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184-095
RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 1F WELL COMPLETION OR RECOMPLETION REPORT AND SCC la.Well Statu Li SPLUG U Other ❑ Abandoned ❑ Suspended❑ 1b.Well Class: 20AAC 25 105 20AAC 25.110 Development [1� Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL❑ No. of Completions: Service L 1 Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 7/11/2015 184-095/315-369 3.Address: 7. Date Spudded: 15.API Number: P. O. Box 100360 Anchorage,AK 99510 7/9/1984 50-103-20036-00 , 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 110' FSL,654'FEL, Sec. 26,T11N, R8E, UM 7/17/1984 , KRU 2H-14 Top of Productive Interval: 9. KB(ft above MSL): 125' 17. Field/Pool(s): 1325'FSL, 1073'FWL, Sec. 35,T11N, R8E, UM GL(ft above MSL): Kupuruk River Field/Kuparuk River Oil Poo Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1106'FSL,897'FWL, Sec. 35,T11N, R8E, UM 8530'MD/6122'TVD, ADL 25587 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 497745 y- 5948973 Zone- 4 8873'MD/6376'TVD ALK 2673 TPI: x- 494195 y- 5944910 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 494019 y- 5944691 Zone- 4 no SSSV 2754'MD/2445'TVD 5. Directional or Inclination Survey: Yes ❑(attached) No E❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 na (ft MSL) not applicable 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log,spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature, cement evaluation, casing collar locator,jewelry, and perforation record. Acronyms may be used.Attach a separate page if necessary NONE 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 30" 110' 30" 110' 24" 172 sx Cold Set II 9.625" 36# J-55 30" 2839' 30" 2497' 12.25" 980 sx AS III,440 sx Class G 7" 26# J-55 29' 8843' 29" 6354' 8.5" 400 sx Class G,250 sx AS I 4.5" 11.6# L-80 8317' 8716' 5970' 6259' 6.125" 23 bbls Class G 24. Open to production or injection? Yes ❑ No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Botto ; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5" 8232' none perfs cemented off s ,,' t,.1! ,, . // 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7 , 1.---.7-'5. O .5 Was hydraulic fracturing used during completion? Yes ❑ No ❑ Per 20 AAC 25.283(i)(2)attach electronic and printed information ,�.*/♦ DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED none 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing, gas lift,etc.): suspended Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period m.0. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate -► Form 10-407 Revised 5/2015 v7-1_ q'/'Z//5 CONTI ED )N PAGE 2 RBDMS�UG 2 5 2015 Submit ORIGINIAL o y 28. CORE DATA Conventional L,.ie(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored(MD/TVD, From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed). Submit detailed descriptions,core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. NONE 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Permafrost-Top surface surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 2754' 2445' Attach separate pages to this form, if needed, and submit detailed test information, including reports,per 20 AAC 25.071. Top Upper Kuparuk Sand 8458' 6070' Base Upper Kuparuk Sand 8475' 6078' Top Lower Kuparuk Sand 8496' 6094' Base Lower Kuparuk Sand 8698' 6245' Formation at total depth: 31. List of Attachments: Summary of Daily Operations, schematic Information to be attached includes, but is not limited to: summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jason Burke @ 265-6097 Email: Jason.Burke@cop.co Printed Name: Dan Venhaus Title: CTD Supervising Engineer Signature: 47/ y/L— -7 Phone: 263-4372 Date: 7^ 1 c —4S INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection, Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump, Submersible,Water Injection,Gas Injection,Shut-in, or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram, summary of daily well operations,directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only II p 11 11 m 11 r-- 1 1 11 �2 p 11 2 11 ©I p pm 11 pN 2 27) 11 Ha) ao Nm 11 v� rz m@) 11 m co Lio n 11 == Q1 O 1 N m 15 1 11 A N0c11 g 11 O 11 m o p ` m c 1% m coNc m rri r. a 11 N v o i 42 n 0 -E �„ °° 2:47 11 .2 nra ih a d \\ cu °' �m iup rn d �� c d r� a c n w p N a� �g c � \ c .o mem �p mfr d \\ 12 v � � mio `° v� m� m c \\ m id NNY m V' Nm03 pl C 11 a c N 6 n m N v U w 1 W co m !Ya oW� mY x °D 11 cop0 to Qom' �D °P "' CD i ""1 N U) " O O N J d 0 n- (#p 1 Y N E V m C R(Z X A � m � chi'— d � 11 of m ml U m m v co X co in i 1 (V (V Z C.4143 LV Y Y Y flV N Y'N Yco az N / p/7 (`II (p mom ch M comm / // // I // L.. VIII L.,,, II //03 ///I //Amil �(). ,�,AI 111111 _CD 't'. o j'.`;`�`''`...'.:.. :.......:. <yet„.„,nm,...:..'�:-.,''X.,,,-. '.,,,µ rin•,:z.„-�:�:` i �� I x , .uakr.,.e a as0 .. . ... f\v' �„,, Savais::;: i ' : • ;r` ?axs 111 I 11141.1 I'M ra 111111 II IIIIIIIII Iil11i o p v o C O N N N N2 CI hpN� a mN p N y -_ _'m , 2Y p pO) n 0 V p cc)^ N N mJ 4,_2 � � m aQw� aco Fao coTZ aobs m� o.c°D Nd `o Qroo ao acao 1p) 01N VN hm m' 6 3 n .k co 1 ~ ym <t`c2 2H-14 PRE-RIG WELL WORK DATE SUMMARY 5/18/2015 SET& PULLED 2.79" CATCHER @ 8284' RKB. PULLED SOV, SET DV @ 8154' RKB. MIT IA 2500 PSI, GOOD. DRIFTED TBG TO 8497' SLM w/2.63" x 17'WHIPSTOCK DUMMY. TAGGED FILL @ 8505' SLM. READY FOR FCO. 6/7/2015 Perform FCO with 3.80" undereamer in the 4.5" liner down to the Landing Collar© 8,601' CTMD. Made several up and down passes throughout liner until returns cleaned up. Wellbore filled with seawater and freeze protect diesel. Well now ready for SLB E-Line (whipstock). ***Job in progress*** 6/8/2015 TAGGED TD © 8605' SLM; DRIFTED DOWN TO 8619' RKB WITH 2 5/8" DUMMY WHIPSTOCK. IN PROGRESS (READY FOR E-LINE WHIPSTOCK). 6/12/2015 SET WHIPSTOCK TOP OF TRAY AT 8530'. WHIPSTOCK ORIENTATION 4.5 DEGREES RIGHT OF HIGH SIDE. 2 RA TAGS LOCATED AT 8537'. BOTTOM OF WS AT 8543'. CORRELATED TO K1 MARKER AT 8351'AND SLB CBL LOG DATED 7/30/84. JEWELRY LOG RUN FROM TD TO 8000'. JOB COMPLETE 6/16/2015 (PRE-CTD) : DDT SV, MV, SSV(PASSED), PT SV, MV,SSV(PASSED). ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 2H-14 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 7/9/2015 12:00:00 AM Rig Release: 7/20/2015 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 37/08/2015 24 hr Summary Finished reel swap. Moved rig&shop from 2F-18 to 2H-14. Move over well, rig up equipment. 06:00 10:30 4.50 0 0 MIRU MOVE RURD P MIRU CDR2,trucks on location, rig down subs, move off well, install jeeps, pre-move meeting with personnel 10:30 15:30 5.00 0 MIRU MOVE MOB P Mobilize off 3F-pad. Travel to 2H-14 15:30 20:30 5.00 MIRU MOVE MOB P Arrive on 2H-pad. Pad really soft. Spot up&move over the well. Have to utilize cat to pull out of soft gravel. Have tool house bring out grader to work pad. 20:30 00:00 3.50 MIRU MOVE RURD P Rig spotted in&sat down. Begin rigging up equip. 07/09/2015 Complete initial BOPE test, state witnessed by Chuck Shieve. PT inner reel valve, hardline to tiger tank& PDL's. Install coil connector. 00:00 01:00 1.00 0 0 MIRU WHDBO NUND P Nipple up Stack **Note: Rig accepted at 0:00 hours 01:00 01:30 0.50 0 0 MIRU WHDBO RURD P Continue fill reel with water, prep to start BOP test. Call State for witness. 01:30 13:30 12.00 0 0 MIRU WHDBO BOPE P BOPE test,witnessed by Chuck Sheive. Low test 250 psi, high test 3,500 psi, annular test 2,500 psi. 13:30 14:30 1.00 0 0 MIRU WHDBO RGRP T Change out B4 HCR valve. 14:30 20:30 6.00 0 0 MIRU WHDBO PRTS P Fill coil with seawater,test inner reel iron and packoff, PDL, and tiger tank line. 20:30 22:30 2.00 0 0 MIRU WHDBO MPSP P Cocduct TGSM. RU BPV luicator, pull TWC. Lay down equip. 22:30 00:00 1.50 0 SLOT WELLPF CTOP P Conduct PJSM. Cut a couple feet of coil, pull out eline. MWD test E-line, install coil connector. Pull test&PT. 07/10/2015 Tagged TOWS @ 8530'. Milled window&TD rathole @ 8555'. Back reamed window&dry drifted clean. POOH&lay down BHA#1. 00:00 01:00 1.00 0 0 SLOT !WELLPF CTOP P Continue installing CTC&Eline termination. 01:00 01:30 0.50 0 0 SLOT WELLPF SFTY P Conduct pre-spud with all on the rig. 01:30 02:00 0.50 0 0 SLOT WELLPF CTOP P Pump 1 coil volume foward. 02:00 03:45 1.75 0 76 PROD1 WHPST PULD P Shut the ordit valve.watch for no flow,good to go. Conduct TGSM for picking up BHA#1. Pick up BHA#1 Stab on. Re-open orbit valve. Page 1 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:45 06:00 2.25 76 8,365 PROD1 WHPST TRIP P RIH W/window milling BHA. Inspected saddle clamps and pillow blocks and inner reel iron on newly installed reel at 300'and 1000'. At 1,100' LOTO reel and checked torque on bolts and repositioned chain guard. 06:00 06:15 0.25 8,365 8,398 PROD1 WHPST DLOG P Log K1 for+1.0 ft correction 06:15 07:00 0.75 8,398 8,502 SLOT WHPST CIRC P Displace well over to 9.4 ppg FloPro milling fluid, PUW 28k 07:00 07:15 0.25 8,502 8,532 PROD1 WHPST TRIP P RIH,dry tag TOWS at 8,530', PUW 32k 07:15 11:00 3.75 8,532 8,535 PROD1 WHPST WPST P Mill window, 1.55 bpm @ 3,367 psi FS, BHP 3650 psi,WHP 0, IA 925, OA 40 11:00 16:30 5.50 8,535 8,541 PROD1 WHPST WPST P Continue milling window, at midpoint, bled IA from 1500 psi to 263 psi. 1.55 bpm @ 3,367 psi FS, BHP 3650 psi,WHP 0, IA 779, OA 18 16:30 18:00 1.50 8,541 8,555 PROD1 WHPST WPST P Drill rate hole 1.55 bpm @ 3,367 psi FS, BHP 3665,WHP 0, IA 833, OA 20 18:00 20:00 2.00 8,555 8,555 PROD1 WHPST WPST P Back ream window several times. Dry drifted good, pump 5X5. 20:00 22:00 2.00 8,555 100 PROD1 WHPST TRIP P POOH 22:00 00:00 2.00 100 0 PROD1 WHPST PULD P OOH. Close orbit valve. Bleed well to 0. monitor while conducting pre-job. Lay down window milling BHA. 07/11/2015 Drill build section from 8555'to 8675'. POOH due to BHI tool failure to change BHA. RIH w/new BHA& continue drilling build section from 8675'. Trouble time: BHI 6 hours for tool failure. : Nabors 5.75 hours for shaker motor failure. 00:00 01:00 1.00 0 0 PROD1 WHPST RURD P Change out bails. The set needs to be sent to tubo-scope. 01:00 02:45 1.75 0 72 PROD1 DRILL PULD P Conduct PJSM. Pick-up build BHA. 02:45 04:30 1.75 72 8,360 PROD1 DRILL TRIP P RIH W/build BHA 04:30 05:00 0.50 8,360 8,400 PROD1 DRILL DLOG P Tie into K-1. Counter was 40'off. Clean up counter wheel&re-try.Tie in for a-12.5'coreection. 05:00 05:15 0.25 8,400 8,555 PROD1 DRILL TRIP P RIH, PUW 30k 05:15 08:00 2.75 8,555 8,670 PROD1 DRILL DRLG P Drill build section as per plan. 1.50 bpm @ 3,505 psi FS, BHP 3,847, WHP 100, IA 740, OA 20. 08:00 08:15 0.25 8,670 8,360 PROD1 DRILL TRIP P PUH to log K1 and RA marker 08:15 08:30 0.25 8,360 8,570 PROD1 DRILL DLOG P Log K1 for no correction and log RA marker. RA marker at 8,536.5' 08:30 08:45 0.25 8,570 8,670 PROD1 DRILL TRIP P RIH 08:45 09:00 0.25 8,670 8,675 PROD1 DRILL DRLG P Drill build section as per plan. 1.50 bpm @ 3485 psi FS, BHP 3838, WHP 100, IA 720, OA 20 Page2of8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 11:00 2.00 8,675 72 PROD1 DRILL TRIP T POOH due to tool failure/failed DGS -magnetic section of directional package. Close Baker orbit valve, and conduct no flow check. 11:00 11:45 0.75 72 0 PROD1 DRILL PULD T L/D BHA#2 11:45 12:45 1.00 0 72 PROD1 DRILL PULD T MU BHA#3,surface test,and open Baker orbit valve. 12:45 14:45 2.00 72 8,360 PROD1 DRILL TRIP T RIH with BHA#3 14:45 15:00 0.25 8,360 8,383 PROD1 DRILL DLOG T Log K1 and tie in for a-7.5 ft correction **Note: BHI downtime ended,total downtime 6 hours 15:00 20:45 5.75 8,383 8,383 PROD1 DRILL TRIP T Shale shaker motor failure. Motor coming from Prudhoe ** Note: Nabors downtime total of 5.75 hours 20:45 21:00 0.25 8,383 8,675 PROD1 DRILL TRIP P Shaker fixed. Pumps up. RIH 21:00 00:00 3.00 8,675 8,768 PROD1 DRILL DRLG P 1.41 BPM @ 3325 psi FS. Drill ahead 1.41 BPM @ 3446 psi, BHP 3831, ROP 40. ECD 12.13 07/12/2015 TD build section @ 8815'. Drilled ahead from 8815'to 9576'. 00:00 01:30 1.50 8,768 8,815 PROD1 DRILL DRLG P @ 8768', continue drilling ahead 1.40 BPM @ 3396 psi, ROP of 37.TD build @ 8815'. 01:30 03:00 1.50 8,815 72 PROD1 DRILL TRIP P POOH to surface. 03:00 05:00 2.00 72 0 PROD1 DRILL PULD P Tag up, pumps off. 560 psi on well head&falling. Close orbit valve. Bleed off well head from 297 psi to 0 psi. Conduct pre-job. Lay down build BHA. 05:00 05:30 0.50 0 72 PROD1 DRILL PULD P Conduct PJSM. Pick-up BHA#4 05:30 07:30 2.00 72 8,360 PROD1 DRILL TRIP P RIH,with Lateral Drilling BHA, open EDC, pumping min rate. 07:30 07:45 0.25 8,360 8,360 PROD1 DRILL DLOG P Tie into the K1 correction of minus 7.0'. 07:45 08:00 0.25 8,360 8,815 PROD1 DRILL TRIP P Continue RIH to bottom. 08:00 13:30 5.50 8,815 9,111 PROD1 DRILL DRLG P BOBD 1.46 bpm at 3606 psi, BHP 3867,WHP 64, IA 684, OA 14 13:30 13:45 0.25 9,111 8,581 PROD1 DRILL WPRT P Wiper trip, PUW34k 13:45 14:00 0.25 8,581 9,111 PROD1 DRILL WPRT P RBIH 14:00 18:30 4.50 9,111 9,266 PROD1 DRILL DRLG P BOBD 1.38 bpm at 3480 psi, BHP 3808,WHP 25, IA 880, OA 20 18:30 20:30 2.00 9,266 9,415 PROD1 DRILL DRLG P Start mud swap 9.1 ppg, Continue drilling ahead. Get mud all around, 1.50 bpm @ 3339 psi/3834 BHP. Holding choke pressure now, 350 WHP. 20:30 21:15 0.75 9,415 9,415 PROD1 DRILL WPRT P Wiper, 30k off btm. Page 3 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:15 00:00 2.75 9,415 9,576 PROD1 DRILL DRLG P @ 9415, Drill ahead 1.50 BPM @ 3358 psi, 3854 BHP 37/13/2015 Drill ahead in A lateral from 9676'to 10372' 00:00 02:15 2.25 9,576 9,715 PROD1 DRILL DRLG P Continue drilling ahead to 9715' 02:15 03:15 1.00 9,715 9,715 PROD1 DRILL WPRT P Tie in wiper, 28k off btm.Tie in for a +4.5'correction. RIH to bottom. 03:15 10:00 6.75 9,715 9,997 PROD1 DRILL DRLG P Drill ahead 1.50 BPM @ 3550 psi 3873 BHP 10:00 10:15 0.25 9,997 8,900 PROD1 DRILL WPRT P Wiper trip PUW 29.5k 10:15 10:45 0.50 8,900 9,997 PROD1 DRILL WPRT P RIH,wiper trip clean 10:45 16:15 5.50 9,997 10,162 PROD1 DRILL DRLG P BOBD 1.60 bpm @ 3800 psi FS, BHP 3910 psi,WHP 180, IA 933, OA 22. Bled IA to 540 psi 16:15 16:45 0.50 10,162 9,200 PROD1 DRILL WPRT P Wiper trip PUW 30k, early wiper trip due to low ROP and surface weight 16:45 17:15 0.50 9,200 10,162 PROD1 DRILL WPRT P RIH,wiper trip clean. Pump 10 x10 sweep 17:15 22:00 4.75 10,162 10,360 PROD1 DRILL DRLG P BOBD 1.55 bpm 3,700 psi FS, BHP 3875,WHP 200, IA 520, OA 22 22:00 23:40 1.67 10,360 10,360 PROD1 DRILL WPRT P Decision made to do a 200'wiper. Wiper trip(tie in),26k off BTM, Tie in for a+2.5'correction. RBIH 23:40 23:59 0.33 10,360 10,372 PROD1 DRILL DRLG P Back on BTM,drill ahead 1.45 BPM @ 3522 psi, 3906 BHP 37 ROP, 12.25 ECD 37/14/2015 Drill Ahead A Lateral 10372 to 11052 00:00 04:00 4.00 10,372 10,560 PROD1 DRILL DRLG P Continue drilling ahead. 1.43 BPM @ 3619 psi, ROP 42, 3921 BHP 04:00 05:00 1.00 10,560 10,560 PROD1 DRILL WPRT P Wiper, 26k off btm 05:00 09:15 4.25 10,560 10,805 PROD1 DRILL DRLG P BOBD 1.50 bpm 3400 psi FS, BHP 3935 psi,WHP 225 09:15 09:45 0.50 10,805 9,529 PROD1 DRILL WPRT P Wiper trip, PUW 27k 09:45 10:15 0.50 9,529 10,805 PROD1 DRILL WPRT P RBIH, perform mud swap, new mud at bit 10,805' 10:15 16:21 6.10 10,805 10,908 PROD1 DRILL DRLG P BOBD 1.47 bpm 3350 psi FS, BHP 3915,WHP 315, IA 550, OA 22 16:21 16:39 0.30 10,908 10,908 PROD1 DRILL WPRT P Stacking, Hard to get drilling, Pull wiper to 10695, PUW=31.5k 16:39 18:15 1.60 10,908 10,912 PROD1 DRILL DRLG P 10908', Drill, 1.4 BPM @ 3315 PSI FS, BHP=4000 18:15 20:09 1.90 10,912 10,912 PROD1 DRILL WPRT P 10912', Drill,Wiper to window with tie in. +3.5'correction, PUW=27K 20:09 23:27 3.30 10,912 11,052 PROD1 DRILL DRLG P 10912', Drill, 1.4 BPM @ 3315 PSI FS, BHP=3950 23:27 00:00 0.55 11,052 10,226 PROD1 DRILL WPRT P 11052', Running low on push,-8K, Pull wiper to 9500', PUW=27K 07/15/2015 Drilled A lateral to TD @ 11478. Pumped sweeps.Tie in for+2.5'. RIH and confirm TD @ 11478. Pump beaded liner pill. Trip out for liner 00:00 00:18 0.30 10,226 11,052 PROD1 DRILL WPRT P Continue wiper from 11052 00:18 03:36 3.30 11,052 11,164 PROD1 DRILL DRLG P 11052', Driull, 1.41 BPM @ 3425 PSI FS, BHP=3970 Page 4 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:36 03:54 0.30 11,164 11,164 PROD1 DRILL WPRT P 11164 Wiper to 10730. Low surface weight, PUW=36K 03:54 15:45 11.85 11,164 11,306 PROD1 DRILL DRLG P 11164', Drill, 1.39 BPM @ 3425PS1 FS, BHP=3945, Low surface weight with poor transfer to bit. Problems getting it to drill, RIW=6K 15:45 16:51 1.10 11,306 8,555 PROD1 DRILL WPRT P Wiper trip, PUW 28K 16:51 17:00 0.15 8,555 8,575 PROD1 DRILL DLOG P Tie in at RA tag fora+2.0 ft correction 17:00 17:54 0.90 8,575 11,306 PROD1 DRILL WPRT P RIH 17:54 18:54 1.00 11,306 11,375 PROD1 DRILL DRLG P 11306', Drill, 1.42 BPM @ 3490 PSI FS, BHP=4005, RIW=-2K with 2.1K DHWOB 18:54 19:06 0.20 11,375 11,375 PROD1 DRILL WPRT P BHA wiper, stacked out, PUW=30K 19:06 21:24 2.30 11,375 11,478 PROD1 DRILL DRLG P 11375', Drill, 1.39 BPM @ 3450 PSI FS, BHP=4025 21:24 22:12 0.80 11,478 11,478 PROD1 DRILL WPRT P BHA Wiper,work pipe cann't make hole. Pump sweeps while attempting to drill, Call TD 11478'when sweeps reach BHA 22:12 00:00 1.80 11,478 10,328 PROD1 DRILL WPRT P 11478', Call TD, Chase sweeps to window and tie in for+2.5'correction, RBIH 07/16/2015 M/U and run A Liner, 11478 to 9218'with anchored liner top billet 00:00 00:30 0.50 10,328 11,478 PROD1 DRILL WPRT P Tag TD @ 11478 00:30 04:42 4.20 11,478 86 PROD1 DRILL TRIP P Trip out laying in beaded liner running pill, Paint EOP flags at 9100', & 6100'. Reduce speed pulling out due to hot pillow block bearing on reel, >200°. 04:42 06:24 1.70 86 0 PROD1 DRILL PULD P At surface, Close Orbit valve and flow check well for 5 Min. PJSM, Unstab and lay down BHA#4 06:24 09:45 3.35 0 2,263 COMPZ CASING PUTB P PJSM, Pick up A lateral liner assembly, 73 joints of 2 3/8'slotted liner with shorty deployment sleeve 09:45 10:45 1.00 2,263 2,263 COMPZ CASING PULD P MU BHA#5 to A lateral liner,surface test,and open orbit valve 10:45 13:30 2.75 2,263 11,478 COMPZ CASING RUNL P RIH with A lateral liner assembly to EOP flag at 6,100', -12.87 ft. correction,continue to RIH PUW 28.5K 13:30 14:00 0.50 11,478 8,335 COMPZ CASING TRIP P Release from liner, reset counters, and POOH, PUW prior to liner release 32.2K, PUW post liner release 25.6K, 14:00 14:15 0.25 8,335 8,363 COMPZ CASING DLOG P Log GR tie-in for a+7.5 ft.correction 14:15 15:30 1.25 8,363 44 COMPZ CASING TRIP P POOH, paint EOP flag at 8,300' 15:30 16:18 0.80 44 44 COMPZ CASING OWFF T Function orbit valve closed with WHP 706 psi. Monitor well for no flow, Flow check doesn't look good, Function valve open WHP 606 psi. 16:18 17:06 0.80 44 3,483 COMPZ CASING TRIP T RBIH to flush orbit valve Page 5 of 8 •Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/16/2015 24 hr summary M/U and run A Liner, 11478 to 9218'with anchored liner top billet 17:06 17:36 0.50 3,483 3,529 COMPZ CASING CIRC T Circ flush accross orbit valve Pick up above valve 17:36 18:18 0.70 3,529 3,447 COMPZ CASING OWFF T Close orbit valve and monitor-looks good r 18:18 19:06 0.80 3,447 55 COMPZ CASING TRIP T Trip out keeping hole full 19:06 19:42 0.60 55 55 COMPZ CASING OWFF P At surface, PJSM, Flow check well 19:42 20:00 0.30 55 0 COMPZ CASING PULD P Break off injector and lay down BHA #5 20:00 20:24 0.40 0 0 COMPZ CASING BOPE P Perform Bi weekly BOPE function test 20:24 21:36 1.20 0 103 COMPZ CASING PULD P Make up BHA#6, Ported bullnose, 1 Jt slotted liner, OH anchor, aluminum billet. M/U to coiltrack and surface test tool. EDC Open, Pressure up well and open Orbit valve 21:36 23:24 1.80 103 8,400 COMPZ CASING TRIP P RIH, EDC open, Pumping min rate 23:24 23:42 0.30 8,400 8,424 COMPZ CASING DLOG P Tie into K1 for-9.5'correction, PUW=27K, Close EDC 23:42 00:00 0.30 8,424 8,651 COMPZ CASING TRIP P Continue in hole, No pumping. verify depth running past RA marker. No correction 07/17/2015 Set anchored billet @ 9258, TOB=9217, Kick off and drill build/turn to 9475, Drill lateral to 9775' 00:00 00:18 0.30 8,651 9,258 COMPZ CASING TRIP P Continue in hole, set down on liner lower segment @ 9258 00:18 02:06 1.80 9,258 65 COMPZ CASING TRIP P Orient to 150R pumps on see tool shift @ 4800 PSI, Set down 3K. Trip out of hole, Slow down accross orbit valve to flush.TOLTB @ 9217' 02:06 02:36 0.50 65 65 COMPZ CASING OWFF P At surface, Close orbit valve. monitor for flow, PJSM 02:36 03:06 0.50 65 0 COMPZ CASING PULD P Unstab injector, Lay down BHA#6 03:06 04:00 0.90 0 72 PROD2 STK PULD P P/U BHA#7, Build section BHA with 1.2°motor and RR HYC Bi-center, Make up injector and surface test. Pressure up well and open orbit valve. 04:00 05:30 1.50 72 8,370 PROD2 STK TRIP P RIH, EDC closed 05:30 05:45 0.25 8,370 8,389 PROD2 STK DLOG P Tie in to K1 for a-10.0'correction 05:45 06:30 0.75 8,389 9,217 PROD2 STK TRIP P RIH and dry tag billet at 9,217' 06:30 08:15 1.75 9,217 9,218 PROD2 STK KOST P Time drill off billet, 1.45 bpm 3440 psi FS, BHP 3805,WHP 150, IA 220, OA 14 08:15 09:30 1.25 9,218 9,260 PROD2 DRILL DRLG P Drilling formation, 1.45 bpm 3440 psi FS, BHP 3810,WHP 150, IA 225, OA 14 09:30 09:45 0.25 9,260 9,260 PROD2 DRILL TRIP P Dry drift billet,dry drift clean, PUW 27.5K 09:45 13:00 3.25 9,260 9,475 PROD2 DRILL DRLG P BOBD 1.45 bpm 3450 psi FS, BHP 3860,WHP 170, IA 280, OA 15 13:00 13:30 0.50 9,475 8,494 PROD2 DRILL TRIP P 9475 ft, land build section, POOH Page 6 of 8J Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode =T Comment 13:30 15:00 1.50 8,494 700 PROD2 DRILL TRIP P Open EDC, Continue POOH, flush orbit valve with jog. 15:00 16:00 1.00 700 72 PROD2 DRILL TRIP P At 700'a slug of aluminum plug choked, the orbit valve was cycled closed, blew down choke. Jog in hole to 1,000',to clean hole and choke of aluminum, POOH to surface. 16:00 16:15 0.25 72 72 PROD2 DRILL TRIP P PJSM and monitor well for no flow check 16:15 17:15 1.00 72 0 PROD2 DRILL PULD P LD build section BHA 17:15 17:45 0.50 0 72 PROD2 DRILL PULD P M/U BHA#8 with.6°motor and new Hycalog bit, M/U to coil and surface test. Pressure up well and open orbit valve 17:45 19:21 1.60 72 8,370 PROD2 DRILL TRIP P Trip in hole 19:21 19:27 0.10 8,370 8,392 PROD2 DRILL DLOG P Log K1 for-8.5'correction, PUW=24K 19:27 20:09 0.70 8,392 9,476 PROD2 DRILL TRIP P Continue in hole, Clean pass through window and billet 20:09 23:51 3.70 9,476 9,775 PROD2 DRILL DRLG P 9476', Drill, 1.47 BPM @ 3570 PSI FS, BHP=3830 23:51 00:00 0.15 9,775 9,775 PROD2 DRILL WPRT P 9775',Wiper trip to 8770', PUW=29K 07/18/2015 TD AL1 lateral, Condition hole. M/U completion, Non ported bullnose,69 Jts slotted liner 00:00 00:54 0.90 9,775 9,775 PROD2 DRILL WPRT P Continue wiper trip from 9775 to 8770' 00:54 04:30 3.60 9,775 10,075 PROD2 DRILL DRLG P 9775', Drill, 1.44 BPM @ 3450 PSI FS, BHP=3850 04:30 05:15 0.75 10,075 10,075 PROD2 DRILL WPRT P Wiper trip to 9,225', PUW=27K 05:15 08:30 3.25 10,075 10,375 PROD2 DRILL DRLG P BOBD, 1.45 bpm @ 3500 PSI FS, BHP 3880 08:30 09:15 0.75 10,375 8,560 PROD2 DRILL WPRT P Wiper trip, PUW 30K 09:15 09:30 0.25 8,560 8,575 PROD2 DRILL DLOG P Log RA fora+4.0'correction 09:30 10:00 0.50 8,575 10,375 PROD2 DRILL WPRT P RIH 10:00 13:15 3.25 10,375 10,650 PROD2 DRILL DRLG P BOBD, 1.50 @ 3550 psi FS, BHP 3830,WHP 160, IA 550, OA 20 Perform mud swap, new mud at the bit @ 10,403' **Note: System 2 1,832'Drilled, 0.85%DS, 33K LSRV 13:15 14:30 1.25 10,650 8,555 PROD2 DRILL WPRT P Pumped 10 x 10 sweeps and chase to the window 14:30 14:45 0.25 8,555 8,575 PROD2 DRILL DLOG P Log RA for+ 1.0 ft. correction 14:45 15:30 0.75 8,575 10,650 PROD2 DRILL WPRT P RIH to confirm TD @ 10,650' 15:30 20:00 4.50 10,650 63 PROD2 DRILL TRIP P Lay in beaded liner running pill while POOH, Paint EOP flag @ 6300' 20:00 20:24 0.40 63 0 PROD2 DRILL PULD P At surface,close orbit valve, Good flow check lay down BHA#8 20:24 20:48 0.40 0 0 COMPZ CASING PUTB P PJSM, R/U floor to run liner, PJSM to run liner Page 7 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:48 23:36 2.80 0 2,133 COMPZ CASING PUTB P P/U BHA#9 with non ported bullnose,69 jts sloted liner, shorty deployment sleeve. Perform BOP drill at joint 11 in hole. 3:30Min. ------------- 23:36 00:00 0.40 2,133 2,178 COMPZ CASING PULD P PJSM, P/U Coil track, M/U to liner and stab on injector 07/19/2015 Run AL1 completion 10650 to 8516, Roll well to seawater. Freeze protect to 2500'. Set BPV. Leave orbit valve open, RDMO 00:00 00:30 0.50 2,178 2,177 COMPZ CASING PULD P Surface test tool, Open deployment rams, Pressure up well, open orbit valve 00:30 02:18 1.80 2,177 8,492 COMPZ CASING TRIP P RIH BHA#9, EDC closed 02:18 02:24 0.10 8,492 8,477 COMPZ CASING DLOG P Correct and 6300' EOP flag for-14.5', PUW=26K 02:24 03:00 0.60 8,477 10,470 COMPZ CASING TRIP P Continue in hole, clean trip past window and billet 03:00 03:06 0.10 10,470 10,488 COMPZ CASING DLOG P Log K1 for+4.5'correction 03:06 03:18 0.20 10,488 8,516 COMPZ CASING TRIP P Continue in hole, Tag bottom at 10650'. PUW=29K, Pumps on 1.5 BPM @ 3720, PUW=24K, Liner released, BOL=10650,TOL=8516, __PUH and reset counters. 03:18 06:27 3.15 8,516 32 COMPZ CASING DISP P POOH while displacing well to seawater, function close orbit valve, flow check and freeze protect from 2,500' 06:27 06:57 0.50 32 0 COMPZ CASING PULD P LD liner running assebly BHA#9 06:57 11:15 4.30 0 0 DEMOB WHDBO RURD P Flush and blow down coil, pin injector,chain CT reel,and follow rig move check list. 11:15 13:00 1.75 0 0 DEMOB WHDBO MPSP P RU FMC lubricator, pressure test, set BPV, and RD FMC lubricator 13:00 14:00 1.00 0 0 DEMOB WHDBO RURD P Blow down surface lines, bleed koomey, and disconnect putz 14:00 15:00 1.00 0 0 DEMOB WHDBO NUND P Nipple down BOPE and check tree bolts. Did not find any loose tree bolts. FTP=863 psi 15:00 00:00 9.00 0 0 DEMOB WHDBO RURD P Continue RDMO CDR2 to 30-08 **Note: Rig released at 0:00 hours Page 8 of 8 ti OF Tye �w ����-s THE STATE Alaska Oil and Gas ���►-"t���i� ofALAs KA Conservation Commission t t 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279.1433 OFALAS.0' Fax: 907 276 7542 www aogcc alaska goy NED I 0 8 20171 SCAN Jason Burke n Sr. CTD Engineer 7 ConocoPhillips Alaska, Inc. g '�` P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2H-14 Sundry Number: 315-369 Dear Mr. Burke: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this1 day of June, 2015 Encl. STATE OF ALASKA A_ _.5KA OIL AND GAS CONSERVATION COM, ,ION ae� k9V°-) APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate r Atter Casing r Change Approved Program E Rug for Redrill I✓, Perforate New Pool r Repair Well r Re-enter Susp Well r Other: r 2 Operator Name. 4 Current Well Class 5.Permit to Drill Number ConocoPhillips Alaska, Inc Exploratory r Development 17 184-095 - 3.AddressStratigraphic r Service -. 6 API Number P.O. Box 100360,Anchorage,Alaska 99510 50-103-20036-00 - 7 If perforating, What 8 Well Name and Number. Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No F7 KRU 2H-14 + 9 Property Designation(Lease Number) 10.Field/Pool(s): ADL 25587 • Kuparuk River Field/Kuparuk River Oil Pool ' 11 PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft) Effective Depth MD(ft) Effective Depth TVD(ft) Plugs(measured) Junk(measured): 8873 ' 6377 - 8716' - 6354'- none none Casing Length Size MD ND Burst Collapse CONDUCTOR 80 16 110' 110' SURFACE 2809 9.625 2839' 2497' PRODUCTION 8814 7 8842' 6354' RECEIVED SCAB LINER 340 4.5 8716' 6259' (UN 16 2015 AOGGC Perforation Depth MD(ft): Perforation Depth TVD(ft) Tubing Size Tubing Grade Tubing MD(ft). perfs cemented off perfs cemented off 3.5 L80 8324 Packers and SSSV Type Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER 47B2 FHL PACKER MD=8239 TVD=5915 PACKER-BAKER ZXP LINER TOP PACKER MD=8317 TVD=5969 PACKER-BAKER LINER HANGER PACKER MD=8336 TVD=5984 No SSSV 12.Attachments: Description Summary of Proposal 13. Well Class after proposed work Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r 14 Estimated Date for Commencing Operations 15. Well Status after proposed work J \r� 7/1/2015 OIL r VVINJ r WDSPL r Suspended I'7 16.Verbal Approval Date GAS r- WAG r GSTOR r SPLUG r Commission Representative. GINJ r Op Shutdown r Abandoned 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Jason Burke @ 265-6097 Email Jason Burke@conocophillips com Printed Name -son Bur.- Title Sr. CTD Engineer _ Signature 0r1 Phone 265-6097 Dates C Commission Use Only J Sundry Number. Conditions of approval Notify Commission so that a representative may witness 3 1rj-3(Q c( Plug Integrity r BOP Test t Mechanical Integrity Test r Location Clearance r Other: 5G.p tt574 7,z, 3-5-4c p5) (/i4P5 P S 3 2/9p3/y) ,.1-1,-Pk) 1-I u/ p i x 1,-7 7`-�r-i- 5 f �0 2 �clz;p 5 i)- Spacing Exception Required? Yes ❑ No 2/ Subsequent Form Required. /p — 4 O APPROVED BY Approved by //�COMMISSIONER THE COMMISSION Date. b lel 1L-; v7-6. 6,/ if, — Approved atiloll islvalid for 12 r0„gnt?from the date of approval. Submit Form and Form 10-403 Revised 5/2015 , 141 �� t'rSb ' I, / .Attarhmentt in Dunlirate RECEIVED ConocoPhillips JUN 16 2015 Alaska OGCC P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 June 15, 2015,2015 Commissioner-State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits application to abandon the parent well bore of KRU 2H-14 (185- 195). The original perforations of 2H-14 were plugged during a recent work over as per sundry#314-604. The well is planned for a CTD sidetrack in July of 2015 which will recapture the resource from the A-sand perfs. Attached to this application are the following documents: — Summary of CTD sidetrack — Current well bore schematic — Proposed CTD Schematic — 10-403 Sundry Application to Abandon KRU 2H-14(184-195) If you have any questions or require additional information please contact me at 907-265-6097. Sincerely, • • Jason Burke ConocoPhillips Alaska Coiled Tubing Drilling Engineer • KRU 2H-14 CTD Summary for Perfing & Plugging Sundry (10-403) Summary of Operations KRU 2H-14 is a dual lateral well that is being converted from a producer to an injector. A recent RWO was performed to swap tubing,cement a 4-1/2" scab liner in place and install a down hole deployment valve. The objective of this well is to drill 2 laterals on either side of a N-S fault to provide support to the 2H-10,2M-22 and the 2M-24. 2H-14A will kick off in the A4 sand at 8530'MD via a 2 string cemented window exit,then land in the A3 sand. From there the plan is to turn north and invert into the A4 pay,cross fault#1 into the lower A3 and geo-steer in the A3 pay until a TD of 11,400'MD. The lateral will be completed with 2-3/8" slotted liner with an aluminum billet to a depth of 8950'MD. 2H-14AL1 will kick off the billet at 8950'MD in the A4 pay on the east side of fault#1. The plan is to drop into the A3 pay and geo-steer to the north drilling to a TD of 10,300'MD. The lateral will be completed with 2-3/8" slotted liner ran back into the parent well bore to a depth of 8525'MD. This wells perforations have already been cemented off,there is no additional work to be done to abandon the perforations. Pre-CTD Work 1. Coil: Perform FCO of old mud left over from RWO 2. E-line: Set a 4'/2"thru-tubing whip-stock at 8530' MD and 0°HS ✓ Rig Work 3. MIRU Nabors CDR2-AC rig using 2%"coil tubing. NU 7-1/16"BOPE,test. ill l 3 4. 2H-14A Lateral(A4 sand-Northwest) i. Mill 2.80"window at 8530' MD ii. Drill 2.70"x 3.00"bi-center lateral to TD of 11300' MD iii. Run 2'/s"slotted liner with an aluminum billet from TD up to 8950' MD 5. 2H-14AL1 Lateral(A3 sand-North) /V i. Kick off the billet at 8950' MD T`f ii. Drill 2.70"x 3.00"bi-center lateral to TD of 10300' MD iii. Run 2%"slotted liner with shorty deployment sleeve from TD up to 8325' MD 6. Freeze protect the well. Set BPV,ND ROPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. 3. Flow back(less than 30 days) 4. Perform AOGCC witnessed MIT-IA 5. Put back on injection ( gyp/ d(�e�ls "''/ !c 601i/riff/ �- rf of Coh C v/'. T P l' well cart 474 1-1 11 ,/ Ar d -/-Xe o rif^9/ Page 1 of 1 54/0tre 11'11 c' / June 15,2015 7l of 74Pi 1 � � cosS1 Od9 a f r=�i( !,yell COMp4r(y S. 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Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Res nsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the Pa ' i r Steve upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposedatricjor Steve work) the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then check the "Suspended" box and initial that change. Guy or Victoria The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug for Jenni Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the History tab Jenni in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will change Jenni the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 0 9 6 NOTICE OF APPLICATION DEFICIENCY cji--V A 15 D.\'‘'' Li?1 The attached application is being returned due to the deficiency or deficiencies listed below. Please submit a new application and all required supporting information. insufficient information to confirm that the casing and cementing program will protect freshwater aquifers insufficient information to demonstrate that the proposed perforations will be in compliance with applicable spacing provisions insufficient information to demonstrate that adequate barriers to flow will be maintained failure to calculate (or to calculate accurately)anticipated pressures insufficient information to confirm quality of cement and TOC, relative to proposed perforations _insufficient or contradictory well location information or coordinates _insufficient or contradictory geologic prognosis information SCANNED /, Jig, 4 a201c. other I(1S A.6k,,k I‘A ieir < 77) dkii1014-r �'+ �, 101 e as. j other other other STV RECEIVED STATE OF ALASKA • I KA OIL AND GAS CONSERVATION COM .310N JUN 0 5 2015 APPLICATION FOR SUNDRY APPROVALS n^ 20 AAC 25.280 AOGCC 1.Type of Request: Abandon J Rug Perforations r Fracture Stimulate r Rill Tubing f Operations Shutdown f Suspend r Perforate r Other Stimulate ii Alter Casing r Change Aypproved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Othe. r- 2. 2.Operator Name: 4.Current Well Class: 5.Pe it to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r /184-095 3.Address: /5.Stratigraphic r Service I' API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20036-00 7.If perforating, What 8.Well Name and'Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No f KRU 2H/4 9.Property Designation(Lease Number): 10.Field/Pool(s): 1 ADL 25587 Kuparuk River Field/Kuparuk River Oil,wool 11. PRESENT WELL CONDITION SUI 1MARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8873 6377 8716' 6354' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 110' 110' SURFACE 2809 9.6252839\/ /\� 2497' PRODUCTION 8814 7 884 '\'`` q�, 6354' SCAB LINER 340 4.5 837 k> 6259' , '\ ,p Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): perfs cemented off perfs cemented off 3.5 L80 8324 Packers and SSSV Type: Packer and SSSV MD(ft)and TVD(ft) PACKER-BAKER 4762 FHL PACKER Mk= 39 TVD=5915 PACKER-BAKER ZXP LINER TOP PACKER ,ii ;317 TVD=5969 PACKER-BAKER LINER HANGER PACKER ,lr-8336 TVD=5984 No SSSV 12.Attachments: Description Summary of Proposal ;13. Well Class after proposed work: Detailed Operations Program r BOP Sketc Exploratory r Stratigraphic r Development 17 Service r 14.Estimated Date for Commencing Operations: � 15. Well Status after proposed work: 6/19/201 OIL r WINJ r WDSPL r Suspended r- 16. 16.Verbal Approval: Date: GAS r WAG ('- GSTOR r SPLUG r Commission Representative: GINJ f Op Shutdown r Abandoned rq 17. I hereby certify that the foregoing is true and correct to he best of my knowledge. Contact: Jason Burke @ 265-6097 Email: Jason.Burkeanconocophillips.com I Printed Name Jason B rk- Title: Sr. CTD Engineer Signature Phone:265-6097 Date G 5'� Commission Use Only Sundry Number: �( Conditions of approval: Notify Commission so hat a representative may witness 315—S 4 1--f Plug Integrity r BOP Test r echanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: APPROVED BY Approved by: Approved application is va is rorl Li months from the aat°c o lapproval. Date: Submit Form and Form 10-403 Revised 5/2015 ORIGINALtachments in Duplicate RBDMS JUN 1 0 2015 �' . • 3 KUP PROD 2H-14 �- ConocoPhillips er Well Attributes Max Angle&MD TD Also)'.a Inc. Weilbore APIIUWI Field Name Wellbore Status Mel(•) MD(ftKB) Act Blm((MB) Cmoe hiIIpe 501032003600 KUPARUK RIVER UNIT PROD 54.38 3,000.00 8,873.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2H-14,5/23/2015 612(46 PM SSSV:LOCKED OUT 63 12/30/2012 Last WO: 12/25/2015 34.51 7/18/1984 Vertical schematic tactual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ,.,,,.,,,_ _,.•„_-,,., _ .,,,.,,.-, Last Tag:SLM 8,505.0 5/18/2015 Rev Reason:GLV C/O,TAG lehallf 5/23/2015 HANGER;23.7- `y Casing Strings Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade lop Thread CONDUCTOR 16 15.062 30.0 110.0 110.0 62.50 H-40 WELDED Casing Description OD(In) ID(In) Top(ftKB) Set Depth(11KB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 30.0 2,838.9 2,497.2 36.00 J-55 BTC Casing Description OD(In) 10(In) Top(ftKB) Set Depth(rt1(5) Set Depth(NO)...Wt/Len(I...Grade -•p Thread PRODUCTION 7 6.276 28.6 8,842.4 6,353.8 26.00 J-55 BTC Casing Description 013 00) ID(In) Top(ttKB) Set Depth(ftKB) Set Depth(ND)...WULen(I...Grad Top Thread ! 8°0'LINER-RWO 2015 412 4.000 8,316.9 8,716.0 6,259.4 11.60 L.:' BTCM Liner Details Nomnal ID - Top(ftKB) Top(ND)(RKB) Top Incl(.) Item Des Com (In) 8,316.9 5,969.9 44.72 PACKER BAKER ZXP LINER TOP PACKER 4.330 -M�CONDUCTOR;30.0-1100- •r,,�-n,..� 8,336.5 5,983.8 44.64 HANGER BAKER FLEX LOCK LINER HA, ER 4.240 8,352.4 5,995.1 44.58 SBE 80-40 SBE 4.000 Tubing Strings Tubing Description String Ma.,,ID(In) Top(ftKB) Set Depth(tt..Set Depth(N+ (...Wt(10/11) Grade Top Connection TUBING-UPPER- I 3 1/2 2.9921 23.71 8,232.41 .,10.11 9.301 L-80 I EUE 8Rd RWO 2015 SURFACE;30.1.2,838.9-. - Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl Cl item Des Corn (In) 23.7' 23.7 0.00 HANGER FMC GEN V'ANGER 2.992 DEPLOY VW;3.505.6 3,505.6 2,891.7 52.77 DEPLOYVLV BAKER a BIT DEPLOYMENT VALVE 2.910 8,209.7' 5,894.1 45.40'LOCATOR BAKER 01311-22 LOCATOR SUB 2.992 8,210.7 5,894.8 45.40 SEAL ASSY BA ER 80-40 SEAL ASSEMBLY 2.992 Tubing Description String Ma...ID(In) Top(MB) S pth(R.. D)(...Wt(lb/ft) Grade Top Connection TUBING-LOWER- 312 2.992 8,215.5 8,367.01 Set Depth(N 6,005.5 9.30 L-80 I EUE Ord Mod GAS LIFT;8,154.0 RWO2015 I Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top incl(") Item s Corn (In) 8,215.5 5,898.2 45.36 PBR 80-40 PBR(20') 4.000 --, 8,238.6 5,914.4 45.20 PA ER BAKER 47B2 FHL PACKER 2.950 LOCATOR;8.209.7 8,284.0 5,946.5 44.89 NIbPLE HSE 2.813"'X'NIPPLE 2.813 SEAL ASSY;8210.7 8,324.3 5,975.1 44.69 LOCATOR 80-40 GBH-22 LOCATOR SUB 2.980 PBR;8.215.5 -a- 8,325.5 5,975.9 44. SEAL ASSY 80.40 GBH-22 SEAL ASSEMBLY 2.992 Perforations&Slots PACKER;8.238.6 Y° ...Um Shot Dans Top(ND) Btrn(TVD) (she Top(ftKB) Btm(ftKB) (ttKB) (ftKB) Zone Date t) Type Corn 8,460.0 8,476.0 , 6,072.1 6,083.6 C-4,UNIT B, 4/18/1985 12.0 IPERF 120 deg.Ph;5"Baker 2H-14 Tubing Cony NIPPLE;8,284.0 m8,508.0 8,519.. 6,106.6 6,114.5 A-5,21414 4/22/1985 4.0 (PERF 90 deg.Ph;2 1/8" tr EnerJet - 8,530.0 ' 8,5: .0 6,122.5 6,146.5 A-4,2H-14 4/22/1985 4.0 IPERF 90 deg.Ph;2 1/8" EnerJet 8,588.0 ,614.0 6,164.7 6,183.8 A-3,21414 422/1985 4.0 IPERF 90 deg.Ph;2 1/8" EnerJet Cement Squ ezes LOCATOR;8.324.3 Top(TVD) Btm(TVD) : Top(MB) : (RKB) (ftKB) (ftKB) Des Start Date Corn ' ' 8,336.5 :,842.0 5,983.8 6,353.5 4 1/2"liner 1/19/2015 Pump 15 bbls of Mud Push II Followed by 23 bbls of Class""G"15.8 lb/gal cement.Flush lines.Drop Dart SEAL ASSY;8.325.4 ! &pump 5 bbls fresh wu.Displace w/53.5 bbls of mud. e. Total displacement=58.5 bbls.Pressure up&bump if plug with 2500 psi.Plug down at 05:46 hrs.S/Ow/ 45K 8 set slips. A Mat.rel Inserts se sem -- atl o Top(ND) Valve Latch Port Size TRO Run Top(ttKB) (ftKB) Make Model OD(In) Sery Type Type (In) (psi) Run Date Com IPERF;8.460.0-8.476.0- 8,154.0 5,855.1 CAMCO MMG 112 GAS LIFT DMY RKP 5/18/2015 DCR- I? ; 1 1` 11 Notes:General&Safety IPERF;8,508.0.8,519.0- �l End Date Annotation S 10/27/2010 NOTE:View Schematic w/Alaska Schema0c9.0 C IPERF;8.530.041.563.0- IPERF;0,588.041,614.0- LINER-RWO 2015;8,3164 8,716.0 4 i; N PRODUCTION;28.6.8,842.4 RECEIVED STATE OF ALASKA AL A OIL AND GAS CONSERVATION CON .,SIGN FEB 1 8 2015 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed Abandon r Repair well Rug Perforations r Perforate r othAOGCC 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 Exploratory r 184-095 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20036-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25587 KRU 2H-14 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s). GR/CCL Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8873 feet Plugs(measured) None true vertical 6377 feet Junk(measured) None Effective Depth measured 8716 feet Packer(measured) 8238,8317 true vertical 6354 feet (true vertical) 5915,5969 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 110 110 SURFACE 2809 9.625 2839 2497 PRODUCTION 8814 7 8842 6354 SCAB LINER 340' 4.5 8716 6259 SCANNED -) (i ., Perforation depth: Measured depth: perfs cemented off-8460-8476, 8508-8519, 8530-8563, 8588-8614 True Vertical Depth: perfs cemented off-6072-6084,6107-6115,6123-6147,6165-6184 Tubing(size,grade,MD,and ND) 3.5, L-80,8324 MD, 5975 TVD 1 Packers&SSSV(type,MD,and ND) PACKER- BAKER FHL PACKER @ 8239 MD and 5915 TVD PACKER-BAKER ZXP LINER TOP PACKER @ 8317 MD and 5969 TVD PACKER-BAKER LINER HANGER PACKER @ 8336 MD and 5984 TVD no SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): 8336.6'-8742' Treatment descriptions including volumes used and final pressure: 23 bbls 15.8#Class G 13. Representative Daily Average Production or Injection Data 011-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure / Prior to well operation shut-in \`\'0 Subsequent to operation shut-in 1 14.Attachments 15.Well Class after work. / 'J, Copies of Logs and Surveys run Exploratory r Development `P" Service Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP 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 314-604 Contact Theresa Lee C ,263-4837 Email Theresa.M.Lee(a�conocophillips.com Printed Name Theresa Lee Title Workover Engineer Signature n^ Phone:263-4837 Date / 1 / 1 r /--w Vr� 3-/2.57/ 5- RBDMS� FEBJ13 2015 Form 10-404 Revised 10/2012 , 34> ,,---- Submit Original Only t, KUP PROD 2H-14 ConocoPhillips I. Well Attributes Max Angle&MD TD Alaska Inc Wellbore ApvUWI Plaid Name Wellborn Status nci p) MD(RKB) Act Bten(ftKB) rrrrarriPlYip1 / 501032003600 KUPARUK RIVER UNIT PROD 54.38 3,000.00 8.873,0 .•. Comment N25(ppm) Date Annotation End Date KB-Grd(It) 'Rig Release Pate 2R-14,2t17/2015 11 5R18 AM SSSV:LOCKED OUT 63_ 12/3072012 Last WO: 12125/2015 34.51 7/1811984 Vertical schematic(actual) Annotation Depth(1188) End Date Annotation Last Mod By End Date Last Tag SI M 8,600.0 8/772014 Rev Reason:WORKOVER smsmith 2/16,/2015 RANGER;23.7 T Casing Strings Casing Description OD(In) ID(In) Top(ft813) Set Depth(NKB) Set Depth(TVD)...MMLen(L..Grade Top Thread CONDUCTOR 16 15.062 30.0' 110.0 110.0 62.50 1-140 WELDED Casing Description 00(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Widen(I...Grade Top Thread SURFACE 95//8 8.921 30.0 2,838.9 2,497.2 36.00 J-55 BTC Casing Description OD(In) ID(in) 'Top(ftKB) Set Depth MB) Set Depth(TVD)...WtlLen(I...Grade Top Thread Irl PRODUCTION 7 6.275 28.6 8.842.4 6,353.8 26.00 J-56 OTC iii x,..,Casing Description OD(in) ID(In) Top(ftKB) Set Depth(588) Set Depth(TVD)...WI/Len(1...Grade 'Top Thread LINER-RWO 2015 4 112 4.000 8.316.9 8,716.0 6,259.4 11.60 L-80 BTCM Liner Details Nominal ID Top(1068) Top(TVD)(ftKB) Top Ins(°) Rem Dee Com (in) 8,316.9 5,969.9 44.72 PACKER BAKER ZXP LINER TOP PACKER 4.330 8.336.5 5.983.8 44.64 HANGER BAKER FLEX LOCK LINER HANGER 4.240 7-,-000NDUCTOR:30.0-1100` 8,352.4 5,995.1 44.58 ORE 80-40 OBE 4.000 Tubing Strings 1 Tubing Dear/Veen String Ma...'1D(In) Top(ftKB) I Set Depth(ft...Set Depth(TVD)(...'Wt(Ib/ft) 'Grade Top Connection TUBING-UPPER- 31.2 2.902 2371 8,232.4 5.910.1 9.3011-80 EUE 8Rd RWO 20)5 SURFACE;SO.1-2,B30,0 • Completion Details Nominal ID Top(ftKB) Top(TVD)(960) Top Incl(•) kern Des Corn (In) 23.7 23.7 0.00 HANGER FMC GEN V HANGER 2.992 DEPLOY VLV,3,505.6 9,505.6 2,891.7 52.77 DEPLOYVLV BAKER ORBIT DEPLOYMENT VALVE 2.910 8,209.7 5,894.1 45.40 LOCATOR BAKER GBH-22 LOCATOR SUB 2.992 8,210.7 5,894.8 45.40 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.992 Tubing Description String Ma....113(111) Top(RKB) Set Depth(it..JSet Depth(TVD)(...WI(Ibm) 'Grade Top Connection TUBING-LOWER- 31/2 2.992 8215.5 8.367.01 6,005.5 9.30 L-80 EUE Brd Mod • GAS LIFT,8,154.0 • - RWO 2015 Completion Details Nominal ID Top(0188) Top(TVD)(ftKB) Top Incl(") Item Des Com (In) 8,215.5 5,898.2 45.36 PBR 8040 PBR(20) 4.000 8,238.6 5,9144 45.20 PACKER BAKER 4762 F HL PACKER 2950 LOCATOR.8.209.7 8,284.0 5,946.5 44.89 NIPPLE HSE 2.813"'X'NIPPLE 2.813 SEAL ASSY;6.270.7, 8,324.3 5,975.1 44.69 LOCATOR 80-40 GM-I.22 LOCATOR SUB 2.980 PBR:8,215.5 8,325.5 5,975.9' 44.68 SEAL ASSY -80-40 GBH-22 SEAL ASSEMBLY 2.992 I - Perforations&Slots PACKER.8.238.8 Shot I Dens Top(TVD) BM)(TVD) (shotssi Top(ftKB) Btm(ftKB) (ftKB) Zone Date 1) Type Corn 8.460.0 8,476.0 6,072.1 6,083.6 C4,UNIT B. 4/18/1985 12.0 IPERF 120 deg.Ph;5"Baker 2H-14 Tubing Cony NIPPLE;8,284.0 = 8.508.0 8,519.0 6,106.6- 6,114.5-A-5,21-1-14 4/22/1985 40 (PERE 90 deg.Ph:21/8" EnerJet 8530.0 8,563.0 6,122.5 6,146.5 A-4.2)1-14 4722/1985 4.0 (PERF 90 deg.Ph:21/8" EnerJet 8.588.0 8,614.0 6,161.7 6,183.8 A-3,21-1-14 4/2211985 40 (PERF 90 deg.Ph:21/8" EnerJet Cement Squeezes LOCATOR',8.3243 /I Top)TVD) Bern(TVI) Top(155E1) Otto(ftKB) (1356) (HKB) Des , Start Date Corn $336.1, 8.842.0 5,983.8 6,353.5 4 1/2"liner 1/1912015 Pump 15 bbls of Mud Push II Followed by 23 bbls of tur 1 Class-"G""15.8 Ib/gal cement.Flush lines.Drop Dart SEAL ASSY;6,325,4 ;WI +i &pump 58510 fresh wit Displace w/53.5 bbls of mud. 4� Total displacement=58.5 bbls.Pressure up&bump M� plug with 2500 psi.Plug down at 05:46 hrs.S/0 WI i 45K&set slips. 1NVMandrel Inserts ;061 St 01 ..-Iti�,' Top(TVD) Valve Latch Pon Size TRO Run `;i.__ N Top(ftKB) (ftKB) Make Model OD(In)' Sera Type Type (in) (psi) Run Date Corn (PERF.8.4500-8,47x0- t? -1' 8,154.0 5,855.1 GAMCO MMG 11/2 GAS LIFT SOV REP 1/23/2015 OCR- -i .:15- 1 I ,41 ;: >?- Notes:General&Safety 0. iPCR8 0 500 9 519 0- r`4 �� KI End Date Annotation 11::, > X14 10/27/2010 NOTE:View Schematic.w!Alaska Schematic9.0 i y I\9' ,.,., ,,,.4 1)3.5630-- 1\ 1. I` VI 'PERF.8,588.0-8.614.0- `, 1'I a a' LINER•RWO 2010,6,3168- 8.7160 ,316x- 6.7160 ke ,i v L • \Vv' a PRODUCTION;25.6-8.8421 Allsup-Drake, Sharon K From: Schwartz, Guy L(DOA) <guy.schwartz@alaska.gov> Sent: Wednesday,January 21, 2015 11:16 AM To: Lee, Theresa M Cc: Eller,J Gary; Packer,J.Brett; Loepp,Victoria T(DOA) Subject: [EXTERNAL]RE:2H-14 Workover(PTD 184-095) Theresa, Based on the CBL data (very good bond in 7"casing from 8350-8450' and adequate bond above that)you have verbal approval to install a straddle packer to isolate the casing leak(as proposed in your latest schematic) . This puts your upper packer depth 240 ft above the C sand (8460') which is part of the Kuparuk Oil Pool although it is currently isolated .. under 20 AAC 25.412 (b)the packer placement may be modified if confinement can be verified. I will file this email and diagram in our well file for documentation. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Lee, Theresa M [mailto:Theresa.M.Lee@conocophillips.com] Sent: Wednesday, January 21, 2015 9:45 AM To: Schwartz, Guy L(DOA) Cc: Eller, J Gary; Packer, J.Brett Subject: RE: 2H-14 Workover Guy, I'm following up with our phone conversation about stacking a packer to straddle the 7" casing leak. I have attached our proposed completion to set the FHL packer at 8,220'to isolate the 7" casing leak below 8,297' and give us a safe distance above the pre-existing tubing leak at 8,237'. The PTD number is 184-095 and the workover sundry number approved on 11/19/14 is 314-604. Please let me know if you have any questions or need any other documentation submitted. Thank you, Theresa Lee Wells Engineer ConocoPhillips Alaska Office:907-263-4837 Cell:505-301-6483 1 From: Lee,Theresa M Sent: Wednesday, January 21, 2015 8:45 AM To: Schwartz, Guy L(DOA) (quy.schwartz@alaska.gov) Cc: Eller, J Gary Subject: FW: 2H-14 Workover Guy, Please see the information below about 2H-14 if you are available. Thank you, Theresa Lee Wells Engineer ConocoPhillips Alaska Office:907-263-4837 Cell:505-301-6483 From: Lee,Theresa M Sent: Wednesday, January 21, 2015 8:17 AM To: Loepp, Victoria T(DOA) (victoria.loepp@alaska.gov) Subject: 2H-14 Workover Victoria, I have attached the original schematic, current schematic and the CBL from around the 7" casing leak zone.We ran a 4- 1/2" liner with a ZXP liner top packer set at 8,316' and cemented in place over the weekend. Our pressure test after waiting on cement failed in the IA.After the weekly BOPE test yesterday,we ran in hole with a test packer to find the 7" casing leak location.This morning we isolated the 7"casing leak between 8,297'and the top of the packer at 8,316'.We stung into the packer and set down then picked up to ensure the packer was properly set.The original completion we pulled at the beginning of the workover had a leak at 8,237'. I will call to discuss a plan forward at 8:30am. Thank you, 2 k 14 tF • j C r , Ili i aa fi I I -- .... I ,.. y i r p MM f f — n ..ewe.,i„v 3 � 1 1,A. s t_ { la i I1{ _c_ 7r 4 • n .... 1 ii j .�_ .r . _= +1 f .=.A.ai.rr r : 2 i «. ` -. 64 n .. _! i f . : i t i't,ii 4 • ' 1 y . r C ,. i X 1 1+'''&�'1 .1.3".49,...;;;,,,-'1: Theresa Lee Wells Engineer ConocoPhillips AlasI a Office:907-263-4837 Cell:505-301-6483 3 2H-14 PRE-RIG WELL WORK DATE SUMMARY 11/5/2014 MEASURED BHP @ 8580' RKB: 3483 PSI. COMPLETE. 11/17/2014 PULLED DV @ 8276' RKB. JOB COMPLETE (BPV HAS BEEN CALLED IN TO GET SET). 12/2/2014 UNABLE TO MAKE IT TO LOWER CUT DEPTH OF 8413' WITH INITIAL STRING SHOT PASS. INSTRUCTED TO FIRE STRING SHOT AT UPPER CUT DEPTH. FIRE MID STRING SHOT AT 8297'. CCL TO MID STRING SHOT OFFSET: 4.8', CCL STOP DEPTH: 8292.2'. MADE MULTIPLE ATTEMPTS WITH SPENT STRING SHOT TOOLSTRING TO MAKE IT PAST GLM AT 8429'. PULL TENSIONS UP TO 1800#. DECISION WAS MADE TO HAVE SLICKLINE PERFROM BRUSH AND FLUSH. 7' OF THE STRING SHOT DID NOT DETONATE, TWO SEPERATE PIECES WERE USED. THE PIECE COUPLED TO THE DETONATOR DETONATED, THE OTHER PIECE DID NOT DETONATE. MULTIPLE LACERATIONS WERE DISCOVERED UPON INSPECTION OF DET CORD. LOG CORRELATED TO TUBING TALLY RECORD DATED APR 20, 1985. JOB IN PROGRESS. 12/4/2014 BRUSHED & FLUSHED TBG TO 8510' RKB. DRIFTED CLEANLY WITH 1.875"TOOL STRING & 10'x 2" BAILER TO 8532' RKB. READY FOR E-LINE. 12/5/2014 FIRE MIDDLE OF 160 GR/FT STRING SHOT AT 8413'. CCL TO MID STRING SHOT OFFSET: 4.8', CCL STOP DEPTH: 8408.2'. LOG CORRELATED TO TUBING TALLY RECORD DATED APRIL 20 1985. ONE SCREW FOR THE STRING SHOT HARDWARE WAS LEFT IN HOLE. DIMENSIONS:5/8"x 9/16". JOB IN PROGRESS. 12/6/2014 CUT TUBING AT 8413', CCL TO CUTTER OFFSET: 10.4', CCL STOP DEPTH: 8402.6'. CORRELATED TO TUBING TALLY RECORD DATED APRIL 20 1985. ATTEMPT TO RIH WITH STRING SHOT FOR 8297', ENCOUNTERED TROUBLE FALLING. TROUBLE SHOOT ISSUE, NO EVIDENT PROBLEMS FOUND. RAN A DUMMY/DRIFT WITH 1.69"WEIGHT BARS AND CCL TO 8400'. JOB IN PROGRESS. 12/7/2014 FIRED CENTER OF 5', 160 GR/FT STRING SHOT AT 8297', CCL TO CENTER STRING SHOT OFFSET: 4.8', CCL STOP DEPTH: 8292.2'. CORRELATED TO TUBING TALLY RECORD DATED APRIL 20 1985. CRANE LEAKED 0.5 GALLONS OF ANTIFREEZE INTO CONTAINMENT FROM THE RADIATOR HOSE. CRANE TO GO TO KIC AND GET REPAIRED. CWG REP, DSO, SECURITY, AND COORDINATOR HAVE BEEN NOTIFIED. 12/8/2014 CUT TUBING WITH 1.69" RCT AT 8297' CCL TO CUTTER OFFSET: 10.4', CCL STOP DEPTH: 8286.6'. JOB CORRELATED TO TUBING TALLY RECORD DATED APRIL 20 1985. JOB COMPLETE. ConacoPhiIIips Time Log & Summary Wellview Web Reporting Report Well Name: 2H-14 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 12/26/2014 1:30:00 AM Rig Release: 1/24/2015 2:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/25/2014 24 hr Summary Rig down and prepare for move to 2H-14. Move Satellite Camp, shop and pits complex to 2H pad. Move Sub base to 2H pad. Raise derrick. Spot rig over well.Work on rig acceptance. 03:00 06:00 3.00 0 0 MIRU MOVE IRURD I P Rig Down Satellite Camp. Rig Down Pits Complex. Prepare Sub for Derrick layover. Bridle Up blocks and remove derrick pins. 06:00 12:00 6.00 0 0 MIRU MOVE MOB P Lower Cattle chute. Break Kelly hose. Lower Derrick. Remove berming around fuel tank and pits. Pull pit module off of Sub base. Move cuttings bin. Install Pits complex jeep. Begin moving camp, shop and pits complex to 2H pad. 12:00 18:00 6.00 0 0 MIRU MOVE MOB P Complete move of pits to 2H pad. Move sub off of 2K-15 and move to 2H-14. Raise Derrick and pin. Raise Cattle chute and pin. Spot sub base over well. 18:00 00:00 6.00 0 0 MIRU MOVE MOB P Spot Pits complex to Sub base. Lay herculite. Spot cutting tank and parts house. Hook up interconnects. Go through Rig acceptance checklist. 12/26/2014 Work on Rig acceptance.Accept Rig. Bring on mud, dilute to 11.3 ppg. Pull BPV. Kill Well with 11.3 ppg mud. Reverse Circulate 11.7 ppg mud pill and 2 hole volumes. Monitor well. RIG ACCEPTED @ 01:30; Rig on Highline @ 14:00 00:001 01:30 1.50 0 0 MIRU MOVE RURD P Bridle Down Blocks. Hook Up Top Drive Hydraulics. Complete Rig Acceptance Checklist. RIG ACCEPTED @ 01:30 01:30 05:00 3.50 0 0 MIRU WELCTI COND P Take on 11.7 ppg mud.water back to 11.3 ppg. SIMOPS: complete Tiger Tank placement and berming and install hardline and choke shack. mobilize Lubricator to floor to lubricate out BPV. 05:00 08:00 3.00 0 0 MIRU WELCTI MPSP P Test lubricator to 1500 psi. Lubricate out BPV. SIMOPS: Continue bringing on mud and watering back to 11.3 ppg. Retrieve BPV. Lay down Lubricator. Tbg- 1,400 psi, IA = 1,300 psi, OA=0 psi. SIMOPS: off load final Vac Truck. Check final Mud weight in Pits= 11.3 lb/gal. Page I of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 08:30 0.50 0 0 MIRU WELCTL SFTY P PJSM. Discuss bleeding free gas to the KIII Tank. Discuss killing the Well with 11.3 I/gal Mud. Notify Security and the Drill Site Operator that we will be venting gas. 08:30 11:00 2.50 0 0 MIRU WELCTL KLWL P Bleed some free gas from the IA,. However,well is mostly fluid packed. Bring pump on line with 11.3 lb/gal water based mud at 3.0 bpm/1,238 psi down the Tubing.. Taking return from the IA through the Choke House to the Kill Tank. Increase pump rate to 4.0 bpm. Stop at 300 bbls pumped to gauge the kill tank(266 bbls recovered). Bring pump back on line at 1.0 bpm. Grab sample= 10.3 lb/gal. Continue to circulate at 1.0 bpm/630 psi. 11:00 13:00 2.00 0 0 MIRU WELCTL KLWL P Route mud returns to the Gas Buster into the Pits. (SIMOPS: blow down line to the Choke House and to the KIII Tank. Haul return from the Kill Tank). Release gas venting restriction on the Pad. Continue to circulation and condition Mud. 11.3 lb/gal in...11.0 lb/gal out(pressurized out). 13:00 13:30 0.50 0 0 MIRU WELCTL OWFF P Mud weight in 11.3 lb/gal. Mud weight out 11.3 lb/gal pressurized. However returned mud is aerated(no gas smell). Shut down Pump. Monitor well. Very slight flow from the Tubing side. Small flow from the Casing to intermittent"sputtering". 13:30 14:30 1.00 0 0 MIRU WELCTL KLWL P Resume circulating at 2.0 bpm/543 psi through the Gas Buster into the Pits. Mud weight in 11.3 lb/gal. Return weight 11.2 lb/gal pressurized. Add de-foamer. Returns continue to be areated. 14:30 18:30 4.00 0 0 MIRU 'WELCTL KLWL P Mix a 28 bbl 11.7 lb/gal spacer an reverse in. Reverse circulate the spacer back to surface with 11.3 lb/gal Mud at 3.0 bpm/770 psi. 11.3 lb/gal return looking much better. Continue to reverse circulate 2 hole volumes, mud weight in/out 11.4 ppg. SIMOPS: begin to load Pipe Shed with 3 1/2"Drill Pipe. 18:30 19:00 0.50 0 0 MIRU WELCTL OWFF P Monitor well.steady stream coming out of IA @ 1 gal/min. Tubing dead. 19:00 19:30 0.50 0 0 MIRU WELCTL CIRC P Circulate 20 bbls at 3 bpm @ 750 psi down tubing taking returns out IA. 11.4 ppg in/out. 19:30 00:00 4.50 0 0 MIRU WELCTL OWFF P Monitor well.Tubing Dead. IA stream slowing from 1 gal/2 min to 1 gal/23 min. Continue to monitor diminishing stream from IA. Page 2 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/27/2014 24 hr Summary Continue monitoring well.Circulate well down tubing.Weight up to 11.7 ppg. Reverse Circulate well. Circulate well down tubing.Well Dead. Set BPV. 00:00 02:00 2.00 0 0 MIRU 'WELCTL OWFF P Continue to monitor well.Tubing dead. IA very small stream down to 1 gal per 40 min. 02:00 02:30 0.50 0 0 MIRU WELCTL KLWL P Circulate 12 bbls down tubing at 1 bpm @ 380 psi. 11.4 ppg in/out. 02:30 03:00 0.50 0 0 MIRU WELCTL OWFF P Monitor well. Tubing dead.very slight flow from IA. 03:00 03:30 0.50 0 0 MIRU WELCTL KLWL P Circulate 12 bbls down tubing at 1 bpm @ 380 psi. 11.4 ppg in/out. 03:30 04:00 0.50 0 0 MIRU WELCTL OWFF P Monitor well.Tubing dead. very slight flow from IA. Put gauge on IA, observe pressure @ 3.5 psi after 15 min(stable after 5 min). Take gauge off,very slight flow persists. 04:00 07:00 3.00 0 0 MIRU WELCTL KLWL P Circulate well at 2bpm @ 540 psi down tubing taking returns out IA. Mud out IA 11.2+to 11.4 ppg. Traces of hydrocarbons in mud. Circulate 300 bbls. continue to circulate until 11.3 lb/gal in...11.3 lb/gal out. Shut down pump. 07:00 07:30 0.50 0 0 MIRU WELCTL OWFF T Monitor Well x 30 minutes. IA eventually died. Tubing side continue to flow in a small stream/steady drips/small stream/steady drips. 07:30 09:00 1.50 0 0 MIRU WELCTL COND T Discuss weighting up with Anchorage Engineer to 11.6 lb/gal(to include a trip margin). Bring the mud volume in the Pits up to 11.6 lb/gal. 09:00 12:00 3.00 0 0 MIRU WELCTL KLWL T Bring Pump on line at 2.0 bpm/600 psi pumping 11.6 lb/gal Mud down the Tubing taking 11.3 lb/gal Mud from the IA through the Gas Buster back to the isolation Pit to be weighted up to 11.6 lb/gal Mud. Continue to circulate until 11.6 returns. Total volume pumped=340 bbls. Shut down Pump. 12:00 13:00 1.00 0 0 MIRU WELCTL OWFF T Monitor Well. The IA flowed a small trickle and then died in-5 minutes. The Tubing also started out flowing a small flow...then drips/flows/drips. 13:00 16:30 3.50 0 0 MIRU WELCTL KLWL T Reverse in 250 bbls of clean 11.6 Mud. Observe Mud weight spot of 12.0 lb/gal and several weight checks at 11.9 lb/gal...??? Also getting a small amount of sand and tiny paraffin balls. Continue to reverse circulate to balance out the mud weight. Mud weight now 11.7 lb/gal in and out. Total volume reversed to condition well=415 bbls. 16:30 18:00 1.50 0 0 MIRU WELCTL OWFF T Monitor Well. Tubing dead, IA slight flow. Page 3 of 33 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 19:00 1.00 0 0 MIRU WELCTL KLWL T Reverse 95 bbls of 11.7 ppg mud 2.5 bpm @ 720 psi, small paraffin balls at Bottoms Up. Shut down. Circulate 18 bbls down tubing 2.5 bpm @ 700 psi. 11.7 ppg mud in/out entire time. 19:00 20:00 1.00 0 0 MIRU WELCTL OWFF T Monitor well.Tubing dead, IA slight flow. 20:00 22:00 2.00 0 0 MIRU WELCTL KLWL T Circulate 310 bbls down tubing. Consistent 11.7 ppg mud in/out entire circulation, no gas or crude noted.2.5 bpm @ 765 psi. 22:00 23:00 1.00 0 0 MIRU WELCTL OWFF P Monitor well. IA slight flow to dead. Tubing slight flow to dead.Well finally gave up the ghost and is killed. Mobilize FMC to set BPV. 23:00 23:30 0.50 0 0 MIRU WELCTL RURD P Rig Down and blow down circulating equipment. 23:30 00:00 0.50 0 0 MIRU WHDBO MPSP P Set BPV. 12/28/2014 Nipple Down tree. Nipple Up BOPE. Test BOPE. Pull BPV. Pull hanger. Circulate well. Lay down 2-7/8" completion. 00:00 02:30 2.50 0 0 MIRU WHDBO NUND P Nipple Down tree. Inspect threads on hanger,good condition. Set blanking lug 11 turns on, retrieval will take 8.5 turns. 02:30 07:00 4.50 0 0 MIRU WHDBO NUND P Nipple Up BOPE. SIMOPS: Rig up for BOP test. 07:00 14:30 7.50 0 0 MIRU WHDBO BOPE P Perform the initial BOPE test as per ConocoPhillips/AOGCC ' requirements at 250/3,500 psi with a 2 7/8"and 3 1/2"Test Joints. Perform the Koomey draw down test. Test Gas Alarms. The State's right to witness the test was waived by AOGCC Field Inspector,J. Crisp. All pressure tests good and recorded on a chart. Koomey draw test,good. 14:30 14:45 0.25 0 0 MIRU WHDBO RURD P Rig down testing equipment. Suck out Stack. 14:45 15:30 0.75 0 0 MIRU WHDBO MPSP P Pull Blanking Plug. Pull BPV. Monitor Well,dead. 15:30 17:30 2.00 0 0 COMPZ RPCOM PULD P Pick-up Landing joint. Make-up Top Drive. BOLDS. 17:30 18:00 0.50 0 8,261 COMPZ RPCOM PULL P Pull completion, observed completion free at 80 k. Up Wt=74k; Down Wt =56k 18:00 19:15 1.25 8,261 8,261 COMPZ RPCOM CIRC P Circulate well until clean. 5 bpm @ 1450 psi. chucks of paraffin coming out, circulate until larger chunks stop coming out. 19:15 19:45 0.50 8,261 8,261 COMPZ RPCOM OWFF P Monitor well. Static. SIMOPS: Rig Up SLB Spooling unit and check all equipment for laying down completion. 19:45 20:00 0.25 8,261 8,261 COMPZ RPCOM SFTY P PJSM with all hands for laying down completion. Page 4 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 21:15 1.25 8,261 8,061 COMPZ RPCOM PULL P Pull and Lay Down tubing hanger and then 2-7/8"completion with control line. String pulling wet. 21:15 21:30 0.25 8,061 8,061 COMPZ RPCOM SFTY P Well Control Drill. D-1 Drill.Well shut in 37 sec, all hands in position 76 sec.AAR with all crew members. 21:30 00:00 2.50 8,061 6,494 COMPZ RPCOM PULL P Continue laying down 2-7/8" completion with control line. String continues to pull wet. 12/29/2014 Continue to Lay Down 2-7/8"completion. Set Storm Packer at-106'with-3900'of 2-7/8"completion beneath. Nipple Down BOP. Grow 7"casing 9"and set in tension stretching an additional 12"for a total of 21". Replace packoff and tubing head.Test to 250/3000psi. Nipple Up BOP.Test Breaks to 250/3500 psi. Retrieve Storm Packer. 00:00 01:00 1.00 6,494 6,254 COMPZ RPCOM PULL P Continue laying down 2-7/8" completion with control line. String pulling wet. 01:00 01:30 0.50 6,254 6,254 COMPZ RPCOM RURD P Rig Down SLB Spooling Unit. Recovered 33 stainless steel bands. 01:30 04:00 2.50 6,254 5,504 COMPZ RPCOM PULL P Continue laying down 2-7/8" completion. String continues to pull wet. 04:00 04:30 0.50 5,504 5,504 COMPZ RPCOM CIRC P Circulate in 30 bbl 12.6 ppg dry job. 04:30 07:00 2.50 5,504 4,427 COMPZ RPCOM PULL P Continue laying down 2-7/8" completion to 4,427-ft. 07:00 07:15 0.25 4,427 4,427 COMPZ WELLPF SFTY P PJSM...pu/set/test the Storm Packer. 07:15 08:30 1.25 4,427 4,517 COMPZ WELLPF MPSP P Set Storm Packer with Center of element at 106'. Test at 1,000 psi x 5 minutes. Good. Recorded on chart. 08:30 10:00 1.50 4,517 4,517 COMPZ WELLPF NUND P Nipple down the BOP stack and set back on the stump. 10:00 14:00 4.00 4,517 4,517 COMPZ WELLPF NUND P Use Hydratight equipment to control the 7"Casing growth=9". Nipple down the FMC Gen III Tubing Spool. 14:00 18:00 4.00 4,517 4,517 COMPZ WELLPF CUTP P Pick-up 7"Casing Spear BHA#1 and plant same in the Casing. Stretch Casing 7". Pull the old Slips. Install new Slips. Slack-off and leave the 7"Casing with 85k tension. Release Spear and lay down same(total growth+stretch= 21 inches). Dress off 7"Casing with the Wachs Cutter. Install new Pack-off. 18:00 19:00 1.00 4,517 4,517 COMPZ WELLPF PRTS P Test new Pack-off and tubing head to 3000 psi for 10 min. Good test. 19:00 21:30 2.50 4,517 4,517 COMPZ WELLPF NUND P Nipple Up BOP Stack,Turnbuckles and Flow Nipple. 21:30 22:30 1.00 4,517 4,517 COMPZ WELLPF BOPE P Test Break in stack to 250/3500 psi for 5 min. Good test. Pull test plug. 22:30 22:45 0.25 4,517 4,517 COMPZ WELLPF PULD P Pick Up Retrieval tool for storm packer and RIH with same. 22:45 23:15 0.50 4,517 4,517 COMPZ WELLPF MPSP P Equalize Storm packer and then release. Page 5 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:15 23:45 0.50 4,517 4,517 COMPZ WELLPF OWFF P Monitor well.Well dead but showing trace crude. 23:45 00:00 0.25 4,517 4,427 COMPZ WELLPF PULD P POOH and Lay Down Storm Valve. 12/30/2014 Circulate well clean. Lay down 2-7/8"completion. Pick Up BHA#2(2 7/8"overshot). Single in hole. Circulate well clean. 00:00 01:15 1.25 4,427 4,427 COMPZ WELLPF CIRC P Circulate Bottoms Up.some light spots noted to 11.4 ppg.trace crude throughout. 11.6 ppg in/out. Pump 10 bbls 12.6 ppg dry job. Paraffin in returns throughout circulation. SIMOPS: Redress Storm Valve for next run. 01:15 04:00 2.75 4,427 2,551 COMPZ RPCOM PULL P Continue to Lay Down 2 7/8" completion. Up Wt=49k, Dn Wt= 44k 04:00 05:00 1.00 2,551 2,551 COMPZ RPCOM SVRG P Service Rig. Service Skate and electrical system. 05:00 10:00 5.00 2,551 0 COMPZ RPCOM PULL P Continue to Lay Down 2 7/8" completion. Up Wt=46k, Dn Wt= 40k 10:00 11:00 1.00 0 0 COMPZ RPCOM RURD P Rig Down Power Stack Tongs, Clean and clear rig floor. 11:00 11:30 0.50 0 0 COMPZ RPCOM SVRG P Service Top Drive and do Top Drive Drops inspection. 11:30 12:00 0.50 0 0 COMPZ RPCOM RURD P Install Wear Ring(9"). 12:00 15:00 3.00 0 315 COMPZ RPCOM PULD P Pick Up BHA#2(2-7/8"Overshot). Overshot and extension, Bumper Sub and Oil Jar, 9 Drill Collars and Intensifier, Pump Out sub.Total Length: 315' 15:00 15:30 0.50 315 315 COMPZ RPCOM SFTY P Well Control Drill. Shut in=49 sec; All personnel in place on rig=97 sec.AAR with crew afterwards. 15:30 22:15 6.75 315 5,830 COMPZ RPCOM PULD P Running in hole picking up joints from shed. Decision to circulate due to incorrect displacement and total displacement. Up Wt=65k Dn Wt =60k 22:15 23:00 0.75 5,830 5,830 COMPZ RPCOM CIRC P Circulate well at 5830'dpmd. Mud has trace crude and gas break out toward Bottoms Up. 5 bpm/1070 psi. Once uniform 11.6 ppg in/out SPRs taken. Phase 3 called at 22:45. SPRs:TVD 4332' Pump 1:2 bpm=415 psi ;3 bpm= 525 psi Pump 2:2 bpm=425 psi ; 3 bpm= 535 psi 23:00 00:00 1.00 5,830 6,970 COMPZ RPCOM PULD P Continue running in hole picking up joints from shed. 12/31/2014 SIH with Drill Pipe. Circulate well to 11.6 ppg in/out. Monitor well while waiting on Phase 3 weather. Page 6 of 33 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 01:15 1.25 6,970 8,074 COMPZ RPCOM PULD P Continue running in hole picking up joints from shed. Up Wt= 148k; Dn Wt=90k 01:15 02:00 0.75 8,074 7,128 COMPZ RPCOM TRIP P Rack back 10 stands in Derrick. 02:00 03:00 1.00 7,128 8,070 COMPZ RPCOM PULD P Continue running in hole picking up remainder of pipe in shed. 03:00 05:00 2.00 8,070 8,070 COMPZ RPCOM CIRC T Phase 3 weather fieldwide @ 03:00. Circulate well clean. Pump 270 bbls at 5 bpm/1365 psi. Pump 400 bbls at 8 bpm/2770 psi. Up Wt= 154k; Dn Wt=92k. SPRs taken. SPRs:TVD 5950' Pump 1:2 bpm =530 psi ;3 bpm= 650 psi Pump 2: 2 bpm=520 psi ;3 bpm= 640 psi 05:00 09:30 4.50 8,070 8,070 COMPZ RPCOM OWFF T Monitor well while waiting on weather.Well Static. 09:30 10:30 1.00 8,070 8,070 COMPZ RPCOM CIRC T Circulate well while waiting on weather. Pumped 360 bbls at 8 bpm /2770 psi. 10:30 14:30 4.00 8,070 8,070 COMPZ RPCOM OWFF T Monitor well while waiting on weather.Well Static. 14:30 15:30 1.00 8,070 8,070 COMPZ RPCOM CIRC T Circulate well while waiting on weather. Pumped 316 bbls at 8 bpm /2780 psi. 15:30 00:00 8.50 8,070 8,070 COMPZ RPCOM OWFF T Monitor well while waiting on weather.Well Static. 01/01/2015 Monitor well while waiting on Phase 3 weather. Engage/Fish Seal assmebly. Circulate BU.TOOH and LD BHA#2 and fish. PU and TIH BHA#3(PBR Spear). 00:00 04:00 4.00 8,070 8,070 COMPZ RPCOM OWFF T Continue monitor well,while waiting on weather. Circulate well,with no issues, verify no gas. 04:00 06:30 2.50 8,070 8,070 COMPZ RPCOM CIRC P Circulate well to consistent 11.6 ppg mud weight in preparation for latching onto fish and fishing operations, 8 bpm/2760 psi. SIMOPS: Rig Up for fishing operations. Clean pad of snow drifts from phase 3 weather. 06:30 07:00 0.50 8,070 8,300 COMPZ RPCOM TRIP P Trip in hole with drill pipe from 8070' to top of fish @ 8285' DPM. Observed proper displacement. UP WT-145K, SO WT-90K. Pumps at 5 BPM-1275 PSI 07:00 07:45 0.75 8,300 8,300 COMPZ RPCOM FISH P Work drill string and washover top of fish, repeat 2 times to fully engage grapple and pull to 20K over verifying catch. Observed 50 PSI increase verifying over top of fish. Slack off and reset jars. Pull up slowly to 35K over to observe seals pull free. Pull up to 13'and observe seals pull free, and lose 50 PSI in pressure. Pick up and retag higher verifying seals free. Page 7 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 1 07:45 08:30 0.75 8,300 8,300 COMPZ RPCOM CIRC P With seals just at the top of the PBR, circulate bottoms up at 5 BPM - 1275 PSI. Mud weight in/out- 11.6 PPG. 08:30 08:45 0.25 8,300 8,300 COMPZ RPCOM OWFF P Monitor well-static and balanced. 08:45 13:45 5.00 8,300 500 COMPZ RPCOM TRIP P Pull 2 stands, and pump dry job. Continue POOH with fish. 13:45 14:00 0.25 500 500 COMPZ RPCOM OWFF P Monitor well. Static 14:00 16:30 2.50 500 0 COMPZ RPCOM PULD P Lay down BHA including racking back 3 stand Drill Collars.Attempt to release fish from overshot,will not release. Cut joint out of Overhsot per Baker Fishing Rep. Cut joint 17.14', Seals 14.12'. 16:30-17:00 0.50 0 0 COMPZ RPCOM RURD P Clean and clear rig floor and prep for BHA#3. 17:00 17:45 0.75 0 320 COMPZ RPCOM PULD P Pick Up BHA#3(PBR Spear)per Baker Rep.Total length: 314' 17:45 21:30 3.75 320 8,263 COMPZ RPCOM TRIP P Trip in hole with BHA#3 to 8263' DPM 21:30 22:00 0.50 8,263 8,402 COMPZ RPCOM FISH P Establish parameters. Up Wt= 145k, Dn Wt=92k, Rot Wt= 120k, 10 RPM=6.5k. Establish 820 psi @ 3 bpm, observe grapple enter PBR as pressure increases to 1000 psi. Set down 7k. Pull 165k(10k over)to set grapple,set 15k down,pull and set jars, slack off, pull to 200k observe jars fire, pull to 240k and observe packer release. Up Wt= 150k, Dn Wt= 100k SPRs:TVD 5940' Pump 1:2 bpm=820 psi; 3 bpm= 1180 psi Pump 2:2 bpm=820 psi ;3 bpm= 1180 psi 22:00 22:15 0.25 8,402 8,402 COMPZ RPCOM OWFF P Monitor well. Static. 22:15 23:00 0.75 8,402 8,402 COMPZ RPCOM CIRC P Circulate Bottoms Up @ 4 bpm/ 2575 psi. Observed pit gain and lowering pump pressure. 23:00 23:15 0.25 8,402 8,402 COMPZ RPCOM OWFF P Stopped and watched well to ensure it was static, static after 12 min. Champagne bubbles evident. 23:15 00:00 0.75 8,402 8,402 COMPZ RPCOM CIRC P Continue to pump @ 2 bpm/600 psi. Larger bubbles to surface through Bottoms Up. 01/02/2015 Spear PBR. Circulate BU. TOOH and LD BHA#3. No Fish. PU and TIH with BHA#4(PBR Spear#2). Spear PBR.TOOH and LD BHA#4 and fish. 00:00 01:00 1.00 8,402 8,011 COMPZ RPCOM CIRC P Continue Circulating until uniform 11.6 ppg in/out and bubbles stop. 01:00 01:30 0.50 8,011 8,011 COMPZ RPCOM OWFF P Monitor well. Static 01:30 01:45 0.25 8,011 7,825 COMPZ RPCOM TRIP P Pull 2 stands wet checking for hole fill. Page 8of33I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:45 02:00 0.25 7,825 7,825 COMPZ RPCOM CIRC P Pump dry job. 15 bbls of 12.6 ppg mud. 02:00 06:45 4.75 7,825 409 COMPZ RPCOM TRIP P Trip out of hole.Observed proper displacement. 06:45 07:00 0.25 406 409 COMPZ RPCOM OWFF P Monitor well. Static. 07:00 08:30 1.50 409 0 COMPZ RPCOM PULD P Lay Down BHA#3. Fish not recovered. 08:30 09:00 0.50 0 0 COMPZ RPCOM SVRG P Service Crown, Drawworks and Iron Roughneck. 09:00 10:00 1.00 0 314 COMPZ RPCOM PULD P Pick Up BHA#4(Same as BHA#3 with new grapple.Overall length is 314' 10:00 14:00 4.00 314 8,263 COMPZ RPCOM TRIP P Trip in hole with BHA#4.Take SPRs. SPRs:TVD 5937' Pump 1:2 bpm =900 psi ;3 bpm= 1300 psi Pump 2:2 bpm=900 psi ;3 bpm= 1290 psi 14:00 14:30 0.50 8,263 8,399 COMPZ RPCOM FISH P Engage top of fish at 8305', bullnose at 8310'. Slack off 20k, Pick Up to 175k and confirm fish on. Up Wt- 155k with drag to 163k. 14:30 15:00 0.50 8,399 8,262 COMPZ RPCOM TRIP P Pull remainder of 1 stand and 1 full stand observing hole for swabbing. No swabbing. Up Wt= 150k-160k, Drag to 170k. 15:00 15:30 0.50 8,262 8,262 COMPZ RPCOM OWFF P Monitor well. Static. 15:30 19:45 4.25 8,262 504 COMPZ RPCOM TRIP P Trip out of hole. Stop at 504'with 1 stand, BHA and fish in hole to monitor. 19:45 20:00 0.25 504 504 COMPZ RPCOM OWFF P Monitor well. Static to slight loss. 20:00 21:15 1.25 504 99 COMPZ RPCOM PULD P Lay Down BHA#4. 21:15 22:15 1.00 99 99 COMPZ RPCOM RURD P Rig Up Tongs and handling equipment. Have to rig up[different elevators for pulling PBR and packer and change dies for breaking out packer from joint below. 22:15 23:15 1.00 99 0 COMPZ RPCOM PULL P Lay Down Fish: PBR, Packer,2 joints of 2-7/8"tubing, 1 GLM,cut joint(14.02')Total Length: 98.08' 23:15 00:00 0.75 0 0 COMPZ RPCOM RURD P Rig Down Stack Tongs. Clean Rig Floor and mobilize BHA pieces to floor. 01/03/2015 PU and TIH with BHA#5(Wash Pipe).Wash down stub.TOOH and LD BHA#5. PU and TIH with BHA#6(2 7/8"overshot). String fell down hole with BHA and 1 stand of Drill Pipe.TIH to fish string. 00:00 02:00 2.00 0 398 COMPZ RPCOM PULD P Pick Up BHA#5. FB Shoe, 3 joints wash pipe,boot basket, bumper sub, jars, pump out sub, 9 joints drill collars, crossover. Total Length 398.06' Page 9of33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 06:00 4.00 398 5,981 COMPZ RPCOM TRIP P Trip in hole with BHA#5.Trip slowed due to mud coming out pipe due to wash pipe shoe size. 06:00 07:00 1.00 5,981 5,981 COMPZ RPCOM SVRG P Service Top Drive, Roughneck, Drawworks. Top Drive inspection. 07:00 09:30 2.50 5,981 8,345 COMPZ RPCOM TRIP P Trip in hole. Up Wt= 155k, Dn Wt= 97k 09:30 13:00 3.50 8,345 8,467 COMPZ RPCOM WASH P Wash down over stub, GLM, and blast joints to 8466'.Work multiple times to get to 8467'. 6 bpm/1800 psi; 30-40 rpm; Free TQ=4500;TQ on=8-10k 13:00 13:15 0.25 8,467 8,252 COMPZ RPCOM TRIP P Pull 2 stands checking for swabbing. Up Wt=165k; Dn Wt= 100k 13:15 13:30 0.25 8,252 8,252 COMPZ RPCOM OWFF P Monitor well. Static 13:30 18:00 4.50 8,252 491 COMPZ RPCOM TRIP P Trip out of hole. 18:00 20:00 2.00 491 0 COMPZ RPCOM PULD P Lay down BHA#5. Extreme wear on shoe, all carbide gone. Retrieve--2 cups of junk from basket. Most looks like carbide fragments. 20:00 20:30 0.50 0 0 COMPZ RPCOM RURD P Clean and clear rig floor. 20:30 22:15 1.75 0 314 COMPZ RPCOM PULD P Pick Up BHA#6(2 7/8"overshot). Overshot and extension with grapple inside, bumper sub,jars, intensifier, crossover. Total length=314' Up Wt = 42k; Dn Wt=42k 22:15 22:30 0.25 314 407 COMPZ RPCOM TRIP P Trip in hole. after first stand of drill pipe was in hole the crew was preparing to stab the second stand of drill pipe. The string/pipe stump jumped in the slips, the slips jumped and the string fell through the slips and down the hole. 22:30 23:00 0.50 407 407 COMPZ RPCOM SFTY T PJSM for tripping in the hole to fish the BHA and string. SIMOPS: contacted CPAI engineer to inform of problem and plan forward. Inspect slips for any damage, none found. 23:00 00:00 1.00 407 1,532 COMPZ RPCOM TRIP T Trip in hole with drill, pipe to locate and fish string. 01/04/2015 Continue to TIH to fish string. Tag and screw into top of BHA. Pick up to verify added weight to verify catch. Ensure overshot grapple released, and pulled off of fish top. Pick up and CBU to ensure balanced well. TOOH and LD BHA#6 and fish. Perform the weekly BOPE test as per ConocoPhillips/AOGCC requirements at 250/3,500 psi with 3 1/2"and 4 1/2"Test Joints. Right to Witness waived by AOGCC Representative M. Herrera. 00:00 05:00 5.00 1,532 8,040 COMPZ RPCOM TRIP T Continue trip in hole to fish string. 05:00 05:45 0.75 8,040 8,454 COMPZ RPCOM FISH T Obtain parameters. UP WT-0140K, SO WT-90K. Tag top of fish at 8408'. Engage with slow RPM rotation and screw into BHA. Observed torque to 11500 Ft/lbs. Pick up to verify catch with increased weight of 15K, New upweight- 155K, SO WT-95K. Got the fish. Page 10 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:45 06:30 0.75 8,040 8,040 COMPZ RPCOM CIRC P Pick up above original fish top at 8408', and Circulate bottoms up. Verify no gas and well balanced. Mud weight= 11.6 PPG. Pumps at 6 BPM- 1850 PSI. Note: Crew Change 06:30 06:45 0.25 8,040 COMPZ RPCOM TRIP P Pull 2 stands and check for swabbing. No indication of swabbing. 06:45 07:00 0.25 8,040 COMPZ RPCOM OWFF P Monitor well. No gain/loss. Static. SIMOPS: Blow down Top Drive. 07:00 10:30 3.50 8,040 348 COMPZ RPCOM TRIP P Trip out of hole with BHA#6 and fish. 10:30 12:00 1.50 348 30 COMPZ RPCOM PULD P Lay Down BHA#6 12:00 14:00 2.00 30 0 COMPZ RPCOM PULL P Lay down fish to include cut joint (14.94'), GLM (6.56'), Blast joint (29.61').Total Fish length: 51.11' 14:00 14:30 0.50 0 0 COMPZ RPCOM RURD P Rig Down and clean and clear rig floor. 14:30 15:00 0.50 0 0 COMPZ RPCOM WWWH P Wash wellhead with jetting tool. 15:00 15:30 0.50 0 0 COMPZ WHDBO RURD P Install Test plug. 15:30 18:00 2.50 0 0 COMPZ WHDBO SVRG P Change out Saver Sub. SIMOPS: Rig Up to test BOPE. 18:00 20:00 2.00 0 0 COMPZ WHDBO RURD P Rig Up for BOPE test. Rig Up test joints,valves, lines,test equipment. Drain Stack and fill with water. 20:00 00:00 4.00 0 0 COMPZ WHDBO BOPE P Perform the weekly BOPE test as per ConocoPhillips/AOGCC requirements at 250/3,500 psi with 3 1/2"and 4 1/2"Test Joints. Perform the Koomey draw down test. Test Gas Alarms. The State's right to witness the test was waived by AOGCC Field Inspector, Matt Herrera. Choke Valve#16 and Upper IBOP failed, Kill HCR Failed and passed on retest.All pressure other tests good.All tests recorded on a chart.Test continued 1/5/15. 01/05/2015 Continue to perform the weekly BOPE test as per ConocoPhillips/AOGCC requirements at 250/3,500 psi with 3 1/2"and 4 1/2"Test Joints. Koomey test-initial 200 PSI increase-17 seconds, and full 3000 PSI obtained in 87 seconds.AOGCC Representative M. Herrera waived witness of the test. Choke manifold Valve#16, Upper IBOP tests failed. Kill HCR Failed and passed on retest. Commence Top Drive Repairs and repair of BOPE Valve#16 and Upper IBOP. Retest Valve#16 and Upper IBOP, both passed. PU BHA#7(5 3/4" Overshot w/3 1/2"grapple)and TIH. Page 11 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:00 4.00 0 0 COMPZ WHDBO BOPE P Perform the weekly BOPE test as per ConocoPhillips/AOGCC requirements at 250/3,500 psi with 3 1/2"and 4 1/2"Test Joints. Perform the Koomey draw down test. Test Gas Alarms. The State's right to witness the test was waived by AOGCC Field Inspector, Matt Herrera. Choke Valve#16 and Upper IBOP failed, Kill HCR Failed and passed on retest.All other tests good.All tests recorded on a chart. Koomey test-initial 200 PSI increase in 17 seconds,with full 3000 PSI obtained in 87 seconds, 04:00 05:00 1.00 0 0 COMPZ WHDBO BOPE T Rig Down Test Equipment. Blow Down lines and choke and kill. Prepare for Top Drive Maintenance work. 05:00 15:00 10.00 0 0 COMPZ WHDBO RGRP T Top Drive Repair.Top drive repair indicated rotary table in good condition with overflow spout needing repair.The Main bearing was gauged and observed at 45/thousants out of spec. Repair spout and install grease zert. SIMOPS: Replace Valve#16 and repair Upper IBOP. 15:00 15:30 0.50 0 0 COMPZ WHDBO BOPE T Rig Up test equipment for retest of Upper IBOP and Valve#16 15:30 16:00 0.50 0 0 COMPZ WHDBO BOPE T Test Choke Valve#16 and Upper IBOP. Successful test at 250/3500 PSI. 16:00 16:30 0.50 0 0 COMPZ WHDBO RURD P Rig Down Test Equipment and blow down lines. 16:30 17:00 0.50 0 0 COMPZ WHDBO RURD P Pull test plug. Set Wear Ring.RILDS 17:00 21:00 4.00 0 334 COMPZ RPCOM PULD P Pick Up BHA#7(5 3/4"Overshot with 3 1/2"grapple).Total Length 333.57.This included picking up individual joints of HWDP from the shed. 21:00 00:00 3.00 334 5,444 COMPZ RPCOM TRIP P Trip in hole with BHA#7. Observed proper displacemnt. 01/06/2015 TIH with BHA#7. Circulate hole. Fish Blast Ring joint.Circulate BU.TOOH and LD BHA#7. No Recovery. M/U BHA#8 w/2 7/8"grapple in Overshot. RIH&work down over fish. POOH. 00:00 01:30 1.50 5,444 8,282 COMPZ RPCOM TRIP P Continue to trip in hole with BHA#7 to 8282'. Observed proper displacemnent. Page 12 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 03:00 1.50 8,282 8,282 COMPZ RPCOM CIRC P Circulate well to consistent 11.6 ppg. 4bpm @ 940 psi. SPRs taken. SIMOPS: Slip and Cut Drilling Line, 106'. SPRs: TVD 5945' Pump 1: 2 bpm =510 psi ; 3 bpm = 675 psi Pump 2: 2 bpm =500 psi ;3 bpm= 650 psi 03:00 03:30 0.50 8,282 8,282 COMPZ RPCOM SVRG P Service Top Drive. Grease Crown. 03:30 04:00 0.50 8,282 8,436 COMPZ RPCOM FISH P Establish parameters. Up Wt= 160k, Dn Wt=90k, 2 bpm 530 psi. Set down 30k on fish, pulled up and observed no overpull. Repeat attempts to catch fish with no visible success on the weight indicator. Turn pumps off and set down 30k, New Up Wt= 163k-165k. Top of fish at 8456'. 04:00 05:30 1.50 8,436 8,436 COMPZ RPCOM CIRC P Circulate Bottoms Up. 4 bpm/960 psi. Monitor well. 05:30 10:00 4.50 8,436 334 COMPZ RPCOM TRIP P Blow down Top drive. POOH&stand back 3 1/2" DP from 8436 to 334'.. Hole took _correct fill. 10:00 11:00 1.00 334 0 COMPZ RPCOM PULD P Break out& L/D BHA#7. Rack _back 4 3/4"DCs. No recovery. 11:00 11:30 0.50 0 0 COMPZ RPCOM SVRG P Service rig& Inspect Top Drive. 11:30 12:30 1.00 0 334 COMPZ RPCOM PULD P P/U BHA#8 as follows: Overshot w/ 2 7/8"Grapple, 2-String Magnets, Bumper Sub, Oil Jars, 9-4 3/4" DCs, Intensifier, XO. TL=333.57'. P/U &S/O Wt 42K. 12:30 17:00 4.50 334 8,439 COMPZ RPCOM TRIP P Trip in hole w/BHA#8 from 334 to _8439'. 17:00 19:00 2.00 8,439 8,456 COMPZ RPCOM FISH P Break circulation RIH slowly&tag fish @ 8456'.Work pipe down on fish. P/U w/no overpull. Did see guide go over fish. Attempted different RPMs, Pump Rates&S/O wts w/o success. P/U Wt- 160K, S/O Wt-95K, Rot Wt- 115K. Circulating 4 BPM @ 940 psi. Blow ,down Top Drive&monitor well. 19:00 00:00 5.00 8,456 334 COMPZ RPCOM TRIP P POOH w/BHA#8&stand back 3 1/2" DP. Hole took correct fill. 01/07/2015 L/D BHA#8. Recovered 4 pcs of metal in Overshot guide. M/U Wash pipe assy, BHA#8. RIH.Washover from 8456 to 8463'. CBU. POOH w/BHA#9. L/D BHA#9. M/U BHA#10 to dress off fish& RIH. Page 13 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 334 0 COMPZ RPCOM PULD P POOH&stand back DCs, Break out &L/D BHA#8. Recovered 4 pieces of iron, including the Collett and a piece of the blast joint&sleeve. Iron was wedged in overshot guide¬ in grapple. Clean off magnets& recovered 7#s of metal. Clear& clean floor. 02:00 02:30 0.50 0 0 COMPZ RPCOM SVRG P Service rig&Top Drive. 02:30 04:30 2.00 0 390 COMPZ RPCOM PULD P M/U BHA#9 as follows:6.125" FTBM Shoe,2 jts-5.75"Washpipe, Boot Basket, 2 String Magnets, Bump er Sub, Oil Jars, Pump Out Sub, 9-4 3/4" DCs,XO. TL= 389.69'. 04:30 10:30 6.00 390 8,432 COMPZ RPCOM TRIP P RIH w/BHA#9 on 3 1/2"DP from 389 to 8432'. Observedproper displacement. P/U Wt-160K, 5/0 Wt-95K, Rot Wt-115K. 10:30 12:30 2.00 8,432 8,463 COMPZ RPCOM WASH P Slowly con't to wash down over fish @ 8458'w/5K down wt. P/U& rotate.Wash&mill over fish from 8458 to 8463'. Observed tag on tope of fish at 8458'.We had to work the washover shoe down over the top of the fish,washing and milling junk down to 8463'. Pump 6 BPM @ 2000 psi,60 RPMs, Fre TQ 7-8K. TQ while milling 9-10.5K. Pumped 3 hole volumes while washing. Final Circ Press 1890 psi. No Fluid losses observed. 12:30 13:00 0.50 8,463 8,463 COMPZ RPCOM CIRC P Obtain SPRs: #1 2 BPM @ 600 psi 3 BPM @ 780 psi #2 2 BPM©600 psi 3 BPM @ 720 psi. Monitor well,well static. 13:00 17:30 4.50 8,463 390 COMPZ RPCOM TRIP P POOH w/BHA#9 &stand back 3 1/2"DP from 8863 to 390'. Hole took correct fill. 17:30 19:30 2.00 390 0 COMPZ RPCOM PULD P Break out&L/D BHA#9. Clean magnets&recovered 17.5#s of metal. Empty Boot Baskets& recovered 2#of metal. Inspect washpipe shoe, 100%wear. Pictures posted. Clear&clean rig floor. 19:30 21:00 1.50 0 340 COMPZ RPCOM PULD P M/U BHA#10 as follows:6 1/8"Junk Mill, 3-Boot Baskets, Bit Sub,2- String Magnets, Bumper Sub,m Oil Jars, Pump Out Sub, 9-4 3/4"DCs, XO. TL=340.04'. RIH w/same. 21:00 00:00 3.00 340 5,903 COMPZ RPCOM TRIP P RIH w/BHA#10 on 3 1/2"DP from 340 to 5903'.. 01/08/2015 Finish RIH w/BHA#10. Dress Top of Fish from 8458 to 8461'. CBU. POOH&L/D w/BHA#10. M/U BHA #11 &RIH&clean out inside of fish. CBU. POOH. Page 14 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 5,903 8,436 COMPZ RPCOM TRIP P Con't to RIH w/BHA#10 from 5903 to 8436'. Observed proper displacement. 01:30 03:30 2.00 8,436 8,461 COMPZ RPCOM MILL P Establish milling parameters. P/U Wt- 160K, S/0 Wt-95K, Rot Wt- 125K. RPMs 60-70, 4 BPM @ 1060 psi, Free TQ-7.7K, Rot TQ-8.9K, WOM 10-15K. Slowly RIH tag up @ 8458'.Mill from 8458 to 8461'. Milled 3'in— 1 hr.At bottoms up no metal seen on shaker. 03:30 05:00 1.50 8,461 8,451 COMPZ RPCOM CIRC P P/U 10'&Circulate bottoms up. 6 BPM @ 1620 psi. Blow down Top Drive&monitor well.Static. 05:00 06:00 1.00 8,451 8,451 COMPZ RPCOM SVRG P Service Rig&Top Drive. 06:00 07:00 1.00 8,451 6,491 COMPZ RPCOM TRIP P POOH w/BHA#10&stand back 3 1/2" DP from 8451 to 6491'. Hole took correct fill. 07:00 07:30 0.50 6,491 6,491 COMPZ RPCOM SFTY P Hold Well Control Drill.Well SI 48 sec,All on station in 103 sec. Hold AAR. 07:30 10:00 2.50 6,491 340 COMPZ RPCOM TRIP P Con't to POOH from 6491'&stand back DP. Hold took correct fill 10:00 11:00 1.00 340 0 COMPZ RPCOM PULD P Break out&L/D BHA#10. Clean magnets&Boot Baskets. Recovered 20#s metal. 11:00 12:00 1.00 0 344 COMPZ RPCOM PULD P M/U BHA#11 as follows: 2.25 Round Nose PRT mill, Pkr Mill, Triple Connect, 3 Boot Baskets, 2- Magnets, Bit Sub, Bumper Sub, Oil Jars, Pump Out Sub, 9-4 3/4" DCs, XO. TL=344.04'. RIH w/same. 12:00 16:00 4.00 344 8,387 COMPZ RPCOM TRIP P RIH w/BHA#11 from 344 to 8387'. 16:00 17:30 1.50 8,387 8,387 COMPZ RPCOM SLPC P Cut&slip 12 wraps(84')od drilling line. 17:30 18:00 0.50 8,387 8,387 COMPZ RPCOM SVRG P Service&inspect drawworks&Top Drive. 18:00 18:30 0.50 8,387 8,465 COMPZ RPCOM MILL P Slowly RIH from 8387&tag up @ 8461'. P/U Rotate&circulate down into top of tbg. Swallow entire PRT extension. Fan off top of tbg stump w/1K wt. Work up&down several times thru tbg top.Then enter several times w/o rotation.Tbg top 3.5' clean. P/U Wt- 165K, S/O Wt-95K, Rot Wt- 115K. Pump 2 BPM @ 675 psi. 62 RPMs,WOM- 1K. Free TQ- 8K. Rot TQ-8.4K. 18:30 19:30 1.00 8,465 8,455 COMPZ RPCOM CIRC P Circulate bottoms up. 6 BPM @ 2400 psi. Lost 15 bbls. P/U out of tbg 10'due to losses. After P/U out of tbg stub, no losses Finish circulation. Blow down Top Drive& monitor well. 19:30 00:00 4.50 8,455 344 COMPZ RPCOM TRIP P POOH w/BHA#11 from 8455 to 344'. Hole took correct fill. Page 15 of 33 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 31/09/2015 24 hr Summary L/D BHA#11. M/U BHA#12. RIH&spear fish. POOH&L/D recovered fish&BHA. RIH w/RCJB, BHA#13. 00:00 01:30 1.50 344 0 COMPZ RPCOM PULD P Break out&L/D BHA#11. Recovered 11.5#of metal from Magnets& 1/4 Cup of metal in Boot Baskets. 01:30 02:00 0.50 0 0 COMPZ RPCOM SVRG P Service Rig&Top Drive 02:00 03:00 1.00 0 314 COMPZ RPCOM PULD P M/U BHA#12 as follows: Spear w/ 2.339"Grapple,XO, Bumper Sub, Oil Jars, 9-4 3/4"DCs, Intensifier, Pump Out Sub,XO. TL=314.28'. 03:00 06:30 3.50 314 8,450 COMPZ RPCOM TRIP P RIH w/BHA#12 from 314 to 8450'. Observed proper displacement. 06:30 07:00 0.50 8,450 8,464 COMPZ RPCOM JAR P Establish fishing parameters&break circulation. Engage fish @ 8461.0. Swallow spear to 8464'. S/O w/15K. P/U to 175K&insure good grapple set. P/U&Work string.Jar on fish w/200K,210K,215K&pull to 240K. Jarred 10 times Fish pulled free. Pump 2 BPM @ 1860 psi. P/U wt- 160K, S/O Wt-90K.Work string to verify fish on, bu observing higher tgas, and PSI increase. 07:00 09:00 2.00 8,464 8,447 COMPZ RPCOM CIRC P P/U&circulate bottoms up. Pump 3 BPM @ 2820 psi.Attempt to S/O& set 15K @ 8447'. Blow down Top Drive. Monitor well.Well Static. 09:00 14:00 5.00 8,447 314 COMPZ RPCOM TRIP P POOH w/BHA#12&fish from 8447 to 314'. Hole took correct fill. 14:00 16:30 2.50 314 0 COMPZ RPCOM PULD P Break out&L/D BHA#12. L/D fish. Recovered Blast jt Pup Jt&seal assy.TL=32.26'. Observed 5-6 missing&broken Blast Rings on Blast jt. 16:30 17:30 1.00 0 0 COMPZ RPCOM RURD P Clear&clean Rig floor.Send tools out, haul tools to rig floor. 17:30 18:30 1.00 0 0 COMPZ RPCOM SVRG P Service, inspect&change oil in Top Drive. 18:30 20:30 2.00 0 346 COMPZ RPCOM PULD P P/U BHA#13 as follows:6.125" RCJB, PxP Sub, 3-Boot Baskets, Bit Sub,2-String Magnets, Bumper Sub, Oil Jars, Pump Out Sub, 9-4 3/4"DCs,XO. TL=346.02'. 20:30 00:00 3.50 346 6,970 COMPZ RPCOM TRIP P RIH w/BHA#13 from 346 to 6970'. 31/10/2015 Break circulation&attempt to clean out junk. Could not get below 8465'. POOH&L/D RCJB. P/U BHA#14, Double mill ass . RIH&begin cleaning out csg @ 8464'. 00:00 01:00 1.00 6,970 8,434 COMPZ RPCOM TRIP P Con't to RIH w/BHA#13 from 6970 to 8434'. P/U single DP. Page 16 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 02:30 1.50 8,434 8,465 COMPZ RPCOM CIRC P Drop baII.P/U last stand&Break circulation&slowly RIH.Tagged up @ 8465'. P/U&slowly rotate @ 10 RPMs&RIH.Work down to 8465'w/ 5K down wt. P/U&increase RPMs to 50&pump rate to 5 BPM @ 1750 pai,work string up&down,would not go deeper than 8465'. P/U Wt- 162K, S/O Wt-90K, Rot Wt- 155K, Free TQ-7K. Pump 4 BPM @ 1500 psi. Finish circulation. SPRs: #1 2 BPM @ 640 psi, 3 BPM @ 780 psi. #2 2 BPM @ 630 psi, 3 BPM @ 780 psi. 02:30 03:00 0.50 8,434 8,434 COMPZ RPCOM OWFF P L/D single DP. Blow down Top Drive. Monitor well.Well Static. 03:00 07:30 4.50 8,434 346 COMPZ RPCOM TRIP P POOH w/BHA#13&stand back DP. Hole took correct fill. 07:30 09:30 2.00 346 0 COMPZ RPCOM PULD P Strand back DCs. Break out&L/D BHA#13. 09:30 10:00 0.50 0 0 COMPZ RPCOM SVRG P Service&inspect Rig&Top Drive. 10:00 11:00 1.00 0 352 COMPZ RPCOM PULD P P/U BHA#14 as follows: Bit Sub,2- 6.151"Watermelon Mills, PxP Sub, 3-Boot Baskets, Bit Sub,2-String Magnets, Bumper Sub. Oil Jars, Pump Out Sub, 9-4 3/4"DCs,XO. TL=352.33'. RIH w/same. 11:00 14:00 3.00 352 5,368 COMPZ RPCOM TRIP P RIH w/BHA#14 from 352 to 5368'. 14:00 14:15 0.25 5,368 5,368 COMPZ RPCOM SFTY P Hold D-1 Drill; Kick while tripping. Well Secure in 30 sec,All personnel on station in 76 sec. Hold MR. 14:15 17:00 2.75 5,368 8,396 COMPZ RPCOM TRIP P Con't to RIH w/BHA#14 from 5368 to 8396'. 17:00 00:00 7.00 8,396 8,465 COMPZ RPCOM MILL P Establish milling parameters& slowly go in hole. Tag up @ 8464'. Mill from 8464 to 8465'. String torques up&stalls periodically. String pulled tight&had to jar to free. Con't to mill&work pipe.P/U Wt-160K, S/0 Wt-90K, Rot Wt- 115K.80 RPMs, Free Tq-8.5K.6 BPM @ 1900 psi. 01/11/2015 Con't to Mill&clean out csg to 8467'.Could not make add'I progress. CBU&POOH. LI/D BHA#14. Recovered 38#s of blast rings.Jet stack. RIH w/BHA#15, RCJB.Work RCJB down to 8469'. Circ&POOH. 00:00 04:30 4.50 8,465 8,467 COMPZ RPCOM MILL P Con't to mill.Appear to have some junk up around mills causing string to torq up. Pumped 35 bbls Hi-Vis Sweep. Nothing noted in returns. Con't to mill. Milled from 8465 to 8467'. Stopped making hole. Pump a 2nd 35 bbl sweep. P/U Wt-160K, S/O Wt-90K, Rot Wt- 115K. 80 RPMs, Free Tq-8.5K. 6 BPM @ 1900 psi. Page 17 of 33 Time Logs Date From To Dur S. Depth"E. Depth Phase Code Subcode T - Comment 04:30 05:00 0.50 8,467 8,467 COMPZ RPCOM OWFF P Blow Down Top Drive Monitor well. 05:00 10:00 5.00 8,467 352 COMPZ RPCOM TRIP P POOH w/BHA#1 from 8436 to 352'. Hole took correct fill. 10:00 11:30 1.50 352 0 COMPZ RPCOM PULD P Break out, inspect&UD BHA#‘14. Recovered 38#s of broken pieces of Blast Rings. Recovered 10#of metal from Dtich magnets. 11:30 12:30 1.00 0 0 COMPZ RPCOM WWWH P P/U Swizzle stick&function Rams &clean out stack. UD Swizzle stick. Clear floor. 12:30 13:00 0.50 0 0 COMPZ RPCOM SVRG P Service, inspect Top Drive&rig. 13:00 14:30 1.50 346 346 COMPZ RPCOM PULD P P/U BHA#15 as follows: RCJB w/ 6.00"Shoe, PxP Sub, 3-Boot Baskets, Bit Sub, 2-String Magnets, Bumper Sub, Oil Jars, Pump Out Sub, 9-4 3/4"DCs,XO. TL=345.98'. 14:30 19:30 5.00 346 8,446 COMPZ RPCOM TRIP P RIH w/BHA#15 on 3 1/2"DP from 346 to 8446'. P/U Wt- 160K, S/O Wt -90K, 19:30 20:00 0.50 8,446 8,469 COMPZ RPCOM CIRC P Establish circ parameters.. Pump 5 BPM @ 1700 psi. 20 RPMs, Free TQ-9K. P/U-160K, S/O Wt-90K, Rot Wt- 115K. Slowly RIH&work RCJB.Worked up&down 3 times From 8460 to 8469'. Stacked 1-2K down,allow to clear until wt fell off. Worked down to 8469'stacked 5K down&could not make add'I hole. 20:00 20:30 0.50 8,469 8,446 COMPZ RPCOM CIRC P P/U to 8446'. Finish circulating bottoms up. Blow down Top Drive& Monitor well.Well static. 20:30 00:00 3.50 8,446 2,503 COMPZ RPCOM TRIP P POOH w/BHA#15 from 8446'to 2503'. Hole took correct fill. 31/12/2015 Finish POOHw/BHA#15. &recovered 34#s of metal junk, Blast ring pcs, paraffin&sand.. RIH w/BHA#16, RCJB. Recovered 6#s of metal. Pull Wear Bushing. Test BOPE.to 250/3500 PSI. BOP test witnessing waived by Bob Noble w/AOGCC @ 0612 hrs, 1-12-2015 00:00 01:30 1.50 2,503 346 COMPZ RPCOM TRIP P Con't to POOH w/BHA#15. from 2503 to 346'. Hole took correct fill. 01:30 03:00 1.50 346 0 COMPZ RPCOM PULD P Stand back DCs. Break out&L/.D BHA#15. Clean magnets, Baskets &empty RCJB, Recovered: RCJB-12#s of metal, Blast Ring Pcs, parafin&sand. Boot Baskets-4 pcs of Blast Rings Magnets-22#s of metal 03:00 03:30 0.50 0 0 COMPZ RPCOM SVRG P Service Rig. Inspect&service Top Drive. 03:30 04:30 1.00 0 346 COMPZ RPCOM PULD P P/U BHA#16 as follows: RCJB w/ 6.128"Shoe, PxP Sub, 3-Boot Baskets, Bit Sub,2-String Magnets, Bumper Sub, Oil Jars, Pump Out Sub, 9-4 3/4"DCs,XO. TL=345.98'. Page 18 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 09:00 4.50 346 8,380 COMPZ RPCOM TRIP P RIH w/BHA#16 from 346 to 8380'. 09:00 09:30 0.50 8,380 8,482 COMPZ RPCOM CIRC P Establish string parameters. Slowly RIH&tag @ 8467'w/5K. P/U & Clear RCJB.Wash down&retag @ 8471'. P/U&retag @ 8471'Set w/ 8K&dropped thru. Con't to wash down to top of Pkr @ 8488'. set down w/5K&confirm. P/U&rotate down w/8K&tag Pkr @ 8488'.. Repeat 3 times. increased wt to 10K no further progress. No Torque increase. P/U Wt-160K, S/0 Wt- 90K, Riot Wt- 115K. Pumped 5 BPM @ 1700 psi. 20 RPMs. Free TQ-8K. P/U 5'. 09:30 11:00 1.50 8,482 8,482 COMPZ RPCOM CIRC P Ccirculate bottoms up 5 BPM @ 1700 psi.. Blow down Top Drive& monitor well. Pump 10 bbl 12.9 ppg dry job. 11:00 15:30 4.50 8,482 346 COMPZ RPCOM TRIP P POOH w/BHA#16 from 8482'to 346'. Hole took correct fill. 15:30 17:00 1.50 346 0 COMPZ RPCOM PULD P Stand back DCs. Break out&L/D BHA#16. Recovered 6#s of metal/Blastring pcs in RCJB. 17:00 18:00 1.00 0 0 COMPZ RPCOM RURD P P/U running tool &pull Wear Bushing. L/D same. 18:00 19:00 1.00 0 0 COMPZ RPCOM WWWH P P/U Swizzle stick&jet stack. Function Rams. 19:00 20:30 1.50 0 0 COMPZ WHDBO RURD P Test gas alarms. R/U test jts. R/U testing equip. 20:30 00:00 3.50 0 0 COMPZ WHDBO BOPE P Perform weekly BOPE test. LP 250 psi, HP 3500 psi. Tested w/3 1/2"& 4 1/2"test jts.tested Blind rams, 2" Demco kill, Outer test spool valve, Upper IBOP, HCR Kill valve, Inner Test spool, Lower IBOP, Upper Pipe Rams, Manual Kill, Dart valve, 3 1/2" EUE TIW, Super Choke, Manual Adj. Choke,Lower Pipe Rams, Choke Manifold Valves#1,#2,#3,#4,#5, #6,#7,#8,#9,#10,#11,#12,#13, #14,#15,#16. Tested Gas Alarms. Had no Failures. BOPE test witnessing waived by Bob Noble w/AOGCC @ 0612 hrs, 1-12-2015. 01/13/2015 Finish Testing BOPE. Install Wear Bushing. M/U BHA#17, RCJB. RIH w/same. Cut&slip Drilling line.Work RCJB to 8488' Pkr depth. POOH. Recovered 14.5#s junk.. M/U BHA#18, RCJB. RIH. Page 19 of 33 7 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 03:00 3.00 0 0 COMPZ WHDBO BOPE P Con't performing weekly BOPE test. LP 250 psi, HP 3500 psi. Tested w/ 3 1/2"&4 1/2"test jts.Test Annular, Manual Kill, P/U 4 1/2" Acme Jt&test Upper Pipe Rams, HT-38 TIW,Annular, HCR Choke, HT-38 TIW, Manual Choke, Lower Pipe Rams, Tested Koomey. Had no Failures. BOPE test witnessing waived by Bob Noble w/AOGCC @ 0612 hrs, 1-12-2015. 03:00 04:00 1.00 0 0 COMPZ WHDBO RURD P L/D test jts. Blow down lines. R/D test equip. Set Wear Bushing. 04:00 04:30 0.50 0 0 COMPZ RPCOM SVRG P Service&Inspect rig&Top Drive. 04:30 05:30 1.00 0 346 COMPZ RPCOM PULD P P/U BHA#17 as follows: RCJB w/ 5.75"Shoe, PxP Sub, 3-Boot Baskets, Bit Sub, 2-String Magnets, Bumper Sub, Oil Jars, Pump Out Sub, 9-4 3/4"DCs,XO. TL=345.87'. 05:30 07:15 1.75 346 2,240 COMPZ RPCOM TRIP P RIH w/BHA#17 from 346 to 2,240-ft. 07:15 07:30 0.25 2,240 2,240 COMPZ RPCOM SFTY P BOP Drill...Kick While Tripping. Well secured in 40 seconds. .After action review. 07:30 11:00 3.50 2,240 8,390 COMPZ RPCOM TRIP P Continue to trip in with BHA#17 on 3 1/2"Drill Pipe from the Derrick to 8,390-ft. Up weight= 160K. Down weight=90K. 11:00 12:30 1.50 8,390 8,390 COMPZ RPCOM SLPC P Slip and cut Drilling Line(104-ft). Inspect dead man brass. Calibrate block height. 12:30 13:00 0.50 8,390 8,390 COMPZ RPCOM SVRG P Service Top Drive. Grease Crown. 13:00 14:00 1.00 8,390 8,488 COMPZ RPCOM CIRC P Continue in hole with BHA#17, RCJB. Bring Pump on line at 5.0 bpm/1,700 psi. Rotate at 15 rpm's. Wash from 8,390-ft down to 8,488-ft (top of the Packer). Repeat x 3. 14:00 15:00 1.00 8,488 8,483 COMPZ RPCOM CIRC P Pick up off the Packer. Circulate and condition well at 5.0 bpm/1,700 psi. 15:00 16:00 1.00 8,483 8,359 COMPZ RPCOM OWFF P Set back one stand of 3 1/2"Drill Pipe. Lay down one single Drill Pipe. Monitor Well static x 30 minutes. Pump dry job. Hole Took correct fill. 16:00 20:00 4.00 8,359 346 COMPZ RPCOM TRIP P Trip out w/BHA#17. Hole took correct fill. Page 20 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 21:30 1.50 346 0 COMPZ RPCOM PULD P Stand Back DCs, Break out&L/D BHA#17. Recovered: Pcs of Blast Rings&metal. RCJB-3#s,15 pcs greater than 1 square inch+several smaller pcs of metal&Blast Rings Boot Baskets- 1/2#of small Blast ring pcs. _ Magnets- 11 #s of metal. 21:30 22:00 0.50 0 0 COMPZ RPCOM SVRG P Service& Inspect Top Drive. 22:00 23:00 1.00 0 346 COMPZ RPCOM PULD P P/U BHA#18 as follows: RCJB w/ 5.75"Shoe, PxP Sub, 3-Boot Baskets, Bit Sub, 2-String Magnets, Bumper Sub, Oil Jars, Pump Out Sub, 9-4 3/4"DCs,XO. TL=345.87'. 23:00 00:00 1.00 346 2,005 COMPZ RPCOM TRIP P RIH w/BHA#18 on 3 1/2"DP from 346 to 2005'. 01/14/2015 Work RCJB on top of pkr©8488'. CBU. POOH. P/U Pkr mill. RIH&mill Pkr. Push to 8545'. Circ&sweep hole. 00:00 01:45 1.75 2,005 5,172 COMPZ RPCOM TRIP P Con't to RIH w/BHA#18 on 3 1/2" DP from 2005 to 5172.'. 01:45 02:00 0.25 8,445 8,488 COMPZ RPCOM SFTY P Hold D-1 Drill-Kick while tripping drill. Well secure in 49 sec.All hands on station 82 sec. Held AAR. 02:00 03:30 1.50 5,172 8,445 COMPZ RPCOM TRIP P Cont to RIH w/BHA#18 from 5172 to 8445'. 03:30 04:00 0.50 8,445 8,488 COMPZ RPCOM CIRC P Con't to slowly RIH with BHA#18, RCJB. Bring Pump on line at 5.0 bpm/1,800 psi. Rotate at 20 rpm's. Wash from 8,445-ft down to 8,488-ft (top of the Packer). Repeat 5 times w/5K down wt. P/U Wt- 160K, S/O wt-90K, Rot wt- 115K.. Free Tq- 8K, Max TQ-9.5K. 04:00 05:00 1.00 8,488 8,478 COMPZ RPCOM CIRC P P/U off Pkr&finish circulating bottoms up, 7BPM ©2900 psi. Blow down Top Drive&Monitor well.Well static. 05:00 08:30 3.50 8,478 346 COMPZ RPCOM TRIP P POOH w/BHA#18 from 8478', standing back Drill Plpe.. Took correct fill. 08:30 10:00 1.50 346 0 COMPZ RPCOM PULD P Set back Drill Collars. Clean String Magnets. Recovered the usual expected metal particles. Empty the RCJB. Recovered several pieces of metal...no carbide pieces. Dump Boot Baskets...clean. Lay down BHA#18. 10:00 11:00 1.00 0 0 COMPZ RPCOM SVRG P Inspect Top Drive. Clear and clean Floor. Prep for the next BHA. 11:00 12:00 1.00 0 318 COMPZ RPCOM PULD P P/U BHA#19 as follows:6 1/8"x 2 3/8"Packer Mill, 3-Boot Baskets, Bit Sub, Bumper Sub, Oil Jars, Pump Out Sub, 9-4 3/4"DCs,XO. TL=317.33'. RIH w/same. �.... .__._ Page 21 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 16:00 4.00 318 8,488 COMPZ RPCOM TRIP P RIH w/BHA#19 from 318 to 8488'. 16:00 23:30 7.50 8,488 8,545 COMPZ RPCOM MILL P Break circulation&slowly RIH&tag up on Pkr @ 8488'. Begin milling Pkr from 8488 to 8,490'. P/U Wt- 160K, S/O Wt-90K, Rot Wt- 115K.Pump 4 BPM @ 1000 psi. RPMs-80/100, WOM-5/15K. Free TO 7K, On Bottom TO 8/10K. Occasionally Dry drill, vary WOM, pump rate& RPMs while milling.After making 2' Pkr started to move. Con't milling&push Pkr to 8545'. Could go no further w/ 15K down wt. Pkr was dragging when P/U. Had very small amount of gas to surf after milling Pkr. SPRs: #1 2 BPM @ 660 psi, 3 BPM @ 770 psi #2 2 BPM @ 640 psi, 3 BPM @ 770 psi 23:30 00:00 0.50 8,545 8,543 COMPZ RPCOM CIRC P P/U 3'&circulate well. Pumped 35 bbl Hi-Vis Sweep. Pump 7 BPM @ 2650 psi. 01/15/2015 Finish circ. Monitor well. POOH w/BHA#19. RIH w/BHA#20& fish Pkr. POOH& L/D fish. 00:00 00:30 0.50 8,543 8,543 COMPZ RPCOM CIRC P Cont to circulate well. Pumped 35 bbl Hi-Vis Sweep. Pump 7 BPM @ 2650 psi. 00:30 01:30 1.00 8,543 8,543 COMPZ RPCOM OWFF P S/D& monitor well.Well Static. Pump Slug. Blow down Top Drive. 01:30 06:00 4.50 8,543 318 COMPZ RPCOM TRIP P POOH w/BHA#19, standing back 3 1/2" Drill Pipe in the Derrick. 06:00 07:30 1.50 318 0 COMPZ RPCOM PULD P Set back 4 3/4" Drill Collars. Lay down Packer Mill...Mill face=junk. Pilot Mill still in gauge. Recovered —7 lbs of mill cuttings and small metal pieces in the Boot Baskets. Clear floor. 07:30 08:00 0.50 0 0 COMPZ RPCOM SVRG P Service and inspect Top Drive. 08:00 09:00 1.00 0 316 COMPZ RPCOM PULD P Make-up BHA#20 as follows: ITCO Spear w/3.198"Grapple, Spear Extension,XO, Bumper Sub, Oil Jar, 9 ea 4 3/4"Drill Collars, Intensifier Pump-Out-Sub,XO. 09:00 11:45 2.75 316 8,485 COMPZ RPCOM TRIP P Trip in BHA#20 with 3 1/2" Drill Pipe from the Derrick to 8,485-ft. Up Weight= 150K. Down weight=95K. 11:45 12:15 0.50 8,485 8,576 COMPZ RPCOM CIRC P Bring Pump on line at 1.0 bpm/660 psi. Wash down and tag the top of the Fish at 8,551-ft dpmd. Continue to push the fish down to 8,576-ft dpmd. End Pump. Blow down Top Drive. Page 22 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:15 14:00 1.75 8,576 8,576 COMPZ RPCOM SFTY P Well Control Drill. Shut in and secure Well. Suspend operations so the Crew and invited guests can attend the one year without No Recordable injuries Safety Stand-Down Lunch. 14:00 14:30 0.50 8,576 8,588 COMPZ RPCOM FISH P Resume operations. Push Fish down hole until the Packer hung up again at 8,588-ft. Stack 10K. Pick up and observe 4K over pull. Set back down and stack 20K. Pick up and observe slight overpull once again. 14:30 14:45 0.25 8,588 8,358 COMPZ RPCOM TRIP P Trip out with BHA#20. Observe fish hanging up in Casing Collar(30K overpull to pass-by). Continue to trip out to 8,358-ft. 14:45 16:00 1.25 8,358 8,358 COMPZ RPCOM CIRC P Stop with Fish above the top perforation. Circulation and condition hole at 4.5 bpm/2,390 psi. Monitor Well static. Pump dry job. 16:00 22:00 6.00 8,358 316 COMPZ RPCOM TRIP P Continue to trip out with BHA#20, standing back 3 1/2"Drill Pipe in the Derrick. 22:00 23:30 1.50 316 0 COMPZ RPCOM PULD P Stand back DCs. Break out&L/D BHA#20. Recovered Remaining Fish consisting of Pkr, Mill Out Extension,XO,Tbg Pup, "D"Nipple, Tbg Pup&WLEG.TL= 11.53'. 23:30 00:00 0.50 0 0 COMPZ RPCOM SFTY P Suspend operation for Crew's Safety Stand-Down Lunch. 31/16/2015 RIH w/BHA#21 &clean out to 8745'. POOH&L/D BHA. Pull Wear Bushing. Jet out stack. Re-Install Wear Bushing 00:00 00:30 0.50 0 0 COMPZ RPCOM SFTY P Suspend operation for Crew's 1 year Safety Stand-Down Lunch. 00:30 01:00 0.50 0 0 COMPZ RPCOM SVRG P Service Rig&Inspect Top Drive. 01:00 03:00 2.00 0 359 COMPZ WELLPF PULD P P/U BHA#21 as follows: Bladed Junk Mill, 3-Boot Baskets, Bit Sub, 2-String Mills, Csg Scraper, 2- String Magnets, Bumper Sub, Oil Jars, Pump Out Sub,9-4 3/4"DCs, XO. TL=359.04'. 03:00 08:30 5.50 359 8,496 COMPZ WELLPF TRIP P RIH w/BHA#21 to 8,496-ft. Establish parameters as follows: Up weight= 160K. Down weight=95K. RT weight= 115K. Free Torque= '9K ft/lbs. Pump=6.0 bpm/2,100 psi. Page 23 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 11:45 3.25 8,496 8,746 COMPZ WELLPF WASH P Continue in with the Clean-Out Assembly. Set down at 8,591-ft dpmd. Continue milling on debris and occasionally hanging up on junk while going through the lower perforated section. Continue rotating and washing with little problem. Returns=some sand and a few tiny pieces of rubber. Once the BHA cleared the bottom perforations,end rotation. Continue to wash down to the 7"Float collar at 8,746-ft dpmd. Rotate slowly on top of the Float Collar. Made no further progress. Short trip.Tagged up at the same spot. 11:45 15:00 3.25 8,743 8,746 COMPZ WELLPF CIRC P Pick-up 3-ft off bottom. Pump a 40 bbl Hi-Vis Sweep and chase back to surface at 6.0 bpm/2,000 psi. until clean. Returns=lots of Carb-O-Lite Frac Sand. Spot a 15 bbl heavy/gell Perf Pill. 15:00 19:45 4.75 8,746 359 COMPZ WELLPF TRIP P Trip out with BHA#21, Standing the 3 1/2"Drill Pipe in the derrick. Hole took correct fill. 19:45 20:00 0.25 359 359 COMPZ WELLPF SFTY P Hold D-1, Kick While Tripping Drill. Well SI 28 sec,All personnel in position in 76 sec. Held AAR. 20:00 22:00 2.00 359 0 COMPZ WELLPF PULD P Break out&UD DCs&BHA#21. Mill had 25%wear. Recovered 5#s of metal in Boot Baskets&15#s of metal from Magnets. 22:00 23:00 1.00 0 0 COMPZ WELLPF RURD P Clear&clean Rig Floor. P/U running tool&pull Wear bushing.. 23:00 00:00 1.00 0 0 COMPZ WELLPF WWWH P P/U Swizzle stick. Jet BOP stack& cycle Rams. Re-install Wear Bushing. 01/17/2015 R/U&run 4 1/2"Scab Liner. R/U E-line&Space out liner. unable to correlate liner on depth, no enough rathole. Cut&slip drilling line. POOH w/4 1/2"liner. 00:00 00:30 0.50 0 0 COMPZ WELLPF SVRG P Service rig&Inspect Top Drive. 00:30 02:00 1.50 0 0 COMPZ RPCOM RURD P R/U to run 4 1/2"Scab Liner. 02:00 02:30 0.50 0 0 COMPZ RPCOM SFTY P Hold PJSM&review liner running procedure. 02:30 04:30 2.00 0 442 COMPZ RPCOM PUTB P M/U 4 1/2"Scab liner as per program &RIH w/same. 04:30 06:00 1.50 442 828 COMPZ RPCOM RUNL P Run 2 stands,then pump thru liner. Blow down Top Drive. Con't RIH w/4 1/2"Scab Liner on 3 1/2"DP from 442 to 828'. 06:00 14:15 8.25 828 8,747 COMPZ RPCOM RUNL P Continue to run the 4 1/2"Scab Liner on 3 1/2"Drill Pipe. Stop every 5 stands to fill the Drill Pipe with 11.6 lb/gal Drilling Mud. Tagged up at 8,747. Up Weight= 155K. Down Weight=90K. Page 24 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 14:30 0.25 8,747 8,747 COMPZ RPCOM CIRC P Circulate at 2.0 bpm/780 psi. Did not make any hole. Have to assume that the tag was the at the expected Float Collar(no fill). 14:30 18:00 3.50 8,747 8,747 COMPZ RPCOM ELOG P Spot E-Line Unit. Space out Drill Pipe for working height at the Rig Floor. Bring E-Line tools to the Floor.R/U equip. 18:00 20:00 2.00 8,747 8,747 COMPZ RPCOM ELOG P RIH w/E-line Correlation Log&Tie-in Liner to depth on 07/30/1984 CBL Log. Discuss correlation w/engineer for space out. Could not go deeper to set liner on acceptable depth. Elect to POOH&re-configure liner running order per engineer. 20:00 20:30 0.50 8,747 8,747 COMPZ RPCOM ELOG T POOH W/Correlation log. 20:30 21:30 1.00 8,747 8,747 COMPZ RPCOM ELOG T R/D E-line equip. 21:30 23:00 1.50 8,747 8,747 COMPZ RPCOM SLPC T Slip&cut 95'of drilling line. Service rig&Top Drive.Adjust brakes. 23:00 00:00 1.00 8,747 8,277 COMPZ RPCOM TRIP T Trip out of hole w/DP&4 1/2"liner from 8745 to 8277'. 01/18/2015 POOH w/liner. L/D 1 jt of 4 1/2"csg below wndow jt. Re-Run liner&Tie in depth. Space out liner&M/U cmting head. Circ well. 00:00 04:30 4.50 8,277 534 COMPZ RPCOM TRIP T Con't to POOH w/stands of DP&4 1/2"scab liner from 8277 to 442'. 04:30 05:00 0.50 442 442 COMPZ RPCOM RURD T Moinitor well. R/U casing tongs& equip to L/D liner. 05:00 07:30 2.50 442 175 COMPZ RPCOM PULL T POOH&L/D 4 1/2"liner and the Hydraulic Setting Tool assembly. Kick out the first 4 1/2"Liner Joint (43.03')under the Window Kickoff Joint. 07:30 08:00 0.50 175 430 COMPZ RPCOM PUTB T Pick the 4 1/2" Liner Assembly as per the revised running order. Pick up the Hydraulic Setting Tool assembly(with a new Liner Wiper Plug installed). 08:00 08:15 0.25 430 525 COMPZ RPEQP1 RUNL T Run the 4 1/2"Liner Assembly in on 1 stand of 3 1/2"Drill Pipe. 08:15 08:45 0.50 525 525 COMPZ RPCOM RURD T Rig down GBR liner handling equipment. Ready floor. 08:45 09:00 0.25 525 525 COMPZ RPCOM CIRC T Bring pump on line at 4.0 bpm/160 psi x 10 bbls to confirm circulations through the Hydraulic Setting Tool/4 1/2"Line assembly. Good. 09:00 16:30 7.50 525 8,735 COMPZ RPCOM RUNL T Trip the 4 1/2"Liner Assembly in on 3 1/2"Drill Pipe. Stop to fill the Drill Pipe every 5 stands. Continue in to 8,747-ft...Float Collar. Up Weight= 115K. Down Weight=90K. Pick-up to 8,735-ft 16:30 17:00 0.50 8,735 8,735 COMPZ RPCOM SVRG T Service Top Drive SIMOPS: HES E-Line Unit arive on location. 17:00 19:00 2.00 8,735 8,735 COMPZ RPCOM ELOG T Spot E-Line Unit. R/U E-Line equip. Page 25 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 21:00 2.00 8,716 8,716 COMPZ RPCOM ELOG T RIH w/Correlation Log.Tie into the CBL dated 07/30/1984. Space out liner. Calc. P/U 20'. Pkr @ 8316.95'. Window Jt from 8501.00 to 8543.73'. Depth of Float shoe at 8,716-ft. POOH w/Logging tools. 21:00 21:30 0.50 8,716 8,716 COMPZ RPCOM ELOG P R/D E-Line equip. 21:30 22:30 1.00 8,716 8,716 COMPZ RPCOM RURD P P/U&L/D 1 jt DP. Install 15' DP pup &Cementing head. Space out liner as per calculations. 22:30 00:00 1.50 8,716 8,716 COMPZ RPCOM CIRC P Circulate well. Pump 3 BPM @ 925 psi. SIMOPS: R/U ccementers. 01/19/2015 Circulate&R/U cementers. Cement liner.WOC.Attempt to test csg..no test.Wait on Mud. 00:00 02:30 2.50 8,716 8,716 COMPZ RPCOM CIRC P Circulate well. Pump 3 BPM @ 925 psi. SIMOPS: R/U ccementers. 02:30 03:00 0.50 8,716 8,716 COMPZ RPCOM SFTY P Hold PJSM w/all hands. Review Cementing plan&assign tasks to personnel. 03:00 06:00 3.00 8,716 8,716 COMPZ RPCOM CMNT P Pressure test lines 4500 psi. Cement well as follows: Pump 15 bbls of Mud Push II Followed by 23 bbls of Class "G" 15.8 lb/gal cement. Flush lines. Drop Dart&pump 5 bbls fresh wtr.Displace w/53.5 bbls of mud. Total displacement=58.5 bbls. Pressure up&bump plug with 2500 psi. Plug down at 05:46 hrs. S/O w/ 45K&set slips. Confirm liner hanger set. Pressure up to 4000 psi&set ZXP packer. Hold for 10 min. Bleed off pressure&check floats. Floats holding. Rig down Cementing Head. 06:00 07:00 1.00 8,316 8,316 COMPZ RPCOM PACK P Note: depth reference is now the top of the ZXP Line Top Packer....Slack off Running Tool and rotate x 20 turns. Release Running tool. Pressure up to 1,100 psi. Pick-up —6-ft. Observe pressure drop. Bring Pump on line at 3.0 bpm. Observe returns to the Pits. Continue to pick-up. Circulate—20 bbls at 3.0 bpm. Slow down pump rate and slack off to 40K and confirm"Dogs" are set. Good. SIMOPS: Rig down and release Cementers. Page 26 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 10:00 3.00 8,316 8,316 COMPZ RPCOM CIRC P Bring Pump on line at 4.6 bpm/1,326 psi with 11.6 lb/gal Mud and circulate out excess cement from above the Liner Top Packer to the Cuttings Bin. Pumped 300 bbls. Estimate Cement returned 9 bbls. Clear Running Tool from the Liner Top Packer. Increase pump rate and circulate the well clean at 8.0 bpm/2,575 psi. Reciprocate drill pipe while pumping. Pumped a total of 540 bbls during the final well clean out. Total pumped during the entire well clean-out=840 bbls. 10:00 14:00 4.00 8,316 8,316 COMPZ RPCOM WOC P While waiting on cement. Blow down Top Drive. Clean Mud Pits and under the Shakers, Perform Top Drive inspection. Clean Rig Floor. Ready test equipment, Manage Pipe Shed to lay down 3 1/2"Drill Pipe. Prep to displace Drilling Mud with Sea Water. 14:00 16:30 2.50 8,316 8,316 COMPZ RPCOM PRTS X Attempt to establish circulation, unable to. Check/re-check fluid patch on surface. Drill Pipe appears plugged off(?). R/U and attempt to test down the back side. Close Pipe Rams and PT Liner top to 250 psi, good. Attempt to pressure test to 3000 psi; took more than calculated fluid to attain 3000 psi. Pressure bled off to 1100 psi and stabilized. Install valve on the OA and attempt to pressure test again. Pumped 6 bbls to attain 3000 psi. Pressure drop back off to 1100 psi and stabilize. OA pressure did not change(100 psi). 16:30 22:00 5.50 8,316 8,316 COMPZ RPCOM OTHR X Discuss options with town. Order out test packer. Wait on drilling _fluid. 22:00 22:15 0.25 8,316 8,316 COMPZ RPCOM SFTY X Hold D-1 Drill Well secured in 29 sec. all personnel on station in 81 sec. Hold AAR. 22:15 23:30 1.25 8,316 8,316 COMPZ RPCOM COND X Take on mud from MI plant&B-Pad blend mud&check properties. Wt- 11.6 ppg. 23:30 00:00 0.50 8,316 8,222 COMPZ RPCOM CIRC X Pull stand#87. R/U circulating head. Break circulation. Pump 3 BPM @ 800 psi. Drill string not plugged. Fluid level dropped—4"in 30 min. 01/20/2015 Circulate and condition the well. TOOH with liner setting tool both the pusher tool and dog sub were sheared. Perform weekly BOPE test to 250/3500 psi with 3-1/2"test joint, test witnessed by AOGCC field inspector L. Grimaldi. TIH with Retrievamatic test packer to determine the depth of the leak. At midnight 7"casing down to 7861'tested to 3000 psi. Page 27 of 33 Time Logs Date From To Dur S. Depth E. Depth:Phase `Code Subcode T Comment 00:00 01:00 1.00 8,222 8,222 COMPZ RPCOM CIRC X Finish circulating well. &conditioning mud. 3 BPM @ 800 psi. MW-11.6 ppg. Monitor well.Well static. 01:00 05:30 4.50 8,222 42 COMPZ RPCOM TRIP X Pump"dry job". Blow down lines and the Top Drive. Trip out with 3 1/2 Drill Pipe, standing back in the Derrick. 05:30 06:00 0.50 42 0 COMPZ RPCOM PULD X Lay down the Baker Hydraulic Setting Tool. Observe the Dog Sub sheared and the Pusher Tool, sheared. Both positive signs that the ZXP Top Liner Packer is set...! 06:00 07:00 1.00 0 0 COMPZ WHDBO RURD X Clean Rig Floor. Rig up test equipment for the weekly BOPE Test. Perform"shell test". 07:00 10:30 3.50 0 0 COMPZ WHDBO OTHR T Wait on AOGCC Field Inspector(as per his request)to arrive on location for witnessing the test. 10:30 15:00 4.50 0 0 COMPZ WHDBO BOPE X AOGCC Field Inspector arrived on location. Begin the weekly BOPE test at 250/3,500 psi as per ConocoPhillips/AOGCC requirements with a 3 1/2"Test Joint. Tested Gas Alarms and PVTs as directed by the Inspector. Perform the Koomey draw down test. All good. Pressure test recorded on chart. All tests were witnessed by AOGCC Field Inspector L. Grimaldi, Co Man, and Tool Pusher. 15:00 16:00 1.00 0 0 COMPZ WHDBO RURD X RD BOPE testing equipment and install wear ring 16:00 16:30 0.50 0 0 COMPZ RPCOM PULD X PU and MU BHA#22-Model"L" Retrievamatic test packer with sleeve pack-off. 16:30 19:00 2.50 0 4,170 COMPZ RPCOM TRIP X TIH with BHA#22 to 4170', PU= 85K, and SO=67 K 19:00 19:45 0.75 4,170 4,170 COMPZ RPCOM PRTS X Set Retrievamatic test packer per Baker rep at 4170'(center of element =COE). Pressure up on the DP but unable to get pressure past 2100 psi. Bleed DP to 0 psi. Pressure up on the IA to 3000 psi(good test). Bleed IA to 0 psi, release the test packer, and blow down the TD. 19:45 20:45 1.00 4,170 6,253 COMPZ RPCOM TRIP X Continue to TIH from 4170'to 6253', PU= 120K,and SO=73 K 20:45 21:30 0.75 6,253 6,253 COMPZ RPCOM PRTS X Set Retrievamatic test packer per Baker rep at 6253'(COE). Pressure up on the DP but unable to get pressure past 1900 psi. Bleed DP to 0 psi. Pressure up on the IA to 3000 psi(good test). Bleed IA to 0 psi, release the test packer, and blow down the TD. 21:30 22:00 0.50 6,253 7,284 COMPZ RPCOM TRIP X Continue to TIH from 6253'to 7284', PU= 135K, and SO=78 K Page 28 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 22:30 0.50 7,284 7,284 COMPZ RPCOM PRTS X 'Set Retrievamatic test packer per Baker rep at 7284'(COE). Pressure up on the DP but unable to get pressure past 1900 psi. Bleed DP to 0 psi. Pressure up on the IA to 3000 psi(good test). Bleed IA to 0 psi, release the test packer, and blow down the TD. 22:30 23:00 0.50 7,284 7,861 COMPZ RPCOM TRIP X Continue to TIH from 7284'to 7861, PU= 145K, and SO=85 K 23:00 00:00 1.00 7,861 7,861 COMPZ RPCOM PRTS X Set Retrievamatic test packer per Baker rep at 7861'(COE). Pressure up on the DP but unable to get pressure past 1800 psi. Bleed DP to 0 psi. Pressure up on the IA to 3000 psi and seeing slow leak on the IA with response on the DP of an equal pressure increase. Release test packer and reset per Baker rep at 7858'(COE). Pressure up on the IA to 3000 psi(good test). Bleed IA to 0 psi, release the test packer, and blow down the TD. 31/21/2015 Continue to determine location of 7"casing leak with test packer and leak found between 8297'and the top of the liner top packer at 8319'. TOOH with test packer, lay down test packer, and wait on orders from town. Wait for third party equipment to arrive. MU and RIH with FHL/PBR isolation packer assembly on drill pipe to 7150'at midnight. 00:00 00:45 0.75 7,861 8,297 COMPZ RPCOM TRIP X Continue to TIH from 7861'to 8297, PU= 155K, and SO=87 K 00:45 01:45 1.00 8,297 8,297 COMPZ RPCOM PRTS X Set Retrievamatic test packer per Baker rep at 8297'(COE). Pressure up on the DP but unable to get pressure past 1800 psi. Bleed DP to 0 psi. Pressure up on the IA to 3000 psi(good test). Bleed IA to 0 psi, release the test packer, and warm up the TD. 01:45 03:00 1.25 8,297 8,329 COMPZ RPCOM PRTS X SO,sting seals into liner tie back sleeve, and no-go on top of liner at 8319'with 10K down. Pressure up on the DP to 3000 psi(good test). Bleed DP to 0 psi. Set 50K down to ensure ZXP liner top packer is set. Pressure up on the IA but unable to get pressure past 1700 psi. Bleed IA to 0 psi. Leak is between 8297'- 8319'. 03:00 03:30 0.50 8,329 8,329 COMPZ RPCOM CIRC X Pump dry job. Blown down lines and TD. 03:30 07:00 3.50 8,329 0 COMPZ RPCOM TRIP X TOOH with BHA#22-Model"L" Retrievamatic test packer with sleeve pack-off from 8329'to surface standing back DP. 07:00 07:30 0.50 0 0 COMPZ RPCOM PULD X Lay down BHA#22. 07:30 08:00 0.50 0 0 COMPZ RPCOM SVRG X Daily top drive inspection. Page 29 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 12:00 4.00 0 0 COMPZ RPCOM OTHR X Waiting on orders from town. SIMOPS: Clean and service rig equipment 12:00 20:30 8.50 0 0 COMPZ RPCOM OTHR X Waiting for third party equipment. SIMOPS: Clean and service rig equipment 20:30 21:00 0.50 0 0 COMPZ RPCOM SVRG X Daily top drive inspection. 21:00 21:30 0.50 0 0 COMPZ RPCOM RURD X RU GBR tubing running equipment. 21:30 21:45 0.25 0 0 COMPZ RPCOM SFTY X PJSM for running PBR/FHL packer assembly on DP 21:45 22:15 0.50 0 161 COMPZ RPCOM PUTB X PU and MU 3-1/2"tubing seal assembly, nipple assembly, and FHL/PBR assembly 22:15 22:30 0.25 161 161 COMPZ RPCOM RURD X RD GBR tubing running equipment and RU DP running equipment. 22:30 00:00 1.50 161 7,150 COMPZ RPCOM TRIP X TIH with FHL/PBR assembly to 7150' at midnight. 01/22/2015 Continued to TIH with FHL/PBR assembly from 7150'to just above the liner top packer at 8317'and swapped the well over from 11.6 ppg mud to 8.6 ppg seawater. Determined the space out and spotted 10 bbls 8.6 ppg corrosion inhibited pill around the packer assembly. Sting seals into the SBE, pressure up to 2600 psi to set the FHL packer, and PT the IA to 3000 psi for 15 minutes(good test). Shear out of PBR and POOH laying down DP. RIH with 3-1/2"9.3#EUE 8rd Mod tubing completion per detail to 4649'at midnight. 00:00 00:30 0.50 7,150 8,315 COMPZ RPCOM TRIP X Continue to TIH with FHUPBR assembly from 7150'to just above the top of liner top packer at 8317'. 00:30 01:00 0.50 8,315 8,315 COMPZ RPCOM RURD X RU to circulate well over to 8.6 ppg seawater. PJSM. 01:00 04:30 3.50 8,315 8,315 COMPZ RPCOM CIRC X Pump 40 bbl 12.6 ppg high vis mud spacer at 3 BPM=780 psi(ICP) followed by 8.6 ppg seawater keeping pump pressure below 1100 psi. Circulate 8.6 ppg seawater until returns are clean 433 bbls. FCP= 350 psi at 3 BPM 04:30 05:00 0.50 8,315 8,370 COMPZ RPCOM HOSO X Space out packer assembly. Lay down working joint, PU 1 stand of DP, SO, engage seals into SBE, and mark the pipe for spacing out packer assembly 05:00 06:00 1.00 8,370 8,350 COMPZ RPCOM WAIT XT PU out of the SBE. Wait for truck with corrosion inhibited seawater to arrive. 06:00 06:30 0.50 8,350 8,350 COMPZ RPCOM RURD X Spot and hook up truck with corrosion inhibitor. 06:30 07:15 0.75 8,350 8,350 COMPZ RPCOM CRIH X Pump 10 bbls of 8.6 ppg corrosion inhibited seawater followed by 53 bbls of clean seawater to spot corrosion inhibitor around PBR/FHL packer assembly. Page 30 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:15 08:00 0.75 8,350 8,238 COMPZ RPCOM PACK X Ease the Seal Assembly into the 4 1/2"Liner SBE. No-Go at the same Drill Pipe mark as before. Pick up to the 3-ft to the same space-out mark on the Drill Pipe. Bring pump on line and walk pressure up to 2,600 psi to set the FHL Packer. Hold x 10 minutes. Good. Bring pressure up to 3,500 psi x 3 minutes. Good. Bleed pressure from the tubing. Recorded setting pressures on the chart. 08:00 08:15 0.25 8,238 8,238 COMPZ RPCOM PRTS X Bring Pump on line. Pressure test the 7" Casing and the FHL Packer to 3,000 psi x 15 minutes. Good test. Recorded on the chart. Bleed pressure from the 7"x 3 1/2" Annulus. 08:15 16:00 7.75 8,215 0 COMPZ RPCOM PULD P Shear Seal assembly from the PBR at 8,215-ft. Single down 3 1/2"Drill Pipe from 8,215-ft to surface. Lay down the Seal Assembly. 16:00 16:30 0.50 0 0 COMPZ RPCOM RURD P Pick-up Running Tool. Pull the Wear Bushing. Lay down same. 16:30 17:30 1.00 0 0 COMPZ RPCOM RURD P Rig up GBR equipment to handle 3 1/2"Tubing. 17:30 17:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM for running completion 17:45 00:00 6.25 0 4,649 COMPZ RPCOM PUTB P PU and MU seal assembly, 1 joint, GLM with SOV, and single in hole with 3-1/2"9.3#L-80 EUE 8rd Mod tubing to 4649'at midnight. 31/23/2015 MU Orbit deployment valve and continue to RIH with dual control lines on 3-1/2"tubing. Engage seals into PBR,space out, MU tubing hanger, land tubing hanger,and RILDS. PT the tubing to 3500 psi for 10 minutes (good test), bleed the tubing to 2000 psi, PT the IA to 3000 psi for 30 minutes(good test), and quickly bleed off the tubing pressure to shear SOV. Pump through SOV both way and reverse circulate corrosion inhibited seawater(1%Conqor 303A). Install BPV and pressure up on the IA to 1000 psi to test BPV from below (good test). Clean under rotary table,steam tables,and draw works with super sucker. ND BOP stack and set back on stump. 00:00 01:30 1.50 4,649 4,649 COMPZ RPCOM RURD P Bring Cannon clamps, HES spooling units to rig floor,and tool box. RU HES spooling unit and RU sheaves in derrick. 01:30 03:00 1.50 4,649 4,649 COMPZ RPCOM PULD P PU and MU Orbit deployment valve. MU the hydraulic control lines to the open port and to the closed port. PT each control line and function test the valve open/closed. 03:00 03:15 0.25 4,649 4,649 COMPZ RPCOM SFTY P PJSM for running deployment valve with dual controls and cannon clamps 03:15 09:00 5.75 4,649 8,200 COMPZ RPCOM PUTB P Installed 2 stainless steel band on the deployment valve and continue to single in the hole with 3-1/2"tubing installing one Cannon clamp across each connection. Page 31 of 33 • Time Logs Date From To Dur S. DepthE. Depth Phase Code Subcode T Comment 09:00 12:00 3.00 8,200 8,241 COMPZ 1 RPCOM HOSO P Pick-Joints 263,264, 265. Make-up Headpin on Jt 265. Bring pump on line at 1.0bpm/90 psi. Ease in and observe pump pressure increase to 119 psi as the Seals entered the PBR. Pick-up Jt 266. No-Go tagged with 7-ft in. (8,241.0-ft) Lay down Jts 266,265, 264. Pick-up 2-ft Pup Joint and Joint 264. Make-up FMC 11"Tubing Hanger. Feed-thru and connect Orbit Valve control lines both top and bottom. 12:00 12:30 0.50 8,241 8,230 COMPZ RPCOM THGR P Land Tubing Hanger with the Seal Assembly spaced off 5-ft off of No-Go. RILDS. 12:30 13:30 1.00 0 0 COMPZ RPCOM PRTS P Pressure test the tubing ay 3,500 psi x 10 minutes. Good. Bleed pressure back to 2,000 psi and block in. Pressure test the 7"x 3 1/2" Annulus to 3,000 psi x 30 minutes. Bleed the tubing pressure down and observe the SOV shear at 2,000 psi. All test recorded on a chart. 13:30 15:00 1.50 0 0 COMPZ RPCOM CRIH P Line up Pump and pump 10 bbl through the SOV in both directions to confirm full shear. Reverse in with 219 bbls of corrosion inhibited seawater(1%Conqor 303A)at 4.0 bpm/575 psi. 15:00 15:30 0.50 0 0 COMPZ RPCOM CRIH P Blow down and RD circulation line. 15:30 16:00 0.50 0 0 COMPZ WHDBO MPSP P Install BPV into tubing hanger. Pressure up on the IA to 1000 psi to test the BPV from below(good test, charted). 16:00 23:00 7.00 0 0 COMPZ WHDBO OTHR P Blow down choke manifold, mud manifold, and kill/choke. Clean under rotary table,steam tables, and draw works with super sucker. Empty and clean the pits. Break service line 23:00 00:00 1.00 0 0 COMPZ WHDBO NUND P ND BOP stack and set back on stump. 01/24/2015 NU Orbit Valve manifold. NU Tree.Test Hanger void. Pressure and function Orbit Valve. Freeze Protect Well. Install and test BPV. Secure Cellar. Prep to Move off of location. Rig released at 14:00 hrs. 00:00 04:00 4.00 0 0 COMPZ WHDBO NUND P ND DSA. NU manifold for Orbit deployment valve and function test valve. NU tubing head adapter and NU tree. Tree orientation witnessed and confirmed by CPAI 2H DSO Dusty Beller. 04:00 04:30 0.50 0 0 COMPZ WHDBO PRTS P PT the void/tubing hanger pack-off to 250/5000 psi for 10 minutes. 04:30 04:45 0.25 0 0 COMPZ WHDBO MPSP P Pull BPV and install tree test plug. 04:45 06:00 1.25 0 0 COMPZ WHDBO PRTS P PT the tree to 250/5000 psi for 10 minutes. Good. Page 32 of 33 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 07:15 1.25 0 0 COMPZ WHDBO FRZP P Rig up Little Red Services. Rig up Cellar and Wellhead to test the Baker Orbit Valve, 07:15 07:30 0.25 0 0 COMPZ WHDBO SFTY P PJSM with Little Red Services and Rig Crew. 07:30 09:00 1.50 0 0 COMPZ WHDBO PRTS P Pressure test Little Red line to 3,500 psi. Close the Orbit Valve and test from above and below at 3.000 psi. Good. Record on chart. 09:00 11:30 2.50 0 0 COMPZ WHDBO FRZP P Little Red pump 75 bbls of diesel to freeze protect the Well down the 7"x 3 1/2"Annulus. Allow Well to "U-Tube"back into the Tubing. Release Little Red Services. Blow Top drive and all lines. 11:30 12:30 1.00 0 0 COMPZ WHDBO MPSP P Install BPV. Test from below at 250/1,000 psi. Good. Record on chart. 12:30 14:00 1.50 0 0 DEMOB MOVE RURD P Secure Cellar. Disconnect interconnects. Prep Pits to disconnect from the Sub Base. Release Rig at 14:00 hrs. Page 33 of 33 k%24- d 5 25 3(c) WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 21, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 M.K. END F r2, FER 05 M15 RE: Correlation Records: 2H-14 � ; Run Date: 1/17/2015 - 1/18/2015 :�.,�r( 4 :.. .,� The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2H-14 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20036-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE A'FI'ENTION OF: Halliburton Wireline& Perforating - Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 iNEV . Fax: 907-273-3535 `j " FRS_ANC@halliburton.com Date: Signed:-- �e4f.. Schwartz, Guy L (DOA) /I. 111II \\ From: Schwartz, Guy L(DOA) Sent: Wednesday,January 21, 2015 11:16 AM To: 'Lee,Theresa M' Cc: Eller,J Gary; Packer,J.Brett; Loepp,Victoria T(DOA) Subject: RE:2H-14 Workover(PTD 184-095) Theresa, Based on the CBL data (very good bond in 7"casing from 8350-8450' and adequate bond above that)you have verbal approval to install a straddle packer to isolate the casing leak(as proposed in your latest schematic) . This puts your upper packer depth 240 ft above the C sand (8460') which is part of the Kuparuk Oil Pool although it is currently isolated .. under 20 AAC 25.412 (b)the packer placement may be modified if confinement can be verified. I will file this email and diagram in our well file for documentation. Regards, Guy Schwartz sCANNE ) Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793-1226) or(Guy.schwartz@alaska.gov). From: Lee,Theresa M [mailto:Theresa.M.Lee@conocophillips.com] Sent: Wednesday,January 21, 2015 9:45 AM To: Schwartz, Guy L(DOA) Cc: Eller,J Gary; Packer, J.Brett Subject: RE: 2H-14 Workover Guy, I'm following up with our phone conversation about stacking a packer to straddle the 7" casing leak. I have attached our proposed completion to set the FHL packer at 8,220'to isolate the 7" casing leak below 8,297' and give us a safe distance above the pre-existing tubing leak at 8,237'. The PTD number is 184-095 and the workover sundry number approved on 11/19/14 is 314-604. Please let me know if you have any questions or need any other documentation submitted. Thank you, Theresa Lee Wells Engineer ConocoPhillips Alaska Office:907-263-4837 Cell:505-301-6483 1 From: Lee,Theresa M Sent: Wednesday,January 21, 2015 8:45 AM To: Schwartz, Guy L(DOA) (guy.schwartz@)alaska.gov) Cc: Eller, 3 Gary Subject: FW: 2H-14 Workover Guy, Please see the information below about 2H-14 if you are available. Thank you, Theresa Lee Wells Engineer ConocoPhillips Alaska Office:907-263-4837 Cell:505-301-6483 From: Lee,Theresa M Sent: Wednesday,January 21, 2015 8:17 AM To: Loepp, Victoria T(DOA) (victoria.loeppOalaska.gov) Subject: 2H-14 Workover Victoria, I have attached the original schematic,current schematic and the CBL from around the 7"casing leak zone.We ran a 4- 1/2" liner with a ZXP liner top packer set at 8,316' and cemented in place over the weekend. Our pressure test after waiting on cement failed in the IA.After the weekly BOPE test yesterday,we ran in hole with a test packer to find the 7" casing leak location.This morning we isolated the 7"casing leak between 8,297'and the top of the packer at 8,316'.We stung into the packer and set down then picked up to ensure the packer was properly set.The original completion we pulled at the beginning of the workover had a leak at 8,237'. I will call to discuss a plan forward at 8:30am. Thank you, 2 l � �r -- .l.. NM=- _..^ a • , __.---p. H. aa G " ..e,�-� 12 < 1 1111,--.11 NOMIONM s 5d■iiii H . 1 :1 _ '"' BrallaMI ; t 1 1 In- 7 - il F °sem +' , rt ' - '.�1__1 .too 1 ;i I I- / - j1' 1- !" 1' t I I 1 L I' i ' NINNINM z ,MENaa; : , +• 0310 ._ + ( ' E i ii..../ -. '-'4.'.› Ihialillap S - OM 0 T car• ¢ . f. t,. , cc' 1, i : I ' t--, Theresa Lee Wells Engineer ConocoPhillips Alaska Office:907-263-4837 Cell:505-301-6483 3 11 - - I I - ConocoPhi l l i s 2""1 4 CTD Setup Liner install Casing-9-5/8" 36#, J-55 BTC @ 2,838' —► 3-1/2" Baker Orbit Valve @ 3,500' Casing-7"26#J-55 BTC to 8,842' i Tubing-3-1/2"9.3#, L-80, EUE 8rd to 8,300' Miimm ---3-1/2"x 1-1/2" Camco MMG @-8,150' -�; ' _ 41-41r4 3-1/2'x7"FHL Packer @ 8,220' II ] I 2.813"X-nipple @ -8,260' 7" Casing Leak 8,297'-8,316' --op. %ft..\' 4 5" Bullet Seal Assembly @ 8,304' �� 'ic 5"x7"2-RH ZXP Liner top Packer @ 8,316' c:-tiy . — ---- ;..4A-, 5" Flex Lock Liner Hanger @ 8,336' r•r▪•r▪• r•r•f 4•S•S-S ,L•L•ti• f•r•f• r•r•r C-4 Perf @ 8,460'-8,476' _.... r•f▪.f▪• ;•r•r•r 1•YS•ti 1.1.1• L�ti:Lw Cti 4.745 r•r▪w• NV.* iki •r•r▪•f• '•r•r•r -- A-5 Peri 8,508'-8,519' ?..2.?.?:::.; .1~1 11' @ � -� 1r1r-.'1 �?i%;* Proposed CTD kickoff 8,530' r•r-r• r•r•r r•f•f• r.r•r A-4 Pert @ 8,530'-8,563' -0 _....1 ir'r'f• •r•r•s __...c' iii"— Reperforate A sand post RWO for CTD •__.".. 1f;f;. f1.1: pressure monitoring A-3 Perf @ 8,588'-8,614' .1:V:▪ 5� ti.1fti: _� r•r•r• f•f•r low.- . ▪r•r•r• r•r•r %.4,.ca _ al ; Landing Collar 8,616' lrtiftirti tivyti; 9 ▪r•r•r• r•r•r Liner 4-1/2" 11.6# L-80 cemented in place cr f.r tif�ftir Float Collar @ 8,659' L•ti•S.S _ :set: �rtif�r� ter: r Float Shoe @ 8,705' 'ii:1:r•r r.r.f.r.r•f.r•r.r•i i:r �r 9.8.44.V.f~gay...r.*vf~f~fyy.r r•r•r•r.rY•f•r•f-r.r-f.f•f•r.f.r•r ti�lti�ti�ti�SS�L�SiSiS1'iY:~ibiL:ti: Date: January 21,2016 Drawn By:Theresa Lee 11 ConocoPhilli 2H-14 ps - CTD Setup Liner install Casing—9-5/8"36#, J-55 BTC @ 2,838' 44 11.6ppg Mud Casing-7"26#J-55 BTC to 8,842' Planned Tubing-3-1/2"9.3#, L-80, EUE 8rd to8,300' I 0.Qt{_ a`-(J PrO (it./.►�f�3m _62?M 7" Casing Leak to 8,29T-8,319 H ,—Planned 5"Bullet Seal Assembly @ 8,304' ........ 4.1_- 5"x7"2-RH ZXP Liner top Packer @ 8,316' r 5" Flex Lock Liner Hanger @ 8,336' ti-ti•r.ti•rti tit ,......•;._jIA. r C-4 Pert @ 8,460'-8,476'—00- r~rr~ 'el.:4•Y* L — :Vet— 1'1561 T::.:::•/ '- .5r-rr- r.r•r-r .1.1. ti.1...• •r`r•r• 0::.1r:r 7•{rY.1•r1• r•r1r.r r- — A-5 Peri 8,508'-8,519' —� �`r�'~'~ r~rr~rr 4 Proposed CTD kickoff 8,530' 1:Vr.. .5. L L ...iti:•r• r•r•r •r r1.1 1.1.1: A-4 Perf@ 8,530'-8,563' —0 :1:1 SM.'ry:r = — Reperforate A sand post RWO for CTD 7 •1.1• 1.1. pressure monitoring r•r•r• r.r•r •1.1.1 1..i.% A-3 Perf @ 8,588'-8,614' � — 1.{j{5{�{ LS1j•.�r CSr:.... .__] t- SM. Landing Collar @ 8,616' •1.1K :•1.1.•Y :sr.::::;..-is r•r.r Liner 4-1/2" 11.6#L-80 cemented in place {r•r~•4 ' n 1;' Float Collar @ 8,659' ?;3r:::S:• fir Float Shoe @ 8,705' v•1.1.1 1.1.1• r•r•r•r•r r•r•r•r•r•r•r•r•r.r•r.r f~f~f~f�'f�'fti?�'f1f~?ti?tif~?tifti•ti?~ftir SLfM1:{5."{f{d:i:{1'S'11'�tir{r5'tir•E: r•r-r•r•r.r•r•r•r•r-r•r•r•r-r-r•r•r ti:}:1•.1;3;53titi;ti;tiS3S}S�9}S}StiS^.•:ti: Date: January 21,2015 I Drawn By:Theresa Lee trna ect Well History File Covel~bge XHVZE This page identifies those items that were not scanned during the .initial production scanning phase.. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Z ~ ~'~- -~ ~ O_-'Well Hi.tory File Identifier RESCAN DIGITAL DATA [] Color items: [] Diskettes, No, [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: NOTES: BY; BEVERLY BR~ SHERYL MARIA LOWELL Project Proofing BY: ~REN VINCENT SHERYL MARIA LOWELL OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) 12 Logs Of various kinds [] Other Scanning Preparation ~ x 30 =' ~ ~ + /,~ = TOTAL PAGES BY: BEVERLY BREN VINCEN~ARIA LOWELL Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE:' '( BY: Stage 2 BY~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ,~, YES ~ NO IF NO iN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES ~ NO RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE; /si General Notes or Comments about this file: QUality Checked ~, ,~ ConocoPhillips ~~~ ~ ~ ; t^ ~ ~ ~ !'~' Alaska ~, ~ .~, ,~ ~~~ ~~ :, ... P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 °~ i.I.ai.,a's May 14, 2008 ~~~ MAY ~ fl 200 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 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 form 10-404, Report of Sundry Operations. The cement was pumped Apri13 2008 and the corrosion inhibitor/sealant was pumped on April 20~h and 30~' of 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, 1 _.. Perry Kle ConocoPhillips Well Integrity Projects Supervisor ' ,,.5 ,. ConocoPhillips Alaska-Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations d10-404) Date Kuparuk Field 5/14/2008 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 2B-01 184-115 25' 5" 3.25 23" 4/3/2008 1.7 .4!20/2008 26-02 184-122 30' 5" 0.5 20" 4/3/2008 4.3 4/20/2008 2B-03A .203-009 4' 0.5 33" 4/3/2008 10.2. 4/20/2008 2B-04 184-120 30' 4 28" 4/3/2008. 6.4 4!20/2008 26-06 184-022 26' 5 19" 4/3/2008 8.5 4/20/2008' 26-09 184-027 74' 10.5 32" 4/3/2008 11.1 4/20/2008 2B-10 184-029 74' 10.5 33" 4/3/2008 17 4/20/2008 2B-11 184-035 50' - 7.5 29" 4/3/2008 6 .4/20/2008 2B-12 184-038 6' 1 29" 4/3/2008 6 4/20/2008 2H-01 184-077 SF n/a SF n/a 2.5 4/30/2008 2H-02 184-073 SF n/a SF n/a 2 4/30/200 2H-03 184-070 SF n!a SF n/a 4 4/30/200 ,: 2H-04 184-055 SF n/a SF n/a 2 4/30/2008 2H-08 185-171 2' 6" n/a 2' 6" n!a 25 4/30/2008 2H-10 185-260 SF n/a SF n/a 2 4/30/2008 2H-11 185-261 SF n/a SF n/a 2.5 4/30/2008 2H-12 185-262 SF n/a SF n/a 2.5 4/30!2008 2H-13 184-096 2" n!a 2" n/a 2 4/30/2008 2H-14 184-095 SF n/a SF n/a 2 4/30/2008 07/27/07 Sc~lullbepuel' rifl -crJ5~ NO. 4343 i\/f::[) Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth dUL 3 ( 2007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alaska Oil & Gas Coos. Commission Anchoragø SCANNED AUG 01 20m Field: Kuparuk Well BL Color CD Job# Log Description Date 1H-08 11850414 INJECTION PROFILE 07/23/07 1 2L-327 11665460 SBHP SURVEY 07/21/07 1 2M-28 11850413 PRODUCTION PROFILE 07/22/07 1 2M-32 11850415 GLS 07/24/07 1 2P-448A 11850403 SBHP SURVEY 07/21/07 1 1 H-03 11632739 INJECTION PROFILE 07/23/07 1 2T -37 11632740 PRODUCTION PROFILE 07/24/07 1 2H-14 11632738 PRODUCTION PROFILE 07/22/07 1 L6 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . ~=:!Æ~! :} !Æ~!Æ~~«:Æ AI,ASIiA. OIL AlQ) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR November 26,2004 333 W. ]1H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 .~.~ €}CfG \¡~:~ Mr. Mike Wheatall Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 J\nchorage,AJC 99510-0360 Dear Mr. Wheatall: The Alaska Oil and Gas Conservation Commission ("Commission") received a well safety valve system (SVS) test report from ConocoPhillips at Kuparuk River Unit 2H pad ("KRU 2H") dated November 1 0, 2004. Attached is a copy of the SVS Test Report. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. An SVS component failure rate of 11.1 percent was identified during the above-noted inspection. Commission policy, -'as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13, 2003, supported retention of the 10% failure threshold. Effective November 10, 2004 and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2H must be tested every 90 days. When testing is scheduled, you must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to witness the SVS test. Sincerely, cf~ ß:K~c. James B. Regg -l { Petroleum Inspection Supervisor Attachment SCANNEl1 JAM 11 2005 Operator: ConocoPhillips Operator Rep: Noble - AES AOGCC Rep: Waived Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Submitted By: Brad Gathman Field/Unit/Pad: KRU 2H Separator psi: LPS Date: 11/10/2004 96 HPS ".,. ,,~~ll{1!Ji~> " "" '.;;~1:,{(~¥J Well Permit Separ Set LIP Number Number PSI PSI Trip 2H-01 1840770 2H -02 1840730 2H-03 1840700 2H-04 1840550 2H-05 1851680 96 2H-06 1851690 96 2H-07 1851700 96 2H-08 1851710 96 2H-09 1852590 96 2H-I0 1852600 96 2H-l1 1852610' 96 2H-12 1852620 96 2H-13 1840960 2H-14 1840950 2H-15 1840860 2H-16 1840870 2H-17 2000190 t~~~~~i'$~~,~ 'l!~~~~t~~!l~!l!ilit~ ~J1{~:" " ",.(t, ,'~ Test Test Test Date Tested and or Oil, WAG, GINJ, Code Code Code Passed Retest or SI GAS, CYCLE, SI WAG WAG WAG WAG OIL OIL OIL OIL OIL 11/11/2004 OIL OIL 11/11/2004 OIL WAG OIL WAG WAG WAG 96 Wells: 9 Components: Remarks: 70 50 P P 70 65 P P 70 70 P P 70 50 P P 70 55 P P 70 50 P 4 70 55 P P 70 60 P 4 70 50 P P 18 Failures: 11.11 o/B 90 Day 2 Failure Rate: 2H-I0 & 12 serviced and passed re-test Pad to be re-tested in 90 days RJF 09/19/02 Page 1 of 1 SVS KRU 2H 11-10-04.xls MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Julie Huesser, DATE: December 2, 2000 Commissioner THRU: Tom Maunder, P, I. Supervisor FROM: SUBJECT: Chuck Scheve; PetrOleum InspeCtor Safety Valve Tests Kuparuk River Unit 2H Pad Saturday, December 2,-2'000: I traveled to the Kuparuk River Field and witnessed the semi annual safety valve system testing on 2H Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 9 wells and 18 components with four failures observed. The Iow pressure pilots on wellS 2H-5,2H-6 and 2H-12 tripped well below the required set point and the surface safety valve on well 2H-12 failed to pressure test. The three failed pilots were adjusted and retested at the time of this test. The failed valve will be repaired and retested by the operator. -' The 22.2% failUre rate· will require a retest of this Pads Safety Valve System in 90 days rather than the n°rmal/~,~day cycle. Earnie Barndt conducted the testing today he demonstrated good test procedure and was a Pleasure to work with SummarY: RiVer Field. I witnessed the semi annual SVS testing at 2H Pad in the Kuparuk 18 components, KRU 2H Pad, 9 wells' Attachment: sVs KRU 2H Pad 12-2-00 CS 4 failures 22% failure rate X UnClassified Confidential (Unclassified if doc. Removed) SVS KRU 214 Pad 12-2-00 CS.doc AlaSka Oil and Gas Conservation CommiSsion Safety valve System Test Report Operator: .Phillips 'Operator Rep: Emie Bamdt AOGCC Rep: Chuck ScheVe Submitted By: Chuck Scheve Date: Field/Uni~ad: Kupamk / KRU / 2H Pad Separator psi: LPS 96 HPS 12/2/00 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCL~ 2H-01 1840770 2H-02 1840730 2H'03 1840700 2H-04 1840550 : 2H-05 1851680 96 . 70 20 3 P 12/2/00 OIL 2H-06 1851690 96 70 10 3 P 12/2/00 OIL 2H-07 1851700 96 70 60 P P OIL 2H-08 1851710 96 "70 -60 P P OILi 2H-09 1852590 96 70 5(~ P P OIL 2H-i 0 1852600 '96 70 50! P P OIL 2H-11 1852610 96 70 50 P P OIL 2H'12 1852620 96 70 10 3 4 remarks 2H- 13 1840960 , 2H-1'4 18409501 96! 70 60 P P OIL 2H- 15 18408601 ,, 2H- 16 1840870 2H- 17 2000190 Wells: 9 Components: 18 Failures: 4 Failure Rate:' 22.0°/dM90 var Remarks: three failed pilotS repaired and retested, failed SSV to be repaired and retested by op Pad on 90 day teSt cYcle Paoe 1 of 1 SVS KRU 2H Pad 12-2-00 CS.xls ..~ .~... STATE OF ALASKA ~'-~-"' /' ~, OIL AND GAS CONSERVATION COMb, REPOH-r OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging ,. Perforate __ Repair well Other__ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service __ 4. Location of well at surface 110' FSL, 654' FEL, Sec. 26, T11N, R8E, UM At top of productive interval 1325' FSL, 1073' FWL, Sec. 35, T11N, R8E, UM At effective depth 1170' FSL, 948' FWL, Sec. 35, T11N, R8E, UM At total depth 1106' FSL, 897' FWL, Sec. 35, T11N, R8E, UM 6. Datum elevation (DF or KB) RKB 24 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2H-14 9. Permit number/approval number 84-95 10. APl number so-103-20036 11. Field/Pool Kuparuk River Field/Oil Pool 12. Present well condition summary Total Depth: measured true vertical 88 73 feet Plugs (measured) None 6376 feet Effective depth: measured 8 7 5 0 feet Junk (measured) true vertical 6284 feet ORIGINAL Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' - I 6" 172 SX CS II 1 1 0' I 1 0' Surface 2809' 9-5/8" 980SxASIII& 2839' 2497' Intermediate 440 Sx Class G Production 8814' 7" 400 Sx Class G 8843' 6353' Liner 250 Sx AS I Perforation depth: measured 8460' - 8476', 8508'-8519', 8530'-8563',8588'-8614' true vertical 6071' - 6083', 6106'-6114',6122'-6146',6163'-6183' RECEIVED Tubing (size, grade, and measured depth) 2.875", 6.5#/ft., J-55 @ 8512' Packers and SSSV (type and measured depth) PKRS: Baker FHL @.8325' & DB @ 8508'; SSSV: Camco TRDP-.1A @ 1825' MAR ? 0 lqq7 13. Stimulation or cement squeeze summary Fracture Stimulate 'A' Sands on 6/2/96 Naska011&~asCons, Coamissi0n Intervals treated (measured) Ailc~101ragll 8508'-851 9', 8530'-8563',8588'-861 4' Treatment description including volumes used and final pressure Pumped 142.5 Mlbs of 20/40,12/18,& 10/14 ceramic proppant into formation, fp was 4834 psi 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2 6 1 244 7 1015 239 Subsequent to operation 1037 2057 42 1024 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 7. I here~.-~ify that the foregoing is true and correct to the best of my knowledge. Isigned Title Wells Superintendent Form ly4~'4 "R-ev SUBMIT IN DUPLICATE AR~CO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2H-14(W4-6)) WELL JOB SCOPE JOB NUMBER 2H-14 FRAC, FRAC SUPPORT 0528960753.3 DATE DAILY WORK UNIT NUMBER 06/02/96 PUMP "A" SANDS REFRAC. DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 (~ Yes 0 No! (~) Yes O No DS-GALLEGOS JOHNS ESTIMATE KM1208 23ODS28HL $124,82'9 $132,682 Initial Tb.q Press Final Tb.cl Press Initial Inner Ann Final Inner Ann I Initial Outer'Ahn I Fin~tYOuter Ann 526 PSI 1824 PSI 600 PSI 500 PSII 150 PSII 300 PSI DAILY SUMMARY IPUMPED "A" SANDS REFRAC AS DESIGNED. PUMPED 142,488~ PROPPANT BEHIND PIPE, FLUSHED TO TWO SHORT OF PERFS , I 1,611# IN WELLBORE. 10,115# 20/40,132,195# 12/18 AND 6,122# 10/14. I TIME 07:30 09:30 10:20 11:50 11:52 11:53 12:12 13:13 14:40 15:02 15:09 15:40 15:55 15:57 15:59 16:02 -LOG ENTRY MIRU DOWELL FRAC EQUIP., APC SUPPORT EQUIP. QC FRAC FLUIDS, HELD SAFETY MEETING PROBLEM WITH TWO PUMPS, HAD TO EXCHANGE PRESSURE TEST TREAT LINES TO 8200 PSI STARTING WHP IS 527 PSI PUMPED BREAKDOWN STAGES W/1 PPA AND 2 PPA 20/40 SCOUR STAGES, AT 20 BPM TO 15 BPM AND 6985 PSI TO 58O9 PSI. SHUT DOWN FOR ISIP AND FG..72. PUMPED THREE PULSE TEST AT 5BPM FOR 4 MINUTES. PUMPED 156 BBLS DATA FRAC AND FLUSH, SHUT DOWN FOR CLOSURE EVALUATION. PUMPED 220 BBLS PAD OF 50 # GEL, DETERMINED FROM DATA FRAC. START 50# GEL PROPPANT SLURRY AT 2PPA., 15 BPM AND'5805 PSI. RAMP TO 5PPA SLURRY, 15 BPM, START TAPPERING TO 40# GEL SYSTEM. HOLD FLAT8 PPA SLURRY, CUT RATE TO 13.5 BPM FOR WHP AT MAX. RAMP TO 9 PPA SLURRY SWITCHED TO 10/14 PROPPANT AND 10 PPA SLURRY. 14 BPM 4834 PSI PUMPED 24 BBLS WATER GEL AND23 BBLS DIESEL FOR TUBING FLUSH TWO BBLS SHORT OF PERFS. FINALSHUTINPRESSURE1872PSI. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $1,128.00 APC $4,600.00 $6,000.00 DOWELL $117,229.00 $117,229.00 HALLIBURTON $0.00 $5,325.00 LITTLE RED $3,000.00 $3,000,00 TOTAL FIELD ESTIMATE $124,829.00 $132,682.00 STATE Of ALASKA ~-" ALASKA OIL AND GAS CONSERVATION ~OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG . . 1. Status of Well Classification of Service Well REV I SED OIL ~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-95 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0:360 50- 10:3-20036 4. Location of well at surface 9. Unit or Lease Name 110' FSL, 654' FEL, Sec.26, TllN, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1325' FSL, 107:3' FWL, Sec.35, TllN, R8E, UM 2H-14 At Total Depth 11. Field and Pool 1106' FSL, 897' FWL, Sec.35, TllN, RSE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 125' ADL 25587 ALK 267:3 '' I 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 07/09/84 07/17/84 07/18/84* N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back' Depth (ME:H-TVD) 19. DirectionalSurvey 120. Depth where SSSV set [ 21. Thickness of Permafrost 8873'MD, 6376'TVD 8750'MD, 6284'TVD YES [~ NO [] 1827' feet MD 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/FDC/CNL/GR/Cal, BHCS, CBL/VDL/GR/CCL, Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 172 sx Cold Set II 9-5/8" :36.0# J-55 Surf 28:39' 12-1/4" 980 sx AS Ill & 440 sx Class G 7" 26.0# J-55 Surf 884:3' 8-1/2" 400 sx Class G & 250 s~ AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 851 4 ' 8460'-8476' w/12 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 8588'-8614' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8563'-8530' w/4 spf, 90° phasing See attached Addend~,m~ for fracture data. 8508 ' -8519 ' 27. N/A PRODUCTION TEST , Date First Production I Method of Operation (Flowing, gas lift, etc.) I ' I Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ . Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRA~/ITY-APi (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dipsand presence of None oil' gas °r water' Sub~ SC? 6 *Note: Tubing was run and the well perforated 4/22/85. Form 10-407 Rev. 7-1-80 WC3/64: UAN I CONTINUED ON REVERSE SIDE Submit in duplicate(/~". ~. · 29. '~ ' '~' 30. [' ' . GEOL.OGI-C MAR'KER~ "- . . .~. FOI~MATION TESTS ~ - _~.; ~:_ :-_ ~ : , . .,- . · .... .-. . -... ,. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.' _ _ Top Upper Sand 8458' 6070' N/A Base Upper Sand 8475' 6078' Top Lower Sand 8496' 6094' Base Lower Sand 8698' 6245' : . . .- ; - 31. LIST OF ATTACHMENTS Addendum 32. I hereby certify that th~ foregoing is true and correct to the best of my knowledge ',. Signed ~ ]~./)-f,j~.. Title Associate 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- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM I~LL: 9/27/85 2H-14 Frac well in 3 stages w/138 bbls gelled diesel & 2100# of 20/40 mesh. RIH w/CCL & temp surv, log 8660'-8325'. Drillin~ Superintendent Date ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 5, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton. Attached are our notices of intention field well 2H-14. If you have any questions, please call me T. Mark Drumm Kuparuk Operations Coordinator TMD'ps'File Attachment (In Triplicate) to convert Kuparuk at 263-4212. RECEIVED ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION: 110' FSL, 65q' FEL, Sec. 26, T11N, R8E, UM 5. Elevation in feet (indicate KB, DF, etc.) 125 ' (RKB) 12. 7. Permit No. 84-95 8. APl Number 50- 1 03-20036 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2H-14 1 1. Field and Pool KUPARUK RIVER FI ELD 6. Lease Designation and Serial No. KUPARUK RIVER O I L ADL 25587, ALK 2673 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that Kuparuk well 2H-14 be converted from a producer to a water injection we l !. The we l I has produced from both the "A" and "C" sands. Injection wi I I be into the "A" sand. ANTI C! PATED START DATE' February 7, 1986 RECEIVED 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~.~~~~ Tired pA?.UK The space below for Commission use OPERAT IONS COORD I NATOR Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Cammission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Pos! Office B( ,)0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 09-10-85 T~{ANSMITTAL NO: 5341 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 ENGINEEklNG TRANSbIITTED HERA~4ITH ARE THE FOLLOWING IT~YlS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. CASED HOLE LOGS (FINALS): "'¢1Q-15 / 'CBL 6/12/85 8000-8745 ~ 1Q-I~ CCL & PERFORATING RECORD 4/16/85 x3 2V-9 ~ COMPLETION RECORD 4/25/85 7525-7800 ~ ~2H-15~ COMPLETION RECORD 4/13/85 6998-7438 -'~2H-2~ CCL & PERFORATING RECORD 4/24/85 '~ 2H-14~ CCL & PERFORATING RECORD 4/23/85 ' '~ 2R- 16--- CCL & PERFORATING RECORD 4 / 19 / 85 ~lR-9~ PERFORATING RECORD 8/3/85 7800-8'000 X~lB-2--- PACKER SETTING RECORD 6/5/85 7290-7820 '-'~lA-9~ PACKER SETTING RECORD 8/15/85 6700-6950 -'~ 2H-13 -- COMPLETION RECORD 4/17/85 7434-7650 ~-'~iR-10'~ PERFORATING RECORD 8/5/85 8300-8550 ~2Z-8-'~ COMPLETION RECORD 4/27/85 8920-9030 ~'4 3B-11--- CRT 7/5/85 6500-9100 RECEIPT ACKNOW'LEDGED: DISTRIBUTION: BPAE DRILLING* ~. PASHER B. CURRIER L. JOHNSTON EXXON CHEVRON MOBIL PHILLIPS OIL D &~M NSK CLERK* J. RATHMELL "~'~~z~.'; . ~ ~'- ....... _ ,, ,.; . UNION K.TULIN/VAULT ARCO Alaska, inc.,,"'* Post Office i.._., 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-20-85 TRANSHITTAL NO: 5294 RETURIq TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ' ATO-1115B ~.O. BOX 100360 ANCHORAGE, AK 99510 TP, ANSMI~ED HERE~IYH ARE THE FOLLOWING ITE£'IS. PLEASE ACKNO~LEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. FINAL PRINTS / SCHLUHBERGER CET/CEMENT EVALUATIONS (ONE * OF EACH) --HZ-8 ' CET LOG 04-26-85 ~{UN #1 8400-9208 "~2V-9~' CET LOG 04-25-85 RUN #1 7000-7893 ~2H-14-"CET LOG 04-05-85 RUN #1 7400-~700 ~31R-7/CEHENT EVALUATION 06-19-85 RUN #1 4500-7033 FINAL PRINTS / SCHLUMBERGER CBL'S (ONE * OF EACH) 3B-1/~ 05-06-85 RUN #1 ~2U-11~.05-03-85 RUN #1 2U-10/05-03-85 RUN #1 ~2U-9 ~ 05-02-85 RUN ~i ~1Q-16/05-27-85 ~{UN #1 5040-7563 ..... 8423 5500-6963 5850-8089 4290-7018 ~ECEIPT ACKNOWLEDGED: ~PAE CURRIER ~HEVRON ~ & [~ DRILLING*BL L. JOHNSTON MOBIL NSK CLEF, K*BL DISTEIBUTION: W. PASHER EXXON PHILLIPS OIL J. RATHMELL STATE OF ALASKA*BL SOHIO /SE UNION K.TULIN/VAULT*FILMS ARCO *,laska, Inc. 3st Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RET URN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 ~.~TE: 06-19-85 TRANSMIT%~AL NO: 5230 PAGE 2 OF 2 ENGINEERING TRANS['~iTTED HER~;ITH ARE THE FOLLOWING ITEMS. PLEASE ACK74OWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. ***CONTINUED. FROM PREVIO 2D-5 FLOWING BHP ETC 2D-3 ACID JOB PREP 2D-3 ACIDIZE 'C'SD 2E-9 G.R. SBHP 2E-13 SBHP 2E-!4 SBHP 2E-15 SBHP 2G-1 FLOWING BHP 2H-1 BHP&TCL 2H-15 SBHP & ETC. 2H-1 BHP & ETC. 2H-3 BHP & ETC. 2H-4 COMP BHP 2H-14 INT. SBHP&ETC 2U-5 SBHP 2U-6 SBHP & TCL 2U-7 SBHP PRE PROD 2U-8 SBHP & ETC. 2U-9 PRESSURE TEST 2U-!0 BHP SAMPLE 2U-16 'A'SD FLUID ID 2U-16 PBU 2V-10 BHP & ETC. 2V-!l ~ STATIC 2V-11 STATIC 2W-13 'C'SD ACID STIM 2X-12 'C'SD ACID JOB 2Z-2 E/LINE FLUID ID US PAGE*** 05-06-85 CAMCO 05-07-85 BAKER 05-11-85 DOWELL 06-11-85 OTIS 06-10-85 OTIS 06-10-85 OTIS 06-09-85 OTIS 04-2 9-8 5 CAMCO 05-27-85 OTIS 04-29-85 OTIS 05-23-85 CAMCO 05-23-85 OTIS 05-23-85 OTIS 04-28-85 OTIS 05-02-85 CAMCO 05-0 3-85 CAMCO 05-04-85 CAMCO 05-04-85 BAKER/CAMCO 05-27-85 OTIS 06-05-85 OTIS 06-09-85 OTIS 06-07-85 OTIS 05-17-85 OTIS 05-12-85 OTIS 05-23-85 OTIS 05-2 0-85 DOWELL 05-12-85 DOWELL 05-03-85 OTIS/CAMCO RECEIPT ACKNOWLEDGED: B PAE * B. CURRIER CHEVRON* D & M DRILLING L. JOHNSTON MOBIL * NSK CLERK DISTRIBUTION: %~. PASHER EXXON PHILLIPS OIL* J. RATHMELL STATE OF ALASKA SOHIO* UN TON * K .TULIN/VAULT ARCO Alaska, inc. Post O,lice Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 05-2 9-$ 5 TRANSMITTAL NO: 5199 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-!llSB P.O. BOX 100360 AKCHORAGE, AK 99510 TIu~,,S,4I:~ED UEREA~ITH ARE TIlE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TFu-%NSMITTAL. KUPARUK %[EL.L PRESSURE REPORT ENVELOPE DATA: (ONE COPY OF EACH) 2A-4 04-22-85 STATiC-'C' SAND 2A-7 04-23-85 STATIC-'A' & 'C' SAND 2F-6 03-21-85 STATIC-PBU-'A' SAND 2G-8 03-21-85 PBU-'A' SAND 2G-12 03-23-85 STATIC-PBU-'A' SAND 2I!-13 04-26-85 STATIC-'A' SAND 21i-14 04-28-85 STATIC-'A ' SAND 2II-!5 04-29-85 STATIC-'A' SAND 2U-1 04-11-85 PBU-'A' SAND 2U-2 04-11-85 PBU-'A' SAND 2U-3 04-11-85 STATIC-'A' SAND 2U-4 04-11-85 STATIC-'A' SAND 2U-5 05-02-85 STATIC-'A ' SAND 2U-6 05-03-85 STATIC-'A' SAND 2U-7 05-04-85 ST~TC-'A' SAND 2U-8 05-04 -85 STATIC-'A' SAND ~U-=3 03-09-85 STATIC 2U-14 03-21-85 STATIC-'A' & 'C' SAND 2U-15 03-20-85 o~TATIC-'A'&'C-' SAND 2U-!6 03-15-85 STATIC-'A' &'C' SAND 2V-2 03-23-85 STATiC-'C' SAND 2V-SA 03-17-85 STATIC-'C' SAND 2V-SA 01-24-85 STATIC-'A'&'C' SAND V-4 04 13-85 c'"~'mIC 'A' SAND 2X-! 04-14-85 STAT!C-'A'&'C' SAND 2X-3 04-13-85 STATIC''A' &'C ' SAND 2X-13 03-30-85 PBU-'A' SAND IECEIPT ACKNOWLEDGED: DISTRIBUTION: ]PAE* DRILLING W DAS~-T~' P ~,. C""o~,RIER* L. JOIINSTON EXXON lllEVRON* MOBIL~' PHILLIPS OIL* ) & M* NSK CLERK J. ,~AT.'h'.~LL* DAT~,IEsk~_ Oit 6 G~s (.;cr, s. LA-.missio:- STATE OF ALASKA* SO]~iO* K. TULiN/VAULT ARCO Alaska, Inc. Post Office Be~ }0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 3, 1985 Mr. C. V. Chatterton Commi ssioner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton- Enclosed are Well Completion Reports for 2H-2 2H-13 2H-14 2H-16 1Q-4 If you have any questions, please call me Sincerely, Gruber Associate Engineer JG/tw GRU9/L32 Encl osures the fol 1 owing wel 1 s' at 263-4944. I'¢ ECEI VED JUNo 1985 Alaska Oil &.Ga~. Cons. COrnrnission '~nchorage ARCO Alaska, Inc. is a Subsidiary' o! AtlanlicRichfieldCompany · '~' ~-,,. STATE OF ALASKA ALASKA' .L AND GAS CONSERVATION ¢:~'--'MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ~. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-95 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 10:]-200:]6 4. Location of well at surface 9. Unit or Lease Name 110' FSL, 654' FEL, Sec.26, T11N, RSE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1:]25' FSL, 107:]' FWL, Sec.:~5, T11N, R8E, UM 2H-14 At Total Depth 11. Field and Pool 1106' FSL, 897' FWL, Sec.35, T11N, RSE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 125' RKB ADL 25587 ALK 267:] 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 07/09/84 07/17/84 07/18/84* N/A feet MSLI 1 ., 17. Total Depth (M D+TV D) 18. Plug Back Depth (ME>+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set 121. Thickness of Permafrost 8873'MD,6376'TVD 8750'MD,6284'TVD YES [~X NO [] 1827 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/FDC/CNL/GR/Cal , BHCS, CBL/VDL/GR/CCL, Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 172 sx Cold Set II 9-5/8" 36.0# J-55 Surf 2839' 12-1/4" 980 sx AS .Ill & 440 sx Class G 7" 26.0# J-55 Surf 8843' 8-1/2" 400 sx Class G & 250 s~ AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8460' - 8476' w/12 spf, 120° phasing 2-7/8" 8514' 8:]27' & 8499' 8588' - 8614' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 856:]' - 85:]0' w/4 spf, 90° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8508' - 8519' N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE 1GAS-OILRATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. ;24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED J U N 0 4 1985 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 * NOTE: Tubing was run and the well perforated 4/22/85. GRU9/WC18 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .. -*'; E '* GEOLOGIO MARKERS ::-':;'~-¢''~ : <:~-'-.?, ':-,-::¢-.'-'..*~-;-?-,~.'-~ ~ ::'"-'.,:* ;: :FORM~,T.'I'ON?CES'CS' ?: :""' :":"' <'. :-; -' · NAME [ ' -" ' Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and=time of.each phase. · Top Upper Sand 8458' ::~'- 6070' N/A · : Base Upper sand 8475'. 6078' Top Lower Sand -8496' 6094, .... Base LoWer sand 8698'- 6245' - ~, : i-_...i i~.-,: ,:>; ',' . : -~ . ; - ; .; : , · : i~ ,:'- ;": ': .. : . 31. LIST OF ATTACHMENTS · · We! ! M~ story (~nmp'!et~on deta~ !s) -'" 32. I hereby certify,.that the foregoing is trUe and correct to the best of my knowledge Signed ~ ~/~fJ ~ Title Associate Engi neer Date /~ - _ INSTRUCTIONS General' This form is designed for submitting a comPlete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal; water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". . . Fnrrn 1 f]-4N7 ARCO Oil and Gas Company Well History- Initial Report - Dally Instructions: Prepare and submit the "lnllill Rel~ort" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field Alaska ICounty. parish or borough North Slope Borough ILease ADL 25587 or Unit ITitle Comp let ion Kuparuk River IState Alaska -14 Auth. or W.O. no. ~E 103063 Roll'N 4 API 50-103-20036 Operator ARCO W.I. ARCO Alaska, Inc. Spudded or W.O. begun IDate ITM Fr °r status if a w'O' Complete 4/18/85 2400 hrs. 56.24% Date and depth as of 8:00 a.m. 4/18/85 4/19/85 Complete record for each day reported 7" @ 8843' 8750' PBTD, Prep to PU tbg 10.2 ppg NaC1/NaBr Accept rig @ 2400 hrs, 4/18/85. ND tree, NU & tst BOPE. 7" @ 8843' 8750' PBTD, Monitor csg & tbg 11.1 ppg NaC1/NaBr RIH w/5" TCP guns, 12 SPF, 90° phasing. Displ 10.2 ppg brine w/ll.1 ppg brine. Position guns w/RA colr @ 8417' W-LM, top perf @ 8460' WLM, drop'bar & perf. Montior press; OK. RECE]VED Alaska Oil & G-~s Cons. t~ Commissi¢, Anchorage '.'~C e ~ Jo The above is correct Signature Z~.~jj~ ~_~j~ . For form preparation and distribu~n, see Procedures Manual, Section ?0. Drilling, Pages 86 and 87. JDate I Title 5/z5/~5 oriiiing Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time, On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. DistrictField A.'L ,-~ S ka IC°untYLease or or Unit Parish Kuparuk River Auth. or W.O. no. T t e AFE 103063 Roll'N 4 Operator I A.R.Co. W.I. ARCO Alaska, Inc. Spudded or W.O. begun Date Complete Date and depth Complete record for each day reported as of 8:00 a.m. 4/20/85 thru 4/22/85 Accounting cost center code State North Slope Borough Alaska ADL 25587 Completion JWell no. 2H-14 W/O AP1 50-103-20036 ITotal number of wells (active or inactive) on this i ]cost center prior to plugging and J 56.24% ]abandonment of this well i IHour IPrior status if a W.O, 4/18/85 ! 2400 hrs. I 7" @ 8843' AFE 103063 8750' PBTD, RR Crude RIH w/pkr, set @ 8487'. RIH w/275 its, 2-7/8", 6.5#, J-55 EUE 8RD IPC tbg. Stab into btm pkr. Lnd tbg. Set pkr, shear PBR. Set BPV. ND BOPE, NU & tst tree. Displ well to crude. RR @ 2100 hfs, 4/20/85. SSSV @ 1827', Upper pkr @ 8327', Lower Pkr @ 84 ~9~, "D" Nipple @ 8510' Tailpipe @ 85Lo~ Old TD Released rig 2100 Hrs. Classifications (oil, Oil . P.-~0 d u cin~ method Flowing Potential test data I PB 0epth (7/17/84) 8750' Kind of rig 8750' 4/20/85 Rotary pletion (single, dual, etc.) Single - -. Official r New TO IDate 8873 ' Kuparuk Sands , . Well no. Date R ..... ir Producing Interval Oil or gas Test time Prod~iO~ ~ r' ~ % ~ ~=, i.% Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable ' ' ~ ~f~ate corrected ........ ,, ~ u~ Cons. Commission Anchor,~ge ,--, The above is correct Signature~;~ ~ JDate 5/25/85 JTitle For form preparat,,.,n anQ see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. Post Office 1:_, 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/03/8~ Transmittal No: 4943 RETURN TO: ARCO ALASKA, INC. ATTN: Records Cler~ ATO-1115B _~.h'; Box 100360 orage, AK 99510 ' 6,zmndrmv/j~ransmi.tted herewith are the following items. and return one signed copy of this transmittal. Please acknowledge receipt OH LIS SChlumberger . #69798 2E-14 11/26/84 4015 - 8691.5 Run 1 #69895 2H-14 7/16/84 2808 - 8898.5 'Run 1 (Recomputed 12/26/84) #69887 1L-8 9/04/84 2383.5-7825 Run 1 (Recomputed 12/26/84) /cat ,- Receipt Acknowledged: DISTRIBUTION B. Currier BPAE Chevron Drilling · . Geology' Mobil W. Pasher G. Phillips Phillips Oil State of AK Sohio Union D&M NSK Ops. J. Rat~mell Well Files ARCO Alaska. Inc. is a subsidiary o! Alla~.t~cRichfieldCornpany ARCO Alaska, lnc Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 21, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2H-14 Dear Mr. Chatterton' Enclosed are the Well Completion Report and the gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU2/LI04 Enclosures RECEIVED NOV 2 8 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany WELL cOMP 1. Status of OIL [] GAS [] susPENDED Operator Alaska, Inc. Address po 0. Box 100360, Anchorage, AK 99510 Location of welt at surface 110! FSL, 654' FEL, Sec.26, T11N, RSE, UN t Top Producing Interval Sec.35, TllN, R8E, UH A1325, FSL, 1073' ABANDONED [] sERVICE [] Number ! LGC,~7',OIx t ~ VEEIFIF-D ~ At Total Depth 11061 FSL, 897' FWL, Sec.35, TllN, RSE, UM Lease Designation and Serial No. 5. Elevation in feet (indicate KB, DF, etc.) ADL 25587 ALK 2673 17_51 RKB Date comp., Susp. or Aband. 3. Date T.D. Reached 07 Date spudded 07/17 / 84 07/09/84 19. Directional Survey Back Dap NO [] Total De[ 8873, MD,6576' TVD 8750, MD,6284' TVD YES Electric or ther Logs Run CBL/VDL/GR/CCL, G; (GCT) L/SFL/GR/SP/FDC/CNL/GR/Cal, BHCS, D I CASt SETTING DEPTH MD 84-95 Number 50- 103-20036 9. Unit or Lease Name Kuparuk River Unit Number 2H-14 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool No. of completions Water DeE if offshore 1 N/A feet MSL Depth where sssV set !1. Thickness of Permafrost N/A feet MD 1500~ (~ ;ASING 7II .6.0# J-55 Surf 2839' ~6.0# J-55 Surf 8843' 24. Perforations open to Production (MD+TVD of ToP and Bottom and interval, size and number) NONE N/^ 980 s> TUBING ACID, FRACTURE, cEMENT sQUEEZE, ETC. PRoDUC~ ~lethod of Operation (Flowing, gas lift, etc.) Date First Production -ER-BBL O I L-BBL GAs-MCF ; Tested -ER-BBL cHOKE sIZE S-OIL RATIO (corr) of Test PER IOD OIL-BBL ULATED l~ ow Tubing ~sing Pressure RATE DATA ---- .----- core ch ECEIVED 28. lithologY porosity, fractures, apparent dips and presence of oil, gas or water. Submit ' Brief description of NONE NOV 2 8,1984 Alaska Oil & Gas Cons. (;ommission Anchorage Form 10-407 Rev. 7-1-80 GRU2/WC18 cONTINUED ON REVERSE SIDE Submit in duplicate . · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT.. DEPTH .GOR, and time.of each phase. Top Upper Sand 8458' 6070' N/A Base Upper Sand 8475' 6078, Top Lower Sand 8496' 6094' Base Lower Sand 8698' 6245' 31. LIST OF ATTACHMENTS ~,11 Hi~t-nrv I~,v~-n~rnn~-_ : r .~,,rv~y (? copies) 32. I hereby~c~rti~'y that the foregoing is true and correct to the best of my knowledge Signed / . ° Title Area Dri 11 ing Engr. Date /// . , ,i, '11 / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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 (G L) 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". ARCO oIl.~cl Gas Conlpmy C) Well Hlltory- Initial Report - Dally Im~lMimle ~ ind lu~mlt tim "IMiM I~IIM~' on-tM fll~. Wed~m~lly ~ I wMI ii G~ or wooer o~mlon, i~ ~. Ol~d~ Horth S~ope ~orough ~Le~ or Unit F~. ~ ~L #25587 I Auth. or W.O. ,o. ~ 103063 ~ Dr$11, Complete ~ Pe~oraCe IState Alaska Fell no. 2H-14 Operator ARCO Alaska, Inc. IARCO W.I. 56 24% JPrlor statue I1 I W.O. Spudded 7/09/84 1715 Hrs. Date and depth es of 8:00 a.m. 7/lO/84 7/11/84 7112184 7/13/84 Complete record for each day reported 16" @ 110' 1388', (1292') Navi Drlg Wt. 8.9, PV 13, YP 23, PH 9.5, WL 13.2, Sol 5 Accept rig @ 1330 hrs 7-9-84. NU diverter sys. Spud well @ 1715 hfs, 7/09/84. Drl 12-1'/4" hole to 491', Navi-Drl to 1388'. 49t', Assumed vertical 883'MD, 12.0°, S34.0W, 880'TVD, 40VS, 32S, 23W 1094'MD, 18.3°, S31.5W, 1084'TVD, 95VS, 79S, 53W 16" @ 110' 2860', (1472') RU csg tools Wt. 9.8, PV 26, YP 34, PH 9.5, WL 12.0, Sol 8 Navi-Drl 12¼" hole to 3860', 16 std short trip, C&C, TOH. 1305'MD, 24.5°, S37.5W, 1280TVD, 171VS, 142S, 97W 1628'MD, 27.4°, S41.0W, 1569TVD, 317VS, 255S, 189W 2218'MD, 38.5°, S43.SW, 2065TVD, 634VS, 488S, 405W 2750'MD, 48.8°, S45.0W, 2444TVD, 1005VS, 752S, 667W 9-5/8" @ 2839' 2860', (0') FshVg Wt. 8.5, PV 7, YP 12, PH 10.0, WL 10.0, Sol 3 RU & rn 69 its, 9-5/8", 36#, J-55, HF ERW BTC + 1 pup Jt + 2 flt its w/FC @-2757', FS @ 2839'. M&P 980 sx AS III w/l/4# cellophane flake, followed w/440 sx Class "G" cmt w/2% SI + 0.2% D-46. Displ cmt using rig pmps, bump plug. CIP @ 1400 hrs 7/11/84. ND 20" Hydrl & diverter lns. Lost 10# sledge in hole on ND. NU & tst BOPE. Fsh f/10# sledge w/Tri-State magnet w/skirt, TOH, no fsh. TIH w/flat magnet, rec'd sledge on fsh'g run #3. 9-5/8" @ 2839' 3900', (1,040') Drlg Wt. 8.9, pV 8, YP 7, PH 10.0, WL 9, Sol 5 TiM w/8%" BRA to FC, tst csg to 1500 psi, OK. DO FC, cmt, FS + 10' new hole. Conduct formation tst to 12.5 ppg, EMW, OK. Drl 8½" hole to 3900'. 2992', 54-1/2°, S46W, 2595 TVD, 1193 VS, 889S, 803W 3306', 53-1/2°, S46W, 2779 TVD, 1445 rS, 1059S, 988W 3772', 52-3/4°, S44-1/2W, 3058 TVD, 1816 VS, 1322S, 1253W RECEIVED The above 18 corr~t SIg natu re~'~'~~~ Date ] 'ntle 7/20/84 NOV 2 Alaska Oil & Gas Cons. Commission Anphnr,~nn ~- - Drillin~ Superintendent ARCO Oil and Gas Company Daily Well History--Interim Inltruclionl: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work perlormed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerlm" sheets until final completion. Report official or reprelentative telt on "FE~II" form. 1) Submit "Interim" sheets when filled out but not less frequently Ihan every 30 days, or (2) on Wednesday of the week in which oll string II let. Submit weekly for workovers and following setting o! oil string until completion. District Field County or Parish I Stale AlaSka North Slope Borough Lease or Unit Kuparuk River ADL #25587 Alaska IWell no. 2H-14 Date and depth as of 8:00 a.m. 7114184 thru 7/i6/84 7/17/84 7/18/84 Complete record for each day while drilling or workover in progress 9-5/8" @ 2839' 8622', (4722'), TIH Wt. 10.1+, PV 18, YP 15, PH 8.5, WL 6.8· Sol 11 Drl & surv 8½" hole to 8622', lost 600 psi, POOH found in monel. TIH. 4241', 52.6°, S41-1/2W, 3343 TVD, 2188 VS, 1595S 5080', 51.0°, S41-1/2W, 3860 TVD, 2847 VS, 2083S 5580', 50.4°, S41W, 4177 TVD, 3234 VS, 2373S 6078', 49.8°, S40W, 4496 TVD, 3616 VS, 2664S 7076', 49°, S37W, 5147 TVD, 4373 VS, 3246S 7606', 50°, S37W, 5489 TVD, 4777 VS, 3569S 8077', 47°, S36W, 5800 TVD, 5130 VS, 3852S 8271', 44.5°, S35W, 5935 TVD, 5269 VS, 3965S lk'g f/wshout, · 1507W , 1953W , 2208W , 2456W , 2940W , 3183W , 3395W , 3476W 9-5/8" @ 2839' 8873', (251'), TIH to cond hole for 7" Wt. 10.1+, PV 20, YP 15, PH 8.5, WL 6.8, Sol 11 Drl 8½" hole to 8873', CBU, 12 std short trip, C&C f/logs. rn DIL/SFL/SP/GR/CAL/FDC/CNL f/8871' WLM to 2839' (FDC/CNL f/8871' WLM to 8300'). Rn BHCS f/8871' WLM to 8300'. 8795', 41°, S39W, 6319 TVD, 5626 VS, 4249S, 3692W RU & 7" @ 8843' 8873', (0'), Displ cmt w/10.3 NaCl/NaBr Wt. 10.2+, PV 12, YP 7, PH 8.5, WL 7.1., Sol 12 Fin TIH, wsh & rm 8833'-8873', C&C, 15 std short trip, TOH f/7" csg. RU & rn 205 jts, 7", 26#, J-55, BTC csg w/FC @ 8750', FS @ 8843'. Cmt w/400 sx C1 "G" w/3% KC1, .8% D-60 & .2% D-46. Displ cmt w/10.3 ppg NaC1/NaBr using rig pmps. The above ia correct Signature For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 8Z ITille 7/20/84 Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on-the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when.ope~8~0na are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion ar~:l~'~'el~sentative test data in blocks provided. The "Final Report" form may be used Ior reporting the entire operation if space is available. ~. ~. ~. ~ -~ -~ District Alaska Field ICounty or Parish Lease or Unit Title Accounting cost center code North Slope Borough State Alaska no. 2H-14 Kuparuk River ADL #25587 Auth. or W.O. no. AFE 103063 Drill, Complete & Perforate Operator I A.R.Co. W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun ~Date Spudded I 7/09/84 Date and depth as of 8:00 a.m. 7/19/84 7/30/84 7/31/84 Complete record for each day reported I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well I our I Prior status if a W.O. I 1715 Hrs. 7" @ 8843' 8750' PBTD, RR 10.3 NaCl/NaBr Compl cmt displ'ment. CIP @ 0730 hfs, 7/18/84. Set lower pack-off, instl tbg head. Tst flange & pack-off to 3000 psi. RR @ 1200 hrs, 7/18/84. 7" FS @ 8843' - FC @ 8750' Pmp 250 sx AS I, followed w/58 bbls Arctic Pak. Rn CBL/VDL/GR/CCL f/8738' WLM-7200'. Rn GCT gyro f/surf-8725'. RECEIVED Alaska 0il & Gas Cons. Anchorage Old TO New TD PB Depth 8873' (7/17/84) 8750' Released rig Date Kind of rig 1200 Hrs. 7/18/84 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no, Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day i Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Drilling Superintendent $ UB-$ URFA CE DIRECTIONAL SURVEY F~-~ UIDANCE r~ ONTINUOUS [-~ OOL Company Well Name Field/Location ATLANTIC RICHFIELD COMPANY 2H-14 (S26, T11N, R8E, Ut'l) KUPARUK, NORTH SLOPE, ALASI<A Job Reference No. 69421 Logged By: J. WOOD Date 18-SEP-84 Computed By: H. HARTNUP K L.~ P A R t.I K averaqed Oe\,ldtlon a~d azi~,uth Phc,?,.iE:C'J. PO ,.~,','t'd A TARGE'~' AZI.:',~tJ'I'H aOUTH 39 D£G 5 MIN WEST ARCO AL, ASKA, INC~ K U P A R U K M£ASUREI) VI,iRTICAb I) E PTt 1 ~') E P 1' H 1 oO, O0 300, O0 40 {~, (,1 (.) 500.00 6 () 0, G 0 7{30.00' 80 (ii, C r~ 10 o o, o o 1 ! 09,0(.> 120o,00 13 O0,00 · , 1400, O0 15000, O0 160 '00 1800,00 1900,0(.,, 20()o 2100~00 22r)0, 2300 ..00 2400, O0 .250O. O0 2600,0(. 2700,00 2800, o(', 2900,0O 3000.00 3100,00 3200.00 3400,00 3bU(), 360(.), 37(.)(: ();, 3800 ~ O0 390o, U p {. ()0.0'0 .1 "J (), 0 ;) · 6gq,Og 79 ~ ,3 '7 . g94,24 t 'J 9 U, 1 ,) tlH4,2f) t '2 '1 ~.,, '1 ;t 1 .t66. b,l 145q.~ I 719,10 2128,38 2274'8~) 23,t4. rj.) 2410,4 t 2591.2,) 270a~54 2827~75 306q, 29 C <) t4 P U T A T I 0 i'~ ,S { ~; ."'" ., V~RTIC. AL DE~IAT].O,~ AZ i'~u'rii '1 b, 0 0 0 q 3 '7 s: '"; ;,o,., :a s 4 '1 '1 9 fi 67 t,R7 8 54 7.72;11 t2 19 8~9,24 15 1059,20 21 14 ti51,'d.a 23 57 t24,t,2,64 27, 18 [~B, 6'2 27 23 15~')b,~g 2B 35 1594,10 30 14 1845.84 35 38 2001:38 40 .2t 2.149,'86 45 12 2219,'L,[~ 4 7 21 22fl5,41 49 36 2~08,17 54 14 ~66.28 5'~ 23 2583,54 53 4~ '20'1'2,97 53 26 'J 102.75 51 17 2~23,26. 52 46 2')d3,81 b2 4'1 2944,29 52 b5 )004.0h ~2 52 [,)A'rE J 1 g-SE'P-B4 E: V E:~ 100 Vt!:NTICAh SECTION SEV F . ,, .I t) E', ¢1 (). 0 -0.02 0. Oh 0.27 1). b.6 1.36 3 ,'7.3 10.90 23,53 42.05 65.51 93,64 127.22 lhS.bJ 20B.79 ?55, '16 301 397 ,' 5 449.28 S 4~ 28 ~ 5(')3.50 ,S 49. 1] W 550.29 S 4,t JO ~t 61..9,89 .S 44 '47 W 682,86 ,q 4',) 2 w 74.9.04 S 45 I0 w 818.21 .-; 4'3 ?7 ~,,. 8'.1(.,.02 S 45 .18 v, 964,31 3 't5 .,%.' ¢,' 1{,"4l.]0 S 45 52 ~ 1120.99 1201,79 ~ 282 44 1442,7H 1522,54 16C:2,16 1681,45 17~.:0,73 184O. 10 1919.62 /100 (.), uO 0,14 u.13 O. 15 ill, 17 0,62 .3,54 3 .'06 2,67. 2 ,77 3 72 3 0', 66 1 57 I 91' I,H? 2~77 2,84 2.7'2 2,19 2,24. 2;21 2,08 0,46 0 29 0~53 O' o:]1 0,88. O, .%3 0 O, O, 1~ EET ,.u, 00 a 0;02 N 0,01 N 0,02 S "." 0 17 .S - 0 -7 025 o 0o' ,,E 0 OX'.' E 3 17 1 32 11 6 1 5 2,' 90 77.4.0 S., 105,95 S. 71 13'7,57 ~ 93 171.89 S 119 208, O0 2432:0'0 S 79 27t1.17 b 2.10, 59 'h 314,82 S :',. 243', 2 352,98 ,5 2'/.~', 03".'i"~ 392,6,9 $ 315 14.'W :.503 433.,77 S' ~354 64'.:'W ."560. ,1'76',5tt :$ 396 52 "W, .... 619 521,57 S 440 95':-W;.,..'.682 568e65 S 4~7 97',W'. 749 ~1' '. S'Y4( 617,7o 5' 537 22' W. '..'818 1'0'4~ 774~91 S 64""-' S 830.68 ~ 755,~1 ~. 1.122 87. s s ',s:.:.l'; 9~4.0q 8 fl71~84 W' 1.285,"01:".S'::'~ 1000¢84 S 929,35 .W.. 1365, lO57.'/1 6 98h,22 ~. 1446, 16' ',~ 4, 1114,52 ~ 1042,71:W,,,~1526~ 28 :,"8 ('41 1171,~8 S 109~,94' ~..'1606, 25 1228,49 S 1.154,5.1.:~ .1685, 85 ~.J 12~b.5~ S 1209,99 ~'1765. 43 1.34¢'0Y S 1265,05 W.-1845 1~0.:',20 S 1319,64 W,1924 " ' - '. ...... ' ' '. ..... -:'4>:; . ,.. ,,, , ,~. . ~ - , ., ·., , - "- ,. -c?... - 'L . , . ARCU AbASKA, INC. 2 H - 14 KUPA'RI~K N. L:~l,lJi':l": / At,."~,<.J',:/~ L$F, PTI! 4000,0 4100', O0 4200.0.(,~ 430O. O0 4400. (1 4500,0 4600. 4700. O0 48(.)0. 490O. O0 5000. O0 O. O0 {.). 5400. O0 5500, I:, ~', 560O. O0 5700 O~J 5800: 6000 6100'00 6300. O0 64U(,, 00 65~0, O0 6600, 6700, O0 6800, O0 6900.00 700~, O0 71UU. O0 7200.00 73o0,0o 7400, oc, 7600.00 7800.00 790O, 06 32501 .t$kl, 3372, .3494. 35'56, ]617, 3741, 3803, 3929, 405o1 . ! 24 H, 43~2, 43 'I P, 4. 4 d 0 . 4505. 4635. q '1 '.~ tl . 47fi5. 489~: qgo 2, 5027, h693. .5224. 5352: 6480, bS:th , %6!2. CO~PUTATI',.F~N [)ATE: ."[,'~It',!P(.II,ArEt) VAI,',I[,:S P'OR 19-8EP-B'4 I O(.) t. I~:['T v K R T I C A L ~,u;rh SECTION air. FI<FT ,, 4 ~v 2 ~ 52 ~ 55 ~ 41 25 49 .54 49 31 '1'~ 25 49 47. 4 g I 3 49 11 ,~c, 22 48 40 4 a 5'1 48 51 $ 42 S 41 $ 41 54!. $ 41 S ,10 $ 40 S 40 30 w 21 12. 58 W 39 2,.5 '. b~ 1 q) 7 '4 97 95 4 40 40 3 P, 20 15 15 16 '57 20 1999,07 2078.32 2~67,44 2236,55 2315.55 2394.50 2473.31 255i..87 2630,30 2708,56 2'786.69 286.4.46 2941.99 3019,23 30~6.29 3173 2~ 3250~2~ 3327.15 3403,99 34~(..).71 3557,31 3o33,54 37{)9.56 37~5,53 3937.37 4013' ~0 4o e:. 2 '11f'i3,84 '4239.30 4314.62 4390.11 44~6,0'1 4542.30 4618,94 4695.75 4772.67 46g~,6~ 4923,00 ~996.6~ 39 19 14 3 1 53 37 ~7 37 't7 37 31 36 D ~':(, / it:C; RIT'Y 0.23 0,35 0.28.' O, 53 (1,27 0.36 u, 2.7 0/.70 0.39 O. 54 0 ~40 O,hl 0~17 0.62 0,5[, 1,24 0.15 0.6 0 0,70 0,90, ,94 · .40 0,43 1,40 1,07. 1.68 0,67 0,64 -, F E (-.; T F !:.; E.T · ,,. · 1'~,5.9 39 8 1.374'03 W 1517'.4~t $ 142:,8,.26'.W.:~08 1675.3~ 1.6~3,24 ,S 1536,'64.,W.2 17.49, '01. 8 164. 4 i 65 .:' W:':: 2 1806, ~:0' 1864;47 1979.59 ~ 1.858~91'.~,:'W'::2 203~ 08 2153.35 2211~bU 2269,5~ 2327,69 2385,~5 ~44.02 2502,28 2500,59 2(!;1~.90 2677,10 2735.0~ 2792,9'1 2850,96 290 71 29'6~ 54 3O24 72 308.3 32 3142,36 3201,52 3261,06 3321,08.$ 338ii725 344 77 35C, ' Ob 3565,60'$ 3626,22 3685 22 3744:¢,9 PAGE 1.91.2,05 . W '27 1963,94 W 28 2~J5,22 W', 29 2C'e, 6.1,4 W. 30 211'6; 86..' t~. 3103, 2167,44:.W 31'8.0.. 56: 221,7'. 97 226~.27 W. 333'4 23,8,~ 24.1~,02 W~ ] 2467,29, 2.664, 04 W.:"'~944 3~';'::,~'~"':.~4 271 95 W'":4020 ~ 01 .'.':, .&".'.4S 276 W' 4095 280 t'~"" ~." 4'170 ~2';~ 2855,28 W 4245 290~u,91. W' 43'2'0' 294 ,34. W .4396 2994',83 .W 447'1 3041,17 W 4548 3087,57'.' W 4624 3~ 33,97 W 470 1 3] t~O, 31.',.'W .:.4777,. 3226,01 '.W4853 · 3271.36 H 4927 3315,73 ~ 500% . k:.. 83!,:. s. '9.7 ::::.,]: 8:" o95':., s: 41 48:: 78., ?'. 51: S..4 ARC[~ AbASKA, /NC.. KUPARUK N, $ I.., {' t:" I.::, /~, ;..,, 4 .g I', :', '.[' rt., MEASURED YERT.[CAL DE': [" 'i" }'. , ~, E ~ 'l'lt 810 ('. 00 % 81 f), '15 8300.00 8500,00 8600 ~.. ~'Z~,.J,'~ 870O :,,0 ~246,36 8873~o~, ~375..b2 CO~:PI)TA'I'IOh DA'rE: VERTiCAl.,.' DEV~['ATI(}N AZ,[ I>1.:' ~'"'1H [.:E(.; ~'~ I' r., 583!: : '.':': 7 fi902,9.9 44 2~ 5974o8'0..::.. 4 ]....i.'54 612 , 6250%52 4~ 42 i'.'i d '].' t.'~ SECTION SEVERITY !)~, {; "[~ I-'EP."I L)E:(.;/I $ 36 17 w 5142,62 S .~ 8 ~ 5214,2'l S 36 10 W. 5285,08 S ]8 56 W 5424,9] S 3~4 5,.)~'~ 5493.77 S 3B 39 ~, 5561.00 S 38 3.9 ~, 5627 53 S 38 39 w 5676[09 ~,06 1 ,'0.72 0,0(:' DATE []F' ~UR'VEYI ]i'"'.dUhy KEbI,,~' ~U~HING EI,EVATIO FNG] NFk:R :.:'. ~OOD ,.~:....~...,. ::".. ~,"t~.ASIJHE~' DEPTH ~91.9,2.3' :~ '3445,25...W 408':7 ,. 89...< ~ .> 35' ~ 1..'~..71,~;'~:;.W::? 5'~2 8 42~5,7'1 .~, '.3t..~)8 ~68~:..','W. 56]0 4283~70 ,S '3729.,02'"W 56'79 ARCO 2H- .1. KUPAR(Jfi MEASURED VEblT TCAL, D [': [.,,' '.r H I (). 0 () (). (.)() -, 1 2 .,5 1000,00 9YQ,2'~ B69 2000,0(., '1~¢~,,,7 [76't 3000,00 25'gl ,.~B 2466 4000, . . . 5000.00 3803.92 3678 600'0, (~o 7000.~0 5093.55 496~ B 000 ()0 ') 7 '48, '? 2 '5 (, 2., 3 BB';3: 00' 6375,52 b250 CL,~PUTA ION [)A : I. ~., 'J.' I< R i' !..: [, A '!.' 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J.,',l"i.~J.,,~:.'fl,;l~ VAJ.L~I':..,5 VERI'ICAI~ VER'fICAL.:.:::.DEVIATII)N AZ]:NUTH F;'!';PTH I'.)E'(; r,.', I. ;,; ~1'25.00 4325:00 4525.00 & 525, C,O 47~5,00 5025,00 5125,0u 5225.00 5425.00. 5525,Uo 56~5,00 5725.()(i 5825,00 5~25,00 4900, O0 5100,00 S ? ,'.) .('~ ,.(!) 0 530(~.00 5 <% (~ ('1 ~ ~ (; 5500. O0 560(~ ~ ('i(; 57O0.00 5 H t{.(",, () 5900, Ou bO00,O0 6200. UO ~25(~ . 52 48' 52 '} <' 9 49 35 5(~ 5 .50 15 47 46 47 4 46 t6 4 b q 44 ,9.,7' 43 40 4) b'7 41 42 41 42 $39 5 ~ S 38 39 w 5 3H 3q ~, (':. (~ 2 b, 0') 6125. oo (,2'~5,0~i 6325.00 ~,, ~,375, '" I)Al,'i~: OF SURVEY{ 31 JUL, Y I<'{,;L.LY EI.JSH1NG' ELEVATIO I;N(;Ir~EP;H: WOOD i,: t/ }:. t' , :](')(~ l'E[';r i,;F' ,';t,l.~,.':5'kA L)EP'I.'H E i~ T I. C SECTION t,' I? 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'~ .' . ARCO ALA[~KA, I'NC. KLIPARI~K N A R E E R T{tF. LiP[,ff, t~ ;3Ar!b BASE UPPER SANf~ f.L'[:p [.r)~, I;.P COP, PUTATI'.Ur.~ I.,A~..'.: 'l, DA'I'e~ OF SURVEY: ,31 dU,L,Y .KI'~LI.,¥ B~.i$~ING ELEVATION 6078.38 bo94.06 6?.44.87 6375.5~ , 5944.b~ 595.~, 38 5969 ~ Ob 611.9. 625O.52 FEL, SEC..2 RECIA'NGU~A 'NORTH/SOU 4065,t2 4087 4~9~ 42'8'],- ARC(:) ABASKA~ 2H-t q. KUPARUK MARKgR BASE [,('~W~;R SAND TOTAL b/EA~bRI~:D VF',R T lC/Il, I) E IF' '[' !~ t.,', [:. F: q.' !.t ' · t~73.~';~. 0.I'75. ~57, ' v E:RTI CAL ~,2 b(? 5'2 8873.00 t~07~. 38 6244 6375.'52 L) I STAt,:CE AZI ~'td TH St.,/9.q I 1, .'1.1 2 DA.TEyU[',SURVEY;' 31 .auhY'-'lg. 8,' K f,: I,: I.., USHII~G ELEVATIONI . :,, ,, ,,:, , ~. ?.,,.~ ~.~ I'. G I r~ E'ER: ~ 0'0 D t. } k ,l G I'. ~,~ = 1 1 0 ' F 31.,, TV D S u 'B .. $ F. h 5953,38 61 19.87 61 5H, 69 6250.52 SORFACE I, OCATI'ON A 054 'FEI,. SEC 26~ RECTANGUSAR NORTH/SOUTH ~065.12 S 4:087 '~ 41929 0 ,5 4283 70 '$ SCHLUhlBERGER ARCO ALASEA. 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ARCO Alaska. -' -. -; '.c:..._ .c-C'.- 2"7 5C37 Date: 10~/~84 Transmi'ttal No: 4765 Return To: · ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B , P.O. Box 100360 TnZAnchorage, AK 99510 nsmitted herewith are the following items. Please acknowledge receipt return one si~ned copy of this transmittal. CBL' s FINALS/Schlumberger 2V-8A "Variable Density" "GCT" 2G-1 -'~ " " " 8/01/84 Run 1 8/27/84 " 7400 - 8909 5151 - 7991 2G-2 / " " " 2G-3 " " " 8/27/84 " 8127184 -:" 4275 - 6536 5950 - 8526 2G-4 _. " " " 8~27~84 " 5070 - 7650 2G-8 -- " " " 7/31/84 " 6500 - 7830 2H-13 '-' " " " i4 ' 2H- / " " " 7/30/84 " 7/30/84 " 6100 - 7720 7200- 8732 7/30184 " 6100- 7422 2H-16 . " " " '2D-11 -~ " " " 2D-9 ~' " " " 2D-12 / " " '" 2D-10 - " " " Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE 7/30/84 " 8/25/84 " 8/25/84 " 8/25/84 " 8/25/84 " DISTRIBUTION W.V. Pasher G. Phillips Drilling ~ Phillips Oil Geology Mob i 1 J.J. Ra thmell 7000- 8410. 5900- 7588 6700- 7768 6900 - o~oo .~ ;,. ( '_.; ./, - 6 '- ~ . L ~ '. ~. Alaska Oil & Gas Cons. Commlssk C. R. Smit~ ' State of, Alaska' Sohio Union Chevron NSK Operations Well Files ARCO Alaska, Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 20, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the Monthly State Reports for the following wells: 2G-1 2H-13 2D-10 2V-8A 2G-7 2H-14 2D-11 2B-4 2G-8 2H-15 2D-12 Thank you. Sincerely, J. B. Kewin Area Drilling Engineer JBK: ih L01 06/28/84 Enclosures RECEIVED AUG 2 719 4 Alaska 0il & Gas Cons, C0mmisslon Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfleldCompany ~---. STATE OF ALASKA .... ALASK,..)IL AND GAS CONSERVATION C ,vlMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well E~X Workover operation [] 2. Name of operator ARCO Alaska, Inc. 7. Permit No. 84-95 4. Location of Well at surface 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 103-20036 9. Unit or Lease Name il0' FSL, 654' FEL, Sec. 26, TllN, R8E, UM Kuparuk River Unit 6. Lease Designation and Serial No. ADL 25587 ALK 2673 5. Elevation in feet (indicate KB, DF, etc.) Pad 95, RKB 125 10. Well No. 2H-14 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. July , 19__84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud well @ 1715 hrs 07/09/84. Drld 12-1/4" hole to 3860'. Ran, cmtd & tstd 9-5/8" csg. Lost sledge dn hole. Recovered fish. Drld 8½" hole to 8873'TD as of 7/17/84. Ran log. Ran, cmtd & tstd 7" csg. Secured well and released rig @ 1200 hrs 7/18/84. Performed Arctic pak. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 9-5/8" 36# J-55 HF ERW BTC csg w/shoe @2839'. Cmtd 980 sxs AS ~II & 440 sxs Class "G". 7" 26# J-55 BTC Csg w/shoe @ 8843'. Cmtd w/400 sxs Class "G". 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/GR/SP/FDC/CNL/CAL f/8871 '-2839'. BHCS f/8871' to 8300'. 6. DST data, perforating data, shows of H2S, miscellaneous data 'CECEIVEb N/A lUaSka U,¢ g Gss Cons. 4ncl~orage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~,.'r(--/ -- .,~,I / ',.,~, .)/ Area Drilling Engineer SIGNE~ ~ 7. A~ )~_~~ ~~ /~TITLE DATE NOTE--ReporVon this fore requ~d fore'ch calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation~mmissiSn by the 15th of the succeeding month, unless otherwise directed. Form 10404 / UTT f /~1 ~ Submit in duplicate ARCO Alaska. Inc. . ,. -:; ".o:'~ 9.'-' 277 S. L37 Date' 8/17/84 Transmittal .No' 4689 Return To' ARCO .ALASKA, Inc. ATTN: Records Clerk ATO-11!5B P.O. Box 100360 /~A_nchorage, AK 99510 ~/Transmitted herewith the following items. andreturn one signed of this transmittal. copy OH FINALS/Schlumberger 2H-14 2"/5" DI-SFL/GR Run 1 7/16/84 Please acknowledge receipt 2838- 8866 2"/5" BHC Sonic/GR " 1! 2"/~'' Density Neutron "Poro" 7/16/84 8250 - 8856 7/16/84 8250- 8845 7/16/84 8250 -. 8845 " CPL Cyber!ook " 7/17/84 8250 - 8830 /cat Receipt Acknowledged' DISTRIBUTION ]Pate · B. Adams F.G. Baker P. Baxter BPAE D&M W.¥. Pasher Dr ill ing G. 'Phillips Geology ~~Phillips Oil Mobil J.J. Ra thmel~ C. R. Smith State of Alaska Sohio Union Chevron NSK Operations R & D Well Files KUPARUK ENGINEERING-- Type of Tape Date ._ .- . Tape Number DISTRIBUTION State of AK Geoiogy/C. Smith OH LIS Sign & return the copy as tee ' ~t ~f ~.0. Box 100360 ~chor~ge, ~K 99510 Return to: Please note: Blueline, Sepia,~ Tape, Photocopy MEMORANDUM TO: THRU: FROM: State of Alaska ALASKA OIL A~ GAS CONSERVATION COtJRMISSION C. V/~terton DATE: FILE NO: Co~ssio~er " TELEPHONE NO: Bobby Foster SUBJECT: Pet~o~e~ ~nspecto~ July 18, 1984 D.31.36 Witness BOPE Test on ARCO' s 2H-14, Sec. 26, TllN,RSE,UM, Permit No. 84-95 Wednesday, July 11, 1984= I traveled this date to ARCO's 2H-14 to witness the BOPE test, The BOPE test began at 10..00 pm and was concluded at 11:30 pm. As the attached BOPE test report shows, there was one failure which was repaired and tested before I departed the location. In summary, I witnessed the BOPE test on ARCO's 2H-14. Attachment 02-00IA(Rev. 10/79) STATE OF ALAS}%\ ALASKA 0?~. & 'CAS CONSERVATION CfMMISSION B.. P.E.. Inspection Report Drilling Contractor ..~-~~~ location, General_ · C~neral Housekeepina . BOPE Stack ~'~:'~- ] "% " · · ,, Annular Preventer':, Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Test Pressure Check Valve : Test Results: Failures. ' ' ' / ACCUMULATOR SYSTEM _ Ful 1 Charge Pres sure :/~z~ psig Pressure After Closure /~O psig Pump incr. clos. pres. 200 psig mi~J~ sec. Full Charge Pressure Attained:_ ~ min/~ sec. Controls: Master. .L~ J Remote, ~ Blinds switch cover ~c-~ Kelly an~ Floor safety V~v~S · Upper Kelly aii 2ype / Ins ide BOP / Test Pressure Test Pressure Test Pressure. Test Pressure Choke Manifold y~ Test Pressure No. Va_Ives. ~ No. flanges · Adjustable Chok~ I~fdrauically operated choke Test Time' / Repair or. Replacement of failed equipment to be made within Inspector/Ccramission office notified. - .days and Distribution orig. - AO6X3CC . cc - O~erator cc - Supervisor July 3, 1984 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Kuparuk River Unit 2H-14 ARCO Alaska, Inc. Permit No. 84-95 Sur. Loc. IlO'FSL, 654'FEL,' Sec. 26, TI1N, RSE, UM. Btmhole Loc. l146'FSL, l179'FWL, Sec. 35, TllN, RSE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Mr. Jeffrey B. K~_in Kuparuk River Unit 2H-14 -2- July 3, 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a dtverter system ts required., please also notify this office 24 hours prior to commencing equipment instillation so that the'Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance no,afloat!on so that we may have a witness present. Very truly yours, Lonnie C. Smith Commissioner of Alaska Oil and Gas Conservation Commission be Enclosure Department of Fish & Game, Habitat Section w/o encl. DePartment of ~nvironmental Conservation w/o encl. ARCO Alaska, Inc. Post Office 6 i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 26, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2H-14 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2H-14, along with a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat ° A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment Since we estimate spudding this well on July 8, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. ~ ely, JBK/J /tw GRU8/L14 Attachments RECEIVED JUN2 8 Alaska 0il & Gas Cons. C0mmission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~' ALASKA (.,,b AND GAS CONSERVATION CO,,,MISSION PERMIT TO DRILL 20 AAC 25.O05 la. Type of work. DRILL J~X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~X DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0, Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 110' FSL, 654' FEL, Sec.26, T11N, R8E, UM At top of proposed producing interval 1379' FSL, 1368' FWL, Sec. 35, T11N, R8E, UM At total depth 1146' FSL, 1179' FWL, Sec. 35, TllN, R8E, UM 9. Unit or lease name Kuparuk River Unit 10. Well number 2H-14 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.} I 6. Lease designation and serial no. RKB 125', PAD 95' I ADL 25587 ALK 2673 12. Bond information (see 20 AAC 25.025) Federal insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse 2H-15well 60' ~ surface feet 16. Proposed depth (MD & TVD) 8665' MD, 6360' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 500 feet. 21 Distance and direction from nearest town 14. Distance to nearest property or lease line miles 1146' ¢TD feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLEANGLE47.5 o (see 20AAC25.035(c) (2) 18. Approximate spud date 07/08/84 2829 psig@ 80°F Surface 3175 _ psig@ 6225 ft. TD (TVD) Proposed Casing, Liner and Cementing Program sIz E Casing Weight ~-5/8" 36.0# I 7" J 26. O# I CASING AND LINER Grade Coupling Length H-40 Weld 80' J-55 BTC HF-ERW J-55 BTC 8637' HF-ERW 22. Describe proposed program: SETTING DEPTH MD TOP TVD 29' I 29' I 2937' 29' 29' I I I 28' 28' I MD BOTTOM TVD 109' I 109' 2966' I 2505' 8665' 16360' I I QUANTITY OF CEMENT (include stage data) ± 200 cf 980 sx AS III & 440 sx Class G 400 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8665' MD (6360' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak Sands at approximately 2966' MD(2505' TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2829 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed, by the-workover rig, with 3-1/2", 9.2#, J-55, 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) -23. I hereb~ certif~¢~ The space ~s~on use ~at the foregoing is true and correct to the best of my knowledge TITLE Area Drilling Engineer DATE Samples required I Mud log required []YES ~'-NO ! DYES lXNO Permit number APPROVED BY Form 10-401 CONDITIONS OF APPROVAL J Approval date 2¢- GRU8/PD04 Directional Survey required J APl number ~,ES []NO 50- lOS- Z~O0,~(o SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE.T~Iy 3; ]984 by order of the Commission Submit in triplicate PERMIT TO DRILL 2H-14 installed and tested upon completion of the job. 2H-14 will be 60' away from 2H-15 at the surface. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at 7258'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. RECEIVED JUN2 8 191 Alaska Oil & Gas Cons. Commission Anchorage I. . f. OOO ~:: ' III i!1 ' ~ 'i ~ I ' ~ !~] ~ I ~i i ' ' I I ~ I I - - ! - ~ I ~ ~i i-. i!i~ ''~ ~ii ' ' i ~ ~ ~ - - i i! i I ~1 ',~, ~:~-~:-~ t·'" "i" " ' " " 'r"~i-!~' '~' ......... ,'i-~-- ' ~: i'';i !11 ~' ~I' i' L_~ i~i ; ..... 1 I'i ~ i [~ ' .i~ ~,,. .... ill ~ ~ ~ ~ :~ ~ ~:;~, ~;-~: , i :~,:~ ' I ~ I ~ i ' I I i I i i ' i ; I I ~ i i ii' ~;~'~ i i~ I I i ' ; ~ i~ i ! ] ] ~ ~ I .. ~ ~ ~ ..... ~ i ~ . ...+__~ [~$-~ :i+.~ ..... 7 i i~ ..... .... ~+ ... , "'- .... _ ;: ~ ~ ~ ; , _ ; ~ i i I ~ : i ~.~ I~ !-~~ , ; ~ ~ Z~ "_~' ;~i i ~ ' ~ i ~ ' ' ' : ' ' ' -- .... ' ~_~ , , . ' ' ; ' ' - i ~ · . '~'~;'~ .... t.~ ...... ".- ~ ~ii l~ ~i.~ ~ ;~,. ~ : .... i :,--.: .......... :.., '-': ........... .~!'--~ I~-~;~ ~ i i:l ,:. i~ '. ~,:, ~i.'.... -t ..... ~ ..... ~'"""; ........ ~ .......... T"~ ] ~ ~ ' i i i , ~ : :, ~ ~ i i~ ~ ii~ ! i i I i i i ': I i i ' ..... + .............. i ; i ; i i i :' ~-~' ..... : ...... ''~~. ''' ~ill ' ~' "- . , , ............ ~ ........... 7' -~-'~7 ~ : ~ .: '. ; i ~ ;. iii ~i i i i/I ' ..... ~ .......................... _.. ~ ~ ~ ~,~ . , ~._,~:. ~_~. ...... ~ ............... : ....... ~'~.,~;.~ ~,~;- "~i~-~ .~ ~ ...~ .... ~:.-'- .... ~ ............... ~ ................ I~,'~ ~'-~'~ ~: ~'~ : ~'" ' ' i~i~- '~ i i'i~-~ ~ --- · .~--~; ...... ~:~ .... ;::..::~::~f: ~-i_ !'~i,, ~::~;~ ~., ~ :~;~ ..... ~ .... ~_~.- ........... : .............. '~'~ ~ ~' ~ ~'~ '~ ~-t.> !i+t,r~-~'::'"::': ...... '~'~ ............. ; ............. ._.~. ~ ~ii ~,~ :~.~ ~' ~ ..... . , ,...-.."- :.-. ......... . .... ,~.~.-;_,.~. ~:~ --~ -~ ~; ~ ................... ? ~ ~ ' : i ~ :. ~ : l~i.~i ~'~~ : ...... -*~,~i,~A''i'i-~ .:.~: ~[~i~ ':~:' ....... ~:i~: ':;;'~ ~:: ~ - ~ :~': ''~ . ~;;... ;~-.. . ~- .: ~.? .... ~ ~ ~-~ ~.~.~-~- , i , , ' ' · I " :'.:.~.i ~.: ........... ~..lii: ~i,'~- ~-;;:; '" ~ -- ....,.;--.. ,ih.:, .;";:';~ ,~-:- ......... . . ; ;. .......... . , : , l, ~ ~, ~-, -~*- :' ~ i'i ~.-i, i"4 i I:i i. , I' /i '~ i i' I'"i~'i i :] ~ , i'i-; : ~'-:. ........... , : . ... i?V~ ~- t) i '-i i :i~~T ~ r~;~:';: ::?:i'~:' ~: ~ '~ :~' ' ~ .......... ~-~'"f-~k..~ :---l'i ~ ~ i~i .i .~::~.i.iL:~.-i .; i ? i_:i?'~. .;-i ~ i ~'ts~; ..~.' "..~?~-;-. ~ ...... , .... ~.~'l:~ ~;] .: ~. J ,.: .~.~:i~i_' :~;;..,:~ .~:.i;>i...>i:::I- ~ ............ ..... Iff~., : :-~ _-, . , I ,. ...... w-q:~. 'F~'.~::'~-' +<X:~':~':~?; ~ ~ ?~dm , :'~ ~ ~;:'~,~ ~,!~~ ~* ~ ......... ~mmmm~ i 'ANNULAR PR£¥ENTER ' PIPE 8 f BLIND 5 DIAGRAM ~.1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" * 5000 psi drillin9 spool 5. 13-5/8= - 5000 psi pipe rams 6. 13-5/8" - SO00 psi drilling spool w/choke and kill lines 7.- 13-5/8" - 5000 psi pipe rams B. 13-5/8" - 5000 psi blind rams g. 13-5/8" - 5000 psi annular ACCUMULATOR CAPACITY TEST '1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTRF. J~M OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETR.ACT- ED. PREDETERMINE DEP'rl.i THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENq'ER AND VAL'v]~S Ul)S~ 01= CHOI<]~S. DON~T TEST AGAINST CLOSED CHOKES 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD 'FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 B. ~.~'PRESSURE DOWNSTREAM OF CHOKE ISOLATION VALV~S~ TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSi. 11. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING jOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. lZ. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSi WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. RECEIVED JUN 2 8 lgB4 Alaska Oil & Gas Cons. Commission Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick Connect assy. 3. 16" X 20" 2000 psi double studded adapter. 20" 2000 psi drilling spool w/10" side outlets. 5. 10" ball valves, hydraulically actuated, w/lO" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 6. 20" 2000 psi annular preventer. 7. 20" bell nipple. im Maintenance & Operation 1. Upon initial installation close annular preventer and verify Ghat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 1 6" Conductor RECEIVED JUN2 819B Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, In Post Office : 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 ,april ~, }984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive 'Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Wells 1-4, 13-16 Dear Elaine: Enclosed is an If you have any Sincerely, ~'~J. Gruber Associate Engineer GRU6/L86: tw ! as-built location plat for questions, please call me Enclosure Plat - 2H-Pad the subject at 263-4944. wells. ARCO Alaska. Inc. is a Subsidiary of AtlanticRIchfleldCompany '~ Z Z 0 Z Z W LOCATED IN SECTIONS 25,26,35,36 TII N, RSE, UMIAT MERIDIAN. O;il!--J. _SITE 2-H CO[:DUCTORS UILT LOCATIO;]S ~LL I y: 5,948,973.183 Lot.: 70°16'18.548 ' X: 498,414.8509 Long:lSO°O0'46-153 16' FWL III'FSL 99°- Pod 94: 0.0. WELL2 y= 5,948,975.152 X= 498,474.8509 76'FWL III'FSL Lot= 70°16' 18. 5478 Long.= 150° O0' 44.406 98! Pod 94-*0.6. WELL 3 Y = 5,948,973.162 X= 498,534.7709 136' FWL III*FSL Lot.=70°16'18.548 Long.= 150°00'42.661 999 Pod 94~- O.G WELL 4 Y =5,948,975.110 X: 498,594.8709 196'FWL III'FSL Lot.= 70° 16' 18.5476 Long.= 150°00'40.912 99! Pod 95-o O.G. WELL 13 Y:5,948,973.012 X: 497, 685.0009 714'FEL IIO'FSL Lat. = 70°16'18.5444 Lono. = 150001'07. 95-o Pod 90-O O,G. WELLI4 Y= 5,948,973.050 X= 497,745.0609 654'FEL IIO'FSL Lo t.: 70° 16' 18.545 Long.=lSO°Ol'05.654 95°- Pad 90-00.G. WELLI5 Y = 5,9 48,973.018 Lat. = 70° 16'18.5449 X: 497,804.9509 Loncj = 150°01'03-911 594'FEL IIO'FSL 95! Pod 91°-0.6. WELL 16 Y = 5,948,973.067 X= 497,865.0209 534'FE L IIO'FSL Lat. = 70° 16'18.5455 Ler~= 150°01'0Z.162 94~ Pod 91.-° O.G. I HEREBY CERTIFY THAT I All PROPERLY REGISTERED 8~ LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASI(A & THAT THIS PLAT REPRESENTS A SURVEY' MADE UNDER' MY DII~ECT SUPERVISION 13 THAT ALL DETAILS ARE iii i I AR-C-o Ak:sko, Inc. Kuporuk Pr'oject North Slope Drilling DRILL SITE 2-H " CONDUCTOR AS-BUILT_ LOCATIONS Date: 4-1-84 Dro~:jht~: M C./LsN la,_. 0! Scale: 30 D'~. no.: NSK CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE Company Lease & Well No. YES NO REMARKS (1) Fee (2) Loc (2 th'r'h 8) (8) (3) Admin ~'~ ~*Z~-2~ (9 thru nd 11) _., (4) Cas~ ~ -2-9-~ ~(12 thru 20) (21 thru 24) 1. Is the permit fee attached .......................................... ~/~__ at 3. 4. 5. 6. 7. 8. 9, 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Is well to be.located in a defined pool ............................. ~ Is well located proper distance from property line .................. ~ Is well located proper distance from other wells .................... ./~K Is sufficient undedicated acreage available in this pool ............ J~fl Is well to be deviated and is well bore plat included ............... ~/~ Is operator the only affected party ................................. Can. permit be approved before ten-day wait .......................... ~/~ Does operator have a bond in force .................................. ~f Is a conservation order needed ...................................... Is administrative approval needed ................................... Is conductor string provided ........................ ~ ............ ... Is enough cement used to circulate on conductor and s rface . .. Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ................. -~g... Will all casing give adequate safety in collapse, tension and.b.~ t Is this well to be kicked off from an existing wellbore . Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ......................... Is a diverter system required ....................................... ~. Are necessary diagrams of diverter and BOP equipment attached ~o Does BOPE have sufficient pressure rating - Test to ~~) psmg .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: Geology: H~ /~ ,,, j~__---- En~n~e~e~ing: LCS ~e. OBEW JKT~ HJH d~,:' rev: 12/08/83 6.CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. o 8 'i985 COns. Cemmission ~nChorage 000 O00 016 065 000 000 0 '.1. 4 065 000 000 008 06.5 00 ~,') o 00 002 065 000 000 004 065 000 000 002 065 oO0 (.)OO 012 065 000 000 006 065 000 000 004 0(~5 000 000 001 065 4,, 03 :i 3 t',,! P l-t i 3.0742 i [, D ] 1. 9.000 0 {.:~ "1' 3.93 i b ~P~'{I ti, 4 i c, 2 1, I., £ ~ 92, ] 25L; L')T 124,50 :.~ f: ['.~ T b, 726 t:. k~: r"~ b 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 68 00000000000000 I 68 00000000000000 ,1, 68 0000('1000000000 1 68 00000000000000 I 68 O000000000(>OOO 1 68 O0(}O000000O, O00 I 08 00000000000000 ,l 68 00000000000000 ,t 6~,~ O00000000000OO 1 68 00000000000000 1 68 O000000000OUO0 1. 68 00000000000000 1, 68 OUOOOOOOOOOOOU I 68 OOOO0000000000 -999,2500 Its 95,5000 G R - 999,2500 DI<: Fi 0 '999,2900 NC, NL -999.2500 114,5625 -999.2500-999,2500 104,1875 0,0493 1946,0000 2,7 g 69 I b ~l 99.8125 GR 2,4029 DRHO 4-4,4824 NCNL 2,84'57 120.8750 0.0615 1941,0000 15.3438 lb~i ~9.2500 GR 2.2891 URN5 29.8828 NCNL 16,7188 6'1.18'75 0,0239 2850,0000 4,453 1 I [,,, 91. ,6875 2. 4258 30.5175 4,5078 86.8125 0,0605 2396,0000 1,7061 IhB 113.8750 Ga 2,3202 ORi-iO 53,5645 NCNb 1,'1461 134.5000 0 0459 1820~0000 L"~ I'I 111 ii1 iI:~ i~,_. 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