.00 7,787 7,787 COMPZ RPCOM CIRC P Drop Dart, Pressure up&open Pump Out Sub Pump 28 bbl Dry job @ 13.4 ppg. 1700 00:00 7.00 7,787 533 COMPZ RPCOM PULD P POOH&UD DP from 7787 to 533' P/U wt-155k Hole took correct fill. 12/22/2014 Break out&UD BHA#19. Pull Wear Bushing&jet out BOP stack. Set plug&Test Upper Rams 250/3000 psi.Chareted same. R/U&run completion. 00.00 00:30 0.50 533 533 COMPZ RPCOM OWFF P Monitor well prior to UD BHA Hold PJSM to UD BHA. 00 30 03:30 3.00 533 0 COMPZ RPCOM PULD P Break out&L/D BHA#19. UD 9-4 3/4" DCs. UD BHA&DP. Clean Magnets&Empty junk Baskets Recovered 7#of metal from Magnets _¬hing from the Boot Baskets 0330 05:00 1.50 0 0 COMPZ RPCOM WWWH P P/U running tool&pull Wear Bushing. P/U Swizzle stick&jet out BOP stack. Clear&clean rig floor. 05:00 06:30 1.50 0 0 COMPZ RPCOM BOPE P R/U to test BOP Rams. Set test plug Test Upper Pipe Rams w/3 1/2"test jt LP 250 psi, HP 3000 psi. Tested Good. Charted same R/D test equip. Pull Test plug. 0630 09.00 2.50 0 0 COMPZ RPCOM RURD P Clear Floor. Perform the final jewerly inspection and verify running order in the pipeshed. Rig up GBR tubing handling equipment to handle the 5 1/2"Tailpipe section Page 25 of 29 a Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 10:00 1 00 0 130 COMPZ RPCOM PUTB P Begin picking up the CTD Set-Up Completion as follows. 1 Jt 5 1/2", 14 lb/ft, J-55, STC Tubing w/Wearsox every 3-ft...Mule Shoe on the bottom. 1 Jt 5 1/2", 14 lb/ft, J-55, STC Tubing w/Wearsox every 3-ft 1 Jt 5 1/2", 14 lb/ft,J-55, STC Tubing...Slick Joint 5 1/2"STC box x 3 1/2"EUE 8 rd box Ported Sub XO. Note:all connections are BakerLok'd. 10:00 11 00 1.00 130 130 COMPZ RPCOM RURD P Rig down 5 1/2"tubing handling equipment. Rig up tubing equipment to handle 3 1/2"tubing. 11 00 12:00 1.00 130 341 COMPZ RPCOM PUTB P Continue to pick-up the Completion Jewelry as follows: 1 Jt 3 1/2", 9.3 lb/ft, EUE 8rd-M, L-80 Tubing, 2.813" X-Nipple Assembly w/PXX Plug body installed, 4 ea 3 1/2"9 3 lb/ft, EUE 8rd-M, L-80 Tubing, Baker 47B2 FHL Packer, Baker 80/40 PBR. Note: ALL connections below the FHL Packer are BakerLok'd. 12:00 17:15 5.25 341 4,176 COMPZ RPCOM PUTB P Continue to single in with the 3 1/2" Completion as designed from 341 to 4176'. P/U 60K, S/O 47K. 17:15 17:30 0.25 4,176 4,176 COMPZ RPCOM SFTY P Hold D-1 drill, Kick while tripping Well shut in 33 secs.All hands reported on station 76 sec. Hold MR. 17:30 19:30 2 00 4,176 4,176 COMPZ RPCOM RURD P R/U 3rd Party Spooling unit&tools. Bring Cannon Clamps to floor. Rig up Sheaves in derrick. 19:30 22:00 2.50 4,176 4,200 COMPZ RPCOM PUTB P P/U Lubricator Valve Assy. M/U Hydraulic connections&test same. Cycled 3 times &tested each line for 15 min. 22:00 00:00 2.00 4,200 4,882 COMPZ RPCOM PUTB P Con't to RIH w/3 1/2"completion as per program. Install 1 clamp/jt on control lines&2 bands(top& bottom)on GLMs&Nipple Assys. M/U Torq =2800 ft-lbs. 12/23/2014 Finish RIH w/Completion R/U Digital slickline&put on depth Set Packer. Shear out&displace wellbore fluids. 00:00 06:30 6.50 4,882 7,978 COMPZ RPCOM PUTB P Continue to RIH w/3 1/2"completion as per program Install 1 clamp/jt on control lines&2 bands(top& bottom)on GLMs&Nipple Assemblies. Make-up torque=2,800 ft/lbs. Filling each Jt while running tbg. RIH from 4,882-ft to 7,978-ft dpmd(note added Jts#246 and 247 to the completion string to make sure that the X-Nipple with the PXX Plug is deep enough so we have plenty of room to log the K-1 Marker). Page 26 of 29 r Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 06 45 0.25 7,978 7,978 COMPZ RPCOM SFTY P PJSM with Digital Slick-Line Crew and Rig Crew. 06:45 10 00 3 25 7,978 7,978 COMPZ RPCOM ELOG P Rig up Digital Slick Line equipment Make up GR/CCL Tool String. 10:00 10:15 0.25 7,978 7,978 COMPZ RPCOM ELOG P Pressure test Lubricator at 500 psi. Good. 10:15 14:30 4 25 7,978 7,978 COMPZ RPCOM ELOG P Run in with GR/CCL Tool String Set down on the PXX Plug body in the X-Nipple at—7,800-ft dslmd (un-corrected) Record tie in pass .looking for the K-1 Marker. Found K-1 Marker at 7,694-ft dslmd (un-corrected). Drop down and repeat logging pass and correlate to the Compensated Neutron Log dated Oct, 14, 1989. Make a(+)30 foot correction Drop down and repeat correlation pass. Good. Drop down and set on the PXX Plug body. Log up and record the Packer, PBR, and the bottom GLM Assembly tops. Top of the FHL Packer logged= 7,608-ft dslmd Completion tally running summary called for the Packer top to be at 7,598.47-ft md. Packer needs to be shifted up-hole 10-ft to 7,598.0-ft. This will place the top of the 5 1/2"Wearsox section at 7,786.72-ft-and the bottom at 7,916.00-ft(Mule Shoe depth) Co Man reviewed Logs, Completion Running Summary, and the"shift" with the Digital Slick Line Engineer, Baker Packer Service Hand, and the Anchorage Engineer...all agree. POOH with logging tools. 14:30 16:30 2.00 7,978 7,978 COMPZ RPCOM ELOG P Re-configure the Tool String. Pick-up the PXX Prong. Run in the hole. Set the Prong in the PXX body. Good. POOH. 16:30 17 30 1 00 7,978 7,978 COMPZ RPCOM FLOG P Rig down Tool String. Rig down Lubricator. 1730 18:00 0 50 7,978 7,575 COMPZ RPCOM PACK P Set Packer by pressuring up to set pressure and continuing to pressure up to 2500 psi Hold for 10 min. Bleed down to 2000 psi and pull to Shear Seal Assembly from PBR. Good indication of packer set with 20k overpull and shearing as overpull and pressure diminished as shear occurred. 18:00 19:30 1.50 7,575 7,575 COMPZ RPCOM ELOG P Rig Down SLB Digital E-Line. Clean and Clear Rig Floor. Page 27 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 22:45 3.25 7,575 7,575 COMPZ RPCOM HOSO P Roll pumps and observe pressure build as seals engage. Pumps off and fully locate. 7 13'Space out calculated. Lay down 2 joints of 3 5" tubing. Make up space out pups 10.13'and 6.18'. Make up 1 full joint, hanger and pup and landing joint with circulating equipment. Run control lines through hanger and attach control line to top of lines above hanger Pressure Test both hanger penetrations to 5000 psi for 10 min. SIMOPS: Rig Down Power Tongs. 22:45 23 00 0.25 7,575 7,575 COMPZ RPCOM SFTY P PJSM for displacing well to 8 6 ppg seawater and Corrosion Inhibited 8.6 ppg seawater. 23:00 00:00 1.00 7,575 7,575 COMPZ RPCOM DISP P Displace well to 8.6 ppg seawater.4 bpm @ 140 psi 12/24/2014 Circulate well bore to 8.6 ppg Seawater. Corrosion inhibit well with 8.6 ppg Seawater. Land compeltion, RILDS Test tubing and IA. Test Lubricator valve. Set TWC. ND BOPE. MU Lubricator Valve Manifold. NU tree. 00:00 01:30 1.50 7,575 7,575 COMPZ RPCOM DISP P Continue to displace well to 8.6 ppg seawater.4 bpm © 140 psi. 01:30 04:00 2.50 7,575 7,575 COMPZ RPCOM CRIH P Reverse circulate in 8.6 ppg seawater, 5%corrosion inhibitor. 3 bpm©285 psi 04:00 05:00 1.00 7,575 7,598 COMPZ RPCOM THGR P Hang off completion. RILDS. 05:00 08:30 3.50 0 0 COMPZ RPCOM PRTS P Pressure up to 3500 psi on 3.5" EUE8rd tubing for 10 minutes. Bleed tubing to 2000 psi Pressure up on IA to 3000 psi for 30 min Rapidly bleed off tubing to shear SOV Check circulation path open both ways. Function test Halliburton Lubricator Valve closed and test form above and below to 1500 psi. Function the valve to the open position and leave open. 08:30 10:00 1.50 0 0 COMPZ WHDBO MPSP P Set the TWCV in the Tubing Hanger. Test from below at 1,000 psi x 10 minutes Good Record on chart. (SIMOPS, Clear floor of Halliburton Spooling equipment). 10:00 12:30 2 50 0 0 COMPZ WHDBO OTHR P Clean Rotary table with Super Sucker Clean rig floor and pipe racks. Clean Pits Break Services lines. 12:30 15:30 3 00 0 0 COMPZ WHDBO NUND P Nipple Down BOP stack. 15 30 20:30 5 00 0 0 COMPZ WHDBO NUND P Nipple Up manifold for HES Lubricator valve. Nipple Up tree and adapter Tree orientation witnessed and confirmed by CPAI 2K DSO Wayne Zeringe. 20 30 21:30 1.00 0 0 COMPZ WHDBO PRTS P Test Tree and packoffs 250/5000 psi. Page 28 of 29 e Time Logs _Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 22 00 0.50 0 0 COMPZ WHDBO MPSP P Verify no pressure on IA. Pull TWC 22:00 00:00 2.00 0 0 COMPZ WHDBO FRZP P Freeze Protect well pumping 75 bbls of diesel down IA taking returns out tubing, 2 bpm @ 300 psi Hook up jumper lines and allow to U-Tube. SIMOPS: Rig Up line to pressure test OA to 1800 psi. 12/25/2014 Test tree Pull TWC. Freeze Protect.Test OA. Set BPV. RDMO. OA/IA/Tubing: 0/0/0 psi RIG RELEASED @ 03:00 00:00 01 15 1 25 0 0 COMPZ WHDBO FRZP P Continue Freeze protect by U-Tubing with jumper hoses. SIMOPS: Pressure test OA to 1800 psi. bleeds to 1650 after 5 minutes bump up pressure and see same results each time. (Charted test) OA/IA/Tubing: 0/0/0 psi 01:15 02:00 0.75 0 0 COMPZ WHDBO MPSP P Install BPV.Test to 500 psi from below. 02:00 03:00 1.00 0 0 DEMOB MOVE RURD P Blow down all lines. Secure Cellar Disconnect interconnects and prepare pits to be moved off of Sub. RIG RELEASED @ 03:00 Page 29 of 29 Loepp, Victoria T (DOA) From: Regg,James B (DOA) Sent: Tuesday, December 09, 2014 9:04 AM To: Schwartz, Guy L(DOA); Loepp,Victoria T(DOA) Subject: FW:2K-15 Follow Up Flag: Follow up Flag Status: Flagged Jim Reggcik �N� ��I`, Supervisor, Inspections sc�1 AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Nabors 7ES Company Man [mailto:n2364@conocophillips.com] Sent: Monday, December 08, 2014 11:01 PM To: DOA AOGCC Prudhoe Bay Cc: Crisp, John H (DOA); Nesvold,Janelle R; Rauchenstein, Rock D; Packer,J.Brett Subject: 2K-15 Gentlemen, I notified John Crisp but wanted to follow-up with an email note about our use of the Annular preventer this evening at 19:11. There are 2 Bridge Plugs in the hole at 2640' MD and 5900' MD, both tested when set.We had cut our 7" (at 2076'MD) and were starting to lay it down. Prior to this we had circulated hot diesel followed by hot 8.6 ppg seawater to clear the arctic pack. Once we broke off the first full joint we observed the well out of balance.We lined up to pump a hole volume to get balanced fluid all the way around.At bottoms up we had gas alarms going off in the pits and gas breaking out of the 8.6 seawater. In an effort to stop further gas from getting in the pits/rig we shut down the pumps,observed gas breaking out in the hole with slight flow and closed the bag(with no pit gain)so we could take the returns outside through the choke shack to the tank we have for the Arctic pack displacement(the gas breakout likely was from arctic pack/diesel/crude that was in the OA). No pressure build observed on the gauges.After the circulation we monitored with no pressure on the 7"or backside. We opened up and observed the well to be static. We then circulated a hole volume to ensure hole was in balance,clean and without gas or problems at bottoms up or during circulation. Monitored well after circulation. Hole was static. Due to an identified surface casing leak(at 660'MD)we are in a diverter status but we have not diverted anything out that leak to our knowledge. 1 We are continuing to lay down the 7" casing. If you have any questions please let us know.We will be testing BOPs once out of the hole with the 7"casing. Edward Scott Heim / Edward Oglesby Rig Supervisor/Nabors 7ES Office 659-7844 Rig 659-7247 2 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: ~'~Bren Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Beverly Bren Vincent Nathan Lowell Date: Is~ NOTScanned.wpd a) 0 a) a) .o (_, a) 0- 7 N fC . a) f0▪ v a) t — +-, aJ 4- t 0 C . O_ O U O U 2 @. c v O a, V1 y .<" J to Q LL C CV °1 3 u9 v o E o o ` t N CO u w W CO c O• (a cu 3 Z IC i 5 O - E t U 00 n3 c v o CO E a) 18 a) 0• -o o E aa)) c-) o a U O tea, as a Q y s3 O 2 _o LL t � O y Baas ~ao O Q J V a) U E U O >, r) u) N 0N• — LI -) O ) 0- 0 N— U U▪ Q hM a5 w.- a o O O vl M im u0 U) a c O U E• � Urn43 47- U N CD NO, 0- ▪ v cc U N � ° D a) 7 3 E E ' E u, a, U o >;-c op o ro L � � UzH 3 N 2 Cl- c 8 � in in o n —y a) TO Q Z Z N N c 0 a v O � Y +' c � c) N � a E 0 o O c N O T U — , Q :L a O �, 3LS0 G I-Y a) (1 <0 °o N N T a) O- a3 R L "d (a Y 0 Q f� 1 .0 = = o a7 N a 0) 0 T V -0 al (0 O oc da) - a) ., a; C C7 °- uw 0 ' t o 0 vi u O d. v E a)• a, v Ct E orrn 0 m'� _c cu t .+ a) U d i_ E - 5 CI U _ 0 u C OTC a) U.• U) Q(O < IR CD , a mdCOQ. dwaljalioglo CD O O O d O N T T I , I I ,I : . I, 1 ,1 I, i ,I I I 1, I I I, 1, 1 , I I I, a) I 1 y ,1 _ `- T Q _ i - T I I N I _ T I) - I - Q 00- d (v)- T .t. 1 II� N U N �11 _ (.6 C11 0 le G 1 I CO ❑ ► - T Y� I I 5 NOM 7 If"" I - T j, - d CO r - - N- I y 1 J — D j _ II -- co T W 1 ,I I I' I ,I II I I, I ,1 1 11 1 , 1 'I i I' If 'I ` I' I 'I I -D 0 WO ° ° ° b b U a o CD o a T T CO CJ V N ISd KUP 2K-15 Alaska,Inc. 501032011300 KUPARUK RIVER UNIT .PROD _ tr,.v,rnPr,ln,p, 1 Max Angle MD(HK MD ITD « Well Attributes Field Name Well Status nc.() ■MD(ftKB) T Btm(ftKB) ConocoPhilli 1 46 42 6,500 00 8.304.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ••• Well Conf9.-2K-15,7/16/2012 1;04:07 PM SSSV:TRDP 48 10/5/2011 Last WO: -- 40.19 10/16/1989 - Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod_.End Date Last Tag: 7,926.0 4/7/2004 Rev Reason WELL REVIEW osborl 7/16/2012 - _ Casing Strings I 11 1 Casing Description String 0.. String ID Top(ftKB) Set Depth(f...Set Depth(TVG).. String Wt..String...String Top Thrd HANGER,31 CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(TVD).. String Wt...String...String Top Thrd SURFACE 9 5/8 8.921 35.0 3,319.7 2,946.5 36.00 J-55 BTC Casing De pt String 0... String ID...Top(ftKB) Set Depth(1.. Set Depth(TVD) String Wt...String String Top Thrd I s I PRODUCTION 7 6 276 33.0) 8,285 6 6 480 7 26.00), J 55 ETC Eubrng Strngs (Tubing D ptlon S[ g 0... St g ID Top(ttKB( Set D pth(f...,Set Depth(TVD) String WI.Str,ny String Top Thrd TUBING j 3 1/2I 2.992 , 31.1 7 743 9 j 6,074 2 9 30 J-55 RUE-MOD I CONDUCTOR, Completion Detail 36-115 Top Depth -. (TVD) Top loci Monti... Top(ftKB) (ftKB) n Item Description Comment ID(In) 31.1 31.1 0.14 HANGER FMC-GEN IV TUBING HANGER 3.500 SAFETY VLV, �.. 1,812.3 1,791.0 25.71 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.992 1.812 7,679.4 6,025.9 41.45 PBR BAKER 80-40 PBR w/10'STROKE;4"SEAL BORE 3.000 7,693.1 6,036.2 41.44 PACKER BAKER HB RETRIEVABLE PACKER 2.890 GAS LIFT, 7,731.9 6,065.1 41.30 NIPPLE OTIS 2.813"XN NIPPLE w/2.75"NO GO 2.750 2,440 " 7,743.2 6,073.6 41.31 SOS BAKER SHEAR OUT SUB 2.992 Mk jr,ilt n,li:7w _+_p ,va ---- -,fish, Top Depth' (TVD) Top Intl Top(ftKB) (ftKB) (°) Description Comment Run Date ID(In) 6.766.0 5,371.1 45.53 PATCH DUAL ECLIPSE PATCH(OAL 26')TOP ELEMENT 6766' 7/3/2004 1.750 RKB,BOTTOM ELEMENT 6790'RKB SURFACE. ' Perfora t "`+ 35-3,320 Shot Top(TVD) Bed(TVD) Dens GAS LIFT, Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (sh•- Type Comment 4,674 7,824.0 7,832.0 6,134.4 6,140.4 C-4,2K-15 5/25/1997 6.0 IPERF 2.5"HSD,60 deg.Phasing 7.934.0 7.974.0 6.216.71 6.246.7',A-4.2K-15 4/19/1990 4.0 IPERF 4.5"HSC,189 deg.Phasing GAS LIFT, Notes:General&Safety 6.026 _ End Date Annotation 9/3/2000 NOTE:E-LINE IDENTIFIED LEAKS @ 2425',6765',7235'MD I 11/3/2010 NOTE:View Schematic w/Alaska Schematic9.0 PATCH,6,766- GAS LIFT, 6,776 BK N IL GAS LIFT II I I GAS LIFT, 7.635 I I PBR,7 679 r_PACKER,7,693 " I' NIPPLE,7.732 I, I SOS.7,743 IPERF, 7,824-7,632 Mandrel Details Top Depth Top Port )TVD) Inol OD Valve Latch Sine TRO Run Stn Top(ftKB) (ftKB) F) Make Model (in) Bern Type Type (in) (psi) Run Date Coin... 1 2,439.8 2,325.6 41.11 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,290.0 7/6/2005 2 4,673.6 3,896.3 45.66 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,330.0 7/6/2005 IPERF, 3 6,025.7 4,851.1 44.54 MERLA TMPD 1 GAS LIFT OV BK 0.156 0.0 7/6/2005 7,934-7974 4 6,775.8 5,378.0 45.55 MERLA TMPD 1 GAS LIFT PATCH BK 0.000 0.0 7/3/2004 5 7,243.2 5,705.9 46.64 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/20/2004 6 7,634.5 5,992.3 41.47 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/12/1999 PRODUCTION. 3341,286\ TD,8,304 • • ConocoPhillips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 29, 2008 ' ;~ ~ ~~ ~ ~ ~ ~~~~ Mr. Tom Maunder Alaska Oil & Gas Commission 1 -- (,~ ~ g 333 West 7~' Avenue, Suite 100 4 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). 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 foam 10-404, Report of Sundry Operations. The cement was pumped June 30, July 4 and July 20, 2008. The corrosion inhibitor/sealant was pumped June 29, June 30, JulylO,and July 24, 2008. 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. Sincerely, - ,~ `~'~ M.J. Loveland 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) Date Kuparuk Field 7/29/2008 Well Name 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 2K-01 188-122 SF NA 10" 6/30/2008 2 6/29/2008 2K-02 188-121 SF NA 10" 6/30/2008 2 6/29/2008 2K-03 188-120 24" NA 24" 6/30/2008 8.5 6/29/2008 2K-05 188-118 SF NA 10" NA 2.55 7/10/2008 2K-06 189-082 SF NA 15" NA 1.27 7/10/2008 3K-13 189-095 8'1" 1.00 25" 7/4/2008 6.38 7/10/2008 2K-15 189-089 SF NA 6" 6/30/2008 1 6/30/2008 2K-17 189-119 10" NA 10" 6/30/2008 23.8 6/30/2008 2K-18 189-108 SF NA 11" NA 2.12 .7/10/2008 2K-21A 198-158 20' 2.70 14" 7/4/2008 4.68 7/10/2008 2K-22 189-115 6" NA 6" 6/30/2008 5.1 6/30/2008 2K-25 190-012 SF NA 12" NA 2.55 7/10/2008 2K-26 190-015 SF NA 10" 6/30/2008 2 6/29/2008 2K-28 201-154 3'10" NA 3"10" 6/30/2008 23.8 6/30/2008 2M-04 192-093 SF NA 20" NA 3.4 7/10/2008 2M-27 192-071 9'9" 1.2 18" 7/4/2008 2.55 7/10/2008 2B-07 184-024 20' 2.7 34" 7/4/2008 5.95 7/10/2008 2V-01 183-158 24" NA 24" NA 20.4 7/24/2008 2V-02 183-161 11" NA 11" NA 1.3 7/24/2008 2V-03 183-164 24' 6" 3.40 8" 7/20/2008 5.5 7/24/2008 2V-04 183-165 20' 4" 2.80 8" 7/20/2008 5.1 7/24/2008 2V-05 183-176 SF NA 4" NA 2.1 7/24/2008 2V-09 185-037 SF NA 4" NA 1.7 7/24/2008 2V-11 185-049 SF NA 4" NA 1.7 7/24/2008 2V-12 185-050 40' S.4 8" 7/20/2008 8.5 7/24/2008 2V-13 185-030 18" NA 18" NA 3.8 7/24/2008 2V-14 185-031 SF NA 4" NA 1.7 7/24/2008 2V-15 185-032 SF NA 4" NA 1.7 7/24!2008 ) ) Conoc~hillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 3, 2005 ,tr"\. f. ." ~ 'I"'·'" ~!~, '.~"A·I Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 JUt () S 2005 Dear Mr. Maunder: Enclosed please find a 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. we1l2K-15 (PTD 1890890). The report regards a casing head welding operation. Please call Marie McConnell or MJ Loveland at 659-7224 or me at 659-7043 if you have any questions. Sincerely, ý!..._~ L~ Jerry Dethlefs Problem Well Supervisor SCANNED JUL 0 '7 2005 Attachments 1, Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 154' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: measured 8304' feet true vertical 6495' feet measured 7918 feet true vertical 6276' feet Length Size MD 115' 16" 115' 3165' 9-5/8" 3319' 8129' 7" 8283' ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Repair Well 0 Pull Tubing D Ope rat. ShutdownD Stimulate D Waiver D Other D D D Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development _ 0 Stratigraphic D Time Extension Re-enter Suspended Well Exploratory D Service D 5. Permit to Drill Number: 189-089 1 6. API Number: 50-103-20113-00 9. Well Name and Number: 2K-15 10. Field/Pool(s): Kuparuk Oil Pool Plugs (measured) Junk (measured) TVD Burst Collapse 115' 2946' 6479' Measured depth: 7824-7832', 7934-7974' true vertical depth: 6134-6140',6217-6247' 2005 fJ <i.Y. Tubing (size, grade, and measured depth) 3-1/2" , J-55, 7744' MD. I, ìW'"1 Packers & SSSV (type & measured depth) pkr= BAKER 'HB' RETR. pkr= 7693' SSSV= Cameo TRDP - !A-SSA SSSV= 1812' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 13. Treatment descriptions including volumes used and final pressure: N/A RBDMS BFl JUl 0 5 2005 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Oil-Bbl 99 NA Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl 32 156 Tubinq Pressure 222 Casinq Pressure 1201 15. Well Class after proposed work: Exploratory D Development 0 Service D 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJ D 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: Daily Report of Well Operations _X Contact WDSPL D Printed Name Signature Marie McConnell/MJ Loveland 659-7224 I~ill~ ;~I~ne -;7 þ~c- Form 10-404 Revised 04/2004 Problem Well Supervisor Date Submit Original Only ) 2K-15 DESCRIPTION OF WORK COMPLETED SUMMARY ) Date Event Summary 6/25/2005 SET 3 1/2" WRP 3.77' OAL, ON HES SLICK SHOT @ 6696' RKB MIT T 2500# GOOD TEST ,SET SLIP STOP ON WRP @ SAME, PULL 1" OV @ 6026' RKB, LRS ON LOCATION TO DO FLUID SWEEP FROM TUBING TO lA, FLOWLINE, LDFN, JOB IN PROGRESS CONTINUE IN AM, 6/25/2005 PULLED LV'S AND SET DMYS @ 2440',4674',6026' RKB, PULLED SLIP STOP @ 6676' WLM, BLEED T & IA TO 300# , DUMPED TRSSV AND FINISH BLEEDING TUBING TO 0 , 6/29/20051 Prep for BH weld, bleed IA & OA, install purge valves 7/1/2005 Purge N2 across IA & OA during 3 pass BH weld. Three passes to seal buttress thread connection between casing head and surface casing. T/l/0=1501010. Pulled purge jewelry and re-installed IA & OA VR plugs. 7/2/2005 Post weld QA/QC passed, MITOA - passed, Initial T/I/O= 1501010 Pressure up OA with diesel to 1800 psi, start MITOA T/I/O= 15010/1800, 15 minute reading T/I/O= 15010/1700, 30 minute reading T/I/O= 15010/1680 bleed down OA. IK 0.156 1290 7/9/2004 IK 0.188 1330 7/9/2004 BK 0.156 0 7/9/2004 BK 0.000 0 7/3/2004 RK 0.000 0 5/20/2004 RK 0.000 0 6/12/1999 Otl1er(pILigs;equip.; ek) .~. JeWELRY·" · .' iption ID 1812 1790 SSSV Camco TRDP-1A-SSA 2.812 6756 5364 PATCH DUAL ECLIPSE PATCH(OAL 26') TOP ELEMENT 6758, BOTTOM ELEMENT 6782 1.750 set 7/3/2004 7679 6026 PBR Baker '80-40' w/ 10' Stroke 3.000 7693 6036 PKR Baker 'HB' Retr. 2.890 7732 6065 NIP Otis 'XN' NippleNO GO 2.750 7743 6074 SOS Baker 2.992 7744 6074 TTL 2.992 G¢néraINø~ø$" ..... . Date Note 9/3/2000 E-LlNE IDENTIFIED LEAKS @ 2425',6765',7235' MD 5/21/2004 CONFIRMED LEAK @ 6776' GLM #4 V Type VOD Latc h Port TRO GLV to E GLV 1.0 E OV 1.0 PATCH to DMY 1.5 DMY 1.5 Descr V Mfr Date Run Vlv Cmnt Size Top Bottom TVD Wt Grade Thread 16.000 0 115 115 62.50 H-40 9.625 0 3319 2946 36.00 J-55 7.000 0 8283 6479 26.00 J-55 . [ Thread EUE-MOD Zone Status Ft SPF Date Type Comment C-4 8 6 5/25/1997 ¡PERF 2.5" HSD, 60 deg. Phasing A-4 40 4 4/19/1990 ¡PERF 4.5" HSC, 180 deg. Phasing Angle @ TS: 41 deg @ 7822 Angle @TD: 41 deg @8304 Rev Reason: GLV design Last Update: 7/4/2004 Well Type: PROD Orig Completion: 10/16/1989 Last W/O: Ref Log Date: TO: 8304 ftKB Max Hole Angle: 46 deg (á¿ 6500 2K-15 KRU ) API: 501032011300 SSSV Type: TRDP Annular Fluid: Reference Log: LastTag: 7926 Last Tag Date: 4/7/2004 C~$¡ng.str.it:19;'AI;;.L'$TRJNGS .. '. : Description CONDUCTOR SUR. CASING PROD. CASING 1:;¡:.djÎl1g$trihg:·rUBING ... ...... Size I Top 3.500 0 PéiJóratiôn$ SUmmary'" .. Interval TVD 7824 - 7832 6134 - 6140 7934-7974 6217-6247 Gas Li ff \J(al)drelslVa IVeis" :... st MD TVD Man Mfr Man Type I~~¡ ~...,.¡ ~ )I~. I . ~ I I -r- += -4-- ~ r ¡ ~ 1 i ¡ ~ ~ -+- -+ r -+- -+- Perf (7934-7974) TUBING (0-7744, 00:3.500, J 10:2.992) sos (7743-7744, 00:3500) Perf (7824- 7832) NIP (7732-7733, 00:3,500) PKR (7693-7694, 00:6.151) PBR (7679-7680, 00:3.500) Gas Lift 1drel/Oummy Valve 6 (7635-7636, 00:5.793) Gas Lift 1drelIDummy Valve 5 (7243-7244, 00:5.793) PATCH (6756-6782, 00:3.500) Gas Lift andrellValve 3 (6026-6027, Gas Lift andrellValve 2 (4674-4675, Gas Lift andrellValve 1 (2440-2441, sssv (1812-1813, 00:3.500) . :iiii¡i: ::,::::;;:¡;;;;:;t:¡:.¡:::ii~ ConocoPhUUpsAlaska tne :::::. .. "':::':::'::::;i¡W . . ..... .' . .. : . '.. ..' .~. '. ~ ) .. ]¡¡¡¡iiij!::!:i......ll~ ¡ ¡ ·]'¡¡¡¡¡¡I::::··}.~:::?:~· ....... ..' .... "i" . ;.:.:.:.:....,.:.,:::{.:.:. ¡ ¡ ,Z:lil[ I ~'.:: I : ! l'J'" .) ,. ." r· 'q ~ ¡ ~ .. ,'-t'" Þ]i:" . ',".' LJ:I' ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Repair Well 0 Pull Tubing 0 Ope rat. ShutdownD Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Plug PenoraliOns 0 Penorate New Pool 0 Penorate 0 4. Current Well Status: Development - 0 Stratigraphic 0 D Time Extension D Re-enter Suspended Well 0 5. Permit to Drill Number: 189-089 1 6. API Number: 50-103-20113-00 P. O. Box 100360 7. KB Elevation (ft): RKB 154' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: ,. Operalions Penormed. Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: Stimulate 0 Waiver 0 Other Exploratory 0 Service 0 9. Well Name and Number: 2K-15 10. Field/Pool(s): Kuparuk Oil Pool measured 8304' feet true vertical 6495' feet measured 7918 feet true vertical 6276' feet Length Size MD 115' 16" 115' 3165' 9-5/8" 3319' 8129' 7" 8283' Plugs (measured) Junk (measured) TVD Burst Collapse 115' 2946' 6479' Measured depth: 7824-7832',7934-7974' true vertical depth: 6134-6140',6217-6247' I .. i " Tubing (size, grade, and measured depth) 3-1/2" , J-55, 7744' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'HB' RETR. pkr= 7693' SSSV= Cameo TRDP - !A-SSA SSSV= 1812' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A 13. Treatment descriptions including volumes used and final pressure: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run- Daily Report of Well Operations_X 217 15. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A If C.O. Exempt: Contact Marie McConnell/Jerry Dethlefs 659-7224 Printed Name MJ L~~nd / Title Signature /~ ;7 ~ ~ Phone Form 10-404 Revised 04/2004 Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Caslnq Pressure Tubinq Pressure 95 178 211 Service D WDSPLD Problem Well Supervisor 6 --;-7 - 7.)-;).1 Dat:r~Nr~¿~¿~'~~59-7224 'I,w , ,: II ' , .... .' Submit Original Only ~ ~ 2K-15 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 7/312004 SET WEATHERFORD DUAL ECLIPSE STRADDLE PATCH ASSEMBLY ACROSS GLM#4. TIE IN TO SWS LDL DATED 5/28/04. SET LOWER ELEMENT AT 6781.5'. SET UPPER ELEMENT AT 6758'.23.4' BETWEEN ELEMENTS. TOP OF PATCH AT 6755.5'. PATCH MIN ID: 1.75". WELL LEFT SHUT IN. 7/512004 LRS MITIA passed @ 2500 psi. Loaded IA with 46 bbls diesel to fill void (DVs in tubing). Pre MIT pressures 600/1200/600 psi, Initial 600/2500/600 psi, 15 minute 600/2400/600 psi, 30 minute 600/2360/600 psi. Lost 140 psi in 30 minutes. Bled IA to 500 psi. Final WHPs 600/500/600 psi. ....:¡~:. ConocoPhillips ~Iaska, Inc. 2K-15 API: 501032011300 SSSV Type. TRDP Annular Fluid: Reference Log. Last Tag: 7926 Last Tag Date: 4/7/2004 Casing String. ALL STRINGS Description CONDUCTOR SUR. CASING PROD. CASING Tubing String. TUBING Size I Top 3.500 0 Periorations Summary '..1 iiIi8 Interval TVD ~ 7824-7832 6134-6140 7934 - 7974 6217 - 6247 Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type sssv (1812-1813. 00 3.5001 Gas Llh andrelN alve 1 (2440-2441. Gas L,ft andrelNalve 2 (4674-4675. Gas LIf1 andrelNalve 3 (6026.6027. PATCH (6756.6782. 00'3.500¡ Gas Lift ,drel/Dummy Valve 5 (7243-7244, 00:57931 Gas Lift ,rjrel/Oummy Valve 6 17635-7636. 00:5.7931 PBR (7679-7680. 00:35001 PKR 17693-7694. 00:6.151, NIP (7732-7733. 00351)01 TUBING 10-77-1-1. 00:3500. J 10:2 9921 50S (77-13.774-1. 00.3 SOÙ) P"rt 17824-78321 Peri (79'34.79741 ~ IÞ .. ..j .. '"I.k . ~: .'~" ... u . , I' KRU 2K-15 Well Type: PROD Orig Completion 10/16/1989 Last W/O. Ref Log Date: TD: 8304 f1KB Max Hole Angle' 46 deg @ 6500 Angle @ TS: 41 deg @ 7822 Angle @ TD' 41 deg @ 8304 Rev Reason GL V design Last Update: 7/4/2004 Size 16.000 9.625 7.000 TVD 115 2946 6479 Top 0 0 0 Bottom 115 3319 8283 Bottom 7744 I Grade I J-55 TVD 6074 Wt 9.30 Wt 62.50 36.00 26.00 Grade H-40 J-55 J-55 Thread Thread EUE-MOD Zone C-4 A-4 Status Ft SPF Date Type Comment 8 6 5/25/1997 IPERF 2.5" HSD. 60 deg. Phasing 40 4 4/19/1990 IPERF 4.5" HSC. 180 deg. Phasing Cameo TRDP-1A-SSA DUAL ECLIPSE PATCH(OAL 26') TOP ELEMENT 6758. BOTTOM ELEMENT 6782 set 7/3/2004 Baker '80-40' wI 10' Stroke Baker 'HB' Retr. OtiS 'XN' NippleNO GO Baker 1 2440 2325 Merla TMPD 2 4674 3897 Merla TMPD 3 6026 4851 Merla TMPD 4 6776 5378 Merla TMPD 5 7243 5705 Cameo MMG-2 6 7635 5993 Cameo MMG-2 Other (plugs, equip., etc.) . JEWELRY Depth TVD Type 1812 1790 SSSV 6756 5364 PATCH V Mfr V Type VOD Latch Port GLV 1.0 BK 0.156 GLV 1.0 BK 0.188 OV 1.0 BK 0.156 PATCH 1.0 BK 0.000 DMY 1.5 RK 0.000 DMY 1.5 RK 0.000 Description 7679 6026 7693 6036 7732 6065 7743 6074 7744 6074 General Notes Date Note 9/3/2000 E-LlNE IDENTIFIED LEAKS @ 2425', 6765'. 7235' MD 5/21/2004 CONFIRMED LEAK @ 6776' GLM #4 PBR PKR NIP SOS TTL TRO Date Run Vlv Cmnt 1290 1330 0 0 0 0 719/2004 71912004 7/9/2004 713/2004 5120/2004 6/1211999 ID 2.812 1.750 3.000 2.890 2.750 2.992 2.992 J .", ~ PHilliPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY P,O, BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 29, 2002 Tom Maunder Alaska Oil & Gas Commission 333 West 7t1J Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-404 Sundry Notice forms for Phillips Alaska, Inc., wells 2K-15, 2T-202, 30-14, 30-20 and 3Q-08A. The notices are to report annulus "top job" cement operations for the five wells. Also attached are brief summaries and field report for the cementing operation. Please call Jerry Dethlefs or me at 907-659-7224 if you have any questions. Sincerely, ~1rf Phillips Problem Well Supervisor Attachments SCANNED AUG 0 9 2002 :~? F FJ ,jUL j ~í ?OO? Þ'!8.S!<a1J11 61 Uu; CCi\j. CU:iH(¡iS2;IOi Þ\nchorP,oe nO'(::!î\1 It I ' I \ f ( .' " V I \ E \=J i ; \j /4 ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 119' FNL, 94' FEL, Sec. 11, T10N, R8E, UM At top of productive interval 1475' FNL, 1082' FEL, Sec. 12, T10N, R8E, UM At effective depth At total depth 1494' FNL, 1018' FEL, Sec. 12, T10N, R8E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service__ 6. Datum elevation (DF or KB feet) RKB 154' feet 7. Unit or Property name Kuparuk River 8. Well number 2K-15 9. Permit number / approval number 189-089 / 10. APl number 50-103-20113-00 11. Field / Pool Kuparuk River Field / Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 80' 16" Surface 3285' 9.625" Production 8253' 7" 8304 feet 6494 feet 7918 feet feet Plugs (measured) Junk (measured) Cemented Measured Depth True vertical Depth 176 sxAS II 80' 115' 1000 sxAS III, 450 sx Class G 3319' 2946' 225 sx Class G 8283' 6479' Perforation depth: measured 7824'-7832',7934'-7974' true vertical 6134'-6140', 6217'-6247' Yubing (size, grade, and measured depth) 3.5", 9.3#, J-55 tubing @ 7744' Packers & SSSV (type & measured depth) Baker'HB' Retd. @ 7693' MD. Camco TRDP-1A-SSA SSSV @ 1812' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Averaqe Production or Iniection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil__ X Gas__ Suspended__ Service _Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. PeterNezati. k. ~/// / Questions? Carl Peter Nezaticky 659-7224 Title: Wells Team Leader Date Prepared b,v Sharon AIIsup-Drake 263-4612 SCANNED AUG 0 9 2002 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE PI-IILI',IPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1 (2K-15 (W4-6)) WELL JOB SCOPE JOB NUMBER 2K-15 ANN-COM M 0727021646.17 DATE DAILY WORK UNIT NUMBER 07/28/02 CEMENT TOP JOB DAY OPERATION COMPLETE J SUCCESSFUL KEY PERSON SUPERVISOR 1 YESI YES DS-CULPEPPER NEZATICKY FIELD AFC# CC# DALLY COST ACCUM COST Signed ESTIMATE WCW.K02.KR9 $4,000.00 $4,100.00 9.2K Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSII 0 PSI 0 PSI DALLY SUMMARY PUMPED 5 BBL OF ARTIC SET 1 CEMENT INTO SURFACE PIPE X CONDUCTOR ANNULUS.[WH Maintenance] TIME LOG ENTRY 10:45 DS ON LOCATION. MIRU 11:00 START MIXING CEMENT - ARTIC SET 1 @ 15.8 PPG. 11:05 PUMPED 5 BBL OF CEMENT. 11:15 WASHED UP. RDMO / IPHILLIPS Alaska, Inc. ~ ASubsidiar/of PHILLIPS PETROLEUM COMPANY APli 501032011300 SSSV (1812-1813, 0D:3.500) Annular Fluid: TUBING (0-7744, 00:3,500, ID:2~992) Reference 7918 Last Tag 6/15100 Mandrel/Valve 1 Date: (2440-2z¢. 1, QD:5.620) CONDUCTOR Gas Lift MandrelNalve 2 (4674-4675, OD:5.620) SUR. CASING PROD. CASING I _..~/Ve!!_T~p~/PROD l_.~i~ Cgm~lt _n: l ~f071~89 L%~t W/O: / TD: 8304 ftKB Angle @ TS: Angle @ TD: Rev Reason Last Update: 46deg@6500 i 41 deg @ 7822 4t deg @ 8304 Pul! PI~g ~dd Data Notes Thread ""';~-;~-~! 62,50 ! H.40 ¢ TUBING Thread EUE*MOD Gas Lift MandreINalve 3 (6026-6027, OD:5.620) Gas Lift Mandrel/Dummy Valve 4 (6776-6777, OD:5.620) Gas Lift Mandrel/Valve 5 (7243-7244, OD:5.793) Gas Lift Mandrel/Dummy Valve 6 (7635~7636, OD:5.793) PBR (7679-7680, OD:3,500) Interval TVD Zone 7824 - 7832 6134 - 6140 I C~4 7934 - 7974 6217 - 6247 i A*4 Comment 2.5" HSD, 60 deg. 4.5" HSC, 180 deg. TMPD MMG~2 VType i V OD i Latch Port SK 0.125 BK 0.188 GLV I 1.0 I SK 0.250 I DMY 1.0 i BK 0.000 I OV I 1.5 i RK i0.188 DMY 1.5 [ RK i0.000 0 Date ~ Vlv Run !Cmnt 6/12/991 Description Camco TRDP-1A-SSA Baker '80-40' w! 10' Stroke Baker !HB' Retr. Baker Pulled XN Plug from 7732' RKB. Schematic updated by J.Peirce. PKR (7693~7694, -- OD:6.151) NiP (7732~7733, OD:3.500) SOS (7743-7744,-- OD:3.500) TTL (7744-7745,-- OD:3.500) Per[ (7824-7832) SCANNED /~UG 0 9 2002 Per[ (7934-7974) ....... SUNDRY NOTICE 10-404 Phillips Kuparuk Well 2K-15 Annular Cement "Top-Job" July 28, 2002 Phillips Alaska, Inc., Kuparuk well 2K-15 top of cement between the surface pipe and conductor (9 5/8" x 16") was measured at 28 feet below grade. Arctic Set I cement (15.8 ppg) was pumped into the annular void (5 bbls) via a hose, filling from the bottom-up. The cement top was brought to the surface of the conductor casing. The State Inspector was notified of the cement job and waived attendance, but will inspect the wellhead post cementing. The field Well Service Report is attached. SCANNED, AUG 0 9 2002 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 24, 20.00 E E C:LO~LM. DOC P.L E W M A T E R IA L U N D ER TH'IS M ARK ER STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Ocerations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Other 2. Name of Operator · ARCO Alaska, Inc. 3, Aaaress P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 119' FNL, 94' FEL, Sec. 11, T10N, RSE, UM At top of productive interval 1410' FNL, 1325' FEL, Sec. 12, T10N, R8E, UM At effective depth 1475' FNL, 1083' FEL, Sec. 12, T10N, R8E, UM At total depth 1494' FNL, 1018' FEL, Sec. 12, T10N, RSE, UM 12. F-esent well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 154 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-15 9. Permit number/approval number "89-89 10. APl number · 5o-103-20113 1 1. Field/Pool Kuparuk River Field/Oil Pool 8304 feet Plugs (measured) None 6494 feet Effective depth: measured 8202 feet Junk (measured) None true vertical 641 7 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6" 176 Sx AS II I 1 5' 1 1 5' Surface 3285' 9-5/8" 1000SxAS III& 3320' 2946' Intermediate 450 Sx Class G Production 8253' 7" 225 Sx Class G 8 2 8 3' 6 4 7 8' Liner Perforation depth: measured 7824'-7832', 7934'-7974' true vertical 61 34'-6140', 6216'-6246' ORIGINAL Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 7744' Packers and SSSV (type and measured depth) Packer: Baker HB @ 7693' · SSSV: Camco TRDP-1A-SSA @ 1812' [~ F 13. Stimulation or cement squeeze summary Perforate 'C' 'Sands on 5/25/97 Intervals treated (measured) ~:.~ 7824'-7832' Treatment description including volumes used and final pressure AJsska 0ii Perforated using HSD charges w/DP charges, 6 SPF, 60° phasing, !p was 850 14. Representative Daily Average Production Or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 355 304 24 780 260 Subsequent to operation 459 350 115 792 235 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 7. I here/I;w~certify that the foregoing is true and correct to the best of my knowledge. Signea Title Wells Superintendent For?404;/-F~ ~:)'~/15"~88 - Date ~'~77 SUBMIT iN I~UPLIdA'~E ARCO Alaska, Inc. KUPARUK RIVER UNIT '~ WELL SERVICE REPORT ~ K1(2K-15(W4-6)) WELL JOB SCOPE JOB NUMBER 2K-15 PERFORATE, PERF SUPPORT 0407970759.3 DA"E DALLY WORK UNIT NUMBER 05/25/97 PERFORATE, PERF SUPPORT 8337 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 (~) Yes O NoI (~) Yes O No SWS-WALSH ~ FIELD AFC# CC~ DAILY COST AOOUM COST ESTIMATE KAWWRK 230DS28KL $5,347 $28,832 Initial Tb.q Press Final Tb_q Press Initial Inner Ann Final Inner Ann, Initial Outer nn , Final Outer Ann 750 PSI 850 PSI I 975 PSI 975 PSII 50 PS10 I 500 PSI DALLY SUMMARY PERFORATED F/7824-7832' ELM W/2.5" HSD DP @ 6 SPF & 60 DEG PHASED. TIME LOG ENTRY 07:30 09:00 MIRU SWS (WALSH & CREW) & LRS. MU GA (2.5" GUN/CCL/WT) TL-21'. PT BOPE TO 2500 PSI & TGSM. RIH TO 7854' ELM. TIE IN TO 10/14/89 SWS GR/DIL & 12/18/89 SWS CBT. PERFORATE F/7824-7832' ELM W/2.5" HSD DP @ 6 SPF & 60 DEG PHASED. POOH. ALL SHOTS FIRED. 11:30 RD & MOVE TO 2K-22. TURN OVER TO PRODUCTION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $147.00 APC $200.00 $6,200.00 DIESEL $0.00 $2,722.00 DOWELL $0.00 $13,753.00 HALLIBURTON $0.00 $423.00 LITTLE RED $800.00 $1,240.00 SCHLUMBERGER. $4,347.00 $4,347.00 TOTAL FIELD ESTIMATE $5,347.00 $28,832.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 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 119' FNL, 94' FEL, Sec. 11, T10N, R8E, UM At top of productive interval 1410' FNL, 1325' FEL, Sec. 12, T10N, R8E, UM At effective depth 1475' FNL, 1083' FEL, Sec. 12, T10N, R8E, UM At total depth 1494' FNL, 1018' FEL, Sec. 12, T10N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 83O4 6494 feet Plugs (measured) feet 6. Datum elevation (DF or KB) RKB 154 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-15 9. Permit number/approval number 89-89 10. APl number 5o-103-20113 11. Field/Pool feet Kuparuk River Field/Oil Pool None Effective depth: measured 8 2 0 2 true vertical 6 41 7 feet Junk (measured) None feet Casing L e n g t h Structural Conductor 8 0' Surface 3 2 8 5' Intermediate Production 8253' Liner Perforation depth: measured 7934'-7974' true vertical 6216'-6246' Size Cemented Measured depth True vertical depth 1 6" 176 Sx AS II 1 15' 1 15' 9-5/8" 1000 Sx AS III & 3320' 2946' 450 Sx Class G 7" 225 Sx Class G 8283' 6478' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 7744' Packers and SSSV (type and measured depth) Packer: Baker HB @ 7693'; SSSV: Camco TRDP-1A-SSA @ 1812' 13. Stimulation or cement squeeze summary Fracture stimulate '^' Sands on 12/22/96 Intervals treated (measured) ORIGINAL 7934'-7974' Treatment description including volumes used and final pressure Pumped 279.4 Mlbs of 20/40, 12/18, and '10/14 ceramic proppant into formation, fD was 4100 psi 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 427 592 52 849 247 Subsequent to operation 647 419 470 863 244 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. Signed .~~ ~~__~.,~,,j, ~~ Title Wells Superintendent Form 10-4'~t I~le~, -"~6/15/88'~- - / Date SUBMI'I~ IN DUPLICATE STATE OF ALASKA ALA'3,..~ OIL AND GAS CONSERVATION COIVi,~.SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,, 1 Status of Well Classification of Service Well OIL [-~ GAS [] SUSPENDED ~ ABANDONED D SERVICE r'-'] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 89-89/9-1091 , , 3 Address 8 APl Number P.O. BOX 100360, Anchorage, AK 99510-0360 50-103-20113 4 Location of well at surface 9 Unit or Lease Name 119' FNL, 94' FEL, SEC 11, T10N, R8E UM i I!~ '©f~S KUPARUK RIVER AtTop Producing Interval i~&*~-TE' j_~ ~ VE?~i,-IF.D' ~ 10 Well Number 1475' FNL, 1082' FEL,SEC 12, T10N, R8E UM 1 ~_ .~' ~ 2K-15 1~i ~. ?~;. ~¢'"- , i~''~'' -{ 11 Fie,d and Poo, '' At Total Depth ~"'~'::;;[ KUPARUK RIVER FIELD 1494' FNL, 1018' FEL, SEC 12, T10N, R8E UM ..... 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 154'I ADL: 25588 ALK: 2674 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. J 15 Water Depth, if offshore 116 No. of Compleiions 10/8/89. 10/13/89. 6/8/90.I NA feet MSLI' 1 . 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set I 21 Thickness of permafrost & 6494' TVD ,8202' MD & 6417' TVD YES ~ NO F--] 1812' feet MDI 1400' APPROX 8304' MD , 22 Type Electric or Other Logs Run DIL/SFL/GR/SP/FDC/CN L/CAL/CBL/GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ,, , 16" 62.5# H~40 SURF 115' 24" 176 SX AS II 9 5/8" 36# J-55 SURF 3320' 12-1/4" 1000 SX AS III, 450 SX CLASS G 7" 26~ J-55 SURF 8283' 8-1/2" 225 SX CLASS G , 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) 3-1/2" 9.3#~ J-55 7744' 7693' 7934' - 7974' W/4-1/2" @ 4 SPF MD 6216' - 6246' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED SEE ATTACHED ADDENDUM 27 PRODUCTION TEST 'Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR iOIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 1 TEST PERIOD ~ FIowTubing Casing Pressure CALCULATED OIL-BBL (~AS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28 CORE DATA Brief description of lithology, po~'osity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARKERS NAME MEAS. DEPTH KUPARUK C TOP 7882' KUPARUK C BOTTOM 8049' KUPARUK A TOP 7822' KUPARUK A BO'I-rOM 7833' 31 LIST OF ATTACHMENTS 6177' 6302' 6132' 6140' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recoVerd and gra~,t¥, GOR, and time of each phase. NA GYRO, FRAC 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Title _AREA DRILLING ENGINEER Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company Well History - Initial Report - Dally Jnsfl'uctiona: Prepare and submit the "Initial Ret~ert" on the first Wednesday after a well Is spudded or workover operations are started. Daily work prior to sPUdding should be summarized on the form giving inclusive dates only. District I County, parish or borough J State ARCO ALASKA INC. { NORTH SLOPE Field ILease or Unit KUPARUK RIVER'UNIT I ADL: 25588 ALK: 2674 Auth. or W.O. no. ITitle AK3706 ~ COMPLETIONS AK JWell no. Operator IARCO W.I. ARCO I 55. 8533 Spudded or W.O. begUnsp[,~) JOate 10/08/89 JHour 00,'00 ]Pri°' status if a W.O. Date and depth as of 8:00 a.m. 04/20/90 ( TD= 8304 PB: 8202 SUPV:DB 9) Complete record for each day reported NORDIC RUNNING 3-1/2" CSG 7"@ 8283' MW:10.4 NaCl/Br MOVE RIG FROM 2K-14 TO 2K-15. ND DUMMY TREE NU BOPE. TEST ACCUMULATOR BOTTLES & BOPE. RU HLS, MU GUN #l-KINK IN LINE, REHEAD, TEST LUBE TO 1200 PSI. RIH W/GUN#l-20', 4-1/2" CSG FUN, 4 SPF, 180 DEG, ORIENTED 125 DEG CCW FROM HISIDE, ALTERNATING 36 GM DP & 30 GM BH SHOTS, TIE IN TO DIL & CBT. PERF A SAND FROM 7954'-7974', READOUT SHOWED SHOTS @ 128 DEG CCW FROM HI SIDE. POH ASF. RIH W/GUN#2-20' SAME AS ABOVE, SHOTS ORIENTED 123 DEG CCW FROM HISIDE. TIE IN & PERF A SANDS FROM 7934'-7954', READOUT SHOWED SHOTS @ 122 DEG CCW FROM HISIDE POH ASF. RD HLS RU DRILLING NIPPLE & FLOW LINE. RU FLOOR & RUN 3-1/2" COMP ASY DAILY:S57,186 CUM:$782,078 ETD:S782,078 EFC:$1,332,000 The above is co~.,~ct or erin preparation ~d}di~tribution, F_~ see Procedures Man lu~ection 10, IDate / 7/~/g~ I Tit~ C~ Drilling. Pages 86 and 87. / ./ AR3B-459-1-D Number all daily well histor~ forms consecutively as they are prepared for each well. iPage no. ARCO Oi, and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used tor reporting the entire operation if space is available. District / or Parish ARCO ALASKA ISfC. C°untYNoRTH SLOPE Field I Lease or Unit KUPARUK RIVER UNIT ADL: 25588 ALK: 2674 Auth. or W.O. no. ~Title AK3706 I COMP LETIONS IAccounting cost center code State AK Well no. 2K-15 Operator ARCO A.R.Co. W.I. 55. 8533 Spudded or W.O. begun Date SPUD 10/08/89 Date and depth as of 8:00 a.m. 04/21/90 (10) TD: 8304 PB: 8202 SUPV:DB Complete record for each day reported NORDIC #1 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our J Prior status if a W.O. I 00:00 I RIG RELEASED 7"@ 8283' MW:10.4 NaCl/Br CONT. TEST CONTROL LINE, CONT. RIH W/ 3-1/2" COMPLETION, MU TBG HGR, ATTACH CONTROL LINE, TEST CONTROL LINE, LAND TBG, RILDS, DROP BALL, PRESS TBG TO 2500 PSI TO SET PKR, PRESS ANNULUS TO 1000 PSI, BLEED ANNULUS, BLEED TBG TO 1600 PSI, BOLDS, PU & SHEAR PBR, BLEED TBG, RELAND TBG, RILDS, PRESS ANNULUS & TBG TO 1000 PSI, CLOSE SSSV AND TEST, OPEN SSSV, BLEED PRESS, SET BPV, ND BOPE, NU TREE AND TEST TO 5000 PSI, PRESS TEST ANNULUS TO 2500, PRESS TBG TO 3750 AND SHEAR OUT BALL, REVERSE CIRC. 6 BBLS DIESEL INTO.ANNULUS, BULLHEAD 2 BBLS DIESEL DOWN TBG, RELEASE RIG 1400 4/20/90 DAILY:S144,039 CUM:$926,117 ETD:S926,117 EFC:$1,332,000 Old TD New TD PB Depth Released rig Date I K nd of rig Classifications (oil, gas, etc.) I Type completion (single, dual, etC.) Producing method I Official reservoir name(s) I Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest 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 ,~.~rect sFeO; ~Orro~ e~uerPe ~ r ~ ,aOrta, % ~: ~ Ul, ~o, n, ~ - (~ Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively I Page no. as they are prepared for each we I, Dlvl~on of AtlantlcRIchfleldCompa~Y ADDENDUM WELL 2~15 5/9/90 Frac Kuparuk "A' sand perfs 7934'-7974' 180 deg oriented 124 deg ccw in nine stages as follows. Stage 1: Stage 2: Stage 3: Stage 4: Stage 5: Stage 6: Stage 7: Stage 8: Stage 9: Pmp 200 bbls YF240 Gel water prepad @ 25 bpm 7000-4100 psi 60 bbls YF240 Ge] water prepad @ 20bpm 3550-3700 psi 45 bbls YF240 Gel water prepad @ 15 bpm 3200-3580 psi 30 bbls YF240 Gel water prepad @ 10 bpm 3100-3500 psi 73 bbls slick diesel flush @ 20-25 bbm 3100-4500 psi 1114 bbls YF240 GW pad @ 25 bpm 3700-4100-4050 psi 110 bbls YF240 w/2 ppg 16/20 Carbolite @ 25 bpm 4065-4020psi 112 bbls YF240w/4 ppg 16/20 Carbolite @ 25 bpm 4020-4000 psi 130 bbls YF240 w/6 ppg 16/20 Carbolite @ 25 bpm 4000-3995 psi 160 bbls YF240 w/8 ppg 16/20 Carbolite @ 25 bpm 4000-4150 psi 79 bbls YF240 w/10 ppg 12/18 Carbolite @ 25 bpm 4150-4800 psi 73 bbls Slick Diesel @ 4800-4000 psi Fluid to recover: 2020 bbls Sand in zone: 112,536 lbs Sand in csg: 658 lbs Avg pressure: 4100 psi Date SUB. SURFACE DIRECTIONAL SURVEY F~UIDANCE ~'~ONTINUOUS r-~OOL MICROFILMED Company ARCO ALASKA, INC. Well Name 2K-15 (119' FNL~94' FEL~SEC ll, Field/Location KUPARUK, NORTH SLOPE, ALASKA TION,R8E~UM) Job Reference No: 73629 COX Date_ 18-DEC-89 Computed By;, SINES SCHLUMBERGER GCT gIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. 2K-15 KUPARUK NORTH SLOPE, ALASKA SURVEY DATE: 18-DEC-89 ENGINEER: M.L.COX METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH T2 OEG 3T MIN EAST COMPUTATION D,~TE: 5-JAN-90 PAGE 1 ARCO ALASKA INC. 2K-15 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 1B-DEC-Bg KELLY BUSHING 'ELEVATION: 154.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH ENGINEER: M.L.COX TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG 0.00 0.00 -154.00 0 0 N 0 0 E 100.00 100.00 -54.00 0 10 N 6,2 2,¢J W 200.00 200.00 46.00 0 13 N 47 19 W 300.00 300.00 146.00 0 15 N 47 24' W 400.00 400.00 246.00 0 19 N 58 15 W 500.00 500.00 346.00 0 22 N 63 22 W 600.00 599.99 445.99 0 25 N 69 38 W 700.00 699.9'9 545.99 0 31 N 74 0 W 800.00 799.99 645.99 0 32 N 77 3 W 900.00 899.98 745.98 0 2.3 S 60 2 W VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 1000.00 999.98 845.98 0 46 1100.00 1099.96 945.96 1 35 1200.00 1199.82 1045.82 4 23 1300.00 1299.43 1145.43 5 40 1400.00 1398.52 1244.52 10 1 1500.00 1496.47 1342.47 12 43 1600.00 1593.20 1439.20 17 1 1700.00 1687.52 1533.52 21 52 1800.00 1779.37 1625.37 24 4 1900.00 1869.94 1715.94 26 16 O.O0 0.00 0.00 N 0.00 E -0.05 0.00 0.02 N 0.05 W -0.37 0.00 0.24 N 0.31 W -0.74 0.00 0.52 N 0.61 W -1.21 0.00 0.82 N 1.01 W -1.79 0.00 1.11 N 1.53 W -2.45 0.20 1.39 N 2.13 W -3.30 O.OZ 1.65 N 2.94 W -4.21, 0.00 1.88 N 3.82 W -4.92 0.28 1.81 N 4.58 W ZO00.O0 1959.35 1805.35 26 53 ZlO0.O0 2047.07 1893.07 31 2 Z200.O0 2131.80 1977.80 32 41 2300.00 2214.10 2060.10 36 23 2400.00 2294.11 2140.11 37 29 2500.00 2371.04 2217.04 42 7 2600.00 2444.25 2290.25 43 48 2700.00 2514.93 2360.93 45 4Z 2800.00 2584.64 2430.54 45 52 2900.00 2654.17 2500.17 46 0 S 7 18 E S 29 28 E S 46 35 E S 48 39 E S 51 23 E S 55 49 E S 59 42 E S 61 29 E S 61 37 E S 63 59 E 3000.00 2723.63 2569.63 45 59 3100.00 2793.20 2639.20 45 54 3200.00 2862.84 2708.84 45 52 3300.00 2932.45 2778.45 45 46 3400.00 3002.66 2848.66 45 14 3500.00 3072.96 2918.96 45 23 3500.00 3143.14 2989.14 45 32 3700.00 3213.20 3059.20 45 32 3800.00 3293.42 3129.42 45 17 3900.00 3353.77 3199.77 45 lB -4.94 0.95 1.12 N -3.79 1.59 0.64 S 0.52 2.33 4.52 S 8.56 Z.O0 10.40 S 20.69 4.93 18.98 S 39.75 2.43 30.79 S 64.21 4.5'7 44.14 S 96.61 4.94 60.37 S 135.41 0.98 177.13 Z.08 S 64 9 E 221.43 S 66 21 : 268.95 S 67 26 I~ 321.82 S 67 5 E 378.33 S 66 58 E 438.03 S 69 0 5 501.65 S 59 54 E 569.67 S 70 49 E 640.34 S 70 31 : 712.01 S 70 19 ~ 783.82 S TO 14 E 855.70 S 70 14 E 927.47 S 70 14 E 999.17 S 70 23 E 1070.90 S 71 47 E 1142.09 S 7Z 19 E 1213.20 S 72 27 E 1Z84.44 S 72 42 E 1355.79 S 73 6 E 1426.99 S 73 18 5 1498.06 0.00 N 0 0 E 0.05 N 61 45 W 0.40 N 52 11 W 0.80 N 49 47 W 1.30 N 50 44 W 1.89 N 53 55 W 2.54 N 56 48 W 3.37 N 60 43 W 4.26 N 63 50 W 4.93 N 68 26 W 4.82 W 4.95 N 76 57 W 4.17 W 4.22 S 81 15 W 0.87 W 4.60 S 10 52 W 5.71 E 11.86 S 28 46 E 15.73 E 24.65 S 39 39 E 32.02 E 44.42 S 46 7 E 53.46 E 69.33 S 50 27 E 82.33 E 102.09 S 53 45 E 79.1,3 S 117.11 E 141.34 S 55 57 E 98.60 S 154.73 E 183.48 S 57 30 E 1.36 4.82 1.56 I .86 2.74 3.51 3.27 0.58 0.57 0.23 118.10 S 195.05 E 228.01 S 58 48 E 138.37 S 238.50 E 275.73 S 59 53 f 158.99 S 287.44 E 328.48 S 61 3 E 180.89 S 339.80 E 384.95 S 61 58 E 204.40 S 395.00 E 444.75 S 62 38 E 228.37 S 454.15 E 508.34 S 63 18 E 252.25 < 517.95 E 576.11 S 64 2 E 275.8'9 S 584.6I E 646.44 S 64 44 E 299.56 $ 652.29 E 717.79 S 65 20 E 323.71 S 719.98 E 789.40 S 65 47 E 0.21 0.16 0.21 0.50 0.78 0.33 0.38 0.32 0.32 0.33 348.0Z S 797.68 E 861.14 S 66 10 E 372.31 S 855.29 E 932.81 S 66 29 E 396.61 S 922.81 E 1004.43 S 66 45 E 420.85 S 990.39 E 1076.10 S 66 59 E 444.03 S 1057.72 E 1147.14 S 67 14 E 465.89 S 1125.39 E 1218.02 S 67 31 E 487.47 S 1193.29 f 1289.02 S 67 47 E 508.87 S 1261.36 E 1360.14 S 68 2 E 529.80 S 1329.41 E 1431.10 S 68 16 E 550.33 S 1397.45 E 1501.91 S 68 30 E COMPUTATION BATE: 5-JAN-g0 PAGE 2 ARCO ALASKA INC. 2K-15 KUPARUK NORTH SLOPE, ALASKA DATE DF SURVEY: 18-DEC-89 KELLY BUSHING ELEVATION: 154,00 FT ENGINEER: M.L.COX INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUS-SEA COURSE MEASURED YERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET BEG/lO0 FEET FEET FEET BEG MIN 4000.00 3424.17 3270.17 45 10 4100.00 3494.82 3340.82 44 56 4200.00 3565.72 3411.72 44 49 4300.00 3636.20 3482.20 45 45 4400.00 3705.67 3551.67 ~6 1 4500.00 3775.20 3621.20 45 55 4600.00 3844.80 3690.80 45 50 4700.00 3914.67 3760.67 45 31 4800.00 3985.08 3831.08 44 58 4900.00 4056.03 3902.03 44 40 S 73 30 E 1569.07 S 73 42 E 1639.83 S 73 52 E 1710.33 S 71 50 E 1781.27 S 71 25 E 1,35.3.18 S 71 46 E 1925.04 S 72 12 E 1996.84 S 72 21 E 2068.38 S 69 39 E 2139.35 S 69 56 E 2209.74 0.31 0.47 0.30 2.22 0.27 0.32 0.29 0.86 0.63 0.40 5'70.66 S 1465.50 E 1572.68 S 68 43 E 590.65 S 1533.39 E 1643.21 S 68 56 E 610.33 S 1601.10 E 1713.49 S 69 8 E 630.95 S 1668.98 E 1784.26 S 69 17 E 653.89 S 1737.15 E 1856.14 S 69 22 E ') 676.60 S 1805.34 E 1927.96 S 69 27 E 698.82 S 1873.62 E 1999.70 S 69 33 E 720.48 S 1941.80 E 2071.16 S 69 39 E 743.64 S 2008.91 E 2142.13 S 69 41 E 768.04 S 2075.03 E 2212.61 S 69 41 E 5000.00 4137.31 3973.31 44 22 5100.00 4199.03 4045.03 44 1 5200.00 42'70.85 4116.85 44 32 5300.00 4341.21 4187.21 45 43 5400.00 4411.07 4257.07 45 39 5500.00 4481.01 4327.01, 45 35 5600.00 4551.01 4397.01 45 32 5700.00 4621.08 4467.08 45 29 5800.00 4691.27 453'7.27 45 18 5900.00 4761.82 4607.82 44 59 S TO 22 E 2279.80 S 70 50 E 234'9.44 S 70 15 E 2419.00 S 67 43 E 2489.87 S 67 54 E 2561.17 S 68 5 E 2632.42 S 68 10 E 2703.60 S 68 20 E 2774.75 S 68 12 E 2845.77 S 68 18 E 2916.44 0.50 0.43 2.71 0.21 0.15 0.13 0.17 0 0.14 0.50 791.87 S 2140.99 E 2282.74 S 69 42 E 815.01 S 2206.72 E 2352.42 S 69 44 E 837.96 S 2272.42 E 2422.00 S 69 46 E 863.82 S 2338.59 E 2493.03 S 69 44 E 890.86 S 2404.83 E 2564.54 S 69 40 E 917.66 S 2471.10 E 2635.99 S 69 38 E 944.27 S 2537.36 E 2707.37 S 69 35 E 970.70 S 2603.64 E 2778.70 S 69 33 E 997.08 S 2669.79 E 2849.91 S 69 31 E 1023.35 S 2735.62 E 2920.77 S 69 29 E 6000.00 4832.81 4678.31 44 37 6100.00 4904.03 4750.03 44 38 6200.00 4975.13 4821.13 44 45 6300.00 5045.72 4891.72 45 24 6400.00 5115.88 4961.88 45 43 6500.00 5184.91 5030.91 46 25 6600.00 5254.30 5100.30 45 37 6700.00 5324.45 5170.45 45 23 6800.00 5394.52 5240.52 45 36 6900.00 5464.38 5310.38 45 48 S 68 24 E 2986.66 S 68 29 E 3056.68 S 69 12 E 3126.84 S 72 22 E 3197.62 S 75 3 E 3268.86 S 80 56 E 3340.78 S 81 31 E 3411.96 $ 81 45 5 3482.34 S ~1 53 E 3552.77 S 81 57 E 3623.39 0.20 0.30 1.72 1.45 5.42 1.07 0.83 0.42 0.15 0.74 1049.35 S 2801.07 E 2991.18 S 69 28 E 1075.18 S 2866.35 E 3061.37 S 69 26 E 1100.76 S 2931.86 E 3131.68 S 69 25 E 1123.97 S 2998.76 E 3202.48 S 69 27 E 1144.44 S 3067.01 E 3273.57 S 69 32 E 1158.73 S 3137.89 E 3345.00 S 69 44 E 1169.65 S 3209.06 E 3415.58 S 69 58 E 1179.99 $ 3279.58 E 3485.40 S 70 13 E 1190.16 S 3350.19 E 3555.31 S 70 27 E 1200.23 S 3421.04 E 3625.47 S 70 40 E 7000.00 5534.01 5380.01 45 52 7100.00 5603.72 5449.72 45 34 7200.00 5673.94 5519.94 45 7300.00 5744.42 5590.42 45 5 7400.00 5816.30 5662.30 42 22 7500.00 5890.83 5736.83 41 32 7600.00 5965.83 5811.83 41 30 7700.00 6040.77 5886.77 41 26 7800.00 6115.74 5961.74 41 24 7900.00 6190.61 6036.61 41 33 S 82 7 E 3694.19 $ ~2 ZZ E 3764.89 S 82 35 E 3335.04 S 82 47 E 3904.88 S 82 20 E 3973.33 S ~2 33 E 4039.03 S 82 24 E 4104.17 S 79 55 E 4169.62 S 76 58 E 4235.45 S 75 47 E 4301.61 0.34 0.80 0.20 0.52 3.60 0.67 1.17 2.03 1.79 0.53 !210.22 S 3492.11 E 3695.87 S 70 53 E 1219.92 S 3563.15 E 3766.20 S 71 6 E 1229.25 S 3633.74 E 3836.03 S 71 19 E 1238.29 S 3704.10 E 3905.60 S 71 31 E 1247.23 S 3773.02 E 3973.83 S 71 42 E 1256.06 S 3839.10 E 4039.36 S 71 53 E 1264.60 $ 3904.69 E 4104.37 S 72 3 E 1274.63 S 3970.13 E 4169.73 S 72 12 E 1287.87 S 4034.96 E 4235.51 S 72 18 E 1303.69 S 4099.34 E 4301.65 S 72 21 E COMPUTA'TION DATE: 5-JAN-gO PAGE .3 ARCO ALASKA INC. 2K-15 KUPARUK NORTH SLOPE, ALASKA DATE 3F SURVEY: 18-DEC-8g KELLY ~USHING ELEVATION: 154.00 FT ENGINEER: M.L.COX INTERPOLATED VALUES FOR EVEN iO0 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG M.IN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ,. DEPARTURE SECTION SEVERITY NORTH/SOUTH ELS'T/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000.00 6265.50 6111.50 41 26 8100.00 6340.55 6186.55 41 16 8ZO0.O0 6415.71 6261.71 41 16 8300.00 6490.86 6336.86 41 16 8304.00 6493.87 6339.87 41 16 S 75 38 E 4367.79 S 73 41 E 4433.81 S 73 41 E 4499.76 S 73 41 E 4565.72 S 73 41 E 4568.36 0.57 0.00 0.00 0.00 0.00 1320.11 S ~163.55 E 4357.82 S 72 24 E 1337.41 S 4227.31 E 4433.83 S 72 27 E 1355.96 S 4290.62 E 4499.78 S 72 28 E 1374.50 S 4353.92 E 4565.73 S 72 29 E 1375.24 S 4356.45 E 4568.37 S 72 29 E C]MPUTATION DATE: 5-JAN-90 ARCO ALASKA INC. ZK-15 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 18-DEC-89 KELLY ~USHING ELEV,~TION= 154.00 FT ENGINEER: M.L.COX INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH E,~ST/WEST DIST. AZIMUTH FEET DEG/IOO FEET FEET FEET DEG MIN O.O0 0.00 -154o00 0 0 1000.00 999.98 845.98 0 46 2000.00 1959.35 1805.35 26 53 3000.00 2723.63 2569.63 45 59 4000.00 3424.17 3270.17 45 10 5000.00 4127.31 3973.3! 44 22 6000.00 4832.81 4678.81 44 37 7000.00 5534.01 5380.01 45 52 8000.00 6265.50 6111.50 41 26 8304.00 6493.87 6339.87 41 16 N 0 0 E 0.00 S 7 18 E -4.94 S 64 9 E 221.43 S 70 14 E 855.70 S 73 30 E 1569.07 S 70 22 E 2279.80 S ,68 24 E 2986.66 S 82 7 E 3694.19 S 75 38 E 4367.79 S 73 41 I 4568.36 0.0 0 0.95 1.36 0.21 0.31 0.50 0 0.34 0..57 0.00 0.00 N 0.00 E 0.00 N 0 0 E 1.12 N 4.82 W 4.95 N 76 57 W 118.10 S 195.05 E 228.01 S 58 48 E 348.02 S 787.68 E 861.14 S 66 10 E 570.66 S 1465.50 E 15T2o68 S 68 43 E 791.87 S 2140.99 E 2282.74 S 69 42 E 10,49.35 S 2801.07 E 2991.18 S 69 28 E 1210.22 S 3492.11 E 3695.87 S 70 53 E 1320.11 S 4163.55 E 4.367.82 S 72 24 E 1375.2~, S 4356.45 E 4568.37 S 72 29 E COMPUTATION DATE: 5-JAN-90 PAGE 5 ARCO ALASKA INC. ZK-15 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 18-DEC-89 KELLY BUSHING ELEVATION: 154.00 FT ENGINEER: M.L.COX INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE ME4SURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTIC&L DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0o00 0.00 -154.00 0 0 N 0 0 E 15¢.00 154.00 0.00 0 13 N 47 7 W 254.00 254.00 100.00 0 14 N 47 39 W 354.00 354.00 200.00 0 17 N 51 50 W 454.00 454.00 300.00 0 21 N 61 6 W 554.01 554.00 400.00 0 22 N 64 36 W 654.01 654.00 500.00 0 30 N 72 4,6 W 754.01 754.00 600.00 0 31 N 75 31 W 854.02 854.00 700.00 0 26 S 79 0 W 954.02 954.00 BO0.O0 0 24 S 19 40 W 0.00 0.00 0.00 N 0.00 E -O.ZZ 0.05 0.13 N 0.19 W -0.56 0.00 0.39 N 0.47 W -0.98 0.00 0.69 N 0.81 W -1.51 0.00 0.98 N 1.28 W -2.14 0.00 1.27 N 1.84 W -2.89 0.00 1.53 N 2.55 W -3.79 0.00 1.78 N 3.41 W -4.67 0.88 1.94 N 4.28 W -5.05 0.81 1.57 N 4.81 W 0.00 N 0 0 E 0.23 N 55 48 W 0.61 N 50 24 W 1.06 N 49 ¢1 W 1.61 N 52 28 W 2.24 N 55 26 W 2.97 N 58 58 W 3.85 N 62 28 W 4.70 N 65 40 W 5.06 N 71 56 W 1054.03 1054.00 900.00 1 2 1154.08 1154.00 1000.00 3 4 1254.37 1254.00 1100.00 5 8 1354.93 1354.00 1200.00 ? 41 1456.54 1454.00 1300.00 11 51 1559.23 1554.00 1400.00 14 57 1664.11 1654.00 1500.00 19 56 1772.24 1754.00 1600.00 23 48 1882.27 1854.00 1700.00 25 51 1994.00 1954.00 1800.00 26 48 S 19 24 E -4.47 0.49 S 40 2 E -2.12 3.66 S 48 37 E 4.65 1.32. S 48 55 E 14.28 4.94 S 54 25 E 30.95 1.52 S 58 28 E 53.31 5.5Z S 60 51 E 84.03 5.?0 S 61 37 E 124.35 0.95 S 63 30 E 169.47 2.80 S ,54 8 E 218.74 0.91 0.28 N 4.60 W 4.61 N 86 29 W 2.34 S 2.95 W 3.77 S 51 34 W 7.57 S 2.50 E 7.97 S 18 18 E 14.53 S 10.41 E 17.87 S 35 37 E 25.51 S 24.45 E 35.33 S 43 47 E 38.39 S 43.84 E 58.27 S 48 47 E 54.18 S 71.0~ E 89.38 S 52 41 E 73.77 S 107.20 E 130.13 S 55 28 E 95.16 S 1'~T.79 E 175.77 S 57 13 E 116.91 S 192.60 E 225.3! S 58 44 E 2108.06 2054.00 1900.00 31 26 2226.49 2154.00 2000.00 33 29 2349.72 2254.00 2100.00 36 50 2477.26 2354.00 2200.00 41 6 2613.54 2454.00 2300.00 44 14 2756.02 2554.00 2400.00 45 50 2899.75 2654.00 2500.00 46 0 3043.67 2754.00 2600.00 45 55 3187.30 2854.00 2700.00 45 51 '~ 3330.82 2954.00 2800.00 45 31 S 66 37 E S 67 25 E S 66 53 E S 68 32 E S 70 6 E S 70 45 E S 70 19 E S 70 15 E S 70 13 E 273.04 4.31 336.22 4.47 407.86 0.37 486.62 5.39 579.04 4.03 680.48 0.21 783.54 0.22 ~87.06 0.05 990.06 0.37 1.57 S 70 39 E 1092.93 140.03 S 242.27 E 279.82 S 59 58 E 164.54 S 300.79 E 342.8.5 S 61 19 E 192.49 S 367.11 E 414.52 S 62 ZO f 222.90 S 440.12 E 493.35 S 63 8 E 255.48 S 526.76 E 585.44 S 64 8 E 289.11 S 622.52 E 686.38 S 65 5 E 323.65 S 719.81 6 789.22 S 65 47 E 358.64 S 817.22 E 892.45 S 66 18 E 393.53 S 914.23 E 995.33 S 66 43 E 428.21 S 1011.16 E 1098.10 S 67 3 E 3473. O0 3054.00 2900.00 45 22 3615.50 3154.00 3000.00 45 32 3758.16 3254.00 3100.00 45 22 3900.33 3354.00 3200.00 45 18 4042.27 3454.00 3300.00 45 4 4183.47 3554.00 3400.00 44 49 4325.56 3654.00' 3500.00 45 59 4469.53 3754.00 3600.00 45 55 4613.20 3854.00 3700.00 45 48 4755.98 39 54.00 3800.00 45 11 S 72 14 E 1193.98 S 72 28 E 12.95.50 S 72 5!' E 1397.24 S 73 18 E 1498.29 S 73 35 E 1599.02 S 73 52 E 1698.68 S 71 23 E 1799.61 S 71 39 E 1903.15 S 72 16 E 2006.30 S 70 43 E 2108.21 0.35 0.46 0.46 0.33 0 0.17 1.03 0.27 0.43 2.99 460.04 S 1107.09 E 1198.87 S 67 26 E 490.80 S 1203.84 E 1300.04 S 67 49 E 521.11 S 1300.96 E 14,01.45 S 68 10 E 550.40 S 1397.68 E 1502.15 S 68 30 E 579.14 S 1494.22 E 1602.53 S 69 49 E 607.09 S 1589.91 E 1701.87 S 69 6 E 636.74 S 1686.38 E 1802.59 S 69 19 E 669.73 S 1784.56 f 1906.09 S 69 26 E 701.71 S 18~32.63 E 2009.15 S 69 33 E 733.04 S 1979.61 E 2110.97 S 69 41 E COMPUTATION DATE: 5-JAN-g0 PAGE 6 ARCO ALASKA INC. 2K-15 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 1B-DEC-Bg KELLY BUSHING ELEVATION: 15.4.00 FT ENGINEER: M.L.COX INTERPOLATED VALUES FOR EVEN 100 FEET CF SU.B-SEA DEPTH TRUE SUB-SEA COURSE MEASURED YERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST' DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET OEG MIN 489'}'.15 4054.00 3900.00 44 40 5037.29 4154.00 4000.00 44 12 5176.43 4254.00 4100.00 44 10 5318.31 4354.00 4200.00 45 42 5461.40 4454.00 4300.00 45 37 5604.26 4554.00 4400.00 45 31 5746.95 4654.00 4500.00 45 26 5888.95 4754.00 4600.00 45 2 6029.75 4854.00 4700.00 44 35 6170.27 4954.00 4800.00 44 41 S 69 55 E 2207.74 $ 70 34 E 2305.82 S 70 43 E 2402.52 S 67 44' E 2502.93 S 68 i E 2604.93 S 68 lO E 2706.64 S 68 16 E 2808.13 S 68 18 Fi:_ 2908.65 S 58 24 E 3007.50 S 68 43 E 3105.96 0.41 0 1.31 0.31 0.21 0.14 0.67 0.38 0.02 0.62 7,57.35 S 2073.15 E 2210.61 S 69 41 E 800.53 S 21~55.53 E 2308.78 S 69 43 E 832.44 S 2256.88 E 2405.51 S 69 45 E 868.79 S 2350.72 E 2506.13 S 69 43 E 907.35 S 2445.53 E 2608.42 S 69 39 E 945.,40 S 2540.19 E 2710.41 S 69 35 E 983.08 S ,2634.74 E 2512.17 S 69 32 E 1020.47 S 2728.36, E 2912.96 S 69 30 E 1057.04 S 2820.49 E 3012.06 S 69 27 E 1093.24 S 2912.34 E 3110.77 S 69 2:5 E 6311.80 5054.00 4900.00 45 24 6455.10 5154.00 5000.00 46 34 6599.57 5254.00 5100.00 45 37 6742.12 5354.00 5200.00 45 31 6885.13 5454.00 5300.00 45 45 7028.71 5554.00 5400.00 45 55 7171.64 5654.00 5500.00 45 Zl 7313.57 5754. O0 5600. O0 45 1 7450.69 5854.00 5700.00 41 46 7584.20 5954.00 5800.00 41 29 S 72 36 E 3206.03 S 79 22 E 3308.52 S 81 31 E 3411.66 S 81 48 E 3511.98 S 81 57 E 3612.87 S 82 1Z E 3714.53 S 82 31 E 3815.17 S BZ 4~ ~ 3914.34 S 82 22 E 4006.74 S 82 37 E 4093.86 1.07 4.85 0.84 0.21 0.52 0.23 0.28 0.89 0.12 1.02 1126.51 S 3006.77 E 3210.87 S 69 28 E 1153.26 S 3105.80 E 3313.00 S 69 38 E 1169.60 S 3208.76 E 3415.28 S 69 58 E 1184.2'9 S 3309.29 E 35.14.82 S 70 19 E 1198.74 S 3410.49 E 3615.02 S 70 38 E 1213.03 S 3512.53 E 3716.09 S 70 57 E 1226.63 S 3613.74 E 3816.25 S 71 15 E 1239.49 S 3713.63 E 3915.02 S 71 33 E 1251.75 S 3806.61 E 4007.14 S 71 48 E 1263.21 S 3894.31 E ,4094.07 S 72 2 E 7717.65 6054.00 5900.00 41 29 7851.06 6154.00 6000.00 41 34 7984.66 6254.00 6100.00 41 29 8117.90 6354.00 6200.00 41 16 8250.95 6454.00 6300.00 41 16 8304.00 6493.87 6339.87 41 16 S 79 23 E 4181.22 S 76 7 E 4269.19 S 75 40 E 4357.66 S 73 41 E 4445.61 S 73 41 E 4533.37 S 73 41 E 4568.36 1.88 0.56 0.38 0.00 0.00 O.O0 1276.71 S 3981.63 E 4181.31 S 72 13 E 1295.79 S 4067.84 E 4269.24 S 72 20 E 1317.59 S 4153.7Z E 4357.68 S 7Z 24 E 1340.73 S 4238.64 E 4445.63 S 7Z Z7 E 1365.41 S 4322.87 E 4533.39 S 72 28 E 1375.24 S 4356.45 E 4568.37 S 7Z 29 E ARCO ALASKA INC. 2K-15 KUPARUK NORTH SLOPEr ALASKA ~ARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A GCT LAST READING PBTD 7" CASING TO COMPUTATION DATE: 5-JAN-g0 PAGE T DATE OF SURVEY: KELLY BUSHING ELEVATION: ENGINEER: INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = IZg· FNL ~ 94' FELt SEC11 TZON RSE MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA 18-DEC-S9 154.00 FT M.L.COX RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3320.00 2946.43 2792.43 425.6,3 S 7822.00 6132.24 5978.24 1291.7.3 S 7833.00 6140.48 5986.48 1292.94 S 7882.00 6177.14 6023.14 1300.76 S 8049.00 6302.27 6148.27 1328.30 S 8093.00 6335.30 6181.30 1336.11 S 8202.00 5417.21 62,53.21 1356.33 S 8283.00 6478.09 6324.09 1371.35 S 8304.00~ 649 3.87 c.~ 6339.87 1375.24 S 1003.87 E 4049.13 E 4056.21 E 4087.77 E 4194.88 E 4222.88 E 4291.88 E 4343.16 E 4356.45 E ARCO ALASKA INC. 2K-15 KUPARUK NORTH SLOPE, ALASKA 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KU@ARUK A BASE KUPARUK A POTD 7" CASING TD COMPUTATION DATE: 5-JAN-90 r PAGE 8 DATE DF SURVEY: 18-DEC-8g KELLY BUSHING ELEVATION: 154.00 FT ENGINEER: M.L.CDX STRATIGRAPHIC SUMMARY' ~~~ SURFACE LOCATION = 119e FNL & 94' FEL~ SEC11 TION RBE MEASURED OEPTH TVO BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAS'T/WEST ,3320.00 2946.43 2792.43 425.63 S 7822.00 6132.24 5978.24 1291o23 S 7833.00 6140.48 5986.48 1292.94 S 7882.00 6177.14 6023.14 1300.76 S 8049.0D 6302.27 61~8.27 1328.30 S BZOZ.O0 6417.Z1 6263.21 1356.33 S 8283.00 6478.09 6324.09 1371.35 S 8304.00 6493.87 6339.87 1375.24 S 1003.87 E 4049.13 E 4056.21 E 4087.77 E 4194.88 E 4291.88 E 4343.16 E 4356.45 E FINAL WELL LOCATION AT TD: TRUE SU3-SEA MEASURE)3 VERTICAL VERTICAL DEPTH DEPTH DEPTH 8304. 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H~.4--.q-¢~-4--f4-b4 4-- 4-.44-4-, 4~-4-~. -H-4-&44--.~4--Z.-..4..LL.: ..... ~..4...~..t...4...LL~...:...t. ~..:..: ..... ~..i..i...~..; "N!+ 'J'N'f' "ff't~-J'ff-i"?J-~ dl-~ ~'" fi-fi-f-'-tH"t-iff'ft'"tf'f'+" 'H"i'+" 'H'"~'i ..... ~-1-?!- -1-~,-~-- ,-1-1-~-!-1-~-~--~-- -¢-~.~-e- - ; r i ~-~-~- -'1-~-~-~- -1-~-~-T'- "~"~'*--~" "~-'-*"1"1-'1 'TI"! -*'-' --'1--I~ --1''-' -1 '---, ' · ' - t" - "1 '1"' '~ ....... ,"' ..~ j-4..~-. ~-.b~-...~4..~_$.~.~..~.~._ ..~_~..4,_!2 _b+.¢.~... ~_4..4.4_4.._ ..i...~..¥..i.._ .~_~_+Z -.~..~--~..~ ..... N+.¥-4.-~--~-.~ · ,~..i-.- -.~-~-.4 -4- - ~ .-~ ..f 4~-$.~-~-~4--,..44-~4-44-4..--+.4-4-4-4M-$$.4-~4~$--j-~4,..H.-4-~-¢-4-4-~, .-i-4.-4..~--~-.4-4-.4.--..4-4..4...i.4-.i.,L4-.i..i i..i...i-~.~.i.4... -~ff--~-, --~-?-~---~--~-~-- -~-~--~--~---~--?--~--~--T.~--?-T--?-,-?-~-~--~ ...... ~.~--! ..... !~..~-?- -l--ff--!'-.t-,~-~--? h+' '--+-.~'?-~ .... ?. ,..4..~4- '-,-4-~M---4~.' ' '. .... L~..~_. ,..~_~_~_~._ _~4~ ~-~..--4.4..-~- ~..~4-4-.-4-~4-~-.-~..4-.-~ ..... ~-~ -4--i-4-4--,..4.-i..4..~..--4-..i.~..i..-~-~.4..~.4..~4 8OO0 107. PROJECTION ON VERTICAL PLANE 107, - 287. SCALED IN V£RTICAL DEPTHS HORIZ SCALE = 1/1000 IN/FT I AoGcc GEOLOGICAL MATERIALS INVENTORY UST ' ' ! c, heck off or list data as it is re~.~eived ~ 40? ! ~'.,~ ,.~"./~ drilling histo~ ~ su~ey ! ~." tests I core desdptionl cored i~te~als ~re anai~is d~ ditch inte~ais ., digital data , [ , LOG TYPE RUN INTEi:~ALS SCAI F NO. ~ ~,.~?.~ , ,, 2} ~ I // ~. ,~ (~ ~ ) I 2/a o/ / ,, ,, (~ ~ I // ~ " ~ ~" , 1~} 16] Gas Detectors ,qTAT~ OP ALASKA Oil. ~ GAS CObLV, ER~rATIOI4 D.O.r.g. Inspection l',eport RECEIYED' . APR 2 o 1990 Alaska 011 & Gas Cons. Commission Anchorage ~neza~ iloumekeeplng.._~/~=Rig_~~=: Full Charge Fre~ure ~~2/p~t~ ' Mud Systems Visual AudLo Pump i.cr. aloe. pzes, 200 p~tg ~ mtn~nne. Tztp I.nk Full Charge Pre~sure A~ent)}~: / mtn~sec, F }7 .... _ .:~elly ~.~ r!9~r ~cy~Va~ves Bltnt Reme Choke Line Valves ' II.C.R, Valve X/ll Li~e Valves .. Cl~eck,Valve .. Upper Kelly ._ Test Pressure__.. _ _. Lower gelly__.~/_~Test-Fressure~_ ~all Type__~~Test Pre~suro.~.~O¢~ ..... ~.,t~. nor .... /._ t..~ r~..,,-=. ~~ ..... Ci, oke Haul,old /~as~ Pressure )o 0 · Repair or Replaceme.~ of fl:Lied equipment to be made .ithin. . days a,td I.~pector/ · -, Insp..et4 ~, , ARCO Alaska, Inc. Date: December 28, 1989 Transmittal #: 7635 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 1 5 Acoustic Cement Bond Log (~CCf"') 1 2 - 1 8 - 8 9 61 6 8 - 81 8 5 2 K - 1 6 Acoustic Cement Bond Log CC~) 1 2 - 1 8 - 8 9 5 8 3 8 - 7 7 6 4 2K-1 6 CET Log 1 2-1 8-89 5838-7764 Receipt Acknowledged: DISTRIBUTION: NSK Drilling State of Alaska(+sepia) RECEIVED .......... ;JAN ~ 2 Alaska 0ii ~ 8as Cons. commissio, r~. Anchorage STATE OF ALASKA ~ ~' A~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface Operation Shutdown X~ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate Pull tubing _ Variance _ Perforate _ Other 6. Datum elevation (DF or KB) 5. Type of Well' Development Exploratory Stratigraphic Service RKB 154' 7. Unit or Property name Kuparuk River Unit 8. Well number 119' FNL, 94' FEL, Sec. 11, T10N, R8E, UM At top of productive interval 1392' FNL, 1259' FEL, Sec. 12, T10N, R8E, UM (approx) At effective depth 1431' FNL, 1034' FEL, Sec. 12, T10N, R8E, UM (approx) At total depth 1443' FNL, 966' FEL, Sec. 12,T10N, R8E, UM (approx) 12. Present well condition summary Total Depth: measured 8304 feet (approx) true vertical 6470' feet Plugs (measured) None 2K-15 9. Permit number 89-8~ 10. APl number 50-103-20113 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool Effective depth: measured (approx) true vertical 8202' 6395' feet Junk (measured) feet None Casing Length Size Structural 8 0' 1 6" Conductor Surface 3285' 9 5/8" Intermediate Production 8253' 7" Liner Perforation depth: measured None Cemented 1000 Sx AS III & 450 Sx Class G 225 Sx Class G Measured depth True vertical depth 115' 115' 3320' 2938' (approx) 8283' R CEIVED 6455' (approx) 13. true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Attachments Description summary of proposal _ Detailed operation program X BOP sketch 14. . February, 1990 16. If proposal was verbally approved 17. Estimated date for commencing operation Name of approver Date approved I hereby certify that the foregoing is true and correct to the best 15. Status of well classification as: Oil ;~ Gas __ Suspended Service of my knowledge. -r. ~,_,,~.~,.~ Title Area Drilling Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IIAppr°val ,~. Plug integrity_ Mechanical Integrity Test BOP Test _ Location clearance Subsequent form require 10- '~; ;) the order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE C. SMITi.] Commissioner Date SUBMIT IN TRIPLICA ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit ,'he "Initial Report" on the first Wednesday afte~ a well is spudced or ,vorkover operations are started Daily work prior to spudding should be summarized on the lorm giving inclusive dates only. District ARCO ALASKA INC. KUPARUK RIVER UNIT County, parish or borough NORTH SLOPE I/ease or Unit ADL: 25588 ALK: 2674 ITitle DRILLING S~ate AK IWell no. Field 2K-15 Auth. or W.O. no. AK3706 Operator ARCO Spudded or W.O. begun IDate Hour SPUD I 10/08/89 12: 30 Date and depth as of 8;00 a.m. 10/09/89 ( 1) TD: 2088' ( 2088 SUPV:CD lO/lO/89 ( 2) TD: 3340'( 1252 SUPV:CD 10/11/89 ( 3) TD: 4940'( 1600 SUPV:CD 10/12/89 ( 4) TD: 7249'( 2309 SUPV:TM 10/13/89 ( 5) TD: 7988'( 7391 SUPV:TM 10/14/89 (6) TD: 8304'( 316 SUPV:TM 10/15/89 (7) TD: 8304'( 01 SUPV:TM Complete record for each day reported DOYON 14 ARCO W I 55.85~3 IPr or slalus f a W.O. DRLG F/2088 MW: 9.0 VIS:101 ACCEPT RIG 0730 10-8-89, NU DIVERTER SYSTEM, PU BHA, FUNCTION TEST DIVERTER, DRLG F/115-2088 DAILY:S84,052 CUM:$84,052 ETD:S84,052 EFC:$1,332,000 CEMENT 9-5/8" MW: 9.3 VIS: 93 DRLG F/2088-3340, CBU, SHORT TRIP 24 STDS, DROP SS, TOH LD BHA, RU AND RUN 84 JTS 9-5/8" CSG, RU AND CIRC CSG, RU DOWELL AND CEMENT CSG WITH 1000 SX ASIII AND 450 SX CL G DAILY:S142,257 CUM:$226,309 ETD:S226,309 EFC:$1,332,000 DRLG F/4940 9-5/8"@ 3319' MW: 9.1 VIS: 33 CONT. DISPLACING CEMENT W/ WATER, BUMP PLUG TO 2000 PSI, FLOATS HELD, CEMENT TO SURFACE, ND DIVERTER SYSTEM, NU BRADENHEAD, NU BOPE STACK, TEST BOPE TO 3000 PSI, PU 8-1/2" BHA, TIH, TEST CASING TO 2000 PSI, DRLG CEMENT, FLOAT EQUIP, AND 10' NEW HOLE, PERFORM LEAKOFF TEST TO 12.5 PPG EMW, DRLG F/3350-4940 DAILY:S120,254 CUM:$346,563 ETD:S346,563 EFC:$1,332,000 DRLG F/7249 9-5/8"@ 3319' MW: 9.5 VIS: 33 DRILL FROM 4940 TO 6554 , CIRC., TOH TO CSG SHOE, CIRC.,PERFORM OPEN HOLE LEAKOFF TEST TO 10.9 EMW, TIH (TIGHT @ 4300), DRILL F/6554 T/7249 DAILY:S50,956 CUM:$397,519 ETD:S397,519 EFC:$1,332,000 DRLG F/ 7988 9-5/8"@ 3319' MW:10.4 VIS: 37 DRILL F/7249 T/ 7988, CIRC POOH TO SHOE, CIRC AND PERFORM LEAK OFF TEST, 10.9 EMW, HELD OK, POOH TO CHANGE TO ROTARY BHA, RIH TO CSG SHOE AND BREAK CIRC., TIH TO 7504, REAM TO 7596, DRILL F/7596 T/ 7988. DAILY:S59,580 CUM:$457,099 ETD:S457,099 EFC:$1,332,000 LOGGING 8.5" HOLE 9-5/8"@ 3319' MW:10.4 VIS: 43 DRILLED F/7988 T/8304, CIRC FOR SHRT TRIP, POOH TO SHOE AND CUT DRLG LINE, RIH TO TD AND CIRC, DROPPED SURVEY, SPOT PILL, POOH, RU LOGGERS, LOG W/ TRIPLE COMBO. DAILY:S61,328 CUM:$518,427 ETD:S518,427 EFC:$1,332,000 RUNNING 7" CSG 9-5/8"@ 3319' MW:10.4 VIS: 44 FINISHED LOGGING, TIH TO TD, CIRC HOLE CLEAN, SPOT DIESEL, POOH, LDDP, RUN 7" 26# J55 BTC CSG. DAILY:S107,669 CUM:$626,096 ETD:S626,096 EFC:$1,332,000 The above is correct Drilling, Pages 86 and 87. AR3B-459-1-D · ..~ ~--i.~-,, F~). ~ - ~ ~ ~,.L :, .i ;:.~'~ ,_ .... "Z INumber all daily well history forms consecutively ~_ ~_~las they are prepared for each well. I Page no. ARCO Oil and Gas Company Daily Well History-Final Report Inslructions: preoare a~d submit the "Final Report" on the first Wednesday afte; alJo',vable has Peen assigned or '.',ell is Pluaaed. Abandoned, or Sold. "Final Report" shouid be submitted also when opera.tions are suspended foranindefin~e or appreciable ~ength of time On wOr-ko',ers when an ofhc~a~ ~est is not required upon comeietion, reded completion and representative test data in blocks provided. The "Final Report" form may be used for reporting ~he entire operation if space is a',adabie. I AccounUng cost center code District County or Parish ~ State ARCO ALASKA INC. /AK I NORTH SLOPE Lease or Uni~ KUPARUK RIVER UNIT J ADL: 25588ALK: 2674 2K-15 I Title I DRILLING IWell no. Auth. or W.O. no. AK3706 Operator A R.Co. W.I. ARCO Date 55.85,~3 Spudded or W.O. begun SPUD 10/08/89 Iotal number of wells (achve or inactive) on this ost center prior to plugging and I bandonment of this well our Prior status if a w,o. 12:30 Date and depth as of 8:00 a.m. 10/16/89 ( 8) TD: 8202'( 0) SUPV:TM I Comprete record for each day reported DOYON 14 RELEASED RIG TO 2K16 7"@ 8283' MW:10.4 VIS: 39 RAN 7" CSG TO 8283, CIRC W/O RETURNS, RECIP CSG, PUMPED 90 BBLS LCM FOLLOWED W/ SPACERS AND 225 SX CL G, REGAIN RETURNS, DISP CMT BUMP PLUG, TST CSG TO 3500#, FLOATS OK, BLOW DOWN BRINE, CUT OFF, ND BOPE, INSTALL PACKOFF, TEST TREE TO 3000#, OK, CLEAR CELLAR, RIG RELEASED @ 1830 HRS, 10/15/89. DAILY:S98,796 CUM:$724,892 ETD:S724,892 EFC:$1,332,000 Old TD New TD Released rig Date PB Oepth Kind of rig Classifications (oil. gas, etc.) Type completion (single. dual. Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P, Water % GOR Gravity Allowable Effective date corrected The above is correct Signat~ ~~__~ DstV / For form preparati'~D.~and distribution, see Procedures Manual. Section 10, Drilling, Pages 86 and 87. Number all daily well h~story forms consecutively I Page no. 4 as they are prepared for each ,',ell. AR3B-459-3-C Division of AllanllcRJchfleldCompany ARCO Alaska, Inc. Date' November 28, 1989 Transmittal #: 7616 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 1 5 OH Edit Tape and Listing 1 1 - 0 2 o 8 9 # 7 3 5 2 1 (Replacement for 10-24o89 O.H. Tape) Receipt Acknowledged' - ............................ Date' DISTRIBUTION: State of Alaska i U;1UCAL' AHCH SCHLUMBERGER WELL SERVICES 500 W. iNTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 COMPANY LOCATION ATTENTION : ARCO ALASKA~ !NC. X · ATO-111g WELL NAME : 2K- 1 5 (REDO) SERVICES · 2 OH LIS TAPES WELL NAME · SERVICES · COMPUTING CENTER PRINT CENTER NO. OF BOXES' ONE. JOB NO. · 73521 ..... ADD'L TAPES 'PLEASE:: NUTE::~.;~:~REP~-ACE. L.~THI$ ~ TAP;E...'FOR "THE ' :: WELL NAME · SERVICES · . . NO. OF BOXES: JOB NO. · ADD'L TAPES · NO. OF BOXES' JOB NO. · ADD'L TAPES ' ONE SENT 10/24/89. THE API # HAS WELL NAME · SERVICES · NO. OF BOXES' JOB NO. · ADD'L TAPES · WELL NAME · SERVICES ' NO. OF BOXES' JOB NO. · ADD'L TAPES · SCHLUMBERGER COURIER: ' WELL NAME · ~ '.. ';q. ':" ;~ :~:.,. SERVICES · ; ...," ~ NO. OF BOX[S: JOB NO. · ADD'L TAPES · DATE DELIVERED: ,: ~ RECEIVED BY: ARCO Alaska, Inc. Date' October 26, 1989 Transmittal #: 7582 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage 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. 2 K-1 5 ';1 .~_OH-T.~~. and Listing ._.._~ Please acknowledge receipt and return #73521 Receipt Acknowledged' ,R ECEIV FD -~las__ka Oil & ~as Co.,:. Commission] D at o' - ........... Anchorago DISTRIBUTION: State of Alaska Lynn Goettinger ARCO Alaska, Inc. Date: October 20, 1989 Transmittal #: 7579 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2K-15 Cyberlook 1 0-1 4-89 7600-8250 2K-15 FDC-Raw Data 1 0-1 4-89 7600-8261 2K-15 FDC-Porosit¥ 1 0-1 4-89 7600-8261 2K- 15 Dual Induction-SFL 2" 1 0 - 1 4 - 8 9 1 000- 8292 2K-15 Duallnduction-SFL 5" 10-14-89 1000-8292 Receipt Acknowledged: ............................. Date: .......... DISTRIBUTION: D&M NSK Drilling Franzen L. J~.t0n(vendor package) '- - OCT Anchorage HUD Trip Annulan preventer 81tn~ rmm~ Choke l~ne vetve~ Ch~ok Pump (ncr m ~LLY.~0 FLOOR. SAF~Y .......... ~' .-' Louor gell~ e~l typ~ ... Inside BOP ~ Te~t pee~ure ~: ,, Choke manifot~ ~, ~u~ben vmlvee Number flan9.~ .... ~ .... - _m ........ Hydrault'c,lly ,TE~T R£SULTS ~ Repair or replacement of failed tqulpmen~ ~o be n~ade within -- d~¥m . .. ~ ..... -, . · i. - ~uporvi~or (rev August 16, 1989 Telecopy: (907)276-7542 Patrick J. Archey Area Drilling Engineer ARCO Alaska, Inc. P. 0. Box 100360 ~nchoraga, Alaska 99510-0360 ~up~uk River Unit 2K- i 5 ARCO Alaska, Inc. Permit No. 89-89 Sur. Loc. iig'FNL, 94'FEL, Sec. il, T10N, RSE, UM. Btnd~ole Loc. 1480'FNL, 1027'FEL, Sec. 12, TION, KSE, Dear Fir. Archey: Enclosed is the approved application for permit to drill the above referenced well. The permit uo drill does not exempt you from obtaining additional permits required by law £rom other gover~rmental agencies, and does no~ authorize conducting drilling operations until all other required pe~mitgin~ d~ne~inations are made. To aid us in scheduling field work, please 'notify this of Zice 24 hours prior to conm~encing in~aliagion of the blowout prevention equipment so that a representative of the Conm~ission may 'b~ present to witness ~esting of the equipment before the surface casing shoe is drilled. Wqnere a diverter system is required, please also notify this office 24 hours prior to commencing equipment instaliagion so that the Co~ission may witness ~esting before drilling below the shoe of the conductor pipe. Very trq!y~Y0urs _.- /'-' ;...// /..'/' . / ~. V. Chatterton Chair~n of Alaska Oil and Oas Conservation Commission BY OF, DER OF THE COi~R~IiSSiON diC Enclosure Depargmenn of Fish & Game, Habitat Secsion 'w/o encl. Department of Environmental Conservation w/o enci. STATE OF ALASKA AI.h,.,,,,A OIL AND GAS C, ONSERVATION ~Mk.,..,,ON PERMIT TO DRILL 2O AAC 25.OO5 ! la. Type of Work Drill ~ Redrill ~ I lb. Type of Well . Exploratory m Stratigraphic Test ~ Development Oil X Re-Entry ~ Deepen --I Service _ Development Gas m Single Zone _.~ Mulliple Zone 2. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ^F{CO Al~.ska. Iht, RKB 154. Pad 118' GL feet Kuparuk River Field 3. Address 6. Prol:)erl,, ~---~i,,n. ~-r ~:--~- Kuparuk River Oil Pool P. O. Box 100360, Anchora~le, AK 99510-0360 A~~,i~"~' ALK'~'~;_:?~ 4. Location of well at surface '~:~' Unit or property Name 11. Type Bond (see 20 AAC 25.025) 119' FNL, 94' FEL, Sec. 11, T10N, R8E, UM Ku.oaruk River Unit Statewide At top ct productive intervaJ (~ TARGET ) s. Well number Number 1420' FNL, 1220' FEL, Sec. 12, T10N, R8E, UM 2K-15 #U630610 At total depth 9. Approximate spud date Amount 1480' FNL, 1027' FEL, Sec 12, T10N~ R8E, UM 8-30-89 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Numbe~ o~ aa'es in property 15. Proposed depth (MD and TVD) property line 2K-14 8226' MD 1027' ~ TD feet 25' at SURFACE' feet 2560 6452' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 1 000'feet Maximum hole anC,,lle 44 ° Maximum =u,=c~ 1 667 P"~f/At totaJ depth ~VD~ 3355 18. Casing program Setting Depth size Specification Top Bottom Quanlit¥ of cement Hole Casin~l Weight Grade Coupling Length bO TVD bO TVD (include sta~e datat 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +P00 CF 12.25 9.625 36.0# H-55 BTC 3295 35' 35' 3330' 2945' 1000 Sx AS III & HF-ERV ~ 450 Sx Class G 8.5 7" 26.0# J-55 BTC 81 92 34' 34' 8226 6452' 200SxClassG HF-ERV Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production , Liner Perforation depth: measured ..~.i-.'.!~,'.'. '.'...i:::"!:= ! .;.:-: true vertical ;~,,- -;,,-',,r~~ 20. Attachments Filing fee ~ Property plat __ BOP Sketch ;X Diverter Sketch ~ Drilling program .2[_ Drilling fluid program ~ Time vs depth plot ~ Refraction analysis ~ Seabed report _20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best el my knowledge Signed (~ -.~ ~C~, Title Area Drillin~ Engineer Date '~/"~'//~' Commission Use Only Perm[t_NumberII APl numberII Approval date 08/~.6_~.. le/s~,,~ See cover letter for ~-- ~' 50- ,//O-'~ "'~'/,~- ~' other recluirements Conditions of approval Samples required ~Y e s ,~!~'N o Mud Icg required~ Y N o Hydrogen sulfide measures ~ Yes ~'N o Directional survey required '~es~ N o Required working pressure for~BOPE ~2M; ~ 3 M; ~ 5 M; ~ 1 0 M; ~ I 5 M by order of .Approved by ~ -.-.~ · ~ ~,~/'~l~,,~'/,~.,4r/~/ Commissioner the commission Date Form 10-401 Rev. 7-24-89 riplicate ARCO ALASKA, Ino, Pad 2K, Wel I No~ 15 Revised Pr'opoeel Kuper'uk Field, Nor'th Slope, Aleeke 0 . RKB ELEVATION, 15,4.' 1000_ KOP TVD=1000 TMD=IO00 DEP=O 3 BUILD 3 OEO PER 100 FT k et$ B/ PERI"IAFROST TVD=1424 TI'ID=1428 DEP=48 2t T/ UGNU SNDS TVD=1544 Tt'IB=1552 DEP=79 '~k 2~_27' 2000_ ~a3 T/ W SAK SNDS TVD=2172 TI'ID=2262 DEP=402 ~ EOC TVD=2333 TMD=24:5 DEP=S~2 '~. B/ W SAK SNDS TVD 2745 TI'ID 3051 DEP=943 3000_ --'"X'9 5/8' CSO PT TVD=2945 TMD=3330 DEP=1138 1 94 TI'ID=3677 DEP=I 381 4000 _ ~ K-5 TVD=4620 TMD-5668 DEP=2770 AVERAGE NGLE r/ ZONE C TVD=6144 TMD=?796 DEP=4255 T/ ZONE A TVD=6181 TMD=7847 DEP=4291 5000 _ 6000 _ 7000 TARGET CNTR B/ KUP SNDS TD (LOG PT) TVD=6245 TPID=7937 DEP=4353 TVD=6309 THD=8026 DEP=4415 TVD=6452 THD=8226 DEP=4555 I I I I I 0 1 000 2000 3000 4000 5000 VERTICAL SECTION HORIZONTAL PROJECTION SCALE 1 !N. = 1000 FEET SURFACE LOCAT[ON~ 119' FNL. 94' FEL SEC. i1, TION, RSE z ARCO ALASKA. ]:ne. Pad 2K. Well No~ 15 Revised Proposal Kuperuk FI · I d. North SI ope, Al a,ke · 1000 1000 .... 1000 2000 3000 _ SURFACE WEST-EAST 0 1000 2000 I I I ,, S 72 DEC 37 MI N E 4355' (TO TARGET) 3000 I 4000 I 5000 I TARGET CENTER TVD-6245 THD-?93Z DEP-4.353 SOUTH 1301 EAST 4154 TARGET LOCAT ! Off ' 1 't'20' FNL. 1220' FEL SEC- 12. TION, R8E TD LOCAT[ON~ 14.80' FNL, 102Z' FEL SEC- 12, TION. R8E 1'00 5O 5O 100 150 200 300 250 200 1 50 1 O0 50 0 50 1 O0 I ..... I, ,,I ,,, I ~ I ,, I I , , I I , 1000 I 3OO I 250 j' 200 800 I 150 ! 4oo / .. 50 _0 _ 5O _ 100 _ 150 _ 200 100 5O 5O 100 DRILLING FLUID PROGRAM (2K-15) Spud to 9-5/8" Drill out to Weight up surface casing weight up to TD Density 8.8-9.0 8.7-9.2 10.0 PV 15-30 5-15 1 1 -1 6 YP 20-40 8-12 8-1 2 Viscosity 70-80 35-40 35-50 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 APl Filtrate 10-15 10-20 6 pH 9- 1 0 9.5-10.5 9.0-10.5 % Solids 10 +/- 4-7 12-15 Drillina Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.0 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The closest well to 2K-15 is 2K-14. This well is 25' away at surface which would be the closest point. The wells would diverge from that point. Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4) Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) 'Drill 8-1/2" hole to logging point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casing. Pressure test to 3500 psig. 11) Downsqueeze Arctic pack' and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. CLEANER SHALE SHAKERS STIR STIR STIR MIlO CLEANER CEHTRIFUGB TYPICAL MUD SYSTEM SCHEMATIC · i iI i -7 · I 6 I , D~~ #1 1~~" 5a::O PSI ~ BC]:' ST/~CK I, 16" - 2CXiO 1::"3I Tllt4<CO S'T.4HTING Ff..ii) 2.. I I' - ~ PSI CASII~G 3. I1' - :~XI3 PSI X 4. 1~-5/8" - 51330 5,, 1~5/8" - 5CX~ KILL LIltS 6,, I~-"JS" - ~ P"=J! C(3LSLE RAM W~=ZI=E ~ ON TCR. AOC~4.LATCR CAPACITY TEST I. C3-E~ ~ FILL ~TCR ~IR TO LEVEL W]TH HYORAI/.IC FLU]D. 2. ~ THAT ACO. M.~TCR ~ IS ~300 PSI 1500 P~! D(~I~TREAM CF TIE REGLLATC~. 15. CIBSERVE TII~.. TI-EN ~ ALL. UN~ SIM. I. TN~CLIELY AN3 RE~ ~ TII~ ~ ~ REIVRINI~ AFTE~ 4. RECORD ~N ~ ~o TI~ ~~IJN. E LCMER LIMZT IS 45 SE~ Cl. OSIN~ ?I1~ ~ 1200 PSl REMAINZNG 1~--518" BOP STACK TEST 4 I. FILL ~ STACK AI~ ~ 1141N]FCLD WITH ~lC DIE~ ~ ~ ~T ~ L~ ~~ IN ~~ ~LY ~~ ~T ~T ~ IN ~ ~ ~I~ JT ~. ~ IN L~ ~~ LI~ V~~~ ~~~ ~ 4. ~~ ~TO~~ ~~~ I0~ ~ ~~ TO~~I ~~~ I0~ ~D ~_~ TO 0 ~I. LI~ V~ ~ T~PI~ ~~~ V~ , ~ KI~ ~ ~ ~ ~TO~~Z~~~Z~ZN~4. ?. 2 ! PLLL (1/T CF I. CLE. lC). CLOSE: BLII~) ~ N~ TEST TO 2~1C) PSI PSI. MN~I~D ~ LII~.S ~ FLLL CF' N~I~ F1.UID. SET ALL VALVe3 IN CRILLING I:'CISITICI~ 12.. TEST 5'I'AI~IP[ VALVEI~ K~I~y, KELLY CCX3<S. ~Ii..L PIPE SAFETY VALVE, NO II, BIDE BCP TO 250 PSI :~X)O PSI. I;ECI::K) TEST II~"CI~41~TICN ~ BLCMOUT ~ER F'CI~4, SIGN,, N~D ~ TO C~ILLING VEEKLY TW~3~J~"T~ FLI~'TIaqALLY ORERATE 51(X)6400 I _ KUPARUK RIVER UNIT 20 DIVERTER SCHEMATIC .I L DESCRIPTION 1. 16' CONDUCTOR 2. FMC SLIP~:)N WELD STARTING HEAD 3. FMC D IVERTER ASSEMBLY WITH TWO 2-1/16' 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL W/10" OUTLETS 5. 10' HCR BALL VALVES W/10' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTEI~ VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20' 2000 PSI ANNULAR PREVENTER ARCO ALASK~ INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 3 MAINTENANCE & OPERATION 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES JG 4~26/88 ARCO Alaska, Inc. Post Office Box P, nchoraqe, Alaska 99510-0360 Telephone 907 276 12'15 December 12, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Conductor As-Built Location Plat - 2K Pad (Wells I - 24) Dear Mr. Chatteron' Enclosed is an as-built location plat for the subject wells. any questions, please call me at 263-4618. Sincerely, If you have D. Martin Engineering Aide DM:hf Enclosure RECEIVED DEC 1 3 1988 Alaska 0il & (~,qs Cons. CornlnissJoi! Anchorage GRU13/010 ARCO Alaska. Inc. is n Subsidiary o! Allat~licFlichfi~ldCr~ml~any N.T.S. SECTION 2 SECTION · WELLS 1'12 ARE LOCATED IN SECTION 2, T I0 N., R. 8 E., UMIAT MERIDIAN. WELLS 13-24 ARE LOCATED IN SECTION II,T. ION., R. 8 E., UMIAT MERIDIAN. SECTION I PROTRACTED' SECTION CORNER I~tes: TIIN !T ION I. COORDINATES ARE A. SR ZONE 4. SECTION RECEIVED DEC ! 1988 ?. ALL DISTANCES SHOWN ARE TRUE. 3. ELEVATIONS ARE B.P.M.S.L, 4. O.G. ELEVATIONS FROM CED-RlXX-$:311, rev. 4. 5. HORIZONTAL POSITION BASED ON 2-K CONTROL MONUMENTS PER LOUNSBURY ~ ASSOCIATES. 6. REFERENCE FIELD BOOK.' L88-40, pgs. 55,56, 58,59, 65 ~ 66. Well ASP's AJa¢ a uIl & C~,~,~ O,,~,: u0n'im;su;u:; DiSt. "Dist. O.G. Pod No. 'Y' 'X' L~;~li)~ LONGITUDE F.S.L. EEL. Elev. Elev. I 5,938,600.18 498,310.17 70°14'36.519" 150°00'49.~:3:3'' 296' 94' 114.0 118.5 2 5,938,575.14 498,$10.28 70° 14' 36.27:3" 150°00'49.130'' 271' 113.9 3 5,938,550.30 498,310.:35 70° 14' 36.029" 150°00'49.128'' 246' 11:3.8 4 5,9:38,525.46 498,310.06 70014' 35.784" 150°00'49.136'' 2;>2' 115.8 5 5,9:38,500.19 498,310.12 70014' 35.5:36" 150°00'49.1:34'' 196' 6 5,938,475.14 498,310.:3:3 70014' :35.289" 150°00'49.128'' I11' 115.8 7 5,938,450.36 i 498,310.36 70°14'35.046" 150°00'49.127'' 146' 113.8 8 5,938,425.30! 498,310.18 70014'34.799" 150°00' 49.132'' 121' 113.8 9 5,938,400.30 i 498,:309.98 70°14' 34.553" 150°00'49.13;:: 96' 113.8 I0 5,9:38,375.19 498,510.14 70° 14, 34.306 150°00 49.15 71' 115.9 I ! 5,938,350.22 498,310.14 70°1 34.061 " 150o00'49.135'' 46' 12 5,938,525.20 498,310.17 70°14' 33.815'' 150 °00' 49.131'' 21' 94' 113.9 118.5 EN.L. 13, 5,938,235.31 498,310.37 70o14'32.950" 150°00'49.125'' 69' 94' 1~3.7 118.5 14 5,938,210.14 498,310.16 70°14' 32.683'' 150°00'49.13,1'' 94' 113.7 15 5,938,185.12 498,310.16 70o14'32.437" 150°00'49.151" 119' 11.:3.8 16 5,9:38,160.11 1. 498,310.20 70°14'32.191'' 150°00'49.130'' 144' 113.8 17 5,938, 135.21 498,310.18 70o14' 31.946" 150°00'49.1:30" 169' 11..,3.9 18 5,938, 110.19 498,310.29 70°14' :31.700" 150°00'49.127'' 194' 114.0 19 5,938,085.~0 498,310.27 70°14' 31.454" 150 °00' 49. 127'' 219' 114.0 20 5,938,060.14 498,310.22 70°14'31.207'' 150°00'49.128'' 244' ,! 114.1 21 5,9 38,035.16 498,310.16 70° 14' 30.962'' 150° 00'49. 130'' 269' ~' 114.0 22 5,938,010.40 [ 498,310.19 70°14'30.718'' 150°00'49,129" 294' 94' 114.0 23 5,937,985.32 I 498,310.13 70°14':30.471" 150°00'49.130" 319' 95' 114.0 24 , 51937,960.29J 498,310.08 70°14'30.225'' 150°00'49.132'' 344' 95' I !13.9 !.18.5 I HEREBY PROPERLY TO PRACTICE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPER- VISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF NOVEMBER ~0~ 1988, CERTIFY THAT i AM REGISTERED AND lICENSED LAND SURVEYING IN THE e~'~: ".. IS- 6299 .o.' .~. _~ ;¢,' DRILL SITE 2_..K CONDUCTOR AS-BUILTS -ANCO Alaska, CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE Fee (2 thru 8)' - (8) (3) A dmin~ g~//~ 9. 13) ' lo. (10 and 13) 12. 13. (4) Casg ~.~.,'..-~:: ?-,,~-o (14 thru 22) (23 thru 28) Company Is the permit fee attached .......................................... ]~- 2. Is well to be located in a defined pool ............................. ~ 3. Is we~] located proper distance from property line .................. 4. Is~we-~l .located proper distance from other wells '. .... ... 5. Is surticient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ ~ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ............... ' ...... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Lease & Well No. YES NO 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........ , ................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. ,,~-~ Is this well to be kicked off from an existing wellbore ............. ,, Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate j~ Are necessary diagrams and descriptions of diverter and BOPE attached. 4~. Does BOPE have sufficient pressure rating - Test to ~~ psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER ~ ~>~ 29'TY - ru 31') Geology: Engineering: rev: 01/30/89 6.011 Fo r 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas z6nes ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INIT'IAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks: 0 ~z 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. .COMPANY NAME ~EL~ NAME ' FfE~D .NAME BOROUGH STATE API NUMBER R~FERENCE NO ARCO ALASKA 5 KUP NORTH $~OPE AUASKA : '50-'103-20115-00 ,73521 MICROFILMED O0-~To~-£OI-O~ ia~WflN Or, 0 : I : # NOIIV~NIINOD t~gEL : 3WVN 3~Vi EZ/OI/68 : 3$~0 $I03 : 3W~N 3OIlUgg O0-~IIO~-EO)-O§'~I - M~'~QSV~(I~'*3NI VWgV~V OD~V : SNNNWO3 : # NOI~VANIiNOD I~EL : 3~VN E~/OT/68 : Tame Verification blsttnq chlomberger AlaSKa Computtnq Center ~3-0CT-1989 2~:52 ~LEVATION$ DATE LOGGED~ RUN NUMBER: 'rD DRILLER: T~ LOGGER: KB~ 1~-0CT-89 ONE 8~04' 8 00' DF: 153' 118' 9 5/8" & DRILLER DEPTH OF 3319' AND LOGGER DEPTH OF 3338' BIT SIZE 1: 8 1/2" ~ 8304' TYPE FLUID IN HOLE: ~T DENSITY: 1014 PH: 9, POLY VISCOSITY: 44 FLUID LOS~: 4,4 MUD RESISTIVITY FILTRATE RESISTIVITY: MUD CAKE RESISTIVITY: 7 @ 70 ~: 4 e 7O ~,78 ~ 70 TIME CIRCULATION ENDEDt 00{00 OC)OBER 14 T~E LOGGER ON BOTTOM: 06~45 OCTOBER 14 MAXIMUM TEMP RECORDED: !36 LOGGING DISTRICT~ LOGGING ENG,INEER~ ~ITNES$~ PRUDftOE BAY , SARBER , MCKAY/B, BEAL TOOL NU~BERS~ SGC,,,JC-2249 D -DA-2191 I E~'"OD' 1347 CN' A"!238 NL~-BC-l~29 DATE jOB ~TARTED; 18-0CT-89 jOB REFERENCE NO,: 73521 5DP/ANA: R, KRONELL FI~E - EDIT,O01 "~AIN PASS LOG DATA" DATA 'SAMPLED EVERY -,5000 FEET DATA INCLUDED - 'tOOL EXTENSION TOOL TYPE USED NA~E DIT-D ,DIL FDC ,FDC CNT-A/D/H ,CNL DUAL INDUCIIDN FORMATION DENSITY COMPENSATED NEUTRON Is Tape Verification bisttnq chlumberqer AlasKa Computlnq Center 23-0CT-1989 21:52 * GR ,CSG GAMMA PAGEI 3 '£ABbE TYPE I CONS TUN! VAbU DEF! CN ARCO AbASKA INC, eom Na~e F~ KUPARU~ rte~n~ame ~ 2K -'15 Well Name APlN 50-103-20115-00 APl Serial Number Fb 144' FN6, & 94' FEb Field 6ocation SEC? 11 Section TOWn 10N Township RANG 8E Range COUN NOR?H SbOP£ County $?AT AbASKA State or Province ~A~ USA Nation ~]' "54T'tMCKA¥/B' BgAb Witnesses na~e &O~ 441 Service Order'Number PDAT MSb Permanent, datum b~F' ' boq ~easu~ed From APO ~ EKE r~ ~Gb F~ 118. TOD FT 8304. ELI FT 8291., Bottom bog lnt. e.~va! T~i FT ~O00. Top boo'Interval TCS 00100 OCTOBER 14 Tlme Circulat!on Stopped TLAB 06145 OC~00ER ~4 ~lme bogger At Bottom TYPE ~ ;CURV' DEFI DfPT SFbU SP RHOB DR~O FFDC NFDC RFF~ DEPTH CHANNEb NAME ~b-Dee ReSistlv~tg Ib-~ed~um'ReSl'stlvltY ~76 Unavetaqed Spontaneous Potential :Gamma Ra~ Tension BUIKDenS Density P~sity Delta tho rat roe Count Rate Near ~DC Count Rate Raw Near ~DC Count Rate Raw rat roe Count Rate TaPe Verification Listing chlumberqer AlaSKa Computinq center 23-0CT-19~9 21~52 ~EF! C~bl Caliper GR Gamma Ray TENS ?enslon NPHI NEUTRON POROSITY TNPH THERMAL NEUTRON POROSITY TNRA CALIBRATED THERMAL NEUTRON RATIO RTNR RAN THERNAb NEUTRON RATIO NPOR NEUTRON PORO$IT'¥ RCNT RAW CORRECTEDn THERMAL COUNTS NEA~UTPUT FROM AN APPLICATION PROGRAM RCFT RAW CORRECTED FAR THERMAL COUNTS CNTC CORRECTED NEAR THERMAL COUNTS CETC CORRECTED FAR THERMAL COUNT& GR Gamma Ray TENS Tension GR Gamma Ray TENS Tension DATA FORMAT SPECIFICATION RECORD &ET TYPE - 64EB TYPE REPR'CODE VALUE 0 73 120 ~ 66 1 tl 66 8 12 68 13 66 0 14 0 66 0 ** SET TYPE - CHA~ ** UMB,$AMP EbE~ ' CODE (HEX) DEP? F? ~4B~4! O0 000 O0 0 ~! 1 1 ~ 6~ O00000OO00 OI~ OHMM 5~4! ~0 0~0 O0 0 ~ ! ! 4 68 000000~000 DI, b OHMM 54844,1 0 000 O0 O ~ 1 1 4 68 0000000000 Tape VerXflcatlon 6istlnq chlumberger AlasKa ComPuting Center 2]-0CT-1989 21:52 NAME SERV UNIT SERVICE AP1 API APl API FILE NUmB NUMB 6IZE REPR PROCESS XD ORDER # LOG TYPE CLASS MOD NUMB SA~P ELEM CODE CHEX) SFbU DI6 OHMM 548441 O0 000 O0 0 X I X 4 bB 0000000000 8P DIL MV 548441 O0 GR DIb GAPI 548441 O0 TENS DI6 LB 548441 O0 RHOB F~C G/C3 548441 O0 DPH! FDC PU 548441 O0 DRHO FDC G/C3 548441 O0 FFDC FDC CPS 548441 O0 NFDC FDC CPS 548441 O0 RNFD FD¢ CPS 548441 O0 RFFD FDC CPS 548441 O0 CALl FDC IN 548441 O0 GR FDC GAPI 548441 O0 TENS FDC 68 548441. O0 NPHI CNb PU 548441 O0 ?NpH CNL PU 54~41 O0 TNRA CNL 54, 41 O0 RTN. CNb 548441 O0 NPO~ CNL PU 548441 O0 RCNT CNb CPS 548441 O0 RCFT CNL CPS 545441 O0 CNTC ~N[, CPS 548441 CFTC Nb CPS 54844~ G~ CNL GAP! 54844! O0 T~N$ CNL 58 54844~ O0 GR CSG GAP! 548441 O0 bB 548441 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 ooo 000 O0 000 0 O0 000 O0 000 O0 000 O0 0 1 1 I 4 68 0 1 1 I 4 68 0 1 ! I 4 68 0 1 1 1 4 68 0 I 1 I 4 68 0 I 1 1 4 68 0 i I I 4 68 0 1, 1 1 4 68 0 1 1 i 4 68 0 1 1 1 4 68 0 1 1 1 4 68 0 1 ! 1 4 68 0 .l 1 1 4 68 0 1 I I 4 68 0 ~ ! 1 4 b 8 0 1 1 I 4 68 0 I 1 1 4 68 0 1 1 1 4 68 0 1 1 1 4 68 0 I 1 I 4 68 0 ~ 1 1 4 68 0 i 1 1 4 68 0 I 1 I 4 bB 0 1 1 I 4 68 0 i 1 I 4 68 0000000000 0000000000 0000000000 0000000000 0000000~00 0000000 O0 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 TENS CSG. O0 000 O0 .0 1 1 1 4 b8 0000000000 DATA DEPT RNFD TENS RTNR CNTC G. DEPT 8P DPHI RNFD RTNR CNTC DIb -21.500 FDC 24'051 FDC 1668'000 FDC 2300.~00 C.N~ 3, 65 CN 1944,822 CSG -999,250 D IL CNL CSG~ 8300,000 '21,625 24'051 1668.000 5308 000 3 765 1944 822 m999 250 ILO DIL GR DRHO FDC RFFD f'DC NPHI CN6 NPOR CNL CFTC Nh TENS IbD,DI6 GR,DI6 .DRHO,FDC RFFD,FD~ NPHI,~CN6 N~OR,CN6 C~TCjCN6 TENS,CSG 78 875 144 0~0 44'396 '~1. 2 999.250 ,, 2¸ 3 0 144 2160 000 44 396 41'662 566'752 -999,250 FFD¢ CA~! DC TENS,DIb FFDC FDC CAbI FDC. RCNT GR CNb SFbU DIL 7 551 GR FDC 41 662 ,NRA CNL 1905 83 ,CFT 97 ~75 ' ~NL TENS Nb 3 021 SFbU,DI~ 308 000 RHOB.FDC 000 NFDC.FDC ~06~ 551 GR.FDC 662 I'NRA,CNL lgO 83 RCFT,CNL 97 875 TENS,CN5 PAGEI 86 500~ 97 875 2300 OO 3 126 86~ 253 97 875 3 492 499 288 5308 000 IS Tape verification Llstinq chlumberger AlasKa Computinq Center DEPT. MP,DIL DPHI.FDC RNFD FDC TENS FDC RTNR CND CNTC CNb GP C~¢ DEpT, SP.DIL DPHI FDC RNFD FDC TENS FDC ~TNR CNb CNTC CNL GR CSG DPMI.FDC RNFD.FOC TENSeFDC R?'NR,C~L CNTC,CN5 OR,CS¢ DEPT SP RNFD FDC TENS FDC RTNR CNL .CNTC CN GE DEPT DPHI. FDC RNFD FDC TENS FDC RTNR CNL CNTC CNL GR CSG DEPT. SP,DIL RNFD TENS:FOC RTNR,CNb C~TC,CNb GR,CSG 8200.000 ,233 1193 000 5360 000 3 795 1991 08 -999 ~50 8100,000 '25.703 12,148 1170,000 5304.~00 oo 182 023 '999.250 8000,000 oo 19 , 86 '299 ~ 50 ,33, 5 14, ,3 ,000 .146 .999.'250 7800,000 -27,500 854 121:000 5284,000 , 825 07 ~999,, 50 7700 000 -~ 000 · 52 ooo 4 '06 1749 ~90 -999 250 ILD.DIL GR,DIb DRHO,FDC RFF~,FDC NPHI.CNL NPOR,iNL CFTC, NL TENS, SG IbD.D1L GR,DIh DNHO,FDC RFFD,FDC NPHI.CNL NPOR,CNb CFTC,CNL TEN$.CSG ILO DIL GR DIb DRHO FDC RFFD FDC NPH! CNb NPOR CNb CFTC,CNb TENS CSG GR.DIb DRHO.FDC RFFD,FDC NPHi,CNh NPOR,CNL .cemc,c~ T~NS,CS~ ILO.OIL DRHO,FDC RFFO.FDC NPHI CNL NPOR CNL TENS. ILO,OIL OR,OIL DRHO,FDC RFFO,FDC NPHI,CNb NPOR, CFTC,~NL TENSeCSG 23-0CT-1989 21152 2 638 97 938 0 O52 1033 000 39 121 40 269 627 215 -999 250 IbM,OIL TENS,OIL FFDC'FDC CALI:FDC TNPH,CNL RCNT.CNL GR.CNL 2 824 5 ' 0 1047 000 39 965 38 881 544 357 "999 250 IbM,OIL TENS,OIL FFDC.FDC CAbI.FDC TNPH,CNL NCNX,CNL GR.CNb 4 658 90 938 0 0~! 1077 000 32 388 32 891 0 '999 IbM.DIL TENS,OI~ CALl, TNFH,CNb RCN~, Nb GR,~NL 1 ! 629 66 1.88 o 2 28 O42 27 537 l 0 4 2 51 8 '999 250 IbM,DIb FFDC. CAL~,FDC TNPH,CN~ NT,.~Nb RCGR, Nb 2,634 96,.7~0 iO.! 0 9 3,500 "9,8~5 6.3 2 620'676 'g99'250 ILM,DIb TENS.OIL FFDC FDC CALl FDC TNPH CNb RCN~ CNb GR CNL 2 OBO ibM,OIL 104 313 TENS,OIL 0 007 FFDC.FDC 10~I 000 ,:CAbI,FOC 848 TNPH.CNb 48 569 RCN~'CN 457 22 CN~ -999 ~50 GR, 2.776 SF'LU,DIL 5360,000 RHOB,FDC 482.750 NF~C.FDC 8 b88 GR.FDC 37 442 TNRA.CNb 1832 6~0 RCFT.CNL 97 9 8 ~ENS,CNL 2 950 SFLU.DIL 5304 000 RHOB.FDC 505 000 NFDC,FDC 8 891 GR.FDC 40 118 TNRA.CNb 18~7 389 RCFT,CNL 99 875 TENS,CNL 4.776 SFLU,DIb 5328,000 RHOB,FDC ,000 NFDC,FDC 52~,969 GR.FDC 32,162 TNRA,CNL 2109,973 RCFT.CNL 90,938 TENS,CNL I1 052 &FLU O0 RHOB FDC FDC FOC CNL CNL CNL 2 651 SFLU.DIL 284 000 RHOB,FDC 5419 500 NFDC,FDC 8 992 , GReFDC 39 932 ~NRA, NL 1783 077 RCFT,~NL 96 750 TEN$.CNL 2,17'7 5288,000 EHOB,~DC :522.000 NFDC,FDC 4 712 ~NRA,CNL 2687.000 ~04,3~3 TEN$.cNb PAGE{ 3.044 2.481 616,000 97,938 3,292 548.315 5360,000 3,292 2.450 612,b00 99.875 .355 48 ,916 5304.000 5,308 ,439 ~'o0o 6~0,938 2'937 651',081 5328~000 12,030 ' 000 6 ',188 92 918 5348,000 500 50 96'755 ~73"~57 2 563 oo 388 433 5288 000 I$ TaPe Verification Listing chlumberger AlasKa Comput ng Center DEPT, 8P,DIL DPH~,FDC RNFD,FDC TENS,FDC RTNR,CNL CNTC,CNL GR,CSG DFPT, SP,DIL DPHI,FDC RNFD,FDC TENS,FDC CNTC,CNL G~,CSG DEPT, DP ,FDC RNFD.FDC TE~S.FDC RTNR,CNL CNTC.CN~ G~,'CS D~PT ...pSP~DI~ D, HY,'FDC RNFD FDC T~S FDC RTNR CNL C~TC G~ DEPT SP DPHI FDC RNFD FDC TENS FDC RTNR CNL CNTC ENL DEPT, SP*DI~ DPHI,FDC R. NFD;FDC TE~S.FDC RTNR.CNL G~,'CSG ooo 0oo 12 754 1231 000 51B8 000 4 000 1781 296 -999 250 7500,000 '32,000 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 7400 000 .-40 -999 ~00 50 -999 250 -999 250 '999 250 '999 2.50 '999 250 73O0,00O . .ooo -9 ,250 '"999.~50 '999,50 m99 ,: 50 '999,250 7200,000 99.~50 "999,250 "999.'250 "999,250 '999,250 '-999,250 7100,000 -40,000 -999,250 -999,~50 "999..250 "999,250 "999,~50 "999,250 IbD GR DIG DRHO FDC RFFD FDC NPH! CNb NPDR tnb CFTC.CNb TENS,CSG IbD.DIb GR.DIb DRHO.FDC RFFD,FDC NPHI,CNb NPOR.~N6 CFTC, N~ TENS,CS I~D,DIb DRHO,FDC RFFD,FDC NPH{.CNh NPOR,CN5 CFTC,CN~ TENS.,CSG ibD DI~ DRHO FDC RFFD FDC NPH! CN~ NPOR CFTC Nb TENS SG GR DRHO FDC RFFD FDC NPH! CNb NPOR CFTC TENS. CSG 1LD.DIL GR,DIG DRHG,FDC RFFD,FDC NPHI;CNL NPOR,CNL CFTC,,CNL TENS.CSG Z3-OCT-1989 21:52 3 251 155 000 0 039 1055 000 46 276 44 641 501 111 -999 250 2 599 264 ooo :99 5 99~ 2 0 290 -999 250 '999 250 -999 250 -999 250 3,5½6 171,8 5 '999,250 "999 250 '999 250 -999 250 -999 250 '999 250 3 504 113 125 -9~9 250 '9 9 250 '999 250 "999 2~0 "999 2.0 '999 250 4.640 106'375 '999..2 -999,250 "999,2~0 "999.2 0 -999,250 , 3 353 13 "9 '999 250 -999 250 -999:250 -999 250 -999,2b0 . TENS.DIL FFDC.FDC CALI.FDC TNPH.CNh TENS.DI~ FFDC.f'D CALI.FDC TNPH.CNh RCNT CNL IbM OIL TENS DIG FFDC FDC CAL! FDC RC,N~ GR CNE 3 413 SFbU,DZL 5188 000 RHOB,FDC 517 500 NFDC,FDC 9 461 GR,FDC 42 971 TNRA,CNL 1687 000 RCFT.CNL 155 000 TENS,CNL 2 690 5540 000 -999 250 -999 250 -999 250 -999 250 -999 250 SFbU.DIL RHOB,FDC NFDCeFDC GR,FDC TNRA,CNb RCFT.CNL TENS,CNL 3,542 SFbU ,250 NFDC "999.250 GR -999.250 TNRA -999,250 RCFT -999,250 TENS ILM,DIb 3,645 &FLU TEN~,DI~ 50~,000 RHOB FFDC~FD -9 ,250 NFDC CALI,FDC -999;250 GR TNPH.CN5 -999.2.50 TNRA RCNT,CN~ -999.250 RCFT GR,CN~ -999,250 TENS TEN~ lb, Fl'DC FDC CAb! FDC TNPH Nh RCNT GR CNb ~ENS,DIG FFDC,FDC CALl FDC TNPH CNL RCN~ G~ CNL ,,DIb ,FDC ,FDC ,FDC ,CNL ,CNL ,CN~ FDC CNE CNL 4 4760 -999 -999 -999 -999 -999 5¸2 0~0 ISFL,U, D I,L RHOB.,FDC 250 NFDC,FDC 250 GR,FDC 250 TNRA,CNL 250 RCFT~,CNL 250 TENS,,CNL 48O o0o -999,250 -999. 0 '999.~50 -999, 50 SFDU, DIE RHOB,FDC NFDC,'FDC GR,FDC' TNRA. tnb RCFT,CNL TE~.S.CNL PAGEI 4.067 2 440 617 000 155 000 ~ 46 422 139 5188,000 3,401 '999,250 '999'250 '999,250 '999,250 "999,250 '999.250 3,738 "999,250 '999.250 -999,250 -999,250 -999,250 -999,250 4,929 "999, 0 '999,250 -999,250 -999,:250 '999,250 -9 250 '99~ 250 ~9 ~50 "999 50 3 578 "999 250 '999 250 "999 250 '999 250 ~'999 250 "999 250 IS Tape Verilication Listino chlumberoer AlasKa ComPutino Center DEPT MP OIL OPH! FDC RNFD FDC TENS DC RTkR ~Nb CNTC CNL O~ CSG DEFT DPHI,FDC RN ,FDC RTNR~CNb CNTC,CNb GR,CSG DEPT.D DPHI.FDC RNFD'FOC TENS.FDC CNG~,CNL DEFT, SP,DIL OPHI,FOC RNFD.FDC TENS.FDC RTNR'CNL CNTC,CNb GR*CSG OEPT DPHI.FDC RNFD.FDC TENS FDC RTNP CNL G~ CSG OEPT · DPMI.FDC RMFD,FDc 1 ..... NS.FDC RTN~'CNb CNTC.CNL ,250 999,250 '999 250 '999 ~50 -999 50 -999 250 -999 250 6900,000 -49,000 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 6800,000 -50.250 -999,250 -999,250 -999 250 -999 250 ''999 250 '99~ 250 6700.000 ,'25,516 '-999 250 '999.250 '999e250 '999,250 '999,250 6600, O0 -18,~66 '999'~0 '-999; 0 · "999 250 '999 50 '999 '999 250 6500,000 '27,000 '999,250 "999,~50 '999, 50 '999,250 "999,250 '999,250 ILD,DIh GR,OI5 DRHO,FDC RFFO,FDC NPHI,CNh NPOR,CNL CFTC,CNh TENSeCSG ILO OIL GR DIL DRHO FDC RFFD FDC NPOR L CFTC CNL TENS CSG GR DRHO FDC RFFD FDC NPH~ CNL NPOR CNL TENS, ILD DIL GR DRHO FDC RFFD f'DC NPHI CN~ NPOR,CNh CFTCeCNL TEN$,CSG GR~DIL DRHO,FDC RFFD,FDC NPH~,CNb NPOR,CN5 CFTC,CNL TENS.CSG ILO.OIL GReD!L DRHO,FDC RFFD,FDC NPH~..CNb NPOR.CNL CFTC.CN~ TENS.CSG 23-0CT-1989 21;52 4 026 136 625 -999 250 -999 250 -999 250 =999 250 -999 250 '999 250 3 544 lj3 750 -999 250 -999 250 -999 250 -999 290 -999 250 -999 250 3 3 -999 250 -999 250 -999 250 -999 250 '99~ 250 '99 250 3,943 '9 ,2bO -999: -999'250 "99~,250 '2 6'6 114 I~8 -999 25 '999 25~ '999 250 '999 250 '999 250 '999 250 3 -~99 5 250 '999 250 '999 0 '99~ 250 '999 250 ILM DIL TENS:DIL FFDC FDC CALI:FDC TNPH,CN~ RCNT.CNL GR,CNL IbM OIL TENS DI FFDC FD~ CALl FDC TNPH CNL RCNT CNL GR CNL IL~ TENS OIL FFDC FD CALl FD~ TNPH CNb RCNT.CNL GR,CNb IbM,OIL FFDC FDC CALl FDC TNPH CNL ~CNT CNb GR CNb FFDC RC:N~ b Ga CNL ibm OIL TENS Dlb FFDC FDC CAb FDC 4 068 SFLU,DIL 4652 000 RHOB,FDC -999 250 NFDCeFDC -999 250 GR.FDC -999 250 TNRA.CNL -999 250 RCFTeCNL '999 250 TENS.CNL 3 567 4580 000 -999 250 -999 250 '999 250 '999 250 -999 250 SFLU,DIL RHOB,FOC NFDC,FDC GR,FDC TNRA.CNL RCFT'CN~ TEN$,CNL 3 4424 -999 -999 -999 -999 -999 791 SFLU,DIb 000 RHOB,FDC 250 .NFDC.FDC 250 GR,FDC 250 TNRA,CNL 250 RCFT'CNL 250 4,0~3 4452.6~0 ~FLU,DIL RHOB,'FDC -999,, 50 NFDC,FDC -999',)50 OR,FDC -999,250 TNRA,CNL '99~,250 HCFT,CNL' '999,250 TENS,,CN~ ~9 '250 NFDC,FDC -999,250 GRm. FDC · '999,250 TNRA..CNL -999,250 RCFT'CNL -999e250 TENSeCNb 3,844 SFLU,DIL 4448,000 RHOB,FDC -999,250 NFDC,FDC '999.250 GR.F~C '999,'250 TNRA.CNL -999;250 RCFTeCNL -999,250 TENS,CNL PAGEI 4,253 "999,250 '999,250 '999.250 999.250 999,250 999,250 3,349 -99 250 -999,250 '99 250 '99 250 3,973 '999,250 '999,250 '999,250 '999,250 "99 , 50 ' ,50 "999 250 '999 250 '999 250 "999 250 '999250 '999 250 '99 ' -99~ 250 -999 250 . '999 0 '999 250 TaPe Verification Listing chlumberger AlaSKa Comput nq Center DEPT. 6400,000 SP,DIL '25,750 DPHT.FOC -99~:150 RNFD,FDC -99 50 TENS.FDC -999.i50 RTNR.CNL "999. 50 G~' .CSG '99 250 DEPT SP DIG OPH! FDC RNFD FD TENS FD~ RTNR CNG CNTC CNG G~ CSG DEPT, OPH! FD RNFD FO~ TENS FDC RTNR CNG ,C~TC CNG G~ OPM! FDC RNFD FDC TENS FDC CNTC CNG GR CSG DEPT, DPHI'FDC RNFD.FDC TENS.FDC RTNR,CNb CNTC.CNL DEPT. pSP,DIG D.HI..FDC RNFD. DC TENS,FDC RTNR,CN5 CNTC,CNL G~,Cs¢ 6300,000 '26,750 -999,250 '999,250 =999.250 '999,250 "999,250 '999,250 6200,000 ~38,750 '99~.250 "99 ,!50 '999, 50 '999, '999,150 -999, .6100.000 'i3~'000 · - 9 ,250 - -9 ,250 ~9~ ,.250 -9 9,~50 '999,,250 6000,000 -2~.750 -99 ,250 '999,250 '999,250 -999,~50 "999'250 5900 000 .~24 750 -999 250 · -999 250 -999 250 · -999 250 -999 .150 -999 50 IGD DIb GR DZG DRHO FDC RFFD FDC NPH! CNG NPOR CNb CFTC.~NG T~N$, SG FDC RFFD FDC NPH! CNG NPOR CNG CFTC CNG TENS CSG tED DIG GR DIG DRHO FDC RFFO FDC NPHI CNG NPOR cftc CN~ TENS ILD GR DRHO FDC RFFO ~DC NPH! CNG NPOR CNG CFTC CNG TENS,CSG ILD,DI~ GR,.DIG DRHO,FDC RFFD,~FDC NPOR,CNL CFTC, Nb TENS.~$G J:bD,OIb GR DIL ' D DRHO, F C RFFD.FDC NPM~ .CNG NPOR.CN~ .CNG 23'0CT-1989 21:52 t O0~ 292 188 '9 250 :9 250 .,999 250 "999 250 81 640 -999 250 -999 250 -999 250 "999 250 "999 250 -999 250 3,844 117,~7~5 '999, 0 "999,250 2'0 "9~99~2~0 '999, "'999,250 "999,250 , 3, 142.'~ 2 5 "'999.250 '99_9,2 "99'~, 250 '"'999,250 "'999,250 -999,25u "999,250 99~,.2~0 '~99 ,250 '999,2~0 '999;25O .. .768 -999 .2 '0 ,-999 250 '999 250 '" 99.9 250 "999 250 -999 250 . · . TENS,DIL FFDC,FD~ CALI.FD TNPH.CNG RCNT.CN~ GR.CN IG~I,DIL TENS.DIG FFDC.FDC CALI;FDC TNPHe~NG RCNT. Nb GR.CNG ~NP.H ~N~ RCNT GR CNG ILM 'TENS .DIG CA~! rD RCNT CN ~R IbM DIG TEN5 DIG .FFDC FDC CALI FDC TNPH CNG TEN~.D! FFDC.FD~ CAL~.FDC TNP .CN~ RCNT~NG GR: Nb 3,276 SFEU,DZL 4380,000 RHOB,FDC '999,250 NFDC,FDC -999,250 GR,FDC -999.250 TNRA.CNG -999.250 RCF~,CNL -999.250 TENS.CNG 3 730 $FGU DIG 4144 000 RHOB FDC -999 250 NFDC FDC -999 250 GR FDC -999 250 TNRA CNb -999 250 RCFT,CNL -999 250 TEN~.CNL :3 859 SFbU 3924 000 RHOB FDC -999 250 NFDC FDC -999 250 GR -999 250 TNRA CNG '999 250 RCFT CNG -999 250 TENS CNL 3,853 SFGU,DZL 4Z48,000 R~OB,FDC -999;250 NPDC,FDC -999,250 GR,FDC "999,250 TNRA,CN~ -999,250 RCFTe. CNL -999,250 TENSeCNL :3,350 4220,000 R ,FDC -999,250 NFDCeFDC -999;250 GR,:FDC -999~250 ~999,250 RCFT,C~L -999,250 1,827 $FLU DIL 19~.000 RHOB FDC 9 ,2,50 NFDC FDC -999~250 ~R 999'250 TN~AF'DC CNG "999;250 RCFT CNG -999.250 TENS CNG PAGEI 2 97b -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 4,020 '999 250 "999 250 -999 -999 250 -999 250 . 3'917 .999,250 0 0 '999.~0 -999,250 3,704 99~250 "999'~50 "9~9'250 "999 "999;250 "999,,250 '999,256 '"999,250 !,676 '"999,250 "999,250 "999 250 -999 250 '999 250 "999 250 Tame VeriflcaCion Listing chlumberger AlasKa Computing Center DEPT, SP,DIL DPHI,FDC RNFD,FDC R.. .CNL CNTC,CNL GR.CSG DEFT 6P DPHI FDC RNFD FDC TENS FDC RTNR CNL C~TC CNL GR CSG DEFT, DPHIFDC RNFDFDC TENS FDC RTNR CNL CMTC CNb DEFT SP DPHI FDC ~N~V FDC TENS FDC RTN~ CNL CN~ CNL CSG D~PT SP OPM! FDC RNFD FDC TENS FDC RTN~ CNb CMTC CNL O~ CSG DFPT, SP,DIL DPHI,FDC FDC ~NFD,F TENS. DC RTNR.CNL CNTC.CNL 58O0 000 -27 500 -999 50 -999 ~50 -999 250 -999 250 -999 250 "999 250 5700,000 ."31.500 999.250 '999.250 -999 250 -999 250 '999 250 "999 250 '46, "999,!50 .-999, 50 "999, 50 "999,250 '999,2 5500,000 "40,000 "999,250 -999.250 '999,250 "99~,250 -99 ,250 "999,250 5400,~00 '36, 50 "999.~50 '"999, .50 "999,.'~50 "999, 50 "999,250 '999,250 5300,000 .~5o -999'250 -999,250 -999,250 -999,250 -999,250 ILD,DI5 GR,DI~ DRHO*FDC RFFD.FDC NPHI.CNb NPOR.CNL CFTC.CNb TENS,CSG GR,DI~ DRHO.FDC RFFD,FDC NPHI,CNb NPOR,CNL CFTC.CNL TENS;CSG ILO.OIL GR.DIh DRHO.FDC RFFO.FDC NPHX;CNb NPOR..CNL CFTC'CNb TEN$,CSG D,DI~ X~R,DIb DRHO,FDC ~FFD.FDC PH~,CNb NPOR,CNb CFTC.CNL TEN~..CSG IhD.OIb GR.DIL DRHO*FDC RFFO..FDC NPHX.CNb NPOR,CNh CFTC.~N5 TENS,CSG DRHO.FDC RFFD..FDC NPHX.CNb NPOR,CN5 CFTC..' G 23-0CT-1959 21:52 2 002 124 688 -999 250 -999 290 -999 250 - 250 -999 250 3 O3,6 136 875 -999 250 .'999 250 -999 250 ,.999 250 ,,,999 250 -999 250 4 04 119 -~99 250 - 9~ 250 "999 290 '999 250 '"999 250 '"999 250 3,896 119,563 -999,250 '999,250 '999,2b0 "999,250 "999,250 "'999,250 9 . 0 -9~,250 · '9 .250 "999,250 '999,250 '999.250 "999.250 2,969 77,688 -999,250 "99c~, 250 ' 9,250 '999.250 '999'250 IL, M,DIb TENS.OIL FFDC,FDC CALX.FDC TNPM.CNL RCNT.CNb GR,CNb TENS FFDC FDC CALl FDC TNPH CNL RCNT CN~ GR CNL IbM,OIL TENS.DXi FFDC.FD CALX.FD TNPH,CN~ RCN~.CNL GR.CN~ ibM,DIL FD F~DC,FD~ CALX, TNPH,CN~ RCN~,CNL GR,CN~ ~bM TENS D'IL FD,. DC FAb~ F C FDC ~NPH CNL RCN~ CN GR CN~ FFDC,FDC CALI.FDC TNPH'CN5 RCN2~;CNb GR.CNL 2, 3904. -999, -999. -999. -999; "999, 035 6FLU DIL 000 RHOB FDC 250 NFDC FDC 250 GR FDC 250 TNRA Cab 250 RCFT C~L 250 TENS.CNb 3,095 SFLU.DI~ 3930,000 RHOB.FDC '999,250 NFDC.FDC "999,250 GReFDC '999.250 TNRA,CNL "999,250 RCFT.CNL "999.250 ~EN$,CNL 4 121 SFbU,DXL 3960 000 RHOB.FDC -999 ~0 NFDC.FDC '999 0 GR,FDC -999 250 TN~AeCNL · 999 250 RCF~eCN~ "'999 250 TENS,.CNL 3,975 ~FLU,DIL 3780,000 RHOB,FDC -999 250 NFDC,FDC -999:250 GR,FDC -999,250 TNRA.CNL -999,250 RCFT,CNL -999,250 TEN$,CNL 3,085 SFbU,DIL 3690,000 R, HOBeFDC -999,~50 NFDC,FDC -999.250 GR'FDC -999,250 TNRA,CNL '999,250 RCFT,CNL "999,250 TENS,CNL ~76~.000 RHOB,'DC 99 ,250 NFDC.FDC -999,250 GR.FDC "999,250 TNRA.CNL -999.250 RCFT,CNL "999.2.50 ~ENS,CNL PAGEI 1',932 '999,250 '999,250 '99i!250 -99 250 -99 250 -99 250 3 3 -99 ~0 -99~ 250 "'999 250 '999 ~0 '999 0 -999 250 4 3 '999;250 -999,250 -999;2~0 "9'99,250 '999,250 250 250 "999 250 '99~ 250 ,250 "99~'250 '250 ",999,250 9~ O75 · 999 250 "999 250 · -999 250 -999 250 -999 250 10 iS ~a~ee Verification Llstin~ Chlum rger AlasKa~Computing Center 23'0CT'1989 21{52 PAGE: 11 DEPT. SP DPH! FDC RNFD FDC TENS FOC RTNR CNL CNTC CNL GP CSG DPHI FDC ~NFD FDC TENS FDC DPHI FDC RNFD FDC TENS FDC RTNR CNL DEPT DP~ DIL FDC RNFD FDC TENS FDC RTNR CNL CNXC CNL GR CSG DEPT &P DIL DPHI~FDC RNFDFDC TENS FDC RTNR CN!',, CN'~C CN DEPT. SP DPH! FDC RNFD FDC TENS FDC RTNR CNL G~ CSG 5200 000 -37 500 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 5100 000 -39 5O0 -999 250 -999 250 -999 250 -999 25O -999 250 -999 250 5000,~00 ,'40, 50 -999,250 -999,250 -999,250 -999,250 '99.9,~0 -999, 0 490~,~00 ~4 , O0 - 9 , .50 '999,~50 '999 ,~ 50 '999,250 '"999, 50 '999,. 50 4800,000 '42,250 '999,250 '999.,~0 '999., 0 '999,!'50 "999, 50 .-999, 50 41~0,000 4,750 -999,250 -999 250 -999 250 ~-999 150 -999 50 -999 50 GR,DIL DRHO.FDC RFFD.FDC NPHI,CNL NPOR.CNL CFTC.~NL TENS, ILD DIL GR DIL DRHO FDC RFFD FDC NPHI CNL NPOR CFTC Nb TENS IGD.DIh GR.DIb DRHO,FDC RFFD'FDC NPH{.'CNh NPOR,CNL CFTC,CNb TEN$,CSG ILD GR DIL DRH. O FDC RFFD FDC NPH{ CNL NPOR CNG TENS 'lbD,DIb GR,DIL DRHO,FDC RFFD,FDC NPHI,.CNG NPOReCNb iLD,DIL DRHO,FDC RFFD,FDC NPHI,CNb NPOR,CNL CFTC'CNb TENS,CSG 3.181 101.750 -999.250 '999,250 -999.250 '999,250 '999.250 '999,250 2,591 108,313 -999,250 '999.250 '999,2~0 -999,250 -999.250 "999,250 3 1'93 104 1.88 '999 250 '999 250 -999 250 -999 250 '999 250 '9~9 250 100 '999 250 "999 "999 50 "999 ~0 "999 '250 '999 250 : 3,291 88.750 -999;.250 e999,250 -999e'250 '"999e250 '999~290 .2 9?9 lO 813 "'99~ 250 '-999 250 -999 250 -999 250 -999 250 '999 250. IL~.DIL TENS,OIL FFDC,FDC CALI.FDC TNPH,CNb RCNT.CNb GR.CNL ILM OIL FF DC CALl DC TNPH ~NL RCNI CNb GR CNb IL~,DIG TENS,DIb FFDC,FDC CALI,FDC TNPH,~Nb RCNT, NL GR.CNL ILM,DIL TEN~,DIb FFD ,FDC CA[,I.FDC TNPH,CNb RCN~,~Nb GR, Nb ILM.DIb TEN$,DIL FFDC,FD~ 'CAL~,FD TNPH,CNb ILM DIG CAbl F TNPH CNb 3 t23 3600 000 -999 250 -999 250 -999 250 -999 250 -999 25O SFLU,DIL RHOB.FDC NFDC,FDC GR.FDC TNRA*CNL RCFT,CNL ~EN$,CNL 2 514 SFLU,DIL 3640 000 RHOB.FDC -999 250 NFDC.FDC -999 250 GR.FDC "999 250 TNRA,CNL "999 250 RCFT.CN~ -999 250 TEN$.CNL 3 103 3494 000 RHOB FDC -999 250 NFDC FDC -999 250 GR FDC -999 250 TNRA CNL -999 250 RCFT CNL -999 250 :~ENS ,CNL 3.159 SFLU,DiL ~84.000 RHOB.,FDC 99,250 NFDC,FDC -999.250 GReFDC -999~250 TNRAeCNL -999,:250 RCFTe. CNL -'999,250 ~ENSeCNb 3 295 'SFLU 3514 000 RHOB -999 250 NFDC '999 250 GR -999 250 ~NRA -999 250 RCFT -999 250 ~ENS ,FDC ,FDC ,CN:L ;CNL ,CNL 2,941 SFLU 34:~,000 ,RHOB, '9 .250 NFDC '999,250 GR -999,250 TNRA -999,250 RCFT -999.250 TENS Di b FDC FDC FDC CNL CNL -99~ 250 -99 250 -999 250 -999 250 -999 250 2 377 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 2,b05 -999,250 '999,2'50 '999,250 "999.250 '"999,250 '999,250 0 .:-999,250 :-999,250 ~9 0 304 '99 250 "99 0 '"99~ 250 - 9 50 '9~ 50 '9 ',250 '99 50 '99 250 IS Tape ~erification Listing chlumberger AlasKa Computing Center RNFD FDC TFNS FDC RTNR CNL CNTC,CNL GR.CSG DEPT, SP.OIL DPHI.FDC RNE'DeFDC TE~,FDC RT ,CNL SP DiL DPH! FDC RNFD FDC RTNR CNb DEPT U HI,FDC RNFD.FDC TENS;FDC RTNR,CN[~ CNTC,CN~ DEPT, 5P.DIL DPHI,FOC RNFD,FOC TfN$.FDC RT~R.CNt C~'I'C,CN~ G~.CSG D~PT. DPHI'FDC 4600.000 ILD.DIL '45,81] GR;DIb '999.250 DRHO.FDC '999,250 RFFD.FDC '999.250 NPHI,CN5 '999.250 NPOR.CN~ '999,250 CFTC.CNL '999.250 TEN$,CSG 4500,000 -46,500 -999,250 -999,250 -999.250 '999,250 '999,250 ,999,250 4400,000 -99 250 .-999:250 '99~,250 '99 '999,250 '999.250 -51 50 · 999:50 '-999'250 '999,250 '999,250 '999,'250 "'999,.250 4200.000 ;OOOo ,25 "999'~50 '999e. 50 "999 ~0 "999~ 0 '999.250 4100 000 '52 000 "999 250 '999 250 '999 250 '999 250 '999 250 ~'999 250 ILD DRHO FDC RFFD FDC NPOR CFTC CNh TENS CSG GR DRHOFDC RF~D ~D~ NPOR NL CFTC Nh TENS $G GR,DIL ORHO.FDC RFFD.FDC NPHX..CNh NPOR,CNb CF~C',CNb TENS,CSG ILD DIS GR DZb DRHO FDC RFFD FDC NPHI. CHh NPOR CN5 CFTC CN5 TENS CSG GR.DIL D~HO.FDC R~FD.FDC NPHI'CN~ NPOR.CN~ CfTC,CN~ TEN$.CSG 23-0CT-1989 21:52 2 953 106 125 -999 250 -999 250 -999 250 -999 250 -99~ 250 '99 250 : 191 9 563 -999,250 -999.250 -999.250 -999.250 -999.250 2,995 ,95e688 -999,250 -999 '999:50 '999 50 '999.250 , 3 071 92 O0 -999 -999 '999 250 -999 250 -999 250 -9~9 2 0 -9~9 250 '999 ,999 ~00 '999 250 "999 250 . 3,445 98'.5~3 -999,250 '999,250 '999,250 '999,250 "999,250 ILM,DI~ ?EN$,DIL Ff'DC.FD~ CA~2.FD TNPH.CN~ RCNT.CND GR,CN~ TEN~.DIL FFDC.FDC CALX.FDC ?NPH:~N~ RCNT Nb GR,CNb FF CA ~NPH,~Nb RCNT, N~ GR,CNb ]284 000 RHOB. C -999 250 NFDC.FDC -999 250 GReFDC -999 250 TNRA.CNL -999 250 RCFT.CNL -999 250 TEN$.CNL '3 120 SFbU.DIL 3200 000 RHOB FDC -999 250 NFDC FDC -999 250 OR FDC -999 250 TNRA CNL -999 250 RCFT CNL -999 250 TENS CNL 2 897 SFhU DIb 3064 000 RHOB FDC -999 250 NFDC FDC -999 250 GE FDC -999 250 TNRA CN~ -999 250 RCFT CN~ -999 250 TENS CN~ Ib~,D:Ib .2,932 SFb~U.DI~ FFDC.FDC ,250 NFDC,FDC CALI,FDC -999,250 GR,:FDC TNPH,CN~ -999,250 TNEA,CNL RCN~,CN~ -999,250 RCFT,CN5 GR,CN~ -999,250 TEN$,CN~ TII~M.DIh 3.155 $FLU.DIL ENS.D.IE 2930.000 RHOB.FDC CAbI.FDC -999.250 .FDC TNPH,CN~ -999,250 ~NRA~:CN~ RC~,CNL -999.250 RCFTeCN~ GReCN~ -999,250 TEN$,CNb FFDC,FD~ TNPH,CNb RCNT.CNL GR,CNb 3 28O 2904 000 -999 250 -999 250 -999 250 -999 250 -999 250 BHOB,.FDC NFDC,'FDC GR,FDC TNRA,CNL RC.FT.CNL TENS.CNL PAGE{ 12 2 683 -99~ 25O -99 250 -999 250 -999 250 -999 250 -999 250 2 951 "999 250 '999 250 -9 250 "999 ~50 "999 50 "999,~ 0 250 , . - 9,250 '999,,~0 '999,, 0 '-999,250 '999,,250 .2 i250 999.250 999,250 999,~50 "999, 50 '999.250 '999~250 '999,~ 0 '999,250 '999, 50 IS Ta~e Yerlfication Listing =hlumhetqer AlasKa Computing Center DEPT, DPH! FDC RNFD FDC TENS FDC CNTC CNL GR DPH! FDC RNFD FD TENS FD~ GR DE~T, SP,DIL DPHI FDC ~NFD' ,FDC rENS,FDC RTNR,CNb CNTC,CNL GR,CSG D~T DPHI,FOC RNFD'FDC TEN$,'FDC RTNReCNb CNTC,CN~ GR,CSG DEPT DPHI,FDC RNFD'FDC ,TENS,FDC DEPT, $P'DIb RNFD,FD~ T~NS,FD R ~R,CNL CNTC,~NL GR,,.CSG 4000 000 -56 5OO -999 250 -999 ~50 -999 50 '999 250 -999 250 -999 250 ]900 000 -55 75O -999 50 -999 -999 250 -999 250 :-999 250 :-999 250 3800,000 -56,250 :999,250 999,250 -999,~50 -999,250 "999~250 '999,250 3700,000 .'58*500 '999,250 ~'999e250 "999,250 -999,250 ~999,250 '999,250 3~0,000 "99 250 -999, 50 '99 ~50 3500,000 .-60,750 '-999~250 50 "999'~50 -999,, "999,2:!0 '999,2 ~ ~999,2 ILD,DIL GR,DIb DRHO,FDC RFFD,FDC NPHI,CNb NPOR,CNb CFTC,C~9 TEN$,C~ GR,DIL DRHO,FDC RFFD,FDC NPHI,CNb NPOR'INh CFTC, Nh TENS, SG lbo GR DRHO FDC RFFD FDC NPH/ CNb NPOR !N~ CFTC N~ TENS SG ILD,DIh GR,DIb DRHO,FDC RFFD,FDC NPHI,CNh NPOR,CNL CFTCeCN~ TENS,,CSG ibO,Dlb GR,DIh U~,HO'FDC R FD,FDC NPHI,CN5 NPOR.CN5 C~TC~CNb T .S,CSG ZGR,DIL D~HO,FDC R. FD,FDC NPB'~,CN~ NPOR,CN5 CFTC~CN,~ TENS,CS~ 23-0CT-1989 21{52 3 578 95 813 -999 250 -999 250 -999 250 -999 250 -999 250 ~999 250 . 3,741 116,250 '999,250 '999,250 - ,250 "999,250 '999,'250 12 423 79 OOO -999 250 -999 250 -999 250 '99 50 '999 250 3,921 '9 , 50 '999,250 '999,250 9,)50 -9990 50 ~ 058 '"999 -999 250 -999 250 -999 250 "999 250 '3 3~4 ~4 813 "999 250 "999 250 -999 250 '-999 250 *~999 250 ~999 250 IbM,DI~ TENS,DIb FFDC,FDC CALI,FDC T~PH,CNG RCNT,CNG GR,CN~ TEN~,DI~ FFDC,FD CA~,FDC TNPH,CN~ RCNT,CN~ GR,CN~ TENS,DI~ FFDC,FDC CALI,FDC RCNI, GR,CN~ FFD< C~IFD¢ TNPH CNb RCNT TENS, TNPH 3 48O SfbU 2974 000 RHOB -999 250 aFDC -999 250 GR -999 250 TNRA -999 250 RCFT -999 250 ~ENS ,DIL ,FDC ,FDC ,FDC ,525 000 ~F~U.DIL HOB.FDC ~9:250 NFDC.FDC -999,250 GR,FDC -999.250 TNRA,CNL -9~,250 RCFT,CNL -9~.'250 TENS,CNL 9 2880 -999 -999 -999 -999 "999 494 SFbU.DIL 000 RHOB.FDC 250 NFDC'FDC 250 GR,FDC 250 TNRA,CN~ ~50 RCFT,CNL TENM,CNL 3 6B1 2650 000 RHOB,FDC -999 250 NFDC,~DC -999 250 GRi~DC -999 250 TN~A~CN~ -999 .2,50 RCFT,'CN~ -999 250 TENS.CN[, i. 3 51:2 27.00'000 RHOB,FDC: -999:250 NF~C,FDC -999,250 , GR,FDC -~99,2~0 ~NRA,CN -999'250 R~FT,CN~ -999.250 TENS,CNL, I~M,Olb 3,053 SF~U RHOB .000 TEN&,OIb 254~ FFDC,FDC -9 ,250 NFDC CALI.FDC -999.250 OR 'TNPH,CNb '-999.2~0 TNRA RCNTeCNb -999,250 RCFT GR.CNb -999.250 TENS ~ DC FDC FDC CNb Cab 3 243 -999 250 -999 250 -999 25O -999 250 -999 25O -999 250 3 413 -999 250 -999 250 '99 50 '999 50 -999 250 18,~34 -99 50 -999, 50 -99 50 "99' 50 ~99 , 50 99 , 50 99 ~250 ~999~250 '9~'250 '9 ,250 i,,2 0 9, 50 '999,250 '999.,250 "999,250 250 250 .-999;250 ~'-999,~50 -999'250 '999, 50 13 iS Tame Vertflc&tlon Listing chlumberger AlasKa Computing Center DP~I~FD¢ RNFD FDC TENS FDC RT~R CNL CNTC CNL GR CSG DEPT $P:DIL DPNI,FDC RNFD,FDC TENS.~DC £)EPT SP:DI.b DPH~.FDC RNF .'FDC TFN$,FDC R?N~.CNL CNTC,CNb GR,CSG D£PT SP DIb DPH! FDC RNFD R?~R CNb CNTC CNb DPMI.FDC RNFD FDC TEN~ FDC RTN CNb D~PT DPHI FDC RNFD RTNR CNL CNTC CNb 3400 000 -999.250 -999.250 -999.250 -999;~50 -999, 50 -999.250 ~300,000 .-17.250 -999.250 "999,250 "999.250 "999,250 "999,250 66.813 *999 250 "999 250 "999 ;250 "999,:259 46,438 ~00.000 . 99,250 -999.250 '99~,2'50 -99 e~50 "999m, 50 '999,250 41,719 3000,000 ~999,~50 - ,250 ~999,250 o 0 43,: 5 . 2900,000 -999,250 -999;.250 -999,250 -999,250 -999,250 -999,250 48'906 ILD.DIL GR,DIL DRHO,FDC RFFDeFDC NPHI, Nb NPOR,~Nb CFTC,~G TENS, ILD,DIb GR,DIG DRHO,FDC RFFD FDC NPOR CFTC tnb TENS CSG ILD,DIb GR,DIL DRHO,FDC RFFD,FDC NPOR CFTC T~NS GR OZb DRHO FDC RFFD FDC NPHX NPOR CNb CFTC ND TENS ~5G I./.D,DZb GR.DIL DRHO FDC RFFD FDC NPHX. CNG CFTC T,E~S CSG GR DRHO F'DC RFFD FDC NPHI CN5 NPOR CNb TENS G 23-0CT-1989 2I;52 4 J99 77 750 -999 250 -999 250 -999 ~50 -999 50 -999 250 -999 250 "999 250 "999 250 "999 2~0 -999 250 -999 250 2370 000 "999 250 o - 250 -999 250 -999 250 ~9 50 "999,2~0 "999,'~ 0 "999, 50 "999, "999,250 "999~250 '2340,000 "999,250 '999,,250 "999,250 "999,250 '999,)50 ,-999, 50 -999,250 2280,000 "999 250 "999 '999 '999 250 "999 250 2200 000 ILM,DIL T£N$,DXL FFDC,FDC CALI.FDC TNPH,~NL RCN~, Nb GR,CNb ILM.DIL TENS.DXL FFDC TNPH CNG RCN~ G~ CNb ILM.DIL TEN~.DIb TNPHe~Nb RCNT, Nb GR,CNL iLM,!IL TENS, Fl'DC., CA~1eFDC TNPH,CNL RCNT,CN' GR,CN~ I.bH,Dlb FFDC,FDC CALI,FDC TNPH,CNb RCN~,CN~ GR,CNG TENS,DIL FFDC'FDC CALI,FDC TNPH,CNb RCNT,CNb GR,CNb 3 826 SFLU,DXL 2464 000 RHOB.FDC '999 250 NFDC,FDC -999 250 GReFDC '999 250 TNRAeCNL -999 250 RCFTeCNL -999 250 TENSeCNL 2000 000 SFLU,DIL 2414 000 RNOBeFDC -999 250 NFDC,FDC -999 250 GR FDC -999 250 TNRA CNL -999 250 RCFT CNb -999 250 TENS CNL -999 250 S.FbU~DXL -999 .250 RHOBiFDC -999 250 NFDCeFDC -g99 250 GR,FDC -999 250 -999 250 RC~T,C~L -999 250 TENSeCNL -999 250 SFLU -999 250 RHOB -999 250 NFDC "999250 GR -999:250 TNRA ~999 250 ~CFT -999 250 TENS FDC FDC FDC CNL CNL CNL -999 250 SFLU =999 250 RHOB -999 250 NFDC -999 250 GR -999 250 TNR. A -999 250 RCFT. -999 250 TEN~ FDC FDC CNL '999.~ SFbU,D~L -999, .~HOB,F C '999,250 NFDC,FDC -999.~0 GReFDC "999, 50 TNRA,CNL -999,250 RCFTeCNL -999,250 TENS'CNL PAGE~ 3 345 -999 250 -999 250 -999 250 -999 250 *999 250 -999 250 2000 000 -999 250 -999 250 -99! 0 -99 ~0 -99 250 -99 250 * ,250 "99 , 50 "99 , 50 0 "99 * "999,2~0 ,250 '9 ,,.250 "999.250 '999,250 "999,250 "999,~50 ,250 ,250 "999,250 -999,250 "999,250 ~"999,250 '9.99,250 '999,250 "999,250 14 9T 0~Z,666- 0fI'666" 0G1,666' 0g~.666~, Og~ 666~ Oft 666' 0~Z:~666" 0~:666~' Oil 666* Oil 666" Oil 666' Oft 666' Oig 666' 666' 0GZ666" 0~i:666o 0~.666~ OtZ 666' O~l 666' O~l 666" Oil 666- 0§' 666' O§l 666' Oil 666- O~l 666- Oil 666' OBZ 666- 0~1666-' q'NDegN3~ O~Z 666" O~l 666' 0~ 666' OG1 666' OGg 666' Og~ 666' O~l 666' 0g1~666' {3'~3H 0~Z'666' 0gt'666' qND'V~NI 0gZ'666' 0~Z'666' 30J:~9 0~1e666" DO~eDOJN 0~'666" 0~1'666' qYO'~qJg 0Gl'666' Oil 666' Oil 666' Oil 666' Ot~ 666" O~ 666' 0 i 666' OGl 666' |~9Vd qND*'gN3$ 0G~'666' qNg~V~N& 0~Z'666' 3O&:D~JN 09Z'666' qlO AqJg 0G1'666' ND qlO'Nqi qND ~NDa qlo qND'~D qN3*~N3a qN3 ND qN3 30~ qlO qN3'B9 qND'~NDa *iqVD qlO:~N3~ ~ND'a9 aJ,DoJ~ qlO'WqY 000 i~6t 0~ 666~ 0~ 666~ Oil 666~ 0~ 666~ Of~ 666~ Ogi 666~ 09 666' ooo oooZ OGi 666~ Of 66' O~ 66* 000"~0~ 0~ 66' O~l 666" OgZ'* *666' 000 O~l 666- OGl 666- O~i 666- 0 666- Oil 666- O~i 666" O~ 666' 000 0~ O~l 666~ Oil 666~ 091 666' 0~ 666e Oil 666' ooo Oil 666" Oil 666' Ot~ 666' Oil 666' O~l 666' Oil 666" Oil 666' ~ND:~OSN qIO"O'l! 302 3aJ OHiO qlO ~aJ oH~a qi(l 69 qND*aOaN qND:ZHdN qIO ~9 qND'D&J3 qND*aOdN 3Q~OH~O qlO'BD qIO'OqI qN3 0~i2666" 0~t'e666~ 0ft.666' 0G~,666' 000 0f12666- 0~12666- ~666~'' 666" 0o~0o~ 0g~,666" Oil 666~' 0o0 o0~. 98T ~g 0~ 666' Oil 666' Oil 666- Of~ 666' 666- Oil 666.: 000 0091 Ogl 666" Oil 666. 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FDC RNFD FDC TENS FDC DEPT , FDC RNFDFDC TENS FDC RTNR C~TCCNL GR CSG DEPT,D DP~I,FD~ R~FD ,FOC ~ ,CNL ,CSG DPH! FDC R~F'D FDC T,~NS FDC RTNR CNL CNTC CNL ¢~ CSG ooo =999 =999 250 "999 250 -999 250 -999 250 1500 000 -999 250 -999 250 -999 250 -999 250 -999,250 -999,250 30,328 1400 000 -999250 -999 250 -999 250 -999'250 -999,,250 9999,250 '49,969 1300 000 -999 250 -999 250 -999 250 ,-999 250 -999 250 ""999 250 22 313 1200,000 '999,250 "999',~50 "999,250 '999,250 "999,250 '999,Z50 ]7"906 ~100,~00 .999' 50 999,250 '-999,250 9999':250 -999.250 -999.250 36,000 ILD,DIb GR,DXL DRHO,FDC RFFD,FDC NPHI,CNL NPOR,CNL CFTC,CNL TEN$,CSG ILD,DIb DRHO,FDC RFFD,FDC NPOR,CNb CFTC,CNL TEN$,CSG iLD DIb GR DIb DRHO FDC RFF'D. FDC NPON CN~ CFTC CN5 TENSCSG GR,DIL DRHO,FDC RFFD,FDC NPH~' NPOR.~~b CFTC, N~ TEN'S,~SG ILD,DIb GR,DIb DRHOsFDC ~FFD.FDC NPHi,CNb NPOR,CNL CFTC'CNL TEN'$,CSG ILD,DI5 GR,DIb DRHO,FDC RFf'D,FDC NPMI,CNL NPOR,CNL CFTC,CNL TENS,CSG 23-0CT-1989 21:52 '999,250 "999,250 '999,250 ~999,250 '999,250 -999,250 '999,250 1715,000 '999 250 -999 250 9999 250 '999 250 -999 250 -999 2~0 '"999 250 1660 000 -999 250 99 2~0 -999 250 -999 250 ~999 250 "999 250 1580 000 =999,250 ~999;250 '99~'250 "99 ,250 -999,250 "999,2'50 '999,250 1575,000 "999 250 -999 250 · "999 250 '999250 ~999 250 "999 250 "999 250 1490 000 '-999,,.250 "999,250 '"999,'250 "999~250 "999,250 ~999.250. .999'250 1425,000 IbM,DIb TEN$,DIL FFDC,FDC CALI,FDC TNPH,~Nb RCNT, Nb GR.C~L ILM,DIL TEN$.DIh FFDC.FDC CAbI FDC TNPH CNb GR CNb ILM,DIb TEN$.DIb FFDC FD CALl FD~ TNPH CNb GR CNL TEN$,DI~ FFDC,FDC CASI,FDC TNPH,CN~ IbM DIb. FFDC FDC CA/,I FD RC~T GR TEN$*DIb FFDC,~DC CALl, DC TNPH'CNL RC~T'CN~ R,CNb -999,250 SFbU,DIL =999,250 RHOB,FDC -999,250 NFDC,FDC '999,250 GR,FDC ~999,250 TNRA.CNL -999.250 RCFTeCNL -999.250 TENSeCNL -999,250 SFbU.D1L -999,250 RHOB,FDC -999,250 NFDC,FOC -999,250 _ GR,FDC 9999,250 TNRA,C~L =999,250 RCFT.CNL '999,250 TENS,CNL '999,250 SFLU,DIL '99~:250 RHOB,FDC -99 250 NFDC,FDC =99~,250 GR,FDC -99 ,250 TNRA,CNL =99 1250 TEN$,CNL , 9999,250 SFLU,DIL "999,250 RHOB,FDC -999,250 NFDC,FDC "999 ~50 GR,FDC -999:50 .TNRA;CNb -999 ~50 RCFT,CNL m999:50 TENSeCNb -99~,250 999 ,250 9999,250 9999,2,50 -999,250 -999'~50 -999,250 SFbU,DIL RHOB,:FD~ ':FDC TNRA CNL RCFT TEN$CN~ -999,250 SFbO,DIL -999 250 RHOB,'FDC =999 250 NFDC,FDC "999 250 GR,FDC -999 250 TNRA,CNL -999 2'50 RCFT,.CNL -999 .250 TENS,C~L PAGE: 999,250 -99 250 - 250 -99 250 =999 0 -999 250 50 -999 =999 -999 250 =999 250 '999.~50 '999,250 -999, 5o "999*250 -999 0 -999,250 '999,250 "999',250 "999,250 '999,250 '999,250 "999,250 ':'999,250 '999,250 '999.,250 '999,250 '999,250 9999,250 "999,250 "999,250 '999'2,50 :'999,~50 '999,~0 '"999,20 "999,250 '999,250 17 XS l'ape YertfXcatton Ltsttnq Chlumbetger AXasKa Computtng Center 23-0CT-~989 2~52 PAGES 18 DEPT, DPHI'FD¢ RNFD,FDC TENS,FOC RTNR,CN[, CNTC,CNL GR,CSG I000 000 -999 250 -999 250 -999 250 -999 250 -999,250 -999,250 48,!88 DEPT SP DPHI RNFD TENS RTNR 984,500 DIL -999,250 FDC '999,250 FDC '999,250 FDC '999,250 CNL -999,250 CNL -999,250 CSG 43,000 END OF DATA ILO,DIL GR,OIL DRHO,FDC RFFO,FDC NPOR,CNL CFTC,CNL TENS,CSG ILD OIL GR DRHO FDC RFFO FDC NPOR CNh CFTC CNb TENS CSG '999,250 '999,250 '999,250 '999,250 '999,250 '999,250 '999,250 1445,000 "999 290 -999 250 -999 250 '999 250 -999 250 '999 250 '999 250 i410 000 ., ILN TEN& OIL FFDC FDC CALl FDC TNPH CNL RCNT CNL GR,CNL IbM,OIL TEN~,DI~ FFDC,FDC CALI,FDC RCN ,CN~ GR,CN~ -999,250 SFLU,,DIL '999,250 RHOB,FDC '999,250 NFDC,FOC -999,250 GR,FDC -999,250 TNRA,CNL -999,250 RCFT,CNL -999,250 TEN$,CNL -999 250 SF~U,DIL -999 250 RHOB,FDC -999 250 NFDC,FDC -999 250 GR,FDC -999 250 TNRA,CNL -999 250 RCFT,CNL -999 250 TEN$,CNL -999 250 -999:250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 **** FILE TRAILER FILE NAME :'EDIT ,001 SERVICE : FbIC VERSION , O~)AO~ DATE ,8 10 23 MAX REC SIZE , 1024 f'ILE TYPE , LO LAST FILE **** FILE HEADER **** FILE NAMg : EDIT ,002 VER ION ~9/~0/~ DATE : ~AX REC SIZE : 1024 FILE TYPE : LO ~ASTFILE ******************************************************************************* , * FILE - EDIT,002 * * "HIGH RESOLUTION PASS" , * DATA SAMPLED EVERY -,1000 FEET IS Tape Verification l, lstinq Chlumberger AlasKa Computinq Center DATA INCLUDED - TOOL EXTENSION TYPE USED FDC .FDH CNT-A/D/H .CNH TOOL NAME FORMATION DENSITY COMPENSATED NEUTRON PAGE: 19 TUN! VA~U DEF! ~! ARCO ALA3KA INC, Company Name ~N KUPARUK Field.Name wN 2K- 15 well Name APIN 50-~03-20115-0~ API-Serlal Number FI, 144 Fab,& 94 FEb rleldbOcat~on SECT 11' Section TO,~ .10N Township RAnG UE Range COON NO~TH SLOPE County STAT A/,A'SKA Sta[e or Province NRTI USA Nation , W~TN ~ MCKAY/B. BEAL W~tness.s name SON 5~'8441 Service Order Number L~F ~ bog Measured From APD FT EKS FT z54, EDF FT 153, ~DO rT 8304, DEFY DEPT DEPTH CHANNEL NA~E DPHI Density P~rosit¥ Bulk D~nsity" RHOB DRHO Delta tho FFDC Far FDC Count Rate.. NFDC Near FDC Count Rate RNFD Raw Near FDC Count Rate RFFD Raw Far FDC Count Rate AbI Caliper R GammaRay IS Ta~e VerltlcmCton btstlno 23-0CT-1989 21:52 chlumoerger AlasKa Computlno Center TENS NPHI TNRA RTNR RC~T CNTC CFTC GR TENS DEF! Tension NEUTRON POROSITY THERNAL NEUTRON POROSITY CALIBRATED THERMAL NEUTRON RATIO RAW THERMAL NEUTRON RATIO NEUTRON POROSITY OUTPUT FROM AN APPLICATION PROGRAM RAW CORRECTED NEAR THERMAL COUNTS RAW CORRECTED FAR THERMAL COUNTS CORRECTED N~AR THERMAL COUNTS CORRECTED FAR THERMAL COUNTS ~amma Ray Tension ~mm~Nmmm~mmMNmmmmmmmmmm~m~mmm~m~mm~mmmmM~mm~m~mm~mm PAGE: 2O DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB~*~ TYPE REPR CODE VA~UK 1 66 0 2 66 0 4 66 I1 6 12 6 13 6~ 0 14 65 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 APl' APl: AP1 FiLE NUMB NUMB SIZE REPR PROCESS ID ORDER'#.. LOG,TYPE CLASS MOD NUMB SA~P ELE~ CODE (HEX) ~ ~,~ ~$~ oo ooo oo o ~ ~ ~ ~ ~s ooooooouoo V~rV. p,J s~44~ oo ooo ~o o ~ ~ ~ ~ 6~ oooooooooo DRHO FD. G/C3 548441 O0 000 O0 0 2 1 I 4 68 0000000000 ~'oc ~o~ c~$ s4s~ oo ooo oo o ~ ~ ~ ~ ~ oooooooooo ~oc ~VH C~S ~4~ oo ooo oo o 2 1 ~ 4 6~ oooooooooo RNFD FDH CPS 548441 O0 000 O0 0 ,2 I 1 4 68 0000000000 IS Tape verification Listing Chlumberger AlasKa Computing Center PAGE= 21 HFFD FDH CPS 548441 CAb! FDH 1N 548441 GR FPH GAP! 548441 TENS FDH LB 548441 NPH! CNH PU 548441 TNPH CNH PU 548441 TNRA CNH 548441 RTNR CNH 548441 NPOR CNH PU 548441 RCaT CNH CPS 548441 RCFT CNH CPS 548441 CNTC CNH CPS 548441 CFTC CNH CPS 548441 mm{im mN # ml ~ m mmmm # m mmm~ # il, ~ m m {mmm~ klm, ~i~ imm ~M) m 'm ~m, m Mm m m! ~ ID ORDER # bOG TYPE CLASS MOD NUMB SAMP EbEM CODE (HEX) O0 000 O0 0 Z I I 4 b8 0000000000 O0 000 O0 O 2 ! I 4 68 0000000000 O0 000 O0 0 2 1 I 4 68 0000000000 O0 000 O0 0 2 1 I 4 b8 0000000000 O0 000 O0 0 2 1 1 4 b8 0000000000 O0 000 O0 0 2 1 I 4 68 0000000000 O0 000 O0 0 2 1 I 4 68 0000000000 O0 000 O0 0 2 1 I 4 68 0000000000 O0 000 O0 0 2 1 I 4 68 0000000000 O0 000 O0 U 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 I 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 GR CNH GAP154~884~64~ O0 000 O0 0 2 1 I 4 68 0000000000 TENS CNH LB 5_~_-. O0 000 O0 0 2 1 i 4 68 0000000000 DE.PT, FFDC FDH AbI FDH NPH CNH RCNT CNH GR CNH DEPT, FFDC,FDH CALI,FDH TNpH,CNH RCNT,CNH GReCNH D£PT FFDC:FDH CALI,[DH TNPH,CNH RCNT,.CNH G~,'CNH DEPT FFDC:'FDH CALI,FDN TNPH,,CNH RC~T,CNR G~,CNH 322,100 ,02 1920,41~ .108,~13 8jO0,O00 1254,000 7,180 40,023 I08, 8200 000 5O925O 8 727 42225 ~9~7488 .103000 O0 8t00'$0~ '523'852 1815, 2 94,313 DPHI,.FDH Nf'DC,F'DH GR'FDH R~F~,CN~ ?EN&,CN~ DPHI,FDH NFDC;FDH GR,~DH TNRA,.CNH RCFT,CNH TEN$,CNH DPHI,FDH NFDC,FDH GR FDH TNRA:CNH RCFX,CNH T~N$'.CNH .NFDC,FDH GR,'FDB TNRA,CNH RCFT,.CNH TENS'CNH 30,526 869,000 108,313 3,388 518,664 2850.000 ~0,526 869,000 I08,3{3 ,~94 51~4.000 12 606 1.03 448 5224 , , 5e7 94 5o7 5228 RHOB.FDH RNFD,FDH TENS, DH RiNR,~Nh CNTC,CNH R~OB, FDH RNFD,F!H TENS:~ ~ R%'NR ft CN~C,CNB ,877 RBOB,FDB ,000 RNFDeFDB cO00 TEN&,FD~ ,585 R~NR,CNH ,353 CNTC;CNH ,000 0~000 RHOB,FDH R~FD,FDH 442 RTNR NH 087 CNTC,CN~ 000 2. 146 DRHO,FDH ~04.000 RFFD,.FDH . ,000 NPHI.CNH 3,653 NPOR,.CNB 1959,955 CFTC,CNH 2,146 DRHO,FDH ~68 ,000 516~ RFFD,FDH ,000 NPHI,CNH 3~653 NPOReCNH 1959,955 :CF~CeCNH 2 438 DRHO 11,52 000 RFFD 5224 000 NPHZ 3828 NPOR 1969 068 CFTC .FDH ,:FDH ,CNH ,CNH 2,402 t)RHO.,FDH 11.22,000 RFFD,.FDH 5228,000 NPH2'CNH 3'731 NPOR,CNH 1906,439 CFTC,CNH 0 105 2554000 42 8 588 745 0 ~05 2554000 .588 7,45 0,030 1105'000 44, 4 6 566,$59 9~.,DOb ,000 ,82~ .553,335 Tape verification Listing Chlumberger AlasKa COmputing Center DEPT FFDC RCNT 8000,000 DPHI,FDH FDH 480,750 NFDC FDH FDH 8,922 GR:FDH Chh 32.374 TNRA,CNH CNH 2369,175 RCFT,CNh Chh 88,0'63 TENS.CNh DEPT, FFDC, CALl. G~, FDH FDH CNH 7900 000 526 5OO 8 26 852 2936 03 49 96~ DPH[ FDH NFDC FDH GR FDH TNRA CNM TENS DEPT FFDC CALl. TNPH RCNT GR 7800,000 FDH .104,3t3 FDH 8.719 CNH 3~,354 ChH 267 ,482 CNH 5[,875 DPH! FDH NFDC FD~ GR FDH TNRA CNH TENS D~PT FFDC RCNT 7700,000 FDH 476,000 FDH 8 97~ Chh 45i07 Chh 1703 825 Chh .107,125 DPHf NFDC GR TNRA RCFT TEN~ FDH FOb FDH CNn .C, NH DEPT FFDC CAb/ TNPH 7600,000 DPH{,FDH FDH 47 000 NFDC.FDH :i!i Chh 44, TNRA,CNH Chh 1753, RCF~,CN~ Chh ~61,500 TENS,.CNB DfPT 7593 FFDC:FDH 618 CALIeFDH 10 T:NPH,CNM ."999 RCNT,CNM -999 GE,Chh -999 6OO 5OO O70 250 < 50 DPHZ,FDH NFDC.FDH TNRA':CN~ ~F~.C~ TENS,Chh END OF DATA 23-0CT-1989 21152 11,571 594.500 88,063 92,899 6 8,007 5088,000 14,162 605.000 49,969 i07 252 5148,000 '30 855 419 250 51 875 '3 O98 882 276 5140 000 948 619 5(!,)0 107 125 3 763 420 646 5032 000 12,866 558;500 16I,.500 "3,?~1 479,462 4900'000 16,170 665,000 179,375 '999,250 '"999,:250 '999':~250 RHOB FDH RNFD FDH TENS FDH R~NR ~NH CNTC NH RHOB,FDH RNFD,FDH TENi!FDH CNT CNd RHOB.FDH RhFD.FDH TENS,FDB RTNRe~NH ,CNTC, N~ RHOB,FDH RNFD,FDH TEN~,FDH RTNR,CNH CNTC.CNH RHOB, FDH RNFD..FDB TEN$'FD{~ RTNR'CNM CNTC,CNh RHOB, FDH RNFD,FDH TEN$,FD~t CNTC, 2 459 DRHO,FDH 1165 000 RFFD,FDH 5088 000 NPHI.CNH 2 810 NPOR,CNH 2293 222 CFTC.Chh 2 416 DRHO.FDH 1185 000 RFFD,FDH 5148 000 NPHI,CNH 2 796 NPOR.CNH 2860 208 CFTC,CNH 3 159 DRHO.FDH 846 000 RFFD,FDH 5140 000 NPHI,C~H 3 148 NPOR,CNH 2564 399 CFtC.Chh 2 495 DRHO ~,182 000 i~FFD NPOR I739 136 .CFTC FDH FDH CNH CN'H 2 438 DRHO 000 NPH! 3 708 NPOE 1826 836 CFTC ,FDH ,FDH ,Chh ,Chh ,Chh 2,383 DRHO 1310,000 RFFD 4940,000 NPHI. -999,250 NPOR "999,250 CFtC iFDH FDH Chh ,Chh ,Chh PAGE: 22 0 028 919 000 31 881 31 606 801 086 0 022 1044 000 25 953 25 741 1147 243 0,107 192.250 8 381 0'0 0 0~0 942 47 319 45 47O 474 721 "0,001 985,500 46,586 44',576 50&'280 0 055 1:281, 000 '"999 250 · ,999 250 -999 250 : ~av~ ~nola3~d DZq& : NiDI~O K[/01/68 : ZOO' ~I0~ : ~VN 3~lJ E~ bUT%sTq UOT=e=I~t~eA ade~ ~1 J .;C,,KOF:'AA[.'~ ,2i,, 1 5,5[;-1 ,"' 3-2 (:, 1 3 - (.:. 0 - R A ~'¢ (; F,: I8 Tape ve..ri'fi, cat:lo:', ;'.?': 153" ............. ~ ~ [3F 333P' '" .... . .. 2 " 'F'II:Tr4,.~T.F2 .,,,,..S?.ST.tvl Y,, 4. .... 4 '~ 7'..~ r~,, U t.', C a k' [ .P F.', 8 .;. [',; P I 51[ 'i' f: 2., 'l 8 a 7 () P A G E: TAP. I.,E 'f'YFE : (7,'i, 6 F T ;t. () 2K - !b ':~'ell x~ame bO- lC, 3-2¢~ 1 3-~,~0 &PI ~ .N Der - · oerial um 14,~' F:':L, & u4' WEI, Field Location i :1. SOCt i Oh I C,r~' Townsh:Lp bE Range ,~,b~,"';K~, :State or Province U S .A a a t i o n T. ~,:C[;aY/b. ~.~E,qL ~,,itness' ~qame 54U,ial ' Service Order Number ,~SL., Permanent datum (-~;'i.~; boq "~easured From 1 5 4, 153, 29t., 00 3. 0: *,,,} 0 Botto,,'.~ I,:oq Interval Top Loq Interval (.)CTO!.tEF: ~.,4 Time Circt.llation Stopped PAGE; ,, $}2.:HV .... l.'r St',? ! r.> .,. -- i'~ :3, I, 21 2,~53 860, O0 97,875 3,,492, 4 9 9,2 B 8 2., 3 0 0,0 0 0 3 126 2 253 86O 500 97 875 3 492 499 288 53{)8 000 ........ ,~,~, ].1. 3. ~,] ~ ....... PEUJ. FF.C '~ ~',, 7..~ 3 i.'RFO. FbC 0.662 R]~'..'~,C:.j1.. '~,'tcb. .'.:P[".F',("'~,~:_, 40,2}hq C ~: TC. C ~,: L :! '.,:, ~: 1 . 5 (; ~ CFT C. C :,: L f'~ 2 '7.2 I 5 (4 F,.',. C ~'.7 L D ~: P T. ~: 1,. L, {':. t,. t., ,9 [ ~, L). r:. '~ ~., 2. ~: 24 7 L, ,','~. [J I L b~i-tI, Fi~C ~2. 1,.~ [)q~. FL)C 0,039 F.~'DC. ~bC TEi~18 .FDC ~.~'4,, r~:,, ,'t.PF~ i. C:.~ L, 5q.965 ~;'I'~'(' (~ (,)~i ~F~C' FDC CNTC., C ~; l~ 21 ~,~ ........ 3 1 n ~ C ~'''I'C . C' ;'~ L 7 ~ 9.2 10 ...... . ...... , ,~':~ -9c9.250 D P H I. F r~ C ] ,%, ,~; 53 0 ~ h O. t,'.' t)C 0. O 'L 2 F F I) C, F' C C ' "' ' ......... * ............ *('"" 2 537 G [,'. C 5 (,~ ,'- 999,2 B "* ,:L' ~1 ~"~ 5, C S r3 - 999,250 D E: P T, '78 (..~ ~.~. () 0 ,'.Z?I i.~ 0..?, t L 2.63 ~ I '.!., ~.,.i. ~ I L ..... "' "" '{~ J" '~'~ 96, 'i 5 () T E: N ,.$, ;) Z b [~PH$. ~'r~C "'~, ':;.;~;.~:~ i,)P~'ir'~ F!.:~C ()~ !00 FE~'"C FL)C P T ?~ R, C ~'.:~ L 3..¢ 25 ;'I P 0 R, C ;~'.~ L, 4 {~. 3 ~ 2 C N T C, C N ,t"., 2 '(,; 7 ~,':,. '3 j,, 3C F T C. C i',~ L 620. e '16 S P', f) t L ~ 3 ~ .... , <), C, ~': (] P , ~) I (~1, t,, fl, 31 3 t,f' i,,,[" J',"' 5,,", Q, 1. b D P H )'., F r'~ C 'i ,%, ":.~ C~' "') ......... . 00 · , ';,,~ . ,, , ,,~ " ~ 'T ,~" G ~, C 8 C , q r=, 9. v 5 '.) i~' ~., ~" S (:: ' '999,250 , ,, .~ ...... ;,. ~ ~ ., 2. 't7~_ 5360.00U R 2,75 0 37.44.2 .t ~ 32,620 97,93b 2.950 5304.000 b q ,'5.000 8.891 e.O, 1 .!. 8 ,1837. 389 99,875 4..,776 5328, 32.162 2109.973 11.. 052 5348 90O 519 5O0 g 7,.58 26 299 2425 702 2.651 4. I. 9,500 ~4.992 39,932 :1783,,077 96.7 ~0 2,177 5288,000 522.0 () 9.0 '70 1o87. 000 $ F !, LJ. L; t. b R dr) fl. F'f)C h, ~' ~, ~, [-,' j'; C . E T i',, F< A. RCFT, ('~L T [< h' S · (:~:L 3,0qO 2,481 615,000 97,938 3,292 548,315 5360,000 3,292 2,450 612,500 99,~75 3.355 ~83,91B 5304,000 5,308 2.439 620 000 90 938 2 937 651 081 5328 000 12 030 2 412 592 000 66 2 630 922 918 5348 000 8 161 2 587 626 500 96 750 3 355 472 657 5284 000 2 b63 2 404 58'1 000 104 313 4 073 388,433 5288,(,)00 ibb.(:b(J :'[Fti,,d~.t_ ] I.., i..;. u; 3 9 FVOC. FL.)C l~;'b5,0()9 CAb,T. FF~C ~ , , , ~ .. %u t . J .)..t 2,559 -999.2b0 C,T ].., ~. '~ UC -999.250 -9~9.250 '999.250 G~'::, Cr~L -9 g' 9.2 b 0 t 7 ! "~ 75 999.2~0 C -999.25U GR, -999,250 3,504 I b :'"~, [: I, L -999 250 FFDC F'DC -999 250 '999 250 '999 250 ~Ck.T, Ci~'~,~ ~ 999 · 250 -999,250 4, b 4. 0 ,[ L ~."~, [).ii L -999,250 FFOC, Fi.)C -999,250 ChLI,Fi~C ":) 99,25 0 R C ~ T C "' - 9 c, 9.2 ~ 0 C; ~. C ~',, L -999,250 3.3 53 1' L ~,!. D I b 11, 8 ' 3 ! ,3 T - 999.250 F F' 0 C'.. ? b C - 9 99, '2 5 t..i C 1~ L :I:. g [) C -999'25() - 'g 99.250 -999.25O 3.4 :i 3 9.4bl 42.971. 1 b 8 7,0 (') ! 55. 2. 554:0. 000 -999.250 -999,25O -999,250 -q99. 250 -999,2b0 3,542 4.944. -999.2~0 -999 ' 250 -999,250 -999.250 -999,250 3.645 5092. 000 - 999.250 -999 25O -, 999,25 -99q - 999 . 4,~22 7 6 0.0 00 ~99.25O -999,250 -999,250 -999,950 3,350 ,~.800,000 -9q9.250 ~.', c,) q 25 .... , .... -999,.~;:~ . -999,250 :,.Ff..,C. F DC G~ , F[.'..C R C ~:,' 'T. C a, L Ri-[O~~, . FbC f.., }~' t?. C. F D C G~.t- DC RCFT, C r'.: L TE~.,S. CqL 5 I;' L L~. I')IL RH[i.a_. FDC !~ F 1) C, F :0 C G .R. F 0 C ]:}'.,iRA. C~iL RCF'T. CI,!L SFLO. DIL R !q Ii.'.; B. F D C' ~; .FF'C, FDC j:'" f' V' T P.'": i:',,! .9. C i'~! L ['.~ i:.'i'L ii)', '[) I L R !rr]' C,i f~, .It.' D C GB., FDC RCFT, 'i; g l'q $. C i,,i L S {;' !., Lt, ~;,~ F t) C ~ F D C 6ki. ':!'"' !'i:: k S, C ;',! 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(. ~,.; 9 -30oH55 4 i 9.25 () R iV 1"' 0 ,., F' i"> 3,098 R 7'.b R, C h,, H H't'2,276 C r'., T C, C J"...~ F~ 16, ;,i... 70 }q H [,,) i:.'-, F D .ti 665 ,, O, U 0 P r,, F I,:). F D :t 79,3 'i 5 7' 'E','~',~ S. F [) il - 999,250 R 7"N i'~. C' N H -999,250 Z,459 !. i b 5, U 0 u 5088.000 2.~10 2293.25,]2 410 '196 2860,208 3.I59 64b. 000 bl 40, 3.148 2564. 399 2,495 I l. 82,000 5032.00[) 3. 782 1,739.13o 2 . 4,38 103 3.000 4900 ' 00 U 3 o '108 2,383 31 (,'.::? {) 00 'II" q. 94. 0,0 0 g 999. 250 -999,250 ,.t P H Z. C N H CFTC.CNh D R F:: 0 ,, F D H R F F D · F D H N P ~-~ l ' C'N H CFTC. C:NH PAGE: 22 0,028 919 000 31~$81 31,60b 801,086 0,022 25 953 25:741 1~47,243 0,107 192,250 35 511 32~765 842,381 0 060 942 000 47 319 45 470 474 721 4 6 5 8 '7 44 576 504 28(3 0 O55 1281 000 ','999 250 -999 250 -999 25.0 PAGEI 23 Ii,iC.,Ki]PA~O~,2K 1 5,5 0 .. 1 ',') 3 -2 0 1 3 - (.; 0 ~ 5,50-103-20.13-C0
