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Home My WebLink About213-077 (2-5-8 1 3077 '= 1 3076 21 3076 76 25875 25874 BAKER PRINT DISTRIBUTION LIST HUGHES Please sign and return one copy of this transmittal form to: DATA LOGG C E I V E D COMPANY ConocoPhillips Baker Hughes INTEQ � /l5/zot (mandatory) 795 East 94th Avenue M K.BENDS WELL NAME 3C-09L1(C-09L1-01PB�3C-09PB2 Anchorage,Alaska 99515 JUN 0 3 2015 (ma i�al,rtl) FIELD Kuparuk River Unit to acknowledge receipt of this r data. O�C(mandato COUNTY North Slope Borough LOG TYPE LWD-Coil (mandatory) (mandatory) STATE Alaska BH DISTRICT Alaska (mandatory) (mandator LOG DATE: March 30,2015 TODAYS DATE: 2-Jun-16 DISTRIBUTION LIST AUTHORIZED BY: Paula Lacey EMAIL: paula.lacevCo�bakerhughes.com (mandator HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No COMPANY CD FIELD FINAL (digit FFinal Final nal ADDRESS(FEDEXWILL NOT DELIVER TO P.O.BOX) LOGS LOGS Survey/Logs Surveys PERSON ATTENTION #OF PRINTS #OF PRINTS #OF COPIES #OF PRINTS V v U U 1 ConocoPhillips Alaska Inc. 1 1 Karen Hipsher/Lynn Hallford NSK 69 700 G Street Anchorage,AK 99510 2 BP Exploration(Alaska)Inc. 1 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:Analisa Steger 3 Chevron/KRU Rep I 1 1 iAttn:Glenn Frederick P.O.Box 196247 ,Anchorage,AK 99519 4 State of Alaska -AOGCC 1 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 1 I Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR TOTALS FOR THIS PAGE: 0 4 5 0 0 0 TOTALS FOR ALL PAGES: 0 4 5 0 0 0 L 1 3 0 7 '; 4-7-1 30 7 % 2 1 3 0 76 ,C- 1573 :, 25736 25737 BAKER PRINT DISTRIBUTION LIST HUGHES Please sign and return one copy of this transmittal form to: COMPANY ConocoPhillips Baker Hughes INTEQ RECEIVED (mandatory) 795 East 94th Avenue DATA LOGGED WELL NAME 3C-09L1;3C-09L1-01PB1;3C-09L1PB2 Anchorage,Alaska 99515 51za/2ospR 2 7 2015 (mandatory) M.K.BEN FIELD Kuparuk River Unit to acknowledge receipt of this data. AOGCC (mandatory) 1 COUNTY North Slope Borough LOG TYPE LWD-Coil (mandatory) (mandatory) STATE Alaska BH DISTRICT Alaska (mandatory) (mandatory) LOG DATE: March 28,2014 TODAYS DATE: 23-Apr-15 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: Paula Lacey EMAIL: paula.lacey@bakerhughes.com (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No COMPANY FIELD FINAL CD Final CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #Ur PRIN 1 S #OF COPIES #OF COPIES#OF COPIES a a a a a a a 1 ConocoPhillips Alaska Inc. 1 1 Attn:Ricky Elgaricio ATOS-344 MAY 212015 700 G Street SCANNED Anchorage,AK 99510 2 BP Exploration(Alaska)Inc. 1 I Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:Dodie Stinson 3 Chevron/KRU Rep I I 1 I I I 'Attn:Glenn Frederick P.O.Box 196247 Anchorage,AK 99519 4 State of Alaska -AOGCC II 1 I 1 I Attn:Makana Bender 333 W.7th Ave,Suite 100 'Anchorage,Alaska 99501 S,DNR-Division of Oil&Gas *** 1 1 I Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR TOTALS FOR THIS PAGE: 0 4 5 0 0 0 TOTALS FOR ALL PAGES: 0 4 5 0 0 0 Image Project Well History File Cover Page 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. c _13- 0_ _ Well History File Identifier 7 7 Organizing (done) ❑ Two-sided ❑ Rescan Needed /CAN: OVERSIZED: NOTES: olor Items: ❑ Maps: Grayscale Items: /gs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: 01,40 BY: MED Date: /s/ Project Proofing BY: 112, Date: /6 I f Is/ Scanning Preparation 3 x 30 = I O + I I = TOTAL PAGES / dt (Count does not include cover she BY: ACP Date: �.�i �� /� /s/ 1 Production Scanning Stage 1 Page Count from Scanned File: II 0 (Count does include covers et) Page Count Matches Number in Scanning Pre aration: YES vvif NOBY: 410 Date: 4 PW !S /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. 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C) W re ° I mE ZaN � 0Eco 0 0 w ` 1 0 a? c o (" cc Qoa) (o o U U U U U U U U U U U o o U C o p 'v — J N a) •2- O 0 O 0. '70 0 a c N U. E o E a 2 w WW w w w LU WW w °W J LU 3 ? 0 a c0 0 0 CC O vn O 0 N T Co u7 O N in O M Z T ~ N N o in w o \ Z Nr\r)1 DO C.) d N m m < o c O m ` a 3 Om n UJ = ce a O c..) W z U o O co Q o. N J o co a10 0 N a /• wo E V EsiM c U c J Qth 0 a U M ~ fh 2 n O N II 1Ca 1 CL 0 Q = Y o 0 )------1 Q o a Q Z E E U m / 2 m • co u, 1 0 ti j m O ~ 'O M d T NN m F. 0 6 O re CO N C N c U T N CU7 E E E niCERIED 2., 1-t( 10i AUG 11 '' Letter of Transmittal AOGCC 1:4'12 BAKER Date: DATA LOGGED August 14, 2014 4�4/ o14 HUGHES M.K.BENDER To: From: State of Alaska, AOGCC Jesse Salyer Makana Bender Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the final well data for the following well(s): 3C-09L1-01 Enclosed for each well(s): 1 compact disk containing final field data 6.eoceat ✓a �aetrov J.Burke Sr.CTD Engineer RECEIVED Drilling&Wells P.O.Box 100360 MAY 12 2014 Anchorage,AK 99510-0360 ConocoPhillips Phone: 907-265-6097 AOGCC May 9, 2014 AOGCC Commissioner 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Subject: Addendum to Completion Report for 3C-09L1-01 PB1 Dear Commissioner: Per the request from AOGCC, please find enclosed an addendum to the completion report for 3C-09L1-01 PB1, PTD# 213-077. The addendum is the report of daily operations covering the period of time from 6/14/2013 to 7/5/2013 during the initial drilling stage of 3C-09L1-01. Please add this report to the completion report already sent to AOGCC on 4/29/2014. If you have any questions, please feel free to call me at anytime. Sincerely, APP J. Burke Sr. CTD Engineer CPAI Drilling and Wells JB/skad ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 3C-09 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 6/14/2013 1:00:00 AM Rig Release: 7/5/2013 12:00:00 PM Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 06/13/2013 24 hr summary Move rig to next well. 05:00 08:00 3.00 0 0 MIRU MOVE MOB P Move rig to 3C-Pad 08:00 08:30 0.50 0 0 MIRU MOVE SFTY P Trucks on location. Conduct PJSM with all crews- Rig move. 08:30 11:00 2.50 0 0 MIRU MOVE MOB P Pull off of well and install jeeps. 11:00 17:30 6.50 0 0 MIRU MOVE MOB P Start Rig move to 3Cpad 17:30 18:00 0.50 0 0 MIRU MOVE SFTY P Conduct PJSM with all crews- spotting rig over 3C-09.Verify correct well. 18:00 20:30 2.50 0 0 MIRU MOVE MOB P Spot subs over well. 20:30 00:00 3.50 0 0 SLOT WELLPF CTOP P Prep for reel swap 06/14/2013 Performed reel maintenance. Installed new reel and secured into reel stand. Installed guards, M/U MP line, coil grapple, inner reel iron, a-line pressure bulkhead, BHP e-line head(pull tested to 35k), Checked tree bolts -2 loose studs found, changed out the o-rings on lubricator,filled coil with sea water,tested tiger tank line 1500psi-2 loose chicksans 00:00 01:00 1.00 0 0 SLOT WELLPF CTOP P Finish removing reel from rig. 0 SLOT ***********Rig Accept at 1:00am ************ 01:00 06:30 5.50 0 0 SLOT WELLPF CTOP T Rig Maintenance on reel drive chain sprocket and reel bearings. *******5.5 Rig Billable Maintenance hrs******** 06:30 09:30 3.00 0 0 SLOT WELLPF CTOP P Install new reel and secure, install guards and M/U MP line. 09:30 12:00 2.50 0 0 SLOT WELLPF CTOP P Install grapple,shim reel, and prep to stab pipe. 12:00 16:30 4.50 0 0 SLOT WELLPF CTOP P Stab Pipe, R/D stabbing equipment. 16:30 18:30 2.00 0 0 SLOT WELLPF CTOP P Install CTC, install inner reel iron, and M/U e-line pressure bulkhead. 18:30 20:00 1.50 0 0 SLOT WELLPF CTOP P Install BHI e-line head. Check studs on tree-2 loose studs. 20:00 00:00 4.00 0 0 SLOT WELLPF CTOP P Change out o-rings on lubricator. Fill coil with sea water. Test tiger tank line,2 loose chicksans. retest to 1500psi,good test. 06/15/2013 Tested BOPE. 250psi low/4500psi high. 3 failed components 2-3/8"uppers and lowers and C10. Replace horse shoe seals on ram bodies as well as C10. Retest. Finish BOP test. 00:00 01:00 1.00 0 0 SLOT WELLPF NUND P Nipple up stack 01:00 01:00 0.00 0 0 MIRU WHDBO NUND P Prep to test BOPE Page 1 0116 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 11:00 10.00 0 0 MIRU WHDBO BOPE P Start BOPE test ******Test waived by Jeff Tuenington 3:51pm 6/12/13 11:00 17:30 6.50 0 0 MIRU WHDBO BOPE T 3 failed BOPE components 2-3/8" upper and lower combi's and C10. Replace and retest. *****6.5hrs billable rig maintenance- all billable maintenance hrs taken for month of June 2013. 17:30 18:30 1.00 0 0 MIRU WHDBO BOPE P Done with BOP test. R/D testing equipment. ******BOPE TEST TIME 16.5hrs ******* 18:30 18:45 0.25 0 0 MIRU WHDBO SFTY P Conduct PJSM-FMC to pull BPV. 18:45 19:30 0.75 0 0 MIRU WHDBO BOPE P R/U FMC lubricator. 19:30 22:00 2.50 0 0 MIRU WHDBO BOPE P P/T lubricator to 2500psi. Pull BPV and RD FMC lubricator.TP- 1200psi 22:00 23:00 1.00 0 0 PROD1 WHPST PULD P Install BHI check valves. Circulate one coil volume forward. 23:00 23:15 0.25 0 0 PROD1 WHPST SFTY P Conduct PJSM-M/U weatherford tools and pressure deploy 23:15 00:00 0.75 0 0 PROD1 WHPST PULD P Deploy BHA. 06/16/2013 Pump one coil volume forward for a-line management. Installed BHI counter, Pulled BPV TP 1200. M/U window milling BHA with 0.6°X-Treme motor. RIH Tied into the K1 +7'. Milled the first 3.5"part of the window. Reamed 3.5"area, POOH 00:00 02:00 2.00 0 0 PROD1 WHPST TRIP P Continue deploying window milling bha. 02:00 03:33 1.56 0 7,435 PROD1 WHPST TRIP P RIH-BHA#1 Window milling 2.79 String reamer 2.80 Diamond window mill Inteq 2-3/8"X-Treme 0.6°AKO 03:33 03:48 0.25 7,435 7,490 PROD1 WHPST DLOG P Tie into K1 correction of+7'. 03:48 04:48 1.00 7,490 7,846 PROD1 WHPST TRIP P Continue RIH. Swapping over to 9.8ppg used PowerPro. 04:48 05:48 1.00 7,846 7,846 PROD1 WHPST MILL P Dry tag WS at 7846'. P/U bring pump up and start time milling at 7845'. 05:48 15:00 9.20 7,845 7,851 PROD1 WHPST MILL P Continuing time milling. Cric PSI: 3,699 WHP: 37 psi Two minor delays one due to generator to high line conversion and the second due to a PLZ componet failure. 15:00 16:00 1.00 7,851 7,851 PROD1 WHPST MILL P Stop at planned depth of 7,851.4'and start reciprocating string reamer through window in 3.5" 16:00 18:00 2.00 7,851 0 PROD1 WHPST TRIP P POOH. 18:00 18:30 0.50 0 0 PROD1 WHPST SFTY P Conduct PJSM w/crew and MI rep for magnastar magnetics-undeploying milling BHA Page 2 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 19:45 1.25 0 0 PROD1 WHPST PULD P Undeploy BHA, scrape magnets, gauge mills, 2.79 no-go on both mills. 19:45 20:00 0.25 0 0 PROD1 WHPST PULD P M/U second window milling BHA. 20:00 21:15 1.25 0 0 PROD1 WHPST TRIP P Deploy BHA,work BHA string through BOP's with 2.0 AKO motor 21:15 21:30 0.25 0 157 PROD1 WHPST TRIP P Tag up and zero counter, RIH wtih window milling BHA. Weatherford motor with 2.0 AKO 2.80 OD Fat Radius window mill 21:30 23:30 2.00 157 7,435 PROD1 WHPST TRIP P Tag up on collar. PUH and orient TF from 140°to 290°. Close EDC and bring pump up to.65bpm. RBIH seeing collars every 31ft. Speed up tripping in hole. Looks clean continue in hole. 23:30 23:45 0.25 7,435 7,485 PROD1 WHPST DLOG P Tie into the K1 marker correction of- 5'. 23:45 23:59 0.24 7,485 7,758 PROD1 WHPST TRIP P Continue in hole to bottom. 06/17/2013 Finish milling through the 7"casing and TD'd rat hole @ 7865'. Swap to new 9.8ppg PowerPro. POOH, undeploy second milling BHA, and L/D weatherford tools. Deploy build BHA w/2.0°AKO, RIH. 00:00 06:30 6.50 7,758 7,865 PROD1 WHPST MILL P Tag bottom at 7852.5'. FS 3622psi @ 1.51 bpm. Start milling second section of exit in the 7". IA 272, OA 317, BHP 3868, WHP 64. 06:30 09:30 3.00 7,865 7,833 PROD1 WHPST MILL P Start up and down ream runs. On up reams orineted to 45 degrees to milled toolface. 6 up reams and 5 down reams. Drifted through window "dry"with no concerns. 09:30 12:03 2.55 7,833 0 PROD1 DRILL TRIP P Swap over to new 9.8 Power Pro and POOH. Circ PSI: 3,319 BHP: 3,960 psi IA:423 psi OA:559 psi 12:03 13:24 1.35 0 0 PROD1 DRILL PULD P At surface. Pressure undeploy. 13:24 14:24 1.00 0 0 PROD1 DRILL PULD P LD Milling BHA. M/U build BHA. 14:24 16:03 1.65 0 0 PROD1 DRILL PULD P Pressure Deploy. 16:03 18:56 2.89 0 7,435 PROD1 DRILL TRIP P RIH. 18:56 19:11 0.25 7,435 7,475 PROD1 DRILL DLOG P Tie into the K1 marker-6'. 19:11 23:59 4.81 7,865 7,949 PROD1 DRILL DRLG P Start drilling build section. Circ PSI: 3,666,WHP 106psi. BHP 3951, 1.5 bpm IA 400psi, OA 534psi 36/18/2013 TD Build section @ 8145,Trip out for lateral BHA#4 with .6°motor, Drill 8145 to 8438 00:00 05:00 5.00 7,949 8,145 PROD1 DRILL DRLG P OBD Build section. 1.5bpm at 3514psi.WHP 91, BHP 3982, IA 404, OA 543. 05:00 05:30 0.50 8,145 7,800 PROD1 DRILL WPRT P TD build section at 8145'. PUH and try to find RA marker. 05:30 07:00 1.50 7,800 0 PROD1 DRILL TRIP P No PIP tags found. POOH Page 3 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 07:15 0.25 0 0 PROD1 DRILL SFTY P OOH, Conduct PJSM-undeploy build BHA 07:15 09:00 1.75 0 0 PROD1 DRILL PULD P Undeploy BHA#3 09:00 09:45 0.75 0 0 PROD1 DRILL PULD P M/U lateral BHA#4 with 0.6°ako motor 09:45 10:00 0.25 0 0 PROD1 DRILL SFTY P Conduct PJSM-deploying lateral BHA. 10:00 11:45 1.75 0 0 PROD1 DRILL PULD P Deploy lateral BHA. 11:45 12:45 1.00 0 0 PROD1 DRILL SFTY P Shon, Brian, and John came out and presented iditarod appreciation to crew. 12:45 15:00 2.25 0 7,450 PROD1 DRILL TRIP P RIH L1 lateral BHA New DGS Res Tool X-Treme motor w/0.6°ako New Hycalog bi-center bit 15:00 15:15 0.25 7,450 7,483 PROD1 DRILL DLOG P Tie into the K1 correction of-0.5'. 15:15 16:00 0.75 7,483 8,145 PROD1 DRILL TRIP P Continue to bottom. 16:00 19:12 3.20 8,145 8,295 PROD1 DRILL DRLG P OBD-1.41bpm at 3500psi, BHP 4019,WHP 152, IA 141, OA 234 19:12 20:54 1.70 8,295 8,295 PROD1 DRILL WPRT P Wiper trip to window with MADD pass, PUW=33K 20:54 00:00 3.10 8,295 8,438 PROD1 DRILL DRLG P 8295', Drill ahead, 1.46 BPM @ 3500 PSI FS, BHP=4010,WHP=110 06/19/2013 Drilled 8438 to 9195 00:00 00:06 0.10 8,438. 8,445 PROD1 DRILL DRLG P Drilling Ahead 00:06 00:48 0.70 8,445 8,445 PROD1 DRILL WPRT P Wiper trip to 7900, PUW=35K 00:48 03:54 3.10 8,445 8,595 PROD1 DRILL DRLG P 8445, Drill ahead, 1.44 BPM @ 3470 PSI FS, BHP=4040 03:54 04:54 1.00 8,595 8,595 PROD1 DRILL WPRT P Wiper to window with tie in for+2' correction, PUW=37K, good increase of cuttings on wiper, Blow down drilling choke. Clean trip up and down 04:54 07:54 3.00 8,595 8,745 PROD1 DRILL DRLG P 8595', Drill Ahead, 1.49 BPM @ 3500 PSI FS, BHP=4030 07:54 08:24 0.50 8,745 7,900 PROD1 DRILL WPRT P Wiper up to the window. PUW 37 08:24 08:54 0.50 7,900 8,745 PROD1 DRILL WPRT P Wiper back in hole. RIW 18 08:54 11:54 3.00 8,745 8,895 PROD1 DRILL DRLG P BOBD- 1.43bpm at 3420psi. BHP 4070,WHP 108, IA 218, OA 169 11:54 12:24 0.50 8,895 8,175 PROD1 DRILL WPRT P Wiper up hole. PUW 37k 12:24 12:42 0.30 8,175 8,895 PROD1 DRILL WPRT P Wiper back in hole. RIW 17k 12:42 16:25 3.72 8,895 9,045 PROD1 DRILL DRLG P BOBD- 1.43bpm at 3500psi. BHP 4075,WHP 119, IA 293, OA 232 16:25 17:10 0.75 9,045 7,870 PROD1 DRILL WPRT P Wiper up hole. PUW 37k 17:10 17:25 0.25 7,870 7,897 PROD1 DRILL DLOG P Tie into the gamma spike at 7858' correction of+0.5' 17:25 17:55 0.50 7,897 9,045 PROD1 DRILL WPRT P Wiper back in hole. RIW 18k Page 4 of 16 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 17:55 22:43 4.80 9,045 9,195 PROD1 DRILL DRLG P BOBD- 1.44bpm at 3462psi, BHP 4104,WHP 128, IA 299, OA 252 22:43 23:59 1.28 9,195 9,000 PROD1 DRILL WPRT P Wiper to window, PUW=37K, BHP=4170 06/20/2013 Drilled 9195 to 10012, Swapped to 9.6PPG Flo Pro 00:00 00:06 0.10 9,000 9,195 PROD1 DRILL WPRT P Continue full wiper 00:06 02:18 2.20 9,195 9,345 PROD1 DRILL DRLG P 9195', Drill ahead, 1.45 BPM @ 3450 PSI FS, BHP=4140,WHP=125 New Mud at bit @ 9305', New mud all around @ 9340 1440'on old system @.9% Drill solids 02:18 03:24 1.10 9,345 9,345 PROD1 DRILL WPRT P Wiper to window, PUW=36K, BHP=4150 03:24 05:42 2.30 9,345 9,495 PROD1 DRILL DRLG P 9345', Drill Ahead, 1.4 BPM @ 3860 PSI FS, BHP=4144 05:42 06:27 0.75 9,495 7,873 PROD1 DRILL WPRT P Wiper to window with tie in, PUW=34K 06:27 06:42 0.25 7,873 7,898 PROD1 DRILL DLOG P Tie into gamma spike correction of+ 3'. 06:42 07:27 0.75 7,898 9,495 PROD1 DRILL WPRT P Wiper back in hole. RIW 17k 07:27 09:15 1.80 9,495 9,645 PROD1 DRILL DRLG P BOBD- 1.41bpm at 3580psi. BHP 4133,WHP 137, IA 329, OA 263. 09:15 09:51 0.60 9,645 8,375 PROD1 DRILL WPRT P Wiper up hole. PUW 33k 09:51 10:27 0.60 8,375 9,645 PROD1 DRILL WPRT P Wiper back in hole. RIW 14 10:27 11:57 1.50 9,645 9,795 PROD1 DRILL DRLG P BOBD- 1.44bpm at 3620psi, BHP 4133,WHP 135, IA 391, OA 322 11:57 12:42 0.75 9,795 8,480 PROD1 DRILL WPRT P Wiper up hole. PUW 33k 12:42 13:18 0.60 8,480 9,795 PROD1 DRILL WPRT P Wiper back in hole. RIW 14k 13:18 16:12 2.90 9,795 9,903 PROD1 DRILL DRLG P BOBD- 1.44bpm at 3620psi, BHP 4158,WHP 136, IA 445, OA 362 16:12 21:00 4.80 9,903 9,945 PROD1 DRILL DRLG P Found Ankorite, ROP<10 FPH, 1.42 BPM @ 3675 PSI FS 21:00 22:54 1.90 9,945 9,945 PROD1 DRILL WPRT P Planned wiper to window, PUW=33K with tie in for+4.5'correction, clean trip up and down 22:54 00:00 1.10 9,945 10,012 PROD1 DRILL DRLG P 9945', Drill ahead, 1.48 BPM @ 3740 PSI FS, BHP=4155 36/21/2013 Drilled 10012 to 10545, Encountered several stringers of Ankorite, Fluid lossses- 1 BPH 00:00 02:00 2.00 10,012 10,095 PROD1 DRILL DRLG P Drill Ahead, 1.48 BPM @ 3750 PSI FS, BHP=4160 02:00 03:00 1.00 10,095 10,095 PROD1 DRILL WPRT P Wiper trip to 9000, PUW=36K, BHP=4160 03:00 06:00 3.00 10,095 10,245 PROD1 DRILL DRLG P 10095', Drill Ahead, 1.46 BPM @ 3740 PSI FS, BHP=4160,WHP=100 PSI 06:00 06:42 0.70 10,245 9,021 PROD1 DRILL WPRT P Wiper up hole. PUW 34k 06:42 07:24 0.70 9,021 10,245 PROD1 DRILL WPRT P Wiper back in hole. RIW 18k 07:24 16:24 9.00 10,245 10,395 PROD1 DRILL DRLG P BOBD- 1.41bpm at 3600psi. BHP 4206,WHP 155, IA 610, OA 521 Page 5 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:24 17:36 1.20 10,395 78 PROD1 DRILL WPRT P Wiper up hole to the window fora tie in. PUW 33k 17:36 17:45 0.15 7,875 7,893 PROD1 DRILL DLOG P Tie in correction of+3.5 17:45 18:57 1.20 7,893 10,395 PROD1 DRILL WPRT P Wiper back in hole. RIW 17k 18:57 22:45 3.80 10,395 10,545 PROD1 DRILL DRLG P BOBD-1.43bpm at 3650psi. 22:45 00:00 1.25 10,545 10,545 PROD1 DRILL WPRT P Wiper trip to 9395, PUW=36K 06/22/2013 TD Lateral 1 @ 11145', pump sweeps and chase to swab valve 00:00 03:42 3.70 10,545 10,695 PROD1 DRILL DRLG P 10545', Drill Ahead 1.48 BPM @ 3750 PSI FS, BHP=4225 03:42 04:54 1.20 10,695 10,695 PROD1 DRILL WPRT P 10695',Wiper trip to 9545', PUW=40K, Dragging 34K, BHP=4191, Encountered tight spot 10380 to 10360 with 5K overpull, Observed weight drop RIH through same area 04:54 07:54 3.00 10,695 10,845 PROD1 DRILL DRLG P 10695', Drill Ahead, 1.47 BPM @ 3750 PSI FS, BHP=4220, RIW=10K 07:54 09:15 1.35 10,845 7,870 PROD1 DRILL WPRT P Wiper up hole fora tie in. PUW 38 09:15 09:30 0.25 7,870 7,883 PROD1 DRILL DLOG P Gamma spike at 7858'tie in correction of+2.0' Bottom hole pressure survey at the window Depth: 7900', Pump rate 1.47bpm, WHP 75 BHI annular pressure-3955 09:30 10:45 1.25 7,883 10,845 PROD1 DRILL WPRT P Wiper back in hole. RIW 10:45 12:21 1.60 10,845 10,933 PROD1 DRILL DRLG P BOBD- 1.43 bpm at 3812psi. BHP 4234,WHP 29, IA 332, OA 352 12:21 12:51 0.50 10,933 10,633 PROD1 DRILL WPRT P Stacked out coil weight. PUW 52k. PUH to 10633'. Start mud swap. ********New Mud at 10933' ********Old Mud 1628'drilled with 0.7%solids 12:51 13:06 0.25 10,633 10,933 PROD1 DRILL WPRT P Wiper back in hole. RIW 15k 13:06 14:21 1.25 10,933 10,995 PROD1 DRILL DRLG P BOBD-1.44bpm at 3944psi. BHP 4220,WHP 29, IA 250, OA 254. 14:21 14:51 0.50 10,995 9,800 PROD1 DRILL WPRT P Wiper up hole to 9800'. PUW 33k 14:51 15:21 0.50 9,800 10,995 PROD1 DRILL WPRT P Wiper back in hole. RIW 15k 15:21 18:03 2.70 10,995 11,145 PROD1 DRILL DRLG P BOBD- 1.44 bpm at 3891psi. BHP 4226,WHP 36, IA 267, OA 264., Pump Hi Lo sweeps call TD @ _ 11145 18:03 22:00 3.95 11,145 200 PROD1 DRILL WPRT P Sweeps coming out start wiper trip to swab, PUW=35K 22:00 00:00 2.00 200 0 PROD1 DRILL WPRT T Reel unable to keep up with injector, planetary making noise RIH. Shot temps on pillow block bearings, 80° on ODS, 170°on DS. Mechanic/ electrician called out to trouble shoot Page 6 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/23/2013 24 hr Summary Complete reel alignment, Finish swab wiper, Lay in 12 PPG liner running pill and 12 PPG completion fluid. Run L1 lower liner segment 11146, Top of lower liner 9534. POOH M/U upper section and RIH 00:00 01:00 1.00 0 100 PROD1 DRILL WPRT T Realign reel pillow block bearings and test 01:00 02:24 1.40 100 7,430 PROD1 DRILL WPRT P Continue wiper to TD and lay in liner running pill and KWF 02:24 02:36 0.20 7,430 7,473 PROD1 DRILL DLOG P Tie into K-1 for-2.5' 02:36 03:42 1.10 7,473 9,150 PROD1 DRILL WPRT P Continue in to lay in liner running pill, stop at 7799 shut EDC, Set down @ 9115, orient TF to as drilled still having trouble getting through. Getting crude in returns to surface. Overpulls coming up. 03:42 04:36 0.90 9,150 11,146 PROD1 DRILL WPRT P 9150 continue in hole, TF=100°to go through 04:36 08:21 3.75 11,146 0 PROD1 DRILL TRIP P Tag bottom at 11146'. POOH laying in 12.0ppg completion fluid with bead up to the window and without beads to surface. Paint EOP flags at 9400' EOP(Yellow),6100'(White) 08:21 08:36 0.25 0 0 PROD1 DRILL SFTY P Conduct PJSM-Flow Check well for flow, L/D BHA#4 08:36 09:21 0.75 0 0 PROD1 DRILL PULD P L/D Lateral BHA#4 09:21 09:36 0.25 0 0 COMPZ CASING PULD P Conduct PJSM-for running L1 completion. 09:36 10:06 0.50 0 0 COMPZ CASING PULD P Start making up L1 liner. 10:06 10:21 0.25 0 0 COMPZ CASING SFTY P BOB drill on joint#3(Time 2min 11 sec) 10:21 12:00 1.66 0 0 COMPZ CASING PUTB P Continue M/U liner 12:00 12:15 0.25 0 0 COMPZ CASING PUTB P Conduct PJSM-for making up BHI tools 12:15 12:30 0.25 0 1,655 COMPZ CASING PUTB P Lower BHI and liner into the slips. 12:30 13:30 1.00 1,655 1,655 COMPZ CASING SVRG P Service Rig 13:30 15:00 1.50 1,655 7,751 COMPZ CASING TRIP P RIH-L1 completion with shorty deplpoyment,52 jts of slotted liner, and a non-ported bull nose. Pumping min rate 15:00 15:15 0.25 7,751 7,751 COMPZ CASING DLOG P At 6100' EOP Flag, Subtract 11ft, PUW 32k 15:15 15:45 0.50 7,751 9,030 COMPZ CASING TRIP P Continue running in hole 15:45 16:00 0.25 9,030 9,050 COMPZ CASING DLOG P Tie into the K1 marker correction of +4'. 16:00 16:30 0.50 9,050 11,146 COMPZ CASING TRIP P Continue in hole. 16:30 16:45 0.25 11,146 11,146 COMPZ CASING TRIP P Tag bottom at 11146'. PUW 40k, Pump up, release from liner. PUW 31k 16:45 19:21 2.60 11,146 43 COMPZ CASING TRIP P POOH 19:21 19:45 0.40 43 0 COMPZ CASING PULD P PJSM while flow checking well, Lay down BHA#5 L1 lower liner section running tools Page 7 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:45 20:45 1.00 0 0 COMPZ CASING BOPE P Perform BOPE Function test-Rig up floor to run liner 20:45 23:30 2.75 0 1,298 COMPZ CASING PUTB P P/U L1 Upper section with ported bullnose, 12 jts slotted 2 3/8",28 jts 2 3/8"blank CS 511, Perform BOPE drill @ jt 14 @ 2 minutes to have well secured with floor valve, Make up to coil track, Make up to coil and surface test 23:30 23:59 0.49 1,298 3,067 COMPZ CASING TRIP P RIH X6/24/2013 Complete L1 liner ops,Tag Billet @ 8276, Kick off and drill ahead to 8769 00:00 01:12 1.20 3,067 7,707 COMPZ CASING TRIP P Continue in hole with L1 upper liner section 01:12 01:18 0.10 7,707 7,698 COMPZ CASING DLOG P Tie into EOP flag for-9.2 01:18 01:42 0.40 7,698 8,665 COMPZ CASING TRIP P Continue in with liner 01:42 01:48 0.10 8,665 8,700 COMPZ CASING DLOG P Tie into GR for+2'correction 01:48 02:12 0.40 8,700 9,532 COMPZ CASING TRIP P Continue in with liner, Tag Top of lower liner @ 9532 02:12 02:36 0.40 9,532 9,046 COMPZ CASING TRIP P PUW=36K, Pumps on 1.2 BPM PUW=27K, Release from liner, BOL=11146, TOL=8278 02:36 04:36 2.00 9,046 33 COMPZ CASING TRIP P Stop and remove liner length from counters,continue trip out 04:36 05:06 0.50 33 0 COMPZ CASING PULD P At surface, PJSM/Flow check well, Lay down BHA#6 liner running tools 05:06 06:36 1.50 0 0 PROD2 STK PULD P M/U BHA#7, Drill off liner top billet 06:36 08:06 1.50 0 7,445 PROD2 STK TRIP P RIH- 1.1°ako motor to kick off of billet at 8280' 08:06 08:21 0.25 7,445 7,450 PROD2 STK DLOG P Tie into the K1 marker correction of- 7'. 08:21 09:21 1.00 7,450 8,275 PROD2 STK TRIP P Continue in hole. Displace 12.0ppg completion fluid with 9.6ppg flo-pro. 09:21 10:21 1.00 8,275 8,275 PROD2 STK KOST P Dry tag billet at 8276.5'. Kick off of billet as per recommended practice. 1.41bpm at 3882psi. BHP 4036, WHP 92, IA 0, OA 134 10:21 10:51 0.50 8,275 8,277 PROD2 STK KOST P Time drilling, autodrill 1 fph 10:51 11:21 0.50 8,277 8,278 PROD2 STK KOST P Time drilling, autodrill 2 fph 11:21 15:21 4.00 8,278 8,425 PROD2 DRILL DRLG P Drill Ahead in the L1-01 15:21 15:36 0.25 8,425 8,290 PROD2 DRILL WPRT P Wiper up to 8290'. PUW 33k 15:36 15:51 0.25 8,290 8,425 PROD2 DRILL WPRT P Wiper back in hole RIW 19k 15:51 18:45 2.90 8,425 8,575 PROD2 DRILL DRLG P BOBD-1.42 bpm at 3900psi. BHP 4057,WHP 37, IA 0, OA 85 18:45 19:15 0.50 8,575 7,915 PROD2 DRILL WPRT P Wiper up hole to 7915', PUW 33k 19:15 19:45 0.50 7,915 8,575 PROD2 DRILL WPRT P Wiper back in hole. RIW 19k 19:45 22:33 2.80 8,575 8,725 PROD2 DRILL DRLG P BOBD- 1.42bpm at 3932psi, BHP 4036,WHP 33, IA 20, OA 137 22:33 22:51 0.30 8,725 8,290 PROD2 DRILL WPRT P Wiper up hole. PUW 33k Page 8 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:51 23:09 0.30 8,290 8,725 PROD2 DRILL WPRT P Wiper back in hole. RIW 18k 23:09 00:00 0.85 8,725 8,769 PROD2 DRILL DRLG P 8725, Drill Ahead, 1.4 BPM @ 3920 PSI FS, BHP=4103 06/25/2013 Complete End of turn @ 8840, POOH perform full BOPE Test,Witnes waived by Bob Noble,AOGCC,trip in and drill lateral 8840 to 8901 00:00 02:30 2.50 8,769 8,840 PROD2 DRILL DRLG P Continue drilling turn section, Call EOB @ 8840 02:30 05:00 2.50 8,840 58 PROD2 DRILL TRIP P POOH for BOPE test/Lateral bend motor, PUW=32K,Avg DLS 12.7° 05:00 07:00 2.00 58 0 PROD2 DRILL PULD P PJSM, PUD BHA#7 07:00 08:30 1.50 0 0 PROD2 DRILL PULD P Lay down BHA#7. 08:30 09:30 1.00 0 0 PROD2 DRILL SVRG P Prep for BOPE Testing. Service inner reel valve and choke. Valve crew on location to grease tree valves. 09:30 16:30 7.00 0 0 PROD2 DRILL BOPE P Test BOPE. (State witness waived by Bob Noble,10:16 24Jun13). 16:30 17:00 0.50 0 0 PROD2 DRILL CIRC P Swap coil back to mud and replace check valves in BHA. 17:00 19:30 2.50 0 72 PROD2 DRILL PULD P Pick up and PD L1-01 lateral drilling BHA#8. .5°motor and Hugh"Stay Sharp"2.7 X 3"Bi Center, M/U to coil and surface test 19:30 21:18 1.80 72 7,438 PROD2 DRILL TRIP P Trip in hole, EDC open 21:18 21:30 0.20 7,438 7,478 PROD2 DRILL DLOG P Log K-1 for,-8'correction, 21:30 21:36 0.10 7,478 7,791 PROD2 DRILL TRIP P Continue in well 21:36 22:12 0.60 7,791 8,841 PROD2 DRILL TRIP P Stop and shut EDC 22:12 00:00 1.80 8,841 8,901 PROD2 DRILL DRLG P 8841', Drill ahead, 1.4 BPM @ 3800 PSI FS, BHP=4030, Getting crude at shaker, no gas divert to TT 06/26/2013 Drill Ahead 8901 to 9740 00:00 02:54 2.90 8,901 8,965 PROD2 DRILL DRLG P 8901, Drill ahead Cont. 02:54 03:36 0.70 8,965 8,965 PROD2 DRILL WPRT P Wiper to billet @ 8276 03:36 05:54 2.30 8,965 9,140 PROD2 DRILL DRLG P 8965', Drill Ahead, 1.4 BPM @ 3900 PSI FS, BHP=4084,WHP=20. 05:54 07:00 1.10 9,140 9,140 PROD2 DRILL WPRT P Wiper trip;33k#off bottom. 07:00 09:45 2.75 9,140 9,290 PROD2 DRILL DRLG P 9140', Drill Ahead, 1.4 BPM @ 3900 PSI FS, BHP=4145,WHP=40. 09:45 11:15 1.50 9,290 9,290 PROD2 DRILL WPRT P Wiper trip#3; 35k#off bottom. Tie-in +2'. 11:15 13:39 2.40 9,290 9,440 PROD2 DRILL DRLG P 9290', Drill Ahead, 1.4 BPM @ 4000 PSI FS, BHP=4125,WHP=5. 13:39 14:33 0.90 9,440 9,440 PROD2 DRILL WPRT P Wiper trip#1; 35k#off bottom. 14:33 18:33 4.00 9,440 9,590 PROD2 DRILL DRLG P 9440', Drill Ahead, 1.39 BPM @ 4000 PSI FS, BHP=4050,WHP=15. 18:33 19:45 1.20 9,590 9,590 PROD2 DRILL WPRT P Wiper trip to 8440', PUW=35K 19:45 00:00 4.25 9,590 9,740 PROD2 DRILL DRLG P 9590', Drill Ahead, 1.4 BPM @ 4000PSI FS, BHP=4150,WHP=22 Page 9of16 W � Time Logs Date._ From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/27/2013 24 hr Summary Drill ahead from 9,741'to 10,513' 00:00 01:00 1.00 9,740 7,870 PROD2 DRILL WPRT P Wiper to window with tie in, PUW=36K 01:00 01:09 0.15 7,870 7,896 PROD2 DRILL DLOG P Log formation tie in for+3', Pump rate=1.4BPM,WHP=0, Return MM=1.38, BHI Press=3975,Wide Open Choke 01:09 02:03 0.90 7,896 9,741 PROD2 DRILL WPRT P RBIH to drill, RIW=20K @ 40 FPM, 9700' start new 9.6 Power Pro down hole Old mud, system#3 made 1693', 25K LSRV, .8%DS 02:03 02:57 0.90 9,741 9,789 PROD2 DRILL DRLG P 9741', Drill Ahead, 1.40 BPM @ 4000 PSI FS, BHP=4236, RIW=16.7K,WHP=96 02:57 04:27 1.50 9,789 9,890 PROD2 DRILL DRLG P 9789, Drill ahead, New power Pro around, 1.43 BPM @ 3250 PSI FS, WHP=285, BHP=4142, 04:27 05:39 1.20 9,890 9,890 PROD2 DRILL WPRT P 9890',wiper trip to 8740, PUW=36K. 05:39 08:21 2.70 9,890 10,040 PROD2 DRILL DRLG P Drill ahead, 1.43 BPM @ 3600 PSI FS,WHP=240, BHP=4155. 08:21 09:21 1.00 10,040 10,040 PROD2 DRILL WPRT P 10,040',wiper trip to 9000, PUW=37K. 09:21 12:27 3.10 10,040 10,190 PROD2 DRILL DRLG P Drill ahead, 1.5 BPM @ 3700 PSI FS,WHP=250, BHP=4180. 12:27 13:33 1.10 10,190 7,875 PROD2 DRILL WPRT P 10,190',wiper trip to window with tie in, PUW=38K. 13:33 13:45 0.20 7,875 7,899 PROD2 DRILL DLOG P 7875 Log tie in for+3'correction, @7900', 1.51BPM,WHP=270. BHI=3980, PUH 5-7 FPM 13:45 14:45 1.00 7,899 10,140 PROD2 DRILL WPRT P Continue wiper back in hole, Hard setdown @ 8920 with HS TF, Roll to 60L and reduce pump rate, Set down 6 to 7K and popped through. Lost alot of surface weight 10,100 to 10170 14:45 18:15 3.50 10,140 10,340 PROD2 DRILL DRLG P 10140', Drill ahead, 1.5 BPM @ 3400 PSI FS, BHP=4180,WHP=230. GEO target 92 Deg. Stacking weight 10,100'- 10,190'. 18:15 19:42 1.45 10,340 10,340 PROD2 DRILL WPRT P Wiper trip to 9,000', PUW=38K, RBIH,some stacking same area 10,100'. 19:42 22:27 2.75 10,340 10,490 PROD2 DRILL DRLG P Drill ahead, 1.5 BPM @ 3750 PSI FS,WHP=245, BHP=4210. GEO target 90 deg inc. 22:27 23:42 1.25 10,490 10,490 PROD2 DRILL WPRT P Wiper trip, PUW=37K, RBIH, slow ROP thru stacking area, no problems. 23:42 00:00 0.30 10,490 10,513 PROD2 DRILL DRLG P Drill ahead, 1.49 BPM @ 3725 PSI FS,WHP=225, BHP=4220. GEO target 90 deg inc. 06/28/2013 Drilled ahead to called TD @ 11,285 Page 10 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:36 1.60 10,513 10,640 PROD2 DRILL DRLG P Continue drilling ahead, 1.49 BPM @ 3705 PSI FS,WHP=205, BHP=4190.GEO target 90 deg inc. 01:36 03:00 1.40 10,640 10,640 PROD2 DRILL WPRT P Wiper trip, PUW=36K, RBIH continue slow thru 10,100'to 10,190'. 03:00 05:06 2.10 10,640 10,790 PROD2 DRILL DRLG P Drilling ahead, 1.48 BPM @ 3650 PSI FS,WHP=220, BHP=4192. 05:06 06:24 1.30 10,790 10,790 PROD2 DRILL WPRT P Wiper trip 06:24 09:30 3.10 10,790 10,940 PROD2 DRILL DRLG P 1.51 BPM@ 3550 PSI FS, RIW=10.8K, BHP=4236,WHP=235 09:30 10:42 1.20 10,940 10,940 PROD2 DRILL WPRT P Wiper to 9800', PUW=38K, BHP=4220 10:42 15:42 5.00 10,940 11,090 PROD2 DRILL DRLG P 10940', Drill ahead, 1.5 BPM @ 3590 PSI FS, BHP=4233, 15:42 18:12 2.50 11,090 11,090 PROD2 DRILL WPRT P 11090, Pump 5 X 5 sweeps,wiper trip, PUW=40K, RBIH. Log secondary tie-in for+1'correction. 18:12 19:06 0.90 11,090 11,220 PROD2 DRILL DRLG P Drilling ahead, 1.49 BPM @ 3625 PSI FS,WHP=235, BHP=4235. GEO 91 deg inc. 19:06 20:36 1.50 11,220 11,220 PROD2 DRILL WPRT P 1,000'wiper trip, PUW=39K, RBIH. 20:36 22:06 1.50 11,220 11,285 PROD2 DRILL DRLG P Drilling ahead to called TD, 1.49 BPM @ 3635 PSI FS,WHP=210, BHP=4238. GEO 91 deg inc. 22:06 00:00 1.90 11,285 8,229 PROD2 DRILL WPRT P Start long wiper trip to swab, circulate sweeps to bit, PUW=40K, ---- ----- - pulled into tight spots, min rate. 06/29/2013 Pulled long wiper to surface. RBIH, unable to get below 11,015'. PUH laying in liner pill, at 10,745'bit depth the hole packed off, unable to circulate or move pipe.Attempt to pump down backside, 1,350 psi @.25 bpm. Continue to work pipe and re-establish circulation, in progress. 00:00 02:45 2.75 8,229 0 PROD2 DRILL WPRT P Continue long wiper to swab chasing sweeps to surface 02:45 04:21 1.60 0 7,740 PROD2 DRILL TRIP P RBIH to lay in completion fluids 04:21 04:27 0.10 7,740 7,475 PROD2 DRILL DLOG P Log K1 for-7'correction, PUW=29K 04:27 06:33 2.10 7,475 11,030 PROD2 DRILL TRIP P Continue in hole, Set down at 8090, 8940, and 9742 06:33 06:51 0.30 11,030 10,916 PROD2 DRILL TRIP P Stack @ 11,000, set down @ 11030, PUW=56K. pulling heavy,stuck at 10916', orient and pull free 06:51 07:03 0.20 10,916 10,940 PROD2 DRILL TRIP P RBIH and set down @ 10967, Pull up hole dragging heavy 07:03 07:27 0.40 10,940 10,749 PROD2 DRILL TRIP P Trip out laying in beaded liner pill, Started pulling heavy @ 10744, RBIH stack at 10753, P/U pull heavy, pack off, stuck,Able to orient freely. Unable to change DH WOB 07:27 08:39 1.20 10,749 10,749 PROD2 DRILL TRIP T Try relaxing pipe and pressures work pipe, pump accross top.WHP pressures up and holds pressure to 1000PSI with no change in BHA annular pressure.Attemp dumping WHP while working pipe Page 11 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:39 10:39 2.00 10,749 10,749 PROD2 DRILL TRIP T Line up down coil and attempt to circulate. Rate in changes rate out. Look to be circulating. Some circulation appears coming from L1 10:39 11:03 0.40 10,749 10,749 PROD2 DRILL TRIP T Work Pipe, looking for sign of 12.0PPG fluid in returns. 11:03 12:03 1.00 10,749 10,749 PROD2 DRILL TRIP T Start LVT down coil, 15.2 BBIs 12:03 15:03 3.00 10,749 10,749 PROD2 DRILL TRIP T 4 BBIs out of coil, S/D pump and soak,Work pipe 15:03 15:33 0.50 10,749 10,749 PROD2 DRILL SFTY T Conference call with town team to formulate options and plan forward 15:33 16:33 1.00 10,749 10,749 PROD2 DRILL CIRC T Perform Pressure test,WHP=615, Pressure up to 800PSI, bled right off to 650 PSI WHP, Pump up to 1000PSI in.5 BBIs Shut C-11 and R-5 to insure fluid leaking off to well, Injecting .25 BPM @ 1300 PSI 16:33 18:18 1.75 10,749 10,749 PROD2 DRILL TRIP T Line up down coil,Try to establish circulation, unable to establish circulation,several different pump rates,shut down pump,well will flow. 18:18 18:48 0.50 10,749 10,749 PROD2 DRILL SFTY T Another conference with town to discuss options. 18:48 22:33 3.75 10,749 10,749 PROD2 DRILL TRIP T Cycle pipe twice to 70K,work pipe, no luck. Open EDC, pump down coil, pressure up annulus from 4,016 psi ti 4,625 psi after.25 bbls, let well relax. 22:33 00:00 1.45 10,749 10,749 PROD2 DRILL TRIP T Continue effort to re-establish circulate,different pump rates, choke setting, annulalus keeps pressuring up. X6/30/2013 Continue to work stuck pipe, make attempts to re-eastablish circulate, no success, make preparations for pipe recovery.Town made decision to release from BHA, no success. Decision made to kill well, bullhead 94 bbls 12.0 ppg fluid down annulus @.5 bpm 1,500 psi, roll coil over to 12.0 ppg fluid ,total 43 bbls. No flow check passed. Observe well and maintain hole fill. 00:00 06:00 6.00 10,749 10,749 PROD2 DRILL TRIP T Continue to work pipe sparingly, make attempts to re-establish circulate, no success, make preparation for pipe recovery. 06:00 07:00 1.00 10,749 10,749 PROD2 DRILL TRIP T Crew change, planning meeting, work pipe, 70K to-8K 07:00 07:18 0.30 10,749 10,749 PROD2 DRILL TRIP T Pump down coil, no communication 07:18 08:30 1.20 10,749 10,749 PROD2 DRILL TRIP T Confer with town, release from BHA, work pipe, pressure up and surge backside, pressure up and surge coil and backside, No good. Still have communication with BHA 08:30 13:30 5.00 10,749 10,749 PROD2 DRILL CIRC T Line up and pump 94 BBIs 12.0 Completion fluid down coil X tubing annulas, .5 BPM @ 1500 PSI. Shut down and monitor. No Flo pass 13:30 15:00 1.50 10,749 10,749 PROD2 DRILL CIRC T Roll coil to 12.0, pumped 43 bbls 12.0, Pumped 2 BBIs to ensure backside full Page 12of16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 18:00 3.00 10,749 10,749 PROD2 DRILL OWFF T Observe/monitor well/Maintain hole fill 18:00 00:00 6.00 10,749 10,749 PROD2 DRILL OWFF T Continue monitoring well, maintain hole fill, rebuild rig pump#1. 07/01/2013 Monitor well and maintain hole fill, rebuild mud pump#1,gather tools for pipe recovery. MIRU HES E-Line. Start pipe recovery procedure,strip off and hot tap coil,well dead, cut coil, pull 20'wire, continue wire recovery,see UQC wire anchor @ 600 to 700 LBS on 6th cycle,wire parted. MU wire to HES unit and retrieve 1,100'wire. RD HES unit,overshot coil in tree and pull up to desired height,set upper/lower slips, install bowl,slips and collar. Install Baker external slip type connector and pull test to 50K, install 2X2 plug valve, stand by for orders. 00:00 08:00 8.00 10,749 10,749 PROD2 DRILL OWFF T Monitor well and maintain hole fill. Rebuild mud pump#1, gather pipe recovery equipment. 08:00 10:00 2.00 10,749 10,749 PROD2 DRILL ELNE T PJSM, R/U HES E-line/Pump to ensure hole and coil full 10:00 10:30 0.50 10,749 10,749 PROD2 DRILL ELOG T PJSM with rig team, HES, BOT. Go over stuck coil recovery procedure. 10:30 13:30 3.00 10,749 10,749 PROD2 DRILL TRIP T Start working procedure, Set coil in slips and test, manual locks set, Strip off and hot tap coil, Coil slight vac-dead. Cut coil and pull-20 wire out by hand and clamp. Cut wire on reel end and move off injector. Start stripping wire with blocks 13:30 15:00 1.50 10,749 10,749 PROD2 DRILL TRIP T Coil slid through BOP slips, Shut lower set and lock. Coil still above upper set. Continue wire recovery ops. See UQC wire ancor @ 600 to 700 LBS on 6th cycle 15:00 15:30 0.50 10,749 10,749 PROD2 DRILL ELNE T Make up wire to HES unit and retrieve wire, Pull out 1100'of wire. 15:30 16:30 1.00 10,749 10,749 PROD2 DRILL ELNE T R/D HES E-Line unit 16:30 17:54 1.40 10,749 10,749 PROD2 DRILL CTOP T Overshot coil in tree, Pull up to desired height above rig floor, Set upper and lower slips, install bowl, slips and collar 17:54 19:42 1.80 10,749 10,749 PROD2 DRILL CTOP T Crew change, Lay down overshot, prep end of coil and install Baker external slip type connector. Pull test and tighten, Pull test to 50K over, Repair HMI block hook weight 19:42 20:12 0.50 10,749 10,749 PROD2 DRILL CTOP T Install 2X2 plug valve on top on coil 20:12 00:00 3.80 11 10,749 PROD2 DRILL CTOP T Stand by on orders, monitor well, maintain hole fill, install connector on injector side of coil. 07/02/2013 Prep E-Line equipment for coil tubing cut, stand by go ahead. Made four attempts to perforate coil tubing with 1"tubing punch above end of wire @ 910'with no success. Coil tubing cut in progress. 00:00 03:00 3.00 10,749 10,749 PROD2 DRILL CTOP T 'Continue to monitor well and hole fill. Call out HES night crew, PJSM, prep E-Line equipment for coil cut. 03:00 13:30 10.50 10,749 10,749 PROD2 DRILL CTOP T Stand by for orders 13:30 14:30 1.00 10,749 10,749 PROD2 DRILL CPBO T Receive plan forward; conduct pre-job safety meeting. begin rigging up eline for tbg punch/cut. Page 13 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 18:00 3.50 10,749 10,749 PROD2 DRILL CPBO T P/T eline pressure equipment to 650 psi-good. Pop back off to make up 1"TS w/tubing punch. RIH and punch tbg at 910',fire punch, POOH, check tool,tool fired,attempt to circulate, no success. 18:00 00:00 6.00 10,749 10,749 PROD2 DRILL CPBO T Made three additional runs with 1" tubing punch assembly @ 10' intervals 900', 890', and 880', all shots fired and checked at surface to confirm, pressure up coil on each shot to different pressures 500,1200,and 1500 psi. No pressure changes after each shot. Decision made to run 1"RCT cutter anyway. 07/03/2013 Two attempts to cut coil @ 870'with HES 1"RCT cutter were unsuccessful. Decision made to run SLB chemical cutter,stand by for SLB E-line equipment from Prudhoe. MIRU SLB equipment, PU tools for dummy run. 00:00 03:00 3.00 10,749 10,749 PROD2 DRILL CPBO T Decision made run 1"RCT cutter. HES MU 1" RCT cutter assembly. RIH w/cutter to 870', pressure coil to 1200 psi,fire cutter, no pressure change, POOH.check tool,tool fired. 03:00 05:30 2.50 10,749 10,749 PROD2 DRILL CPBO T Decision made to make another cutter run. RIH w/same to 870', same parameters,fire cutter, same results as previous run, POOH, check tool,tool fired, LD HES equipment. 05:30 10:30 5.00 10,749 10,749 PROD2 DRILL CPBO T Stand by for direction 10:30 13:00 2.50 10,749 10,749 PROD2 DRILL CPBO T Discuss options with town. SLB Eline truck to be avail this afternoon for chem cut. Demob HES Eline equipment. 13:00 18:30 5.50 10,749 10,749 PROD2 DRILL CPBO T Stand by for SLB Eline crew. 18:30 19:00 0.50 10,749 10,749 PROD2 DRILL CPBO T Gave SLB crew rig orientation 19:00 00:00 5.00 10,749 10,749 PROD2 DRILL CPBO T Spot&RU SLB E-Line unit and equipment. PJSM. Pump 10 bbls 12.0 ppg fluid down annulus @.5 bpm 925 psi. PU/MU tools for dummy run. 07/04/2013 Made to attempts to cut coil with SLB chemical cutters,first attempt with 1.375"cutter @ 920',cutter misfired. Second attempt with 1.25"cutter at same depth was success, pull test verified coil free, RDMO SLB E-Line. 00:00 02:00 2.00 10,749 10,749 PROD2 DRILL CPBO T PU SLB toolstring for drift run,stab on well,test. Pump 10 bbls 12.0 ppg fluid down coil @ .5 bpm 1,500 psi, RIH w/dummy drift to 970', POOH, no issues. 02:00 03:30 1.50 10,749 10,749 PROD2 DRILL CPBO T Unable to arm chemical cutter due to thunderstorm in area, stand by for thunder to pass. Page 14 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 05:00 1.50 10,749 10,749 PROD2 DRILL CPBO T Resume activity. PJSM.Arm cutter, stab on well. RIH w/cutter to 920', fire ctter, POOH to 500', unable to circulate, POOH to check cutter. 05:00 09:00 4.00 10,749 10,749 PROD2 DRILL CPBO T Chem cut failure due to improper igniter use for the chem cutter. SLB crew"houred out." Secure equipment and make arrangements for them to billet in KRU. Discuss options. 09:00 12:30 3.50 10,749 10,749 PROD2 DRILL CPBO T Second BP Eline crew release to work in KRU. Discover correct igniters are unavailable on the slope for 1-3/8"chem cutter;will have to order from Houston in AM(4th of July issues). Decide to run 1-1/4"chem cutter(undersized for cutting our CT). Wait on SLB crew to arrive. 12:30 14:00 1.50 10,749 10,749 PROD2 DRILL CPBO T SLB Eline on location. Perform rig orientation/tour w/Eline personnel. Conduct pre-job safety meeting with rig/eline crews. 14:00 19:00 5.00 10,749 10,749 PROD2 DRILL CPBO T SLB crew rigging back up/prepping to run 1-1/4"chem cutter. Heat mud in pits. 19:00 21:30 2.50 10,749 10,749 PROD2 DRILL CPBO T Pump 10 bbls down annulus, PU cutter,stab on well, RIH to 200', pump 10 bbls down coil, RIH to 920', fire cutter, PUH to 500', circulate, tbg/annulus communicating, POOH. LD SLB tools. 21:30 23:30 2.00 10,749 10,749 PROD2 DRILL CPBO T Prep to pull coil, PU on coil to 5K, open slips, coil free. 23:30 00:00 0.50 10,749 10,749 PROD2 DRILL CPBO IP RD SLB E-Line equipment. 37/05/2013 Finished rigging down SLB E-Line equipment. Recovered 930'of 2"coil from wellbore, leaving approximately 7950'of coil and 72' BHA in hole,top of fish @ 930'.200'diesel cap and 12.0 ppg fluid in wellbore,set BPV. RDMO CDR2. Rig Release @ 12:00 00:00 01:00 1.00 10,749 10,749 PROD2 DRILL CPBO T Finish RD SLB equipment, prep for coil recovery 01:00 03:00 2.00 10,749 10,749 PROD2 DRILL PULL T Cut connector, slide injector, MU splice, dimple connector,zero depth. 03:00 05:30 2.50 10,749 10,749 PROD2 DRILL PULL T Troubleshoot depth counter cable. POOH. Recover 930'of coil, leaving approximately 7950'of coil and 72'of BHA in hole,4398'remaining on reel. 05:30 11:00 5.50 10,749 10,749 DEMOB WELLPF DMOB P Begin demob of rig. Blow down reel/ lines. Disconnect. FMC rep delayed @ Doy 141. Cut off bottom 60'of coil for examination later. 11:00 11:30 0.50 10,749 10,749 DEMOB WELLPF DMOB P Prep to set BPV;find dry-rod has been dismantled(homemade tool issue per Nabors). FMC rep has no lubricator. Fab new dry-rod. Continue prep to move. Page 15 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 12:00 0.50 10,749 10,749 DEMOB WELLPF MPSP P Attempt to set BPV-wrong plug brought to location(drifted thru profile). Wait for FMC rep to bring correct plug to location. On location; set BPV. 10,749 10,749 DEMOB WHDBO NUND P NDBOPE, RDMO XXXXX RIG RELEASE @12:00 XXXXXX Page 16 of 16 Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Wednesday, May 07, 2014 9:36 AM To: 'jason.burke@conocophillips.com' Cc: Davies, Stephen F (DOA); Ferguson, Victoria L (DOA); Bettis, Patricia K(DOA) Subject: Kuparuk 3C-09 L1-01, PTD 213-077, Daily Summaries Jason, While reviewing the Well Completion Report for 3C-09 L1-01, PTD 213-077,API 50-029-21355-61-00, I noticed that ConocoPhillips provided a spud date of 6/24/2013, a TD date of 6/28/2013 and a completion date of July 5, 2013 on that report.The daily summaries attached to the report cover the dates 3/13/2014 to 3/29/2014 and appear to only relate to 3C-09 L1. Please provide the daily summaries for 3C-09 L1-01. If you have any questions, please contact me. Sincerely, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 1 RECEIVED STATE OF ALASKA APR 3 0 2014 • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND JCC la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ • Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory El GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service Q StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. or an July 5,2013 213-077/ 3.Address: 6.D Spudded: 13.API Number: IAG P.O. Box 100360,Anchorage,AK 99510-0360 June 24,2013 50-029-21355-(v I -OO 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1060'FNL,901'FEL,Sec. 14,T12N, R9E,UM June 28,2013 3C-09L1-01 Top of Productive Horizon: 8. KB(ft above MSL): 82'RKB • 15.Field/Pool(s): none GL(ft above MSL): 47'AMSL. Kuparuk River Field • Total Depth: 9.Plug Back Depth(MD+TVD): 1765'FNL, 2184'FEL, Sec. 12,T12N, R9E, UM 10745'MD/6614'TVD Kupuruk River Oil Pool , 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-528673 y- 5995373 Zone-4 11285'MD/6558'TVD • ADL 25634,25629 TPI: none y- none Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-532648 y- 5999963 Zone-4 SSSV @ 1823'MD/1823'TVD 2567,2562 18.Directional Survey: Yes ❑✓ , No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1700'MD/1700'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 8276'MD/6491'TVD . 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT • CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 36' 116' 36' _ 116' 24" 202 sx CSII 9.625" 36# J-55 35' 3943' 35' 3748' 12.25" 1150 sx AS III,300 sx Class G 7" 26# J-55 28' 8299' 28' 6773' 8.5" 440 sx Class G,180 sx PF C 24.Open to production or injection? Yes ❑ No 0 If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) ^`•_ Qel none none none covNa none MY,' ` 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. --at-,-„ED }� ) Was hydraulic fracturing used during completion? Yes No❑✓ DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED none 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) plugged Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ,❑ No ❑✓ Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE RBGMS MAY - 2 2014 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE `/t-3/Z0/1-5- Submit original only vrt 341//5- Afro/fj G 29 GEOLOGIC MARKERS(List all formations and mai encountered) 30 FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results Attach separate sheets to this form,if Permafrost-Bottom 1700' 1700' needed,and submit detailed test information per 20 AAC 25 071. Top Kuparuk A5 8938' 6527' N/A Formation at total depth' Kuparuk A5 31 LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional surveys 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@conocophillips.com Pnnted Name Dar Venhaus Title: CTD Engineering Supervisor / Signatur ^ /� /fiG✓! � Phone 263-4372 Date Z1-2q- INSTRUCTIONS 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. 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. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.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 4b: TPI(Top of Producing Interval). Item 8: 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 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23. 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 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29:Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 • 0 F- r- co a s_.c.,, --L O. �L' MQ I-( ')r MQI -m 0 in AI in 'Q it- a in :„..f:), m Y N U L�Y J r.- o cUa UNcD= 0 C7QF m a2 M coo,' NO c m 0 S�@ I O y a maim I :,,,, I0 co O N- fV (V r', Y co o o o o o m Ea 7o en io o ,\ m CD CC rn m r N �F Q 6 uri Y @ n c aro m n I on w _ l'‘ f co © W W E N vo _ o 5 YN- N U J Z d a. O _ c ii m N N m et LL X C d O F' iii 2 F a y to li co E OI 2 Y CO N r Y Y N L m m co m ~ ICV ,, ,I I 4 �c • \ ' II co .71MIN 113 0III III N ci U I PIM !! 1 1 .F_o N 70 m O N ^^ O n W r a�t0 wm .Yy 2 2 o dit O G n0t . .^ O d r aD UM• IVfO NOy � 0. -o- Eo 0)M L IN;- ;i• N t- o` W D II CLm yN CO '05 O CD N Nr„, m r NfipN d@ ¢rco NSt (S=a ConocoPhiIIips Time Log & Summary We//view Web Reporting Report Well Name: 3C-09 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 3/15/2014 6:00:00 AM Rig Release: 3/30/2014 12:00:00 AM Time Logs Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 03/13/2014 24 hr Summary Waiting on Sows for rig move to 3C-pad 12:00 00:00 12.00 0 0 MIRU MOVE MOB T Waiting on Sows for rig move to 3C-Pad 03/14/2014 Waiting on Sows for rig move to 3C-pad, PJSM, Mobilize CDR2 from 3N-08 to 3C-09 utilizing CH2MHILL equipment, RU on 3C-09, berm cellar. RU landings,steam, comm, and PUTZ. 00:00 06:00 6.00 0 0 MIRU MOVE MOB T Waiting on Sows for rig move to 3C-Pad, prep rig for move. 06:00 15:00 9.00 0 0 MIRU MOVE MOB P Trucks on location, PJSM with new to process CH2MHILL, Pull off well and install jeeps, mobilize to 3C-09. 15:00 18:00 3.00 0 0 MIRU MOVE MOB P Arrive @ 3C, remove jeeps, prep cellar area spot rig module 18:00 21:00 3.00 0 0 MIRU MOVE MOB P Spot up pit module, Berm cellar, R/U landings, Unable to Mob shop,will have to wait for PEAK trailer, 21:00 00:00 3.00 0 0 MIRU MOVE MOB P PJSM-R/U Steam, R/U Comms,TT installed, Rig up cellar, R/U Putz 33/15/2014 NU BOPE. Perform initial BOPE test 250/4,000 psi. Pull BPV, initial tubing 445 psi, Closure test SSSV, good test. 00:00 06:00 6.00 0 0 MIRU MOVE MOB P PJSM-Nipple up BOPE equipment, grease tree valves,tighten up tree flanges,fill stack. Rig Accept: 06:00 AM 06:00 18:00 12.00 0 0 MIRU WHDBO BOPE P Start initial BOPE test, test witnessed by Chuck Sheave, AOGCC rep.Three fail/pass, change-out B-8 and C-10 valves. 18:00 19:00 1.00 0 0 MIRU WHDBO BOPE T Test B-8 and C-10 valves,good. 1 hour non-productive time. 19:00 20:00 1.00 0 0 MIRU WHDBO PRTS P BOPE test complete, pressure test ODS PDL,tiger tank line, 20:00 23:00 3.00 0 0 MIRU WHDBO PRTS P FMC here to pull BPV, suspend PDL PT ops, PJSM to pull valve, LD lubricator assembly,WHP 445 psi, attempt to bleed WHP down, pressure returns to 445 psi, perform closure test on SSSV,good test. 23:00 00:00 1.00 0 0 MIRU WHDBO PRTS P PJSM-Pressure test PDL,start loading coil with seawater 03/16/2014 Test PDL's, Load coil,test stripper, inner reel iron. MU/TIH with clean out BHA#1,-6.5 tie in correction,dry drift window,work from 7,865'to 8,039', bit stuck at 7,945'on 2nd wiper trip to window, CBU to free up, TOOH, standby and RU SLB E-line. Page 1of12 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:36 3.60 0 0 MIRU WHDBO PRTS P Continue load coil,test stripper and inner reel iron. Pre-Spud 03:36 06:09 2.55 0 62 SLOT WELLPF PULD P PJSM-install checks, PU/MU BHA #1 clean out ass'y. Surface test tools 06:09 08:39 2.50 62 7,720 SLOT WELLPF TRIP P TIH with Clean Out BHA#1, stack out on ice?@ 70',work through, continue in hole,tie-in for-6.5' correction, RBIH. 08:39 09:39 1.00 7,220 7,865 SLOT WELLPF CIRC P Circulate hole to used 9.6 ppg mud system. Shut pump,dry drift window, clean. 09:39 11:21 1.70 7,865 8,039 SLOT WELLPF FCO P Start stacking @ 7,865',work through tight spots to 8,010',take 10'-20'bites. Make two wiper trips to window, continue working through tight spots to 8,039'. During second wiper became bit stuck @ 7,945', motor stalled, pumedp bottoms up, pull free. 11:21 13:27 2.10 8,039 66 SLOT WELLPF TRIP P Decision made from town, go to plan B, perforate WS.TOOH, close SSSV. 13:27 14:45 1.30 66 0 SLOT WELLPF PULD P At surface,flow check, LD BHA#1 14:45 19:45 5.00 0 0 SLOT PERF PERF P Stand by for SLB E-line equipment from Prudhoe, service reel, rig projects. 19:45 20:45 1.00 0 SLOT PERF SFTY P SLB onsite, Rig orientation for SLB crew, PJSM-rigging up e-line to CDR,job walk. 20:45 00:00 3.25 SLOT PERF RURD P RU SLB E-line. 03/17/2014 RU SLB E-line, Perf whipstock tray from 7,850'to 7,853' ELM while holding 12 ppg over balance,guns confimed fired. Set Baker XL monobore whipstock with TOWS at 7,827'ELM,2°LOHS, RA tags positioned 6' below TOWS. 00:00 02:00 2.00 0 0 SLOT PERF RURD P Continue to RU SLB E-line 02:00 03:30 1.50 0 0 SLOT PERF RURD T Found raised armore on cable, cut cable and rehead. 03:30 06:00 2.50 0 0 SLOT PERF RURD P Continue to RU SLB E-line, pressure test equipment, break off at test sub and PU 1.56"HSD guns,test break. 06:00 08:15 2.25 0 0 SLOT PERF ELNE T RIH w/gun, unable to work through tree, POOH and weight bar. 08:15 12:30 4.25 0 7,899 SLOT PERF ELNE P RIH w/1.56" HSD guns, make correlation passes, unable to oriented tools, motor not performing properly. Run toolstring up/down hole for proper orientation, got 178 degree, need 172, keep working tools. 12:30 13:00 0.50 7,899 7,825 SLOT PERF ELNE P Shut down E-Line, perform static pressure survey, 13:00 13:30 0.50 7,825 7,825 SLOT PERF ELNE T Continue working tools for proper orientation, unsuccessful, POOH for tool change. Page 2of12 • Time Logs ' Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 16:15 2.75 0 0 SLOT PERF ELNE I T LD E-Line toolstring,function test tools on surface, performed on surface, change complete toolstring. 16:15 18:30 2.25 0 7,890 SLOT PERF ELNE P RBIH with 1.56"HSD guns, make correlation passes, orient guns ti low side, 170 degress, pressure up whp from 130 psi to 800 psi, maintain 800 psi,fire gun, shut down pump,whp bleeding down slowly from 725 psi, appears guns fired, POOH. 18:30 20:45 2.25 7,890 0 SLOT PERF ELNE P PJSM.At surface, LD guns, gun fired. PJSM. MU Baker WS assembly with two RA tags positioned 6'below TOWS. 20:45 00:00 3.25 0 7,827 PROD1 RPEQP1 ELNE P RIH w/3.5" Baker Mono-bore Whipstock, make correlation passes, RBIH and make pull up pass,stop CCL at 7,812.5'with 14.5' offset,TOWS at 7,827'with final orientation 2° LOHS, release off whipstock. Daily losses: 28 bbls 9.5 ppg Flo Pro Total losses: 59 bbls 9.5 ppg Flo Pro 03/18/2014 RD SLB E-line. Milled 3.5"tubing 7827.1'-7833.1'. Found tubing communication by IA, research SOV set at 7580', GLM#5 POOH, RU Slickline. 00:00 01:00 1.00 7,827 0 PROD1 RPEQP1 ELNE P TOOH with Baker setting tool,close SSSV. 01:00 04:00 3.00 0 0 PROD1 RPEQP1 ELNE P PJSM-RD SLB E-line equipment 04:00 06:12 2.20 0 72 PROD1 WHPST PULD P PJSM-PU/MU tubing window milling BHA#2, 6°AKO motor,2.80 Dimond window mill, 2.80 string reamer,open SSSV. 06:12 08:00 1.80 72 7,415 PROD1 WHPST TRIP P TIH with BHA#2,open SSSV. 08:00 08:18 0.30 7,415 7,475 PROD1 WHPST DLOG P Log tie in for-9'correction, PUW 23k. 08:18 08:48 0.50 7,475 7,827 PROD1 WHPST TRIP P RIH to find top of whipstock, Dry tag 7,827.1', PUW 23k. 08:48 12:27 3.65 7,827 7,830 PROD1 WHPST MILL P Call pinch point 7,827.1, stalled one time, Mill per procedure, 1.42 BPM @ 3550 PSI, BHP 4420,exit 3.5" Tbg. Note: IA pressure increasing to 720 psi, attempt to bleed down, noticed return rate decrease, shut in IA, all pressures returned to previous drilling pressures 200/720/380, OA slowly increasing(thermal)research SOV set at 7,580'sheared on last work over not replaced prior to CDR2 moving over well,confer with town engineer. estimate 1 bbl bled from IA. continue on and monitor IA/OA until tubing window complete. Page 3 of 12 Time Logs ' Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:27 15:27 3.00 7,830 7,833 PROD1 WHPST MILL P Continue time milling tubing exit window, 1.45 bpm @ 3609 psi, BHP 4516 psi, 15:27 16:15 0.80 7,833 7,833 PROD1 WHPST REAM P Make reaming passes through window,dry drift window, looks good. 16:15 17:54 1.65 7,833 72 PROD1 WHPST TRIP P TOOH to RU Slikeline and change out sheared SOV in GLM#5 at 7,580' RKB. 17:54 19:24 1.50 72 0 PROD1 WHPST PULD P On surface, close SSSV,flow check, PJSM-LD BHA#2 ****Note: Mills gauged 2.80 nogo 2.79 go 19:24 20:00 0.60 0 0 PROD1 WHPST SFTY T Rig safety orientation for Slickline crew, PJSM-rigging up Slickilne. 20:00 00:00 4.00 0 0 PROD1 WHPST PULD T Rig up slick line,w/30'lubricator, 4.5"BOPE 33/19/2014 M/U, RIH w/3"OM-1 & 1.5"DMY on RK, Set at 7571'SLM, POOH w/sheared SOV, RIH w/3"GS to 7689.8' SLM, POOH w/catcher sub, R/D slickline. M/U, RIH w/second window milling BHA#3, Mill 7"casing exit. 00:00 00:36 0.60 0 0 PROD1 WHPST SLKL T Make up Slickline tools. 00:36 02:06 1.50 0 0 PROD1 WHPST SLKL T M/U, RIH w/2.79"gauge ring down to 7800'SLM. POOH, L/D SLT. 02:06 03:36 1.50 0 0 PROD1 WHPST SLKL T M/U, RIH,w/catcher sub, set at 7689.8'SLM, POOH, L/D SLT. 03:36 05:51 2.25 0 0 PROD1 WHPST SLKL T M/U, RIH w/3"OM-1 & 1.625"JDC to 7,571'SLM (7,580'RKB)POOH w/sheared SOV on RKP 05:51 08:36 2.75 0 0 PROD1 WHPST SLKL T M/U, RIH w/3"OM-1 & 1.5"DMY on RK, SET at 7,571'SLM, bleed IA pressure down f/474 psi to 0 psi, shear off, IA 0 psi-POOH. 08:36 08:51 0.25 0 0 PROD1 WHPST SLKL T PJSM with New Slickline crew 08:51 10:21 1.50 0 0 PROD1 WHPST SLKL T M/U, RIH w/3"GS to 7689.8'SLM- POOH w/catcher sub. 10:21 12:00 1.65 0 0 PROD1 WHPST SLKL T PJSM-RD Slickline, IA holding 0 psi. 12:00 13:00 1.00 0 0 PROD1 WHPST PULD P PJSM-close SSSV, flow check failed, open/close SSSV, flow check, no joy, prep to Pressure Deploy. 13:00 16:00 3.00 0 73 PROD1 WHPST PULD P PU/MU/PD BHA#3, casing exit milling ass'y. 16:00 17:45 1.75 73 7,425 PROD1 WHPST TRIP P TIH with window milling BHA#3, Weatherford 2.0°bend motor, HCC Fat radius window mill,2.79 nogo/ 2.80 go, EDC open. 17:45 18:00 0.25 7,425 7,475 PROD1 WHPST DLOG P Log tie-in to K1,-8'correction, PUW 24k 18:00 18:15 0.25 7,475 7,834 PROD1 WHPST TRIP P Continue RIH to bottom, 18:15 23:15 5.00 7,834 7,837 PROD1 WHPST MILL P 7834.1'-15° ROHS, Start time milling 1.48bpm at 3690psi, BHP 4006,WHP 206, IA 403, OA 263 ****Note: Bleed IA down from 830psi to 293psi. Page 4 of 12 Time Logs • Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 23:15 00:00 0.75 7,837 7,837 PROD1 WHPST MILL P Looks like we exited the 7"casing @ 7836.9', lost 1000lbs WOB, continue time milling as per plan. 03/20/2014 Finished milling 7"casing exit, and rate hole 7853'. POOH, PUD BHA#3, P/U, M/U, PD, RIH w/build section BHA#4. Drill ahead from 7853'-8057'. 00:00 03:15 3.25 7,837 7,853 PROD1 WHPST MILL P Continue time milling 2'past 7" casing exit(7837'), 1.50bpm at 3690psi, BHP 4030,WHP 250, IA 693, OA 568, samples showing 60% formation sand. ****Note: Bled IA 693psi-133psi OA 596psi-151 psi 03:15 06:09 2.90 7,853 7,824 PROD1 WHPST REAM P 7853'TD rate hole. Back ream window area 7839'-7824'. pumping 1.48bpm at 3767psi, BHP 4022, WHP 232, IA 133, OA 151 Back ream at 15° ROHS,60° ROHS, and 30° LOHS. 06:09 08:03 1.90 7,824 73 PROD1 WHPST TRIP P POOH 08:03 10:03 2.00 73 0 PROD1 WHPST PULD P PJSM-PUD, LD BHA#3, even wear on mill face, 2.79 nogo/2.80 go, slight wear to wear pad on motor at bend 10:03 10:39 0.60 0 0 PROD1 DRILL BOPE P PJSM-Perform BOPE function test. 10:39 13:33 2.90 0 63 PROD1 DRILL PULD P PJSM-PU/MU BHA#4, build section drilling ass'y, PD BHA#4,trouble getting BHA to nogo, crooked tree. 13:33 16:00 2.45 63 7,853 PROD1 DRILL TRIP P RIH w/drilling assembly,X-treme motor 2.2°+AKO, HCC bit. Tie-in for -8'correction, close EDC, PUW 22k, RBIH,shut down pump thru window. 16:00 21:15 5.25 7,853 8,010 PROD1 DRILL DRLG P 7,853', Drill ahead, 1.45 bpm @ 3605 psi, BHP 4432 psi, CTW 11.2k, DHWOB 1.2k, ROP 35, circulate _ well to new mud system. 21:15 21:45 0.50 8,010 7,435 PROD1 DRILL WPRT P 8010',Wiper up hole PUW 24k. Pull up through window at min rate. 7800' RIBH to 7821'open EDC and PUH to tie into the K1 marker. ****Note: New mud at the bit 7985'/ 1831'drilled footage-0.9%drill solids. 21:45 22:00 0.25 7,435 7,447 PROD1 DRILL DLOG P 7435',Tie into the K1 marker _ correction of+0.5'. 22:00 22:30 0.50 7,447 8,010 PROD1 DRILL WPRT P Continue Wiper back in hole,tie in the WS. ****Offical Window Depths TOW 7827' RA 7833' BOW 7837' 22:30 00:00 1.50 8,010 8,057 PROD1 DRILL DRLG P 8010', BOBD 1.48bpm at 3500psi, BHP 4019,WHP 106, IA 190, OA 295 Page 5 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/21/2014 24 hr Summary Drill ahead from 8057'to end of build section 8120'. POOH for L1 lateral BHA#5. 00:00 02:00 2.00 8,057 8,120 PROD1 DRILL DRLG P Continue drilling build section. 1.41 bpm at 3500psi, BHP 4014, WHP 101, IA 193, OA 298 02:00 04:00 2.00 8,120 63 PROD1 DRILL WPRT P 8120'TD build section, landed at 6407'TVD,Wiper up hole PUW 25k 04:00 04:15 0.25 63 63 PROD1 DRILL SFTY P PJSM-Undeploying build BHA#4 04:15 06:30 2.25 63 0 PROD1 DRILL PULD P Undeploy BHA#4 06:30 06:45 0.25 0 0 PROD1 DRILL SFTY P PJSM-Deploying BHA#5 06:45 09:09 2.40 0 72 PROD1 DRILL PULD P PU/MU BHA#5, lateral drilling ass'y, PD BHA#5. 09:09 11:21 2.20 72 8,120 PROD1 DRILL TRIP P RIH w/L1 lateral drilling assembly, X-treme motor.8°AKO, new HYC bit. K1 tie-in for-7'correction,close EDC, PUW 22k, RBIH,shut down pump,clean pass thru window and build section. 11:21 14:54 3.55 8,120 8,270 PROD1 DRILL DRLG P 8,120', Drill ahead L1 lateral: 1.41 bpm @ 3954, BHP 4754 psi,WHP 159,CTW 11k, DHWOB 1.42k, ROP 60, IA-0, OA-0. 14:54 16:09 1.25 8,270 8,270 PROD1 DRILL WPRT P 8,270' ,Wiper trip to 7,838'at window with MAD Pass, PUW=25K, RBIH. 16:09 19:09 3.00 8,270 8,420 PROD1 DRILL DRLG P 8,270', Drill ahead 1.40 bpm @ 3865, BHP 4753 psi,WHP 107 psi, CTW 8.5k, DHWOB 2.3k, ROP 60, IA- 133, OA-253. 19:09 19:54 0.75 8,420 7,880 PROD1 DRILL WPRT P 8420'Wiper up hole chasing 5x5 sweep, PUW 26k 19:54 20:12 0.30 7,880 8,420 PROD1 DRILL WPRT P 7880',Wiper back in hole. RIW 11 20:12 22:12 2.00 8,420 8,570 PROD1 DRILL DRLG P 8420', BOBD 1.42bpm at 3658psi, BHP 4094,WHP 61, IA 201, OA 324 22:12 22:36 0.40 8,570 7,854 PROD1 DRILL WPRT P 8570',Wiper up hole. PUW 24 22:36 22:51 0.25 7,854 7,874 PROD1 DRILL DLOG P 7854',Tie into the RA marker correction of- 1.0'. 22:51 23:15 0.40 7,874 8,570 PROD1 DRILL WPRT P 7874', Continue wiper in hole. RIW 12k 23:15 00:00 0.75 8,570 8,624 PROD1 DRILL DRLG P 8570', BOBD 1.45bpm at 3750psi, BHP 4114,WHP 67, IA 294, OA 391 33/22/2014 Drilled ahead from 8120'to 8720'.Wiper from 8720'with tight spots at 8400',8330', and 8200'. RBIH +/-50'at a time cleaning hole. Pump 5x5 sweep,course shale coming across shaker,and plugging off choke, Call town team for plan forward. Make a wiper trip up into casing 2000'. BHI EDC failed at the window,continued POOH, Plugged off choke again at 2300'. Decision it to make a clean out run down to 8250'in preparation for open hole billet. 00:00 00:15 0.25 8,624 8,524 PROD1 DRILL WPRT P 8624', Geo wiper 00:15 00:30 0.25 8,524 8,624 PROD1 DRILL WPRT P 8524',Wiper back in hole RIW 12k 00:30 02:30 2.00 8,624 8,720 PROD1 DRILL DRLG P 8624', BOBD 1.45bpm at 3700psi, BHP 4063,WHP 20, IA 360, OA 424 02:30 03:00 0.50 8,720 7,900 PROD1 DRILL WPRT P 8720',Wiper up hole PUW 26k Page 6 of 12 Time Logs ' Date From To Dur S. Death E. Death Phase Code Subcode T Comment 03:00 03:30 0.50 7,900 8,720 PROD1 DRILL WPRT P 7900',Wiper back in hole RIW 10k ****Note: 8250'-8450'tight spot 03:30 04:00 0.50 8,720 8,140 PROD1 DRILL WPRT P 8720',Wiper up hole to clean up, pumping 1.44bpm pumping 5x5 sweep, pulled 55k at 8,330', pulled thru tight area to 8,200',wiper to end of build. 04:00 07:51 3.85 8,140 7,550 PROD1 DRILL WPRT P 8,140',Wiper back in hole,start ' satcking out at 8,208',take 50±bites w/wipers to end of build to clean up hole, coarse shale coming across shaker, sat down at 8,300'and 8,318' and 8,321', PUW up to 55k with up to-10k on bit to 8,250', packing off above BHA, pump 10 bbls Hi vis sweep, PU into tubing, EDC will not open. 07:51 10:00 2.15 7,550 72 PROD1 DRILL WPRT T TOOH to clean up well, change out EDC as per BHI DD.well unloaded coarse shales at 2,300',jog at surface. 10:00 12:18 2.30 72 0 PROD1 DRILL PULD T PJSM-PUD, lay down drilling BHA #5, inspect choke, service injector. 12:18 12:33 0.25 0 0 PROD1 DRILL SFTY T PJSM-Pressure deploy cleanout BHA#6, 12:33 14:33 2.00 0 63 PROD1 DRILL PULD T PU/MU/PD BHA#6. 14:33 16:48 2.25 63 8,250 PROD1 DRILL TRIP T TIH with BHA#6, cleanout ass'y, K1 11 tie-in for-5'correction, PUW 24k, continue in hole, RIW 11k, clean drift thru window and build section, no issues to 8,250'. 16:48 20:06 3.30 8,250 63 PROD1 DRILL WPRT T 8,250', Pump 5x5 hi/lo sweep, Wiper up hole 20:06 20:21 0.25 63 63 PROD1 DRILL SFTY T PJSM-Undeploy cleanout BHA#6 20:21 21:36 1.25 63 0 PROD1 DRILL PULD T Undeploy clean out BHA#6 21:36 21:51 0.25 0 0 PROD1 DRILL PULD T M/U Open Hole Anchor billet BHA#7 21:51 22:36 0.75 0 73 PROD1 DRILL PULD T Pressure deploy BHA#7, M/U INJH and Test BHI tools. MWD reports failure in lower part of tools. 22:36 22:51 0.25 73 73 PROD1 DRILL SFTY T PJSM-For undeploying BHA#7 Failed DGS and HOT 22:51 00:00 1.15 73 0 PROD1 DRILL PULD T Undeploy Failed BHA 03/23/2014 RIH, set Open Hole Anchored Billet at 8030', POOH, UD,and L/D BHA#7. M/U, PD, and RIH to build/kick off of billet. Kicked off of billet 8031'.Drilled and TD'd the build section at 8235'. POOH for lateral BHA. 00:00 01:12 1.20 0 73 PROD1 STK PULD T Deploy BHA#7 01:12 04:00 2.80 73 7,450 PROD1 STK TRIP T RIH w/Open hole anchored billet 04:00 04:15 0.25 7,450 7,484 PROD1 STK DLOG T 7450',Tie into the K1 marker correction-10.0' 04:15 04:33 0.30 7,484 8,030 PROD1 STK TRIP T Continue in hole to setting depth. PUW above window 26k 04:33 04:48 0.25 8,030 8,030 PROD1 STK WPST T Set TOB at 8030', Setting tool sheared at 4400psi. Page 7 of 12 Time Logs ' Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:48 07:00 2.20 8,030 73 PROD1 STK TRIP T POOH,w/open EDC 07:00 07:15 0.25 73 73 PROD1 STK SFTY T PJSM-For undeploying BHA#7 07:15 08:48 1.55 73 0 PROD1 STK PULD T Undeploy clean out BHA#7 08:48 09:03 0.25 0 0 PROD1 STK SFTY T PJSM-For deploying BHA#8 09:03 10:36 1.55 0 63 PROD1 STK PULD T PU/MU/PD BHA#8 10:36 12:48 2.20 63 8,031 PROD1 STK TRIP T RIH w/kick off and build section drilling ass'y,X-treme motor 1.7° AKO, HCC bit(RR 1-1)Tie-in for-7' correction,continue in hole to window, close EDC, PUW 25k above window, clean drift through window, dry tag TOB at 8,030.9' 12:48 16:42 3.90 8,031 8,050 PROD1 STK KOST T 8,031', Begin time milling billet as per well plan TF 160°, mill at 1,2,3,10,and 20 fph, 1.46 bpm at 3670 psi, BHP 4365. 16:42 16:54 0.20 8,050 8,050 PROD1 STK KOST T 8,050',dry drift billet, clean, PUW 25k. 16:54 21:24 4.50 8,050 8,190 PROD1 DRILL DRLG T 8050', Drill ahead L1 buld section, 1.42 bpm @ 3775 psi, BHP 4412 psi, CTW 11.1k, DHWOB .9k. 21:24 21:54 0.50 8,190 7,870 PROD1 DRILL WPRT T 8190',Wiper up hole PUW 27k 21:54 22:24 0.50 7,870 8,190 PROD1 DRILL WPRT T 7870',Wiper back in hole. RIW 12k 22:24 22:54 0.50 8,190 8,235 PROD1 DRILL DRLG T 8190', BOBD 1.43bpm at 3795psi, BHP 4063,WHP 67, IA 237, OA 383 22:54 00:00 1.10 8,235 5,189 PROD1 DRILL TRIP T 8235',TD build section. POOH 03/24/2014 TD build section 8235', POOH, UD, and L/D build BHA#9, M/U, PD, and RIH w/lateral drilling assy. Drilled ahead in the L1 lateral. 00:00 01:15 1.25 5,189 63 PROD1 DRILL TRIP T 5189', Continue POOH for lateral BHA 01:15 01:30 0.25 63 63 PROD1 DRILL SFTY T PJSM-Undeploy build BHA#8 01:30 02:45 1.25 63 0 PROD1 DRILL PULD T Undeploy, UD BHA#8 02:45 04:00 1.25 0 72 PROD1 DRILL PULD T M/U and deploy L1 lateral BHA#9 04:00 07:00 3.00 72 8,235 PROD1 DRILL TRIP T RIH w/L1 lateral drilling assy, 2-3/8" X-Treme motor, 0.7°AKO, rebuild Reed-Hycalog bit.Tie-in for-9' correction, continue in hole to window, close EDC, PUW 25k above window, clean drift through window, build section clean. 07:00 17:45 10.75 8,235 8,385 PROD1 DRILL DRLG T 8,035', Drill ahead 1.43 bpm at 3947 psi, BHP 4045,WHP 76, IA 183, OA 306, perform mud system swap, up KlaStop to 2.5%per town. **"New mud at the bit 8,274'/972' drilled footage-0.5%drill solids. 17:45 18:24 0.65 8,385 7,875 PROD1 DRILL WPRT T 8,385', Wiper up hole, PUW 24k. _.._ _ Page 8 of 12 Time Logs ' Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:24 18:45 0.35 7,875 8,385 PROD1 DRILL WPRT T 7,875', Wiper back in hole, RIW 12k. 18:45 22:00 3.25 8,385 8,535 PROD1 DRILL DRLG T 8,385', BOBD 1.42 bpm at 3739 psi, BHP 4008,WHP 146, IA 368, OA 520 22:00 22:24 0.40 8,535 8,050 PROD1 DRILL WPRT T 8,535', Wiper up hole, PUW 26k. 22:24 22:42 0.30 8,050 8,535 PROD1 DRILL WPRT T 8,050', Wiper back in hole, RIW 13k. 22:42 00:00 1.30 8,535 8,600 PROD1 DRILL DRLG T 8,535', BOBD 1.41 bpm at 3781 psi, BHP 4076,WHP 148, IA 408, OA 535 33/25/2014 Drill L1 Lateral 8600'to 9540 00:00 01:45 1.75 8,600 8,685 PROD1 DRILL DRLG T OBD 1.5bpm at 3525psi, BHP 4054, WHP 104, IA 461,OA 546. 01:45 02:30 0.75 8,685 7,855 PROD1 DRILL WPRT T 8685',Wiper up hole. PUW 27k 02:30 02:45 0.25 7,855 7,872 PROD1 DRILL DLOG T 7855',Tie into the RA marker correction -0.5'. 02:45 03:15 0.50 7,872 8,685 PROD1 DRILL WPRT T 7872',Wiper back in hole. RIW 12k 03:15 03:48 0.55 8,685 8,720 PROD1 DRILL DRLG T 8685', BOBD 1.5bpm at 3575psi, BHP 4099,WHP 157, IA 443, OA 541 03:48 06:00 2.20 8,720 8,835 PROD1 DRILL DRLG P 8720', OBD 1.5bpm at 3575psi, BHP 4060,WHP 114, IA 570, OA 609 06:00 06:45 0.75 8,835 8,237 PROD1 DRILL WPRT P 8835',Wiper up hole PUW 27k 06:45 07:15 0.50 8,237 8,835 PROD1 DRILL WPRT P 8237',Wiper back in hole. RIW 10k 07:15 09:15 2.00 8,835 8,985 PROD1 DRILL DRLG P 8835', BOBD 1.5bpm at 3791', BHP 4084,WHP 112, IA 604, OA 639 09:15 10:00 0.75 8,985 7,900 PROD1 DRILL WPRT P 8985',Wiper up hole PUW 30k 10:00 10:45 0.75 7,900 8,985 PROD1 DRILL WPRT P 7900',Wiper back in hole. RIW 10k 10:45 12:45 2.00 8,985 9,135 PROD1 DRILL DRLG P 8985', BOBD 1.5bpm at3850psi, BHP 4110,WHP 103, IA 630, OA 657 12:45 13:45 1.00 9,135 7,853 PROD1 DRILL WPRT P 9135',Wiper up hole. PUW 27k 13:45 14:00 0.25 7,853 7,872 PROD1 DRILL DLOG P 7853',Tie into the RA marker no correction. 14:00 14:30 0.50 7,872 9,135 PROD1 DRILL WPRT P 7872',continue wiper back in hole. RIW 12k 14:30 16:30 2.00 9,135 9,285 PROD1 DRILL DRLG P 9135', BOBD 1.45bpm at 3820psi, BHP 4127,WHP 81, IA 150, OA 165 16:30 17:09 0.65 9,285 8,235 PROD1 DRILL WPRT P 9285',Wiper up hole. PUW 27k 17:09 17:39 0.50 8,235 9,285 PROD1 DRILL WPRT P 8235',Wiper back in hole. RIW 11k 17:39 20:45 3.10 9,285 9,435 PROD1 DRILL DRLG P 9285', BOBD 1.45bpm at 3885 PSi FS 20:45 22:03 1.30 9,435 9,435 PROD1 DRILL WPRT P Wiper to 8400, PUW=27K 22:03 00:00 1.95 9,435 9,540 PROD1 DRILL DRLG P 9435', Drill ahead, 1.42 BPM @ 3806 PSI FS, RIW=7K, BHP=4198 03/26/2014 Drill 9540 to 10182, Swap mud @ 9954 Bit 00:00 01:00 1.00 9,540 9,585 PROD1 DRILL DRLG P 9540', Drill ahead, 1.42 BPM @ 3806 PSI FS, BHP=4170 Page 9 of 12 • Time Logs ' Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 03:30 2.50 9,585 9,585 PROD1 DRILL WPRT P Wiper trip to window with tie in for +1', PUW=28K 03:30 06:30 3.00 9,585 9,735 PROD1 DRILL DRLG P 9585', Drill ahead, 1.45 BPM @ 3747 PSI FS, BHP=4156 06:30 07:12 0.70 9,735 8,474 PROD1 DRILL WPRT P 9735',Wiper up hole PUW 27k 07:12 07:54 0.70 8,474 9,735 PROD1 DRILL WPRT P 8474',Wiper back in hole. RIW 10k 07:54 09:54 2.00 9,735 9,862 PROD1 DRILL DRLG P 9735', BOBD 1.43bpm at 3815psi, BHP 4164,WHP 80, IA 328, OA 307 09:54 10:09 0.25 9,862 9,885 PROD1 DRILL DRLG P 9862', Motor stall, PUH, RBIH BOBD 1.43bpm at 3800psi, BHP 4112, WHP 35, Losing fluid to formation 0.10bpm 10:09 10:54 0.75 9,885 8,500 PROD1 DRILL WPRT P 9885',Wiper up hole PUW 30k 10:54 11:24 0.50 8,500 9,885 PROD1 DRILL WPRT P 8500',Wiper back in hole. RIW 10k 11:24 15:00 3.60 9,885 10,035 PROD1 DRILL DRLG P 9885', BOBD 1.43bpm at 3800psi, BHP 4178,WHP 35, IA 356, OA 321 15:00 16:30 1.50 10,035 7,800 PROD1 DRILL WPRT P 10035',Wiper up hole PUW 27k 16:30 17:24 0.90 7,800 5,800 PROD1 DRILL WPRT P 7800', Continue wiper up hole. PUW 24k, Open EDC pull wiper up to 5800'm, 17:24 17:36 0.20 7,450 7,472 PROD1 DRILL DLOG P Tie into K1 for+1.5' 17:36 18:54 1.30 7,472 10,035 PROD1 DRILL WPRT P Continue wiper trip back in hole, Close EDC @7800' 18:54 23:18 4.40 10,035 10,182 PROD1 DRILL DRLG P 10035', Drill Ahead, 1.44 BPM @3690 PSI FS, BHP=4170, looks like ankorite string 10120-10130' 23:18 00:00 0.70 10,182 9,565 PROD1 DRILL WPRT P Wiper to 9400', PUW=26K 03/27/2014 Drill 10182 to 10760', Called TD early. Pumps sweeps and chase to swab 00:00 00:24 0.40 9,565 10,182 PROD1 DRILL WPRT P Continue wiper back in hole to drill 00:24 02:24 2.00 10,182 10,311 PROD1 DRILL DRLG P 10182', Drill Ahead, 1.4 BPM @ 3650 PSI FS, BHP=4166, running out of push near end of drilling interval. Perform BHA Wipers @ 10303 and 10311.-5K surface weight poor transfer 02:24 04:06 1.70 10,311 10,311 PROD1 DRILL WPRT P Wiper to 9100', PUW=29K, Clean trip up and down, RIW near bottom 7K 04:06 09:36 5.50 10,311 10,460 PROD1 DRILL DRLG P 10311', Drill ahead, 1.4 BPM @ 3715, BHP=4177, RIW OBD=-5K, DHWOB=1.91 K 09:36 10:55 1.32 10,460 7,850 PROD1 DRILL WPRT P 10460',Wiper up hole to the window for a tie in chasing 5x5 sweep, PUW 26k 10:55 11:10 0.25 7,850 7,872 PROD1 DRILL DLOG P 7850',Tie into the RA marker with no correction. 11:10 12:25 1.25 7,872 10,460 PROD1 DRILL WPRT P 7872',Wiper back in hole. RIW 10k 12:25 15:40 3.25 10,460 10,610 PROD1 DRILL DRLG P 10460', BOBD 1.44bpm at 3875psi, BHP 4249,WHP 91, IA 376, OA 338 15:40 16:25 0.75 10,610 9,400 PROD1 DRILL WPRT P 10610',Wiper up hole. PUW 30k Page 10 of 12 Time Logs ' Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:25 17:10 0.75 9,400 10,610 PROD1 DRILL WPRT P 9400',Wiper back in hole RIW 6k 17:10 19:16 2.10 10,610 10,760 PROD1 DRILL DRLG P 10610', BOBD 1.43bpm at 3878psi, BHP 4210,WHP 18, IA 459, OA 401 19:16 23:40 4.40 10,760 70 PROD1 DRILL WPRT P Wiper trip to 9800 with 5X5 Sweep, Call TD during wiper, pump 10x10 sweeps and chase to swab, _PUW=32K 23:40 23:59 0.33 70 900 PROD1 DRILL WPRT P Reset counter and trip in hole 03/28/2014 Complete rolling hole to 12.0 PPG completion fluid, M/U L1 Liner and run to TD @ 10760, Trip out 00:00 01:24 1.40 900 7,450 PROD1 DRILL WPRT P Continue in well after chaseing sweeps to swab 01:24 01:36 0.20 7,450 7,472 PROD1 DRILL DLOG P Log K1 for-8'correction, PUW=25K 01:36 03:36 2.00 7,472 10,670 PROD1 DRILL WPRT P Continue in hole,clean pass through window and past billet 03:36 07:06 3.50 10,670 72 PROD1 DRILL TRIP P Trip out of well laying in 12.0 Beaded liner running pill followed by 12.0 PPG Completion fluid. Paint EOP flags @ 7700 and 4700' 07:06 07:51 0.75 72 72 PROD1 DRILL SFTY P At surface, perform flowcheck, PJSM for laying down lateral drilling BHA# 9. 07:51 09:06 1.25 72 0 PROD1 DRILL PULD P LID tools, and prep for M/U liner assy. 09:06 09:36 0.50 0 0 COMPZ CASING SFTY P PJSM-running L1 liner completion 09:36 18:48 9.20 0 2,984 COMPZ CASING PUTB P Start making up L1 liner assy. 18:48 20:06 1.30 2,984 7,684 COMPZ CASING RUNL P RIH w/L1 liner assy. 81jts slotted, 12 jts of solid 20:06 20:12 0.10 7,684 7,684 COMPZ CASING DLOG P Tie into flag for-7'correction, PUW=28K 20:12 21:30 1.30 7,684 7,812 COMPZ CASING RUNL P Continue trip in with liner, Clean pass through window and by billet. Initial set down with liner @ 10690. Worked down to TD @ 10760, Pumps on release from liner, PUH to swap to seawater, BOL=10760, TOL=7820 21:30 22:30 1.00 7,812 7,812 COMPZ CASING CIRC P Roll coil/well to seawater 22:30 22:42 0.20 7,812 7,420 COMPZ CASING TRIP P Trip out on seawater 22:42 22:48 0.10 7,420 7,420 COMPZ CASING DLOG P Log K-1 for+1 22:48 00:00 1.20 7,420 2,500 COMPZ CASING TRIP P Continue trip out 33/29/2014 Run L1 Liner, Swap CT strings 00:00 01:00 1.00 2,500 2,500 COMPZ CASING FRZP P PJSM with LRS, Load coil with 25 BBIs Diesel 01:00 01:42 0.70 2,500 35 COMPZ CASING FRZP P Continue trip out laying in diesel freeze protect to surface 01:42 04:30 2.80 35 0 COMPZ CASING PULD P PJSM, PUD BHA#10 liner running tools, Blow down tools and lay down Page 11 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 06:30 2.00 0 0 DEMOB MOVE CIRC P PJSM, Install nozzle, Stab on and flush-circulate inhibitor through CT and rig ****Note: Inhibitor CONQOR/303 06:30 07:30 1.00 0 0 DEMOB MOVE CTOP P PJSM, R/U LRS, PT line to 3500psi, load 5 bbls of methonal into reel, R/D 07:30 09:30 2.00 0 0 DEMOB MOVE CTOP P PJSM, R/U SLB N2, PT line to 3500psi, blow down with N2 17min at 1500scf, bleed down, R/D SLB N2 09:30 11:30 2.00 0 0 DEMOB MOVE CTOP P PJSM, remove inner reel iron, remove e-line bulkhead, cut BHI UQ and LQ, INJH counter, CTES counter 11:30 13:00 1.50 0 0 DEMOB MOVE CTOP P PJSM, Load, and M/U FMC lubricator 13:00 15:00 2.00 0 0 DEMOB MOVE CTOP P PJSM, Unstab coiled tubing from INJH and secure to the shipping spool. 15:00 17:00 2.00 0 0 DEMOB MOVE CTOP P PJSM, hook up reel bridge crane, remove reel hubs, lower reel onto peak truck, P/U and install new reel. 17:00 18:00 1.00 0 0 DEMOB MOVE CTOP P Install King pin, reel sadle clamps, remove mouse hole. 18:00 22:00 4.00 0 0 DEMOB MOVE CTOP P Crew change, Prep reel for inner reel iron, Lay down DS PDL 22:00 23:30 1.50 0 0 DEMOB MOVE CTOP P Remove stuffing box, Remove and inspect brass, Prep CT for grapple installation, reinstall stuffing box 23:30 00:00 0.50 0 DEMOB MOVE CTOP P PJSM, R/U stabbing cable, Install grapple and stab coil ****Rig Release Midnight*** Page 12 of 12 111 W NI Z `W? 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"a- + LO N N C` O co N co N N COOCO Q =• + Cl 6 N N N V V V 4 R V '.. CO CO CO CO CO (O CO CO (D (0 CO N F a a N- O N• h CO N 00 CCa0 O Q 3 D) o (D M C- t0 CO M r` Y -7--. • ^.. (oo (oo La CC) u°Di o o (`Qi N U (O CD (O (O CO (D (D (O (D (O (D c N Y N l0 "J m CD CO 0 N V CO C. N CD O COM Q C _ .- r U) _ ! N — M M M M L.6 M M M n > ,, Q o -• > _ a 06 8 Y Y m a) a) r` O m M O m O N 2- O O- O0OO c (0dMMM V .- O OOOOOOmm S UYY LO O OgV • ) OCOCaMO• C(j CO. op CO COCO CO O ^ C d ^ OO V Nn O O N N N N o a a at m o c. U f, 'o m a, m v a ed) 3 3 o m' n. / -- — 333 west Sevenih Avenue (:O\'LRNOR SFAN PARZN1-LL Anchorage, Alaska 99501-35/2 P. Mom Mom907 279 1/33 zq Jason Burke CTD Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3C-09L1-01 Sundry Number: 314-079 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, I Cathy P. 'oerster Chair DATED this l3 day of February, 2014. Encl. RECEI VED • STATE OF ALASKA 1. , i ALAS ill_ GAS CONSERVATION COMMIS: FEBa-rZ 4Oj14 APPLICATION FOR SUNDRY APPROVALS AO��C 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r'. Change Approved Program 1- Suspend Suspend r Rug Perforations r Perforate r Pull Tubing r' • Time Extension r Operational Shutdown r Re-enter Susp.Well ry Stimulate r Alter casing r Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 213-077 3.Address: Stratigraphic r Service 47, 6.API Number. P.O. Box 100360,Anchorage,Alaska 99510 50-029-21355-61 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 3C-09L1-01 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25634,25629 , 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): 8315 6785 _ 7812' 6419' none 10705' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 116' 116' SURFACE 3908 9.625 3943' 3748' PRODUCTION 8271 7 8299' 6773' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7774-7789,7949-7996,8018-8040 • 6392-6402,6515-6549,6565-6581 3.5 L-80 7658 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER FHL RETRIEVABLE PACKER ' MD=7667 TVD=6317 PACKER-BAKER F-1 PERMANENT PRODUCTION PACKER ' MD=7804 TVD=6413 Camco'TRDP-IA-SSA'-CAMCO'TRDP-IA-SSA' ' MD=1823 TVD=1754 12.Attachments: Description Surrmary of Proposal , 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service F' 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/1/2014 Oil r Gas r WDSPL r Suspended I- 16.Verbal Approval: Date: WINJ r' GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: so e @ 265-6097 Email: Jason.Burkeconocophillips.com Printed Name Jason B.r.,;,�:= Titl-• CTD Engineer •Signature c �► Phone:266-6097 Date,-/—/ Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3`t-I._ 0—IQ t Plug Integrity r BOP Test F"Mechanical Integrity Test r Location Clearance r Other: go fes / to 4 5-0 0 PS RBDMS MAY 10 2011 Spacing Exception Required? Yes ❑ No 2/ Subsequent Form Required: /6, _ 4 0 1_ APPROVED BY u Approved by: P - COMMISSIONER THE COMMISSION Date: Z -/3—/ / roved a I Il t r 2Enthsptrom the date of approval. f •Ppp Form 10-403(Revised 10/2012) ,'� NH PI Submit Form and Attachments in Duplicate 1/7--i: Z/1 Z / /4 tiny KRU 3C-09 CTD Summary for Running Completion Liner (10-403) Summary of Operations: Well 3C-09 is a Kuparuk A-sand injection well equipped with 3'h"tubing and 7"production casing with the C- sand behind a straddled selective. In June 2013,CTD was rigged up on the well to perform a CTD sidetrack operation. The casing exit on this well was created at 7847' MD and the first lateral was drilled and completed with top of liner at 8277' MD. While drilling the second of two laterals,the CT became stuck and was lost in the hole. The coil was cut downhole,the CTD rig was rigged down,and the well was listed as suspended as of 7/29/13. Both the Ll &the LI-01 were then classified as PB's. Subsequently, in December 2013,a rig work over was performed and most of the CT was recovered,but the workover rig was unable to run a liner to recover the lateral. It is now proposed to re-enter the original L1-01 lateral with the CTD rig,perform a clean out of the open hole,and attempt to run 2-3/8"slotted liner from the window at 7847' MD down to 8300' to recover the 3C-09L1. ConocoPhillips requests permission to re-enter the well to perform well work operations and attempt to recover 3C-09L1. Upon rigging up on the well,Nabors CDR-2 will pick up a cleaning assembly and attempt to clean out the open hole to a depth of 8300' MD. If the clean out is successful,we will pick up 458' of 2-3/8" slotted liner to run in the open hole to a depth of 8300' MD with top of liner being at 7842' MD. The well will then be pre- produced for less than 30 days before being turned over to injection. If the clean out and liner run are unsuccessful,we will then perforate the tray of the existing whip-stock, set a new whip-stock at 7827' MD and a new CTD lateral will be drilled. CTD Complete and possibly drill 3C-09 Lateral: March 2014 Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. Clean open hole out to 8300' MD 3. If successful,run 2-3/8"slotted liner to 8300' MD 4. If unsuccessful, prepare to redrill 3C-09 Ll lateral(New Permit To Drill) 5. Perforate the original whip-stock at 7847' MD 6. Set a new whip-stock at 7827' MD 7. 3C-09L1 Sidetrack(A3 sand, south) a. Mill 2.80"window at 7,827' MD. b. Drill 2.70"x 3.0"bi-center lateral to TD of 11,050' MD c. Run 23/8"slotted liner with shorty deployment sleeve from TD up to 7822' MD 8. Freeze-protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. 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H r _O t�2 pi V a i3 Ferguson, Victoria L (DOA) From: Ferguson,Victoria L(DOA) Sent: Monday, December 02, 2013 3:19 PM To: 'Packer,J.Brett' Subject: RE: 3C-09L1(PTD 213-076); 3C-09(PTD 185-100) Brett, You have verbal approval to proceed with running the liner and completion. Please submit a 10-403 as soon as possible. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave, Ste 100 Anchorage,AK 99501 Work (907)793-1247 victoria ferqusonalaska goy From: Packer,J.Brett [mailto:J.Brett.Packer@conocophillips.com] Sent: Monday, December 02, 2013 11:39 AM To: Ferguson, Victoria L(DOA) Subject: RE: 3C-09 RWO Plan Forward Victoria, Apparently when they drilled the 3C-09L1-01 lateral, they came across very little netpay in the A2 sand, this is why they are not concerned about salvaging the entire L1-01 lateral. The L1 lateral on the other hand had good netpay, therefore they would still like access to it. 5.Brett Packer Drilling at`Wells Workover Engineer Work# (907)265-6845 Cell# (907)980-9467 From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent: Monday, December 02, 2013 11:01 AM To: Packer, J.Brett Subject: [EXTERNAL]RE: 3C-09 RWO Plan Forward Brett, With the coil/BHA recovered from 3C-09L1-01(PTD 213-077) is there any possibility of salvaging this lateral? I will review this with the Commissioners to get verbal approval to proceed. Then submit a 10-403 sundry for the 3C-09L1(PTD 213- 076) for running the liner and completion with this WO rig followed with a 10-407 for the completion operations under this PTD. 1 Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 victoria.ferguson aaalaska qov From: Packer, ].Brett [mailto:J.Brett.Packer@conocophillips.com] Sent: Monday, December 02, 2013 10:29 AM To: Ferguson, Victoria L(DOA) Subject: 3C-09 RWO Plan Forward Victoria, Here is a summary of the operations to date: Well 3C-09 is a Kuparuk A-sand/B-sand injection well equipped with 3 Y2"tubing and 7"production casing with the C-sand behind a straddled selective. The well was recently worked over in April 2013(Sundry#313-169)by removing the original 2-7/8"tubing and replacing it with a 3-1/2"completion in order to set the well up for CTD Drilling. Prior to CTD drilling,the existing B-sand perfs in 3C-09 were plugged with cement(Sundry#313-242)to provide a means to kick out of the 3-1/2"and 7"casing. The existing A-sand perfs were plugged off with a packer in the tubing tail. CT drilling commenced in June 2013(PTD#213-077). A mechanical whipstock was placed in the 3-1/2"tubing tail at 7,847' MD. The mechanical whipstock is attached to the packer below which isolates the existing A-sand perforations. The 3C-09L1 sidetrack exited through the 3-1/2"tubing and 7"casing at 7,847'MD targeting the A3 sand south of the existing well with a 2869' lateral. The hole was completed with a 2-W slotted liner to the TD of 11,146'MD with an aluminum billet at 8,277' MD. The 3C-09L1-01 lateral kicked off from the aluminum billet at 8,277'MD targeting the A2 sand north of the existing well with a 2650 lateral. The hole was supposed to be completed with a 2%"slotted liner to the TD of 11,146'MD with the liner top located inside the 3Y2"tubing at—7,840' MD,but during their final wiper trip out of the hole,the BHA became stuck and they were unable to recover it. They cut the coil at surface, attempted to pull the e-line from inside the coil which should have disconnected at the weak point at the BHA,but instead,parted approximately 1,000' MD below surface. At that point,they decided to cut the coil at 920' MD below surface and move off the well so that the workover rig could attempt to recover the coil. The current workover (Sundry #313-530) plans were to ideally pull the 3 %2" tubing, recover the coil & stuck BHA, and re-run the tubing. We didn't have much confidence in actually pulling the stuck coil BHA,therefore our backup plan was to just cut the coil outside the window once all the e-line wire was removed from the coil. Either way, the original plan post-RWO was for CTD to come back, set another whipstock above the current whipstock and make another attempt to sidetrack this well, basically abandoning the previous L 1 & Ll- 01 laterals. During this workover, unexpectedly, we began dragging the entire BHA out of the hole, and have recovered the entire coil string. With these indications that the hole is still open, the CTD group would like us to run —500 ft of 2-%" liner to provide a conduit to the 3C-09L1 lateral,with the liner top inside the 3 '/2"tubing just above the Whipstock and down to the aluminum billet at 8,277' MD,therefore salvaging the 3C-09L1 lateral. 2 The PTD #213-077 for the coil sidetracks originally covered running a slotted liner in the 3C-09L1-01 lateral from TD back up inside the 3 '/2" tubing above the Whipstock, but they were unsuccessful at completing that lateral. Conditions have changed during this workover, and we'd like to try and salvage the 3C-09L1 lateral by running just—500' of 2-3/8 liner while we have the workover rig over the well. Seeing as this liner wasn't part of the RWO Sundry, we weren't sure whether it is still covered under the CTD permit to drill, or if we need to submit additional paperwork. This is a unique and unusual operation for the workover rig, but well within our capabilities. Attached is a diagram of the wellbore prior to the current workover to give you an idea of where the Whipstock & aluminum billet are located and the interval we'd like to run the liner in. Please advise on what needs to be done moving forward. INImmr i _.) ..._ 2"OD,0203"wall,OT-900 coiled tubing -Stuck at 10,740' -Drift ball 1.313",but should be able to drift 1.375" 7/32"e-line cable -Cable has a rated breaking strength of 5400 lbs -Max safe pull is 50%of breaking strength -Cable anchoredwithone brass pin rated for 700 lb shear . Hole is loaded with 12.0 ppg NaBr brine -Loaded internally&external ly to the co iled tu bing. -Well is dead -Can bullhead down coiled tubing or down the backside, 3-112%9.3ppftubing ; but cannot circulate -Contained SafeLube 111 3.12'PBdre-WS @ 7847 ... 3C-09L1 c Y TD@11,148MU Billet@8'277 MO 3C-09L1-01 TD@11,285MO BH4stuck et 10.746 r 2D#J-55shoe 8299"MD 5.Brett Tacker miffing eZ We(fs Workpver Engineer Work# (907)265-6845 Ceff# (907)980-9467 3 RECEIVED DATA LOGGED SEP 0 4 2013 /1/2013 MKB NDER Ir BAKER PRINT DISTRIBUTION LIST AOGCC HUGHES COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes (mandatory) WELL NAME 3C-09L1-01 RUN NUMBER Z. – (mandatory) Lrj 1 FIELD Kuparuk BH SALESMAN Jesse Salyer (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: July 1,2013 TODAYS DATE: 8/30/2013 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY CD (FIELD FINAL digital/ ADDRESS(FEDEXWILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #Uf-PKIN I S #OF COPIES #OF COPIES 1 ConocoPhillips Alaska,Inc. I I 1 I I NSK Wells Aide,NSK 69 ATTN:MAIL.ROOM 700 C Street, Anchorage,AK 99501 2 AOGCC I 1 I 1 I I Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3 BP I 1 I 1 I I I Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP I I 1 I 1 I I Glenn Fredrick 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 5 Brandon Tucker,NRT I I 1 I State of Alaska;DNR,Div.of Oil and Gas 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501-3510 TOTALS FOR THIS PAGE: 0 4 4 0 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 ' STATE OF ALASKA RECEIVED ALA„I.A OIL AND GAS CONSERVATION COMMI.,SION REPORT OF SUNDRY WELL OPERATIONS JUL 3 0 2013 1 Operations Performed. Abandon r Repair w ell r Rug Perforations r Perforate r Other j'►�„I �a/ �/ Alter Casing r Pull Tubing 14$7Stimulate- Frac r Waiver r Time Extension (g Change Approved Program rOperat. Shutdown',i'y` S �r hate-Other r Re-enter Suspended Well r 2.Operator Name: 'SF.Well ClaQ Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 213-077 • 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-21355-61-6d 7.Property Designation(Lease Number): 8.Well Name and Number: 11 f ADL 25629,25634 3C-09L1-01t'_B-I' v 61A2 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool • 11.Present Well Condition Summary: Total Depth measured 11285 feet Plugs(measured) 7812 true vertical 6558 feet Junk(measured) none Effective Depth measured 7847 feet Packer(measured) 7666, 7804 true vertical 6442 feet (true vertical) 6317,6413 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 116 116 SURFACE 3908 9.625 3943 3748 PRODUCTION 8271 7 8299 6773 Perforation depth: Measured depth: none True Vertical Depth: none Tubing(size,grade,MD,and TVD) none Packers&SSSV(type,MD,and TVD) PACKER-BAKER FHL RETRIEVABLE PACKER @ 7666' MD and 6317'TVD PACKER-BAKER F-1 PACKER @ 7804' MD and 6413'ND SSSV-CAMCO TRMAXX-CMT-SR-5 @ 1822' MD and 1822'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service rr • Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r VVINJ 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. none Contact James Ohlinger C ,265-1102 Email James.J.Ohiinger@conocophillips.com Printed Name James Ohlinger Title Sr. CTD Engineer Signature i: doirC,44,07:1 Phone:265-1102 Date 7/0 9'//5 l7/fVrt13 RBDMS AUG - 7 20 JC Form 10-404 Revised 10/2012 gig/ /3 Submit Original Only RECEIVED ConocoPhillips JUL 30 2013 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 July 29, 2013 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 a 10-404 Sundry Report for the operations completed in KRU 3C-09 under Sundry 313-242 and Drilling Permits 213-076 &213-077. The original objective was to drill dual-lateral wellbores out of 3C-09 using the coiled tubing drilling (CTD) rig Nabors CDR2-AC. The original B-sand perforations were cemented off before CTD operations commenced. In addition, the original C-sand perforations were isolated with the straddle/selective completion and the A-sand perforations were isolated via a packer-whipstock. CTD drilling operations commenced June 13, 2013. A window was cut in the 7" casing at 7847' MD and the 3C-09L1 lateral was successfully drilled to TD and 2%" slotted liner was installed. . While subsequently drilling the 3C-09L1-01 lateral, the coiled tubing and drilling BHA became stuck at 10,745' MD. Ultimately the coiled tubing and internal electric cable were cut at 920' MD, leaving 2" coiled tubing stuck through the window in the 7" casing and the borehole that had been drilled. This has left the 3C-09, 3C-09L1, and 3C-09L1-01 wellbores inaccessible and incapable of production without additional intervention. At this time, ConocoPhillips Alaska has suspended drilling operations on the 3C-09 laterals to organize and plan a rig workover procedure and/or fishing program. The two laterals that have been drilled are now considered plugbacks and will thus be renamed 3C-09L1-PB1 and 3C-09L1-01-PB1. Attached are the 10-404 forms, daily reports, and schematics. If you have any questions or require additional information please contact me at 907-265-1102. Sincerely, James J. Ohlinger Coiled Tubing Drilling Engineer KUP 3C-09 ConocoPhillips P; x t Well Attributes Max Angle&MD TD . \-." .' Wellbore APVUWI Field Name Well Status Incl(') MD(5KB) Act Btm(ftKB) Alaska.II1C caroaaPr-- 500292135500 KUPARUK RIVER UNIT INJ 49.25 4,825.00 8,315.0 "' Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date • Weill Confi 3C-09 8/3120171:3527 PM SSSV:TRDP Last WO: 5/10/2013 34.59 7/12/1985 _ Schematic-Actual Annotation Depth(559) End Date Annotation Last Mod...End Date Last Tag:SLM 8,189.0 5/26/2013 Rev Reason:Sand Plug,TBG Punch,CMT SQZ/Plug osborl 5/31/2013 HANGER,26- - ---{ Casing Strings - - Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd CONDUCTOR 16 15.062 36.0 116.0 116.0 65.00 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(L..Set Depth(TVD)...String Wt..String...String Top Thrd SURFACE 95/8 8.921 34.7 3,943.0 3,748.3 36.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 28.0 8,298.8 6,772.8 26.00 J-55 BTC Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TOD)...String Wt...String...String Top Thrd TUBING WO 31/2 2.992 26.3 7,658.5 6,311.3 9.30 L-80 EUE8rd CONDUCTOR, Completion Details 38-118III Top Depth - (ND) Top Incl Need... SAFETY VLV Top(ftKB) (ftKB) P) Item Descripgon Comment ID(in) 1,822 1 26.3 26.3 -0.15 HANGER CAMERON TUBING HANGER 2.860 1,822.3 1,822.3 0.55 SAFETY VLV CAMCO TRMAXX-CMT-SR-5 SCSSV w/2.813"X-Profile(-1822) 2.812 M7,636.1 6,295.9 46.37 LOCATOR BAKER SEAL LOCATOR 2.992 GAS LIFT, 7,637.1 6,296.5 46.37 SEAL ASSY BAKER 80-40 PBR SEAL ASSEMBLY 2.980 Ma:2,521 Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String WI...String...String Top Thrd UPPER PACKER 3 1/2 2.992 7,643.3 7,808.8 6,416.2 9.30 L-80 EUE ASSY I Completion Details Top Depth (TVD) Top Incl Nomi... SURFACE, _ � Top(ftKB) (ftKB) ("I Item Description Comment ID(in) 35.3,943 7,643.3 6,300.8 46.38 PBR 20'PBR SEAL ASSEMBLY(pinned to 40k lbs to shear) 2.990 C 7,666.4 6,316.8 45.49 PACKER BAKER FHL RETRIEVABLE PACKER(Min ID=3",60k lbs shear) 2.900 cAsiie�n- 7,719.5 6,353.9 46.03 NIPPLE HES'X'NIPPLE 2.812 IIIIII 7,801.7 6,411.2 45.48 LOCATOR BAKER LOCATOR 2.992 IN 7,802.5 6,411.8 45.48 SEAL ASSY BAKER GBH-22 BONDED SEAL ASSEMBLY(80-40) 2.980 Ell Ons LIFTTubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String WL..String...String Top Thrd 5,794- LOWER PACKER 3 1/2 2.992 7,803.5 7,920.0 6,494.8 9.30 L-80 EUE8rd 111111 ASSY Completion Details I Top Depth GAS LIFT, -J (TVD) Top Inc! Nomi... 6932 - Top(MB) (ftKB) (°) Sem Description Comment ID(in) IIII 7,803.5 6,412.5 45.48 PACKER BAKER F-1 PERMANENT PRODUCTION PACKER 4.000 all 7,806.9 6,414.8 45.48 SBR BAKER 80-40 SEAL BORE EXTENSION,5'long 4.000 7,919.3 6,494.3 44.56 SOS SOLID SEAL SHEAR OUT SUB(pinned to 3500 psi) 3.000 GAS LIFT, 7.580 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (TVD) Top Incl Top(ftKB) (ftKB) (°) Description Comment Run Date ID(in) LOCATOR,_ 7,813.0 6,419.1 45.49 TBG TUBING PUNCHES FOR PRE-CTD CEMENTING-CMT 5292013 2.992 7,6 PUNCHES PLUG 7813-7940' SEAL ASSY, 7,940.0 6,509.0 44.62 SAND PLUG SAND PLUG BLOCKING A-SAND PERFS 5/27/2013 0.000 7.637 Perforations&Slots Shot Top(TVD) Btm(TVD) Dens Top(ftKB) Bfrn(ftKB) (MB) (ftKB) Zone Date (eh... Type Comment 7,774.0 7,789.0 6,391.8 6,402.3 C-1,3C-09 8/1/1985 12.0 IPERF 512"Csg Gun,120 deg.phasing 7,838.0 7,850.0 6,436.7 6,445.1 UNIT B,3C-09 -8/1/1985 12.0 CMT A-SAND PERFS CEMENT 0.. SQZ SQUEEZED PRE-CTD 2013-5 1/2" Csg Gun,120 deg.phasing 7,949.0 7,996.0 6,515.4 6,549.0 A-5,A-4,A-3, 8/1/1985 4.0 IPERF 4"HJ II,90 deg.phasing 3C-09 --- 8,018.0 8,040.0 6,564.9 6,581.2 A-2,3C-09 8/1/1985 4.0 IPERF 4"HJ II,90 deg.phasing INJECTION. 7,773 Notes:General&Safety IPERF, - End Date Annotation _ 7,7747,789 -_ 7/15/2010 NOTE:View Schematic w/Alaska Schemetic9.0 PACKER,7,804 SBR,7,807 i 1 TBG .:fp PUNCHES. 7,813 v 7,838-7,8 C MTSOZ, .. 50 Mandrel Details Top Depth Top Port 5... (TVD) Incl OD Valve Latch Size TRO Run N...Top(ftKB) (MKB) 11 Make Model (in) Sere Type Type (in) (psi) Run Date Com... SOS,7,919 ;c 1 2,520.6 2,520.2 5.48 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 5/9/2013 cMT PLUG, 2 4,189.2 3,913.6 47.49 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 5/9/2013 7,873 e 3 6793.6 5,010.5 46.11 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 5/9/2013 ' SAND PLUG, 7.940 4 6,932.3 5,813.5 46.36 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 5/9/2013 IPERF, 7.949-7,998 5 7,580.2 6,257.3 46.44 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 5126/2013 IPERF, 6 7,772.6 6,390.8 45.63 CAMCO MMG 1 12 INJ DMY RK 0.000 0.0 5/9/2013 8,0188,040 PRODUCTION, 28-8,299 TO,8,315 3C-09 Current Condition of CTD Sidetrack 2"coil has been cut at 920'MD The eline cable inside the coil is at 1100'MD 16"65#H-40 shoe @ 116' TRMAXX-CMT-5-SR @ 1822'TVD 36#J-55 shoe 3-1/2"GLMs @ 2521',4189',5794',6932',7580' @ 3943'MD Baker PBR @ 7643'RKB;2.99"ID Baker FHL Packer @ 7666'RKB;2.90"ID 2.813"X Nipple @ 7720' ------- 7773'-Injection mandrel C-sand perfs Baker F-1 Packer @ 7804' 7774'-7789'MD — Baker 80-40 SBE @ 7807' i If= Tubing Tail Perforations B-sand perfs :' im...----- 7838'-7850'MD 41.v: ra 3-1/2"Weatherford Starburst Hollow WS tray @ '� Z:oto, A-5 3C-09L1PB1 t A3 south Tubing Tail @ 7920'MD ;ypti,; 1' TD @ 11,146'MD I Billet @ 8277'MD A-sand perfs — 7949'-7996'MD — '111111111""" Mom- 8018'-8040'MD — - 3C-09L1-01PB1 Existing perfs covered with A2 north sand prior to plugback(or TD @ 11,285'MD RWO). Mill out cement in 7"26#J-55 shoe 3-1/2"TT and perform FCO @ 8299'MD prior to setting WS. 3C-09 Pre-Rig Well Work Summary • • DATE SUMMARY 5/26/2013 TAGGED @ 8189' SLM. MEASURED BHP @ 7850' RKB: 3904 PSI. SET SLIPSTOP CATCHER @ 7608' SLM. PULLED SHEARED SOV @ 7580' RKB, REPLACED WITH DV. PULLED CATCHER. READY FOR CTU. 5/27/2013 Placed 6400 lbs sand over"A"sand perfs with estimate TOS at 7,930-ft. Ready for Slickline. 5/28/2013 TAG @ TOP OF SAND PLUG @ 7941' RKB. READY FOR E-LINE. 5/29/2013 PERFORM JEWELRY LOG AND PERFORATE INTERVAL 7813'-7818' USING 2" HSC LOADED 3 SPF PHASED 120 DEGREES, BH CHARGES. TAG BOTTOM AT 7940'. LOG CORRELATED TO SLB DENSITY/ NEUTRON/GR LOG DATED 10 JUL 1985 AT 7425' K1 MARKER. READY FOR COIL. 5/30/2013 Lay in 15 bbls 15.8 ppg class "G"cement from top of sand plug at 7,940-ft MD. Squeeze—3 bbls to"B" perfs. Clean out tubing to est. TOC at—7,813-ft. POOH jetting across GLM's and all jewelry. Freeze protect. Trap 1,600 psi on tubing for over balance. In Progress. 6/1/2013 TAGGED DV @ 7772' RKB FOR CORRECTION; TAGGED TOC @ 7812' RKB; PRESSURE TEST CEMENT PLUG TO 2000 PSI (GOOD TEST). 6/2/2013 TORQUE T-LDS TO 360 FT-LBS AND GLAND NUTS TO 450 FT-LBS. (COMPLETE). 6/3/2013 UNABLE TO GET BHA TOOLS ACROSS THE RIVER, JOB IN PROGRESS 6/4/2013 CREW C/O DAY, BHA DELAYED ON FLIGHT DUE TO KRU BRIDGE WASH OUT. RESTART IN AM, JOB IN PROGRESS 6/5/2013 Tagged cement top at 7798 CTM, milled 2.98" hole through cement plug (7798-7936) CTM,jetted into sand plug to 7950. Freeze protect and pull out of hole. - In Progress 6/6/2013 Clean out production casing from 7930 CTMD to 8205.6 CTMD with gelled diesel sweeps and slick seawater while maintaining 1:1 returns. Freeze protected well with diesel from 5500' CTMD to surface. -Job Complete. 6/7/2013 (PRE CTD) PT TREE VALVES/SSSV. MV, SSV, AND SV(PASSED) ; SSSV(FAILED) 6/7/2013 DRIFT TBG, TIE INTO GLM @ 7773' RKB, &TAG @ 8140' SLM, DRIFT TBG W/2.625-2.73" DUMMY DRIFT(17.5') DOWN TO 7900' SLM. BRUSH SSSV( VALVE IS FUNCTIONING, BUT UNABLE TO GET CLOSURE TEST). IN PROGRESS. 6/8/2013 TROUBLE SHOOT SSSV; UNABLE TO OBTAIN CLOSURE TEST; ENSURE VALVE IS FULL OPEN. (ABLE TO PUMP INTO WELL @ .25 BBLS PER MIN.) READY FOR E-LINE. 6/9/2013 SET PLANNED TOWS AT 7847'WITH AN ANCHOR REFERENCE OF 8 DEG LHS. 6/11/2013 SET WEATHERFORD WHIPSTOCK WITH 2 RA TAGS @ 7847' RKB. COMPLETE. • ConocoPhitlips Time Log & Summary Wel/view Web Reporting Report Well Name: 3C-09 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 6/14/2013 1:00:00 AM Rig Release: 7/5/2013 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 36/13/2013 24 hr Summary Move rig to next well. 05:00 08:00 3.00 0 0 MIRU MOVE MOB P Move rig to 3C-Pad 08:00 08:30 0.50 0 0 MIRU MOVE SFTY P Trucks on location. Conduct PJSM with all crews- Rig move. 08:30 11:00 2.50 0 0 MIRU MOVE MOB P Pull off of well and install jeeps. 11:00 17:30 6.50 0 0 MIRU MOVE MOB P Start Rig move to 3Cpad 17:30 18:00 0.50 0 0 MIRU MOVE SFTY P Conduct PJSM with all crews- spotting rig over 3C-09.Verify correct well. 18:00 20:30 2.50 0 0 MIRU MOVE MOB P Spot subs over well. 20:30 00:00 3.50 0 0 SLOT WELLPF CTOP P Prep for reel swap 06/14/2013 Performed reel maintenance. Installed new reel and secured into reel stand. Installed guards, M/U MP line, coil grapple, inner reel iron, e-line pressure bulkhead, BHP e-line head(pull tested to 35k), Checked tree bolts -2 loose studs found, changed out the o-rings on lubricator, filled coil with sea water,tested tiger tank line 1500psi-2 loose chicksans 00:00 01:00 1.00 0 0 SLOT WELLPF CTOP P Finish removing reel from rig. 0 SLOT ***********Rig Accept at 1:00am ************ 01:00 06:30 5.50 0 0 SLOT WELLPF CTOP T Rig Maintenance on reel drive chain sprocket and reel bearings. *******5.5 Rig Billable Maintenance hrs******** 06:30 09:30 3.00 0 0 SLOT WELLPF CTOP P Install new reel and secure, install guards and M/U MP line. 09:30 12:00 2.50 0 0 SLOT WELLPF CTOP P Install grapple, shim reel, and prep to stab pipe. 12:00 16:30 4.50 0 0 SLOT WELLPF CTOP P Stab Pipe, R/D stabbing equipment. 16:30 18:30 2.00 0 0 SLOT WELLPF CTOP P Install CTC, install inner reel iron, and M/U e-line pressure bulkhead. 18:30 20:00 1.50 0 0 SLOT WELLPF CTOP P Install BHI e-line head. Check studs on tree-2 loose studs. 20:00 00:00 4.00 0 0 SLOT WELLPF CTOP P Change out o-rings on lubricator. Fill coil with sea water. Test tiger tank line,2 loose chicksans. retest to 1500psi, good test. 06/15/2013 Tested BOPE. 250psi low/4500psi high.3 failed components 2-3/8"uppers and lowers and C10. Replace horse shoe seals on ram bodies as well as C10. Retest. Finish BOP test. 00:00 01:00 1.00 0 0 SLOT WELLPF NUND P Nipple up stack 01:00 01:00 0.00 0 0 MIRU WHDBO NUND P Prep to test BOPE Page 1 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 11:00 10.00 0 0 MIRU WHDBO BOPE P Start BOPE test ******Test waived by Jeff Tuenington 3:51 pm 6/12/13 11:00 17:30 6.50 0 0 MIRU WHDBO BOPE T 3 failed BOPE components 2-3/8" upper and lower combi's and C10. Replace and retest. *****6.5hrs billable rig maintenance- all billable maintenance hrs taken for month of June 2013. 17:30 18:30 1.00 0 0 MIRU WHDBO BOPE P Done with BOP test. R/D testing equipment. ******BOPE TEST TIME 16.5hrs ***** 18:30 18:45 0.25 0 0 MIRU WHDBO SFTY P Conduct PJSM-FMC to pull BPV. 18:45 19:30 0.75 0 0 MIRU WHDBO BOPE P R/U FMC lubricator. 19:30 22:00 2.50 0 0 MIRU WHDBO BOPE P P/T lubricator to 2500psi. Pull BPV and RD FMC lubricator.TP-1200psi 22:00 23:00 1.00 0 0 PROD1 WHPST PULD P Install BHI check valves. Circulate one coil volume forward. 23:00 23:15 0.25 0 0 PROD1 WHPST SFTY P Conduct PJSM-M/U weatherford tools and pressure deploy 23:15 00:00 0.75 0 0 PROD1 WHPST PULD P Deploy BHA. 06/16/2013 Pump one coil volume forward for e-line management. Installed BHI counter, Pulled BPV TP 1200.M/U window milling BHA with 0.6°X-Treme motor. RIH Tied into the K1 +7'. Milled the first 3.5"part of the window. Reamed 3.5"area, POOH 00:00 02:00 2.00 0 0 PROD1 WHPST TRIP P Continue deploying window milling bha. 02:00 03:33 1.56 0 7,435 PROD1 WHPST TRIP P RIH-BHA#1 Window milling 2.79 String reamer 2.80 Diamond window mill Inteq 2-3/8"X-Treme 0.6°AKO 03:33 03:48 0.25 7,435 7,490 PROD1 WHPST DLOG P Tie into K1 correction of+7'. 03:48 04:48 1.00 7,490 7,846 PROD1 WHPST TRIP P Continue RIH. Swapping over to 9.8ppg used PowerPro. 04:48 05:48 1.00 7,846 7,846 PROD1 WHPST MILL P Dry tag WS at 7846'. P/U bring pump up and start time milling at 7845'. 05:48 15:00 9.20 7,845 7,851 PROD1 WHPST MILL P Continuing time milling. Cric PSI: 3,699 WHP: 37 psi Two minor delays one due to generator to high line conversion and the second due to a PLZ componet failure. 15:00 16:00 1.00 7,851 7,851 PROD1 WHPST MILL P Stop at planned depth of 7,851.4'and start reciprocating string reamer through window in 3.5" 16:00 18:00 2.00 7,851 0 PROD1 WHPST TRIP P POOH. 18:00 18:30 0.50 0 0 PROD1 WHPST SFTY P Conduct PJSM w/crew and MI rep for magnastar magnetics-undeploying milling BHA Page 2 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 19:45 1.25 0 0 PROD1 WHPST PULD P Undeploy BHA, scrape magnets, gauge mills, 2.79 no-go on both mills. 19:45 20:00 0.25 0 0 PROD1 WHPST PULD P M/U second window milling BHA. 20:00 21:15 1.25 0 0 PROD1 WHPST TRIP P Deploy BHA,work BHA string through BOP's with 2.0 AKO motor 21:15 21:30 0.25 0 157 PROD1 WHPST TRIP P Tag up and zero counter, RIH wtih window milling BHA. Weatherford motor with 2.0 AKO 2.80 OD Fat Radius window mill 21:30 23:30 2.00 157 7,435 PROD1 WHPST TRIP P Tag up on collar. PUH and orient TF from 140°to 290°. Close EDC and bring pump up to.65bpm. RBIH seeing collars every 31ft. Speed up tripping in hole. Looks clean continue in hole. 23:30 23:45 0.25 7,435 7,485 PROD1 WHPST DLOG P Tie into the K1 marker correction of- 5'. 23:45 23:59 0.24 7,485 7,758 PROD1 WHPST TRIP P Continue in hole to bottom. 36/17/2013 Finish milling through the 7"casing and TD'd rat hole @ 7865'. Swap to new 9.8ppg PowerPro. POOH, undeploy second milling BHA, and L/D weatherford tools. Deploy build BHA w/2.0°AKO, RIH. 00:00 06:30 6.50 7,758 7,865 PROD1 WHPST MILL P Tag bottom at 7852.5'. FS 3622psi @ 1.51 bpm. Start milling second section of exit in the 7". IA 272, OA 317, BHP 3868, WHP 64. 06:30 09:30 3.00 7,865 7,833 PROD1 WHPST MILL P Start up and down ream runs. On up reams orineted to 45 degrees to milled toolface. 6 up reams and 5 down reams. Drifted through window "dry"with no concerns. 09:30 12:03 2.55 7,833 0 PROD1 DRILL TRIP P Swap over to new 9.8 Power Pro and POOH. Circ PSI:3,319 BHP: 3,960 psi IA:423 psi OA:559 psi 12:03 13:24 1.35 0 0 PROD1 DRILL PULD P At surface. Pressure undeploy. 13:24 14:24 1.00 0 0 PROD1 DRILL PULD P LD Milling BHA. M/U build BHA. 14:24 16:03 1.65 0 0 PROD1 DRILL PULD P Pressure Deploy. 16:03 18:56 2.89 0 7,435 PROD1 DRILL TRIP P RIH. 18:56 19:11 0.25 7,435 7,475 PROD1 DRILL DLOG P Tie into the K1 marker-6'. 19:11 23:59 4.81 7,865 7,949 PROD1 DRILL DRLG P Start drilling build section.Circ PSI: 3,666,WHP 106psi. BHP 3951, 1.5 bpm IA 400psi, OA 534psi 06/18/2013 TD Build section ©8145, Trip out for lateral BHA#4 with .6°motor, Drill 8145 to 8438 00:00 05:00 5.00 7,949 8,145 PROD1 DRILL DRLG P OBD Build section. 1.5bpm at 3514psi.WHP 91, BHP 3982, IA 404, OA 543. 05:00 05:30 0.50 8,145 7,800 PROD1 DRILL WPRT P TD build section at 8145'. PUH and try to find RA marker. 05:30 07:00 1.50 7,800 0 PROD1 DRILL TRIP P No PIP tags found. POOH Page 3 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 07:15 0.25 0 0 PROD1 DRILL SFTY P OOH, Conduct PJSM-undeploy build BHA 07:15 09:00 1.75 0 0 PROD1 DRILL PULD P Undeploy BHA#3 09:00 09:45 0.75 0 0 PROD1 DRILL PULD P M/U lateral BHA#4 with 0.6°ako motor 09:45 10:00 0.25 0 0 PROD1 DRILL SFTY P Conduct PJSM-deploying lateral BHA. 10:00 11:45 1.75 0 0 PROD1 DRILL PULD P Deploy lateral BHA. 11:45 12:45 1.00 0 0 PROD1 DRILL SFTY P Shon, Brian, and John came out and presented iditarod appreciation to crew. 12:45 15:00 2.25 0 7,450 PROD1 DRILL TRIP P RIH L1 lateral BHA New DGS Res Tool X-Treme motor w/0.6°ako New Hycalog bi-center bit 15:00 15:15 0.25 7,450 7,483 PROD1 DRILL DLOG P Tie into the K1 correction of-0.5'. 15:15 16:00 0.75 7,483 8,145 PROD1 DRILL TRIP P Continue to bottom. 16:00 19:12 3.20 8,145 8,295 PROD1 DRILL DRLG P OBD-1.41bpm at 3500psi, BHP 4019,WHP 152, IA 141, OA 234 19:12 20:54 1.70 8,295 8,295 PROD1 DRILL WPRT P Wiper trip to window with MADD pass, PUW=33K 20:54 00:00 3.10 8,295 8,438 PROD1 DRILL DRLG P 8295', Drill ahead, 1.46 BPM @ 3500 PSI FS, BHP=4010,WHP=110 06/19/2013 Drilled 8438 to 9195 00:00 00:06 0.10 8,438 8,445 PROD1 DRILL DRLG P Drilling Ahead 00:06 00:48 0.70 8,445 8,445 PROD1 DRILL WPRT P Wiper trip to 7900, PUW=35K 00:48 03:54 3.10 8,445 8,595 PROD1 DRILL DRLG P 8445, Drill ahead, 1.44 BPM @ 3470 PSI FS, BHP=4040 03:54 04:54 1.00 8,595 8,595 PROD1 DRILL WPRT P Wiper to window with tie in for+2' correction, PUW=37K, good increase of cuttings on wiper, Blow down drilling choke. Clean trip up and down 04:54 07:54 3.00 8,595 8,745 PROD1 DRILL DRLG P 8595', Drill Ahead, 1.49 BPM @ 3500 PSI FS, BHP=4030 07:54 08:24 0.50 8,745 7,900 PROD1 DRILL WPRT P Wiper up to the window. PUW 37 08:24 08:54 0.50 7,900 8,745 PROD1 DRILL WPRT P Wiper back in hole. RIW 18 08:54 11:54 3.00 8,745 8,895 PROD1 DRILL DRLG P BOBD-1.43bpm at 3420psi. BHP 4070,WHP 108, IA 218, OA 169 11:54 12:24 0.50 8,895 8,175 PROD1 DRILL WPRT P Wiper up hole. PUW 37k 12:24 12:42 0.30 8,175 8,895 PROD1 DRILL WPRT P Wiper back in hole. RIW 17k 12:42 16:25 3.72 8,895 9,045 PROD1 DRILL DRLG P BOBD- 1.43bpm at 3500psi. BHP 4075,WHP 119, IA 293,OA 232 16:25 17:10 0.75 9,045 7,870 PROD1 DRILL WPRT P Wiper up hole. PUW 37k 17:10 17:25 0.25 7,870 7,897 PROD1 DRILL DLOG P Tie into the gamma spike at 7858' correction of+0.5' 17:25 17:55 0.50 7,897 9,045 PROD1 DRILL WPRT P Wiper back in hole. RIW 18k Page 4 of 16 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:55 22:43 4.80 9,045 9,195 PROD1 DRILL DRLG P BOBD-1.44bpm at 3462psi, BHP 4104,WHP 128, IA 299, OA 252 22:43 23:59 1.28 9,195 9,000 PROD1 DRILL WPRT P Wiper to window, PUW=37K, BHP=4170 06/20/2013 Drilled 9195 to 10012, Swapped to 9.6PPG Flo Pro 00:00 00:06 0.10 9,000 9,195 PROD1 DRILL WPRT P Continue full wiper 00:06 02:18 2.20 9,195 9,345 PROD1 DRILL DRLG P 9195', Drill ahead, 1.45 BPM @ 3450 PSI FS, BHP=4140,WHP=125 New Mud at bit @ 9305', New mud all around @ 9340 1440'on old system @.9%Drill solids 02:18 03:24 1.10 9,345 9,345 PROD1 DRILL WPRT P Wiper to window, PUW=36K, BHP=4150 03:24 05:42 2.30 9,345 9,495 PROD1 DRILL DRLG P 9345', Drill Ahead, 1.4 BPM @ 3860 PSI FS, BHP=4144 05:42 06:27 0.75 9,495 7,873 PROD1 DRILL WPRT P Wiper to window with tie in, PUW=34K 06:27 06:42 0.25 7,873 7,898 PROD1 DRILL DLOG P Tie into gamma spike correction of+ 3'. 06:42 07:27 0.75 7,898 9,495 PROD1 DRILL WPRT P Wiper back in hole. RIW 17k 07:27 09:15 1.80 9,495 9,645 PROD1 DRILL DRLG P BOBD- 1.41bpm at 3580psi. BHP 4133,WHP 137, IA 329, OA 263. 09:15 09:51 0.60 9,645 8,375 PROD1 DRILL WPRT P Wiper up hole. PUW 33k 09:51 10:27 0.60 8,375 9,645 PROD1 DRILL WPRT P Wiper back in hole. RIW 14 10:27 11:57 1.50 9,645 9,795 PROD1 DRILL DRLG P BOBD- 1.44bpm at 3620psi, BHP 4133,WHP 135, IA 391, OA 322 11:57 12:42 0.75 9,795 8,480 PROD1 DRILL WPRT P Wiper up hole. PUW 33k 12:42 13:18 0.60 8,480 9,795 PROD1 DRILL WPRT P Wiper back in hole. RIW 14k 13:18 16:12 2.90 9,795 9,903 PROD1 DRILL DRLG P BOBD-1.44bpm at 3620psi, BHP 4158,WHP 136, IA 445, OA 362 16:12 21:00 4.80 9,903 9,945 PROD1 DRILL DRLG P Found Ankorite, ROP<10 FPH, 1.42 BPM @ 3675 PSI FS 21:00 22:54 1.90 9,945 9,945 PROD1 DRILL WPRT P Planned wiper to window, PUW=33K with tie in for+4.5'correction, clean trip up and down 22:54 00:00 1.10 9,945 10,012 PROD1 DRILL DRLG P 9945', Drill ahead, 1.48 BPM @ 3740 PSI FS, BHP=4155 06/21/2013 Drilled 10012 to 10545, Encountered several stringers of Ankorite, Fluid lossses- 1 BPH 00:00 02:00 2.00 10,012 10,095 PROD1 DRILL DRLG P Drill Ahead, 1.48 BPM @ 3750 PSI FS, BHP=4160 02:00 03:00 1.00 10,095 10,095 PROD1 DRILL WPRT P Wiper trip to 9000, PUW=36K, BHP=4160 03:00 06:00 3.00 10,095 10,245 PROD1 DRILL DRLG P 10095', Drill Ahead, 1.46 BPM @ 3740 PSI FS, BHP=4160,WHP=100 PSI 06:00 06:42 0.70 10,245 9,021 PROD1 DRILL WPRT P Wiper up hole. PUW 34k 06:42 07:24 0.70 9,021 10,245 PROD1 DRILL WPRT P Wiper back in hole. RIW 18k 07:24 16:24 9.00 10,245 10,395 PROD1 DRILL DRLG P BOBD- 1.41bpm at 3600psi. BHP 4206,WHP 155, IA 610, OA 521 Page 5 of 16 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:24 17:36 1.20 10,395 78 PROD1 DRILL WPRT P Wiper up hole to the window fora tie in. PUW 33k 17:36 17:45 0.15 7,875 7,893 PROD1 DRILL DLOG P Tie in correction of+3.5 17:45 18:57 1.20 7,893 10,395 PROD1 DRILL WPRT P Wiper back in hole. RIW 17k 18:57 22:45 3.80 10,395 10,545 PROD1 DRILL DRLG P BOBD-1.43bpm at 3650psi. 22:45 00:00 1.25 10,545 10,545 PROD1 DRILL WPRT P Wiper trip to 9395, PUW=36K X6/22/2013 TD Lateral 1 @ 11145', pump sweeps and chase to swab valve 00:00 03:42 3.70 10,545 10,695 PROD1 DRILL DRLG P 10545', Drill Ahead 1.48 BPM @ 3750 PSI FS, BHP=4225 03:42 04:54 1.20 10,695 10,695 PROD1 DRILL WPRT P 10695',Wiper trip to 9545', PUW=40K, Dragging 34K, BHP=4191, Encountered tight spot 10380 to 10360 with 5K overpull, Observed weight drop RIH through same area 04:54 07:54 3.00 10,695 10,845 PROD1 DRILL DRLG P 10695, Drill Ahead, 1.47 BPM @ 3750 PSI FS, BHP=4220, RIW=10K 07:54 09:15 1.35 10,845 7,870 PROD1 DRILL WPRT P Wiper up hole fora tie in. PUW 38 09:15 09:30 0.25 7,870 7,883 PROD1 DRILL DLOG P Gamma spike at 7858'tie in correction of+2.0' Bottom hole pressure survey at the window Depth:7900', Pump rate 1.47bpm, WHP 75 BHI annular pressure-3955 09:30 10:45 1.25 7,883 10,845 PROD1 DRILL WPRT P Wiper back in hole. RIW 10:45 12:21 1.60 10,845 10,933 PROD1 DRILL DRLG P BOBD-1.43 bpm at 3812psi. BHP 4234,WHP 29, IA 332, OA 352 12:21 12:51 0.50 10,933 10,633 PROD1 DRILL WPRT P Stacked out coil weight. PUW 52k. PUH to 10633'. Start mud swap. ********New Mud at 10933' ********Old Mud 1628'drilled with 0.7%solids 12:51 13:06 0.25 10,633 10,933 PROD1 DRILL WPRT P Wiper back in hole. RIW 15k 13:06 14:21 1.25 10,933 10,995 PROD1 DRILL DRLG P BOBD- 1.44bpm at 3944psi. BHP 4220,WHP 29, IA 250, OA 254. 14:21 14:51 0.50 10,995 9,800 PROD1 DRILL WPRT P Wiper up hole to 9800'. PUW 33k 14:51 15:21 0.50 9,800 10,995 PROD1 DRILL WPRT P Wiper back in hole. RIW 15k 15:21 18:03 2.70 10,995 11,145 PROD1 DRILL DRLG P BOBD-1.44 bpm at 3891psi. BHP 4226,WHP 36, IA 267, OA 264., Pump Hi Lo sweeps call TD @ 11145 18:03 22:00 3.95 11,145 200 PROD1 DRILL WPRT P Sweeps coming out start wiper trip to swab, PUW=35K 22:00 00:00 2.00 200 0 PROD1 DRILL WPRT T Reel unable to keep up with injector, planetary making noise RIH. Shot temps on pillow block bearings, 80° on ODS, 170°on DS. Mechanic/ electrician called out to trouble shoot Page 6 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 36/23/2013 24 hr Summary Complete reel alignment, Finish swab wiper, Lay in 12 PPG liner running pill and 12 PPG completion fluid. Run L1 lower liner segment 11146,Top of lower liner 9534. POOH M/U upper section and RIH 00:00 01:00 1.00 0 100 PROD1 DRILL WPRT T Realign reel pillow block bearings and test 01:00 02:24 1.40 100 7,430 PROD1 DRILL WPRT P Continue wiper to TD and lay in liner running pill and KWF 02:24 02:36 0.20 7,430 7,473 PROD1 DRILL DLOG P Tie into K-1 for-2.5' 02:36 03:42 1.10 7,473 9,150 PROD1 DRILL WPRT P Continue in to lay in liner running pill, stop at 7799 shut EDC, Set down @ 9115,orient TF to as drilled still having trouble getting through. Getting crude in returns to surface. Overpulls coming up. 03:42 04:36 0.90 9,150 11,146 PROD1 DRILL WPRT P 9150 continue in hole,TF=100°to go through 04:36 08:21 3.75 11,146 0 PROD1 DRILL TRIP P Tag bottom at 11146'. POOH laying in 12.0ppg completion fluid with bead up to the window and without beads to surface. Paint EOP flags at 9400' EOP(Yellow), 6100'(White) 08:21 08:36 0.25 0 0 PROD1 DRILL SFTY P Conduct PJSM-Flow Check well for flow, L/D BHA#4 08:36 09:21 0.75 0 0 PROD1 DRILL PULD P L/D Lateral BHA#4 09:21 09:36 0.25 0 0 COMPZ CASING PULD P Conduct PJSM-for running L1 completion. 09:36 10:06 0.50 0 0 COMPZ CASING PULD P Start making up L1 liner. 10:06 10:21 0.25 0 0 COMPZ CASING SFTY P BOB drill on joint#3(Time 2min 11 sec) 10:21 12:00 1.66 0 0 COMPZ CASING PUTB P Continue M/U liner 12:00 12:15 0.25 0 0 COMPZ CASING PUTB P Conduct PJSM-for making up BHI tools 12:15 12:30 0.25 0 1,655 COMPZ CASING PUTB P Lower BHI and liner into the slips. 12:30 13:30 1.00 1,655 1,655 COMPZ CASING SVRG P Service Rig 13:30 15:00 1.50 1,655 7,751 COMPZ CASING TRIP P RIH-L1 completion with shorty deplpoyment,52 jts of slotted liner, and a non-ported bull nose. Pumping min rate 15:00 15:15 0.25 7,751 7,751 COMPZ CASING DLOG P At 6100' EOP Flag, Subtract lift, PUW 32k 15:15 15:45 0.50 7,751 9,030 COMPZ CASING TRIP P Continue running in hole 15:45 16:00 0.25 9,030 9,050 COMPZ CASING DLOG P Tie into the K1 marker correction of +4'. 16:00 16:30 0.50 9,050 11,146 COMPZ CASING TRIP P Continue in hole. 16:30 16:45 0.25 11,146 11,146 COMPZ CASING TRIP P Tag bottom at 11146'. PUW 40k, Pump up, release from liner. PUW 31k 16:45 19:21 2.60 11,146 43 COMPZ CASING TRIP P POOH 19:21 19:45 0.40 43 0 COMPZ CASING PULD P PJSM while flow checking well, Lay down BHA#5 L1 lower liner section running tools Page 7 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:45 20:45 1.00 0 0 COMPZ CASING BOPE P Perform BOPE Function test-Rig up floor to run liner 20:45 23:30 2.75 0 1,298 COMPZ CASING PUTB P P/U L1 Upper section with ported bullnose, 12 jts slotted 2 3/8",28 jts 2 3/8"blank CS 511, Perform BOPE drill©jt 14 @ 2 minutes to have well secured with floor valve, Make up to coil track, Make up to coil and surface test 23:30 23:59 0.49 1,298 3,067 COMPZ CASING TRIP P RIH 06/24/2013 Complete L1 liner ops, Tag Billet @ 8276, Kick off and drill ahead to 8769 00:00 01:12 1.20 3,067 7,707 COMPZ CASING TRIP P Continue in hole with L1 upper liner section 01:12 01:18 0.10 7,707 7,698 COMPZ CASING DLOG P Tie into EOP flag for-9.2 01:18 01:42 0.40 7,698 8,665 COMPZ CASING TRIP P Continue in with liner 01:42 01:48 0.10 8,665 8,700 COMPZ CASING DLOG P Tie into GR for+2'correction 01:48 02:12 0.40 8,700 9,532 COMPZ CASING TRIP P Continue in with liner,Tag Top of lower liner @ 9532 02:12 02:36 0.40 9,532 9,046 COMPZ CASING TRIP P PUW=36K, Pumps on 1.2 BPM PUW=27K, Release from liner, BOL=11146,TOL=8278 02:36 04:36 2.00 9,046 33 COMPZ CASING TRIP P Stop and remove liner length from counters, continue trip out 04:36 05:06 0.50 33 0 COMPZ CASING PULD P At surface, PJSivi/Flow check well, Lay down BHA#6 liner running tools 05:06 06:36 1.50 0 0 PROD2 STK PULD P M/U BHA#7, Drill off liner top billet 06:36 08:06 1.50 0 7,445 PROD2 STK TRIP P RIH-1.1°ako motor to kick off of billet at 8280' 08:06 08:21 0.25 7,445 7,450 PROD2 STK DLOG P Tie into the K1 marker correction of- 7'. 08:21 09:21 1.00 7,450 8,275 PROD2 STK TRIP P Continue in hole. Displace 12.0ppg completion fluid with 9.6ppg flo-pro. 09:21 10:21 1.00 8,275 8,275 PROD2 STK KOST P Dry tag billet at 8276.5'. Kick off of billet as per recommended practice. 1.41 bpm at 3882psi. BHP 4036, WHP 92, IA 0, OA 134 10:21 10:51 0.50 8,275 8,277 PROD2 STK KOST P Time drilling, autodrill 1 fph 10:51 11:21 0.50 8,277 8,278 PROD2 STK KOST P Time drilling, autodrill 2 fph 11:21 15:21 4.00 8,278 8,425 PROD2 DRILL DRLG P Drill Ahead in the L1-01 15:21 15:36 0.25 8,425 8,290 PROD2 DRILL WPRT P Wiper up to 8290'. PUW 33k 15:36 15:51 0.25 8,290 8,425 PROD2 DRILL WPRT P Wiper back in hole RIW 19k 15:51 18:45 2.90 8,425 8,575 PROD2 DRILL DRLG P BOBD-1.42 bpm at 3900psi. BHP 4057,WHP 37, IA 0, OA 85 18:45 19:15 0.50 8,575 7,915 PROD2 DRILL WPRT P Wiper up hole to 7915', PUW 33k 19:15 19:45 0.50 7,915 8,575 PROD2 DRILL WPRT P Wiper back in hole. RIW 19k 19:45 22:33 2.80 8,575 8,725 PROD2 DRILL DRLG P BOBD-1.42bpm at 3932psi, BHP 4036,WHP 33, IA 20, OA 137 22:33 22:51 0.30 8,725 8,290 PROD2 DRILL WPRT P Wiper up hole. PUW 33k Page 8 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:51 23:09 0.30 8,290 8,725 PROD2 DRILL WPRT P Wiper back in hole. RIW 18k 23:09 00:00 0.85 8,725 8,769 PROD2 DRILL DRLG P 8725', Drill Ahead, 1.4 BPM @ 3920 PSI FS, BHP=4103 06/25/2013 Complete End of turn @ 8840, POOH perform full BOPE Test,Witnes waived by Bob Noble,AOGCC,trip in and drill lateral 8840 to 8901 00:00 02:30 2.50 8,769 8,840 PROD2 DRILL DRLG P Continue drilling turn section, Call EOB @ 8840 02:30 05:00 2.50 8,840 58 PROD2 DRILL TRIP P POOH for BOPE test/Lateral bend motor, PUW=32K,Avg DLS 12.7° 05:00 07:00 2.00 58 0 PROD2 DRILL PULD P PJSM, PUD BHA#7 07:00 08:30 1.50 0 0 PROD2 DRILL PULD P Lay down BHA#7. 08:30 09:30 1.00 0 0 PROD2 DRILL SVRG P Prep for BOPE Testing. Service inner reel valve and choke. Valve crew on location to grease tree valves. 09:30 16:30 7.00 0 0 PROD2 DRILL BOPE P Test BOPE. (State witness waived by Bob Noble,10:16 24Jun13). 16:30 17:00 0.50 0 0 PROD2 DRILL CIRC P Swap coil back to mud and replace check valves in BHA. 17:00 19:30 2.50 0 72 PROD2 DRILL PULD P Pick up and PD L1-01 lateral drilling BHA#8. .5°motor and Hugh"Stay Sharp"2.7 X 3"Bi Center, M/U to coil and surface test 19:30 21:18 1.80 72 7,438 PROD2 DRILL TRIP P Trip in hole, EDC open 21:18 21:30 0.20 7,438 7,478 PROD2 DRILL DLOG P Log K-1 for,-8'correction, 21:30 21:36 0.10 7,478 7,791 PROD2 DRILL TRIP P Continue in well 21:36 22:12 0.60 7,791 8,841 PROD2 DRILL TRIP P Stop and shut EDC 22:12 00:00 1.80 8,841 8,901 PROD2 DRILL DRLG P 8841', Drill ahead, 1.4 BPM @ 3800 PSI FS, BHP=4030, Getting crude at shaker, no gas divert to TT 06/26/2013 Drill Ahead 8901 to 9740 00:00 02:54 2.90 8,901 8,965 PROD2 DRILL DRLG P 8901, Drill ahead Cont. 02:54 03:36 0.70 8,965 8,965 PROD2 DRILL WPRT P Wiper to billet @ 8276 03:36 05:54 2.30 8,965 9,140 PROD2 DRILL DRLG P 8965', Drill Ahead, 1.4 BPM @ 3900 PSI FS, BHP=4084,WHP=20. 05:54 07:00 1.10 9,140 9,140 PROD2 DRILL WPRT P Wiper trip; 33k#off bottom. 07:00 09:45 2.75 9,140 9,290 PROD2 DRILL DRLG P 9140', Drill Ahead, 1.4 BPM @ 3900 PSI FS, BHP=4145,WHP=40. 09:45 11:15 1.50 9,290 9,290 PROD2 DRILL WPRT P Wiper trip#3; 35k#off bottom. Tie-in +2'. 11:15 13:39 2.40 9,290 9,440 PROD2 DRILL DRLG P 9290', Drill Ahead, 1.4 BPM @ 4000 PSI FS, BHP=4125,WHP=5. 13:39 14:33 0.90 9,440 9,440 PROD2 DRILL WPRT P Wiper trip#1;35k#off bottom. 14:33 18:33 4.00 9,440 9,590 PROD2 DRILL DRLG P 9440', Drill Ahead, 1.39 BPM @ 4000 PSI FS, BHP=4050,WHP=15. 18:33 19:45 1.20 9,590 9,590 PROD2 DRILL WPRT P Wiper trip to 8440', PUW=35K 19:45 00:00 4.25 9,590 9,740 PROD2 DRILL DRLG P 9590', Drill Ahead, 1.4 BPM @ 4000PSI FS, BHP=4150,WHP=22 Page 9 of 16 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 36/27/2013 24 hr summary Drill ahead from 9,741'to 10,513' 00:00 01:00 1.00 9,740 7,870 PROD2 DRILL WPRT P Wiper to window with tie in, PUW=36K 01:00 01:09 0.15 7,870 7,896 PROD2 DRILL DLOG P Log formation tie in for+3', Pump rate=1.4BPM,WHP=0, Return MM=1.38, BHI Press=3975,Wide Open Choke 01:09 02:03 0.90 7,896 9,741 PROD2 DRILL WPRT P RBIH to drill, RIW=20K @ 40 FPM, 9700' start new 9.6 Power Pro down hole Old mud, system#3 made 1693',25K LSRV, .8%DS 02:03 02:57 0.90 9,741 9,789 PROD2 DRILL DRLG P 9741', Drill Ahead, 1.40 BPM @ 4000 PSI FS, BHP=4236, RIW=16.7K,WHP=96 02:57 04:27 1.50 9,789 9,890 PROD2 DRILL DRLG P 9789, Drill ahead, New power Pro around, 1.43 BPM @ 3250 PSI FS, WHP=285, BHP=4142, 04:27 05:39 1.20 9,890 9,890 PROD2 DRILL WPRT P 9890',wiper trip to 8740, PUW=36K. 05:39 08:21 2.70 9,890 10,040 PROD2 DRILL DRLG P Drill ahead, 1.43 BPM @ 3600 PSI FS,WHP=240, BHP=4155. 08:21 09:21 1.00 10,040 10,040 PROD2 DRILL WPRT P 10,040',wiper trip to 9000, PUW=37 K. 09:21 12:27 3.10 10,040 10,190 PROD2 DRILL DRLG P Drill ahead, 1.5 BPM @ 3700 PSI FS,WHP=250, BHP=4180. 12:27 13:33 1.10 10,190 7,875 PROD2 DRILL VPRT P 10,190',wiper trip to window with tie in, PUW=38K. 13:33 13:45 0.20 7,875 7,899 PROD2 DRILL DLOG P 7875 Log tie in for+3'correction, @7900', 1.51 BPM,WHP=270. BHI=3980, PUH 5-7 FPM 13:45 14:45 1.00 7,899 10,140 PROD2 DRILL WPRT P Continue wiper back in hole, Hard setdown @ 8920 with HS TF, Roll to 60L and reduce pump rate, Set down 6 to 7K and popped through. Lost alot of surface weight 10,100 to 10170 14:45 18:15 3.50 10,140 10,340 PROD2 DRILL DRLG P 10140', Drill ahead, 1.5 BPM @ 3400 PSI FS, BHP=4180,WHP=230. GEO target 92 Deg. Stacking weight 10,100'-10,190'. 18:15 19:42 1.45 10,340 10,340 PROD2 DRILL WPRT P Wiper trip to 9,000', PUW=38K, RBIH, some stacking same area 10,100'. 19:42 22:27 2.75 10,340 10,490 PROD2 DRILL DRLG P Drill ahead, 1.5 BPM @ 3750 PSI FS,WHP=245, BHP=4210. GEO target 90 deg inc. 22:27 23:42 1.25 10,490 10,490 PROD2 DRILL WPRT P Wiper trip, PUW=37K, RBIH,slow ROP thru stacking area, no problems. 23:42 00:00 0.30 10,490 10,513 PROD2 DRILL DRLG P Drill ahead, 1.49 BPM @ 3725 PSI FS,WHP=225, BHP=4220. GEO target 90 deg inc. 36/28/2013 Drilled ahead to called TD @ 11,285 Page 10 of 16 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 00:00 01:36 1.60 10,513 10,640 PROD2 DRILL DRLG P Continue drilling ahead, 1.49 BPM @ 3705 PSI FS,WHP=205, BHP=4190. GEO target 90 deg inc. 01:36 03:00 1.40 10,640 10,640 PROD2 DRILL WPRT P Wiper trip, PUW=36K, RBIH continue slow thru 10,100'to 10,190'. 03:00 05:06 2.10 10,640 10,790 PROD2 DRILL DRLG P Drilling ahead, 1.48 BPM @ 3650 PSI FS,WHP=220, BHP=4192. 05:06 06:24 1.30 10,790 10,790 PROD2 DRILL WPRT P Wiper trip 06:24 09:30 3.10 10,790 10,940 PROD2 DRILL DRLG P 1.51 BPM@ 3550 PSI FS, RIW=10.8K, BHP=4236,WHP=235 09:30 10:42 1.20 10,940 10,940 PROD2 DRILL WPRT P Wiper to 9800', PUW=38K, BHP=4220 10:42 15:42 5.00 10,940 11,090 PROD2 DRILL DRLG P 10940', Drill ahead, 1.5 BPM @ 3590 PSI FS, BHP=4233, 15:42 18:12 2.50 11,090 11,090 PROD2 DRILL WPRT P 11090, Pump 5 X 5 sweeps,wiper trip, PUW=40K, RBIH. Log secondary tie-in for+1'correction. 18:12 19:06 0.90 11,090 11,220 PROD2 DRILL DRLG P Drilling ahead, 1.49 BPM @ 3625 PSI FS,WHP=235, BHP=4235. GEO 91 deg inc. 19:06 20:36 1.50 11,220 11,220 PROD2 DRILL WPRT P 1,000'wiper trip, PUW=39K, RBIH. 20:36 22:06 1.50 11,220 11,285 PROD2 DRILL DRLG P Drilling ahead to called TD, 1.49 BPM @ 3635 PSI FS,WHP=210, BHP=4238. GEO 91 deg inc. 22:06 00:00 1.90 11,285 8,229 PROD2 DRILL WPRT P Start long wiper trip to swab, circulate sweeps to bit, PLAN=40K, 'pulled into tight spots, min rate. 36/29/2013 Pulled long wiper to surface. RBIH, unable to get below 11,015'. PUH laying in liner pill, at 10,745'bit depth the hole packed off, unable to circulate or move pipe.Attempt to pump down backside, 1,350 psi @.25 bpm. Continue to work pipe and re-establish circulation, in progress. 00:00 02:45 2.75 8,229 0 PROD2 DRILL WPRT P Continue long wiper to swab chasing sweeps to surface 02:45 04:21 1.60 0 7,740 PROD2 DRILL TRIP P RBIH to lay in completion fluids 04:21 04:27 0.10 7,740 7,475 PROD2 DRILL DLOG P Log K1 for-7'correction, PUW=29K 04:27 06:33 2.10 7,475 11,030 PROD2 DRILL TRIP P Continue in hole, Set down at 8090, 8940, and 9742 06:33 06:51 0.30 11,030 10,916 PROD2 DRILL TRIP P Stack @ 11,000,set down @ 11030, PUW=56K.pulling heavy,stuck at 10916', orient and pull free 06:51 07:03 0.20 10,916 10,940 PROD2 DRILL TRIP P RBIH and set down @ 10967, Pull up hole dragging heavy 07:03 07:27 0.40 10,940 10,749 PROD2 DRILL TRIP P Trip out laying in beaded liner pill, Started pulling heavy @ 10744, RBIH stack at 10753, P/U pull heavy, pack off,stuck,Able to orient freely. Unable to change DH WOB 07:27 08:39 1.20 10,749 10,749 PROD2 DRILL TRIP T Try relaxing pipe and pressures work pipe, pump accross top.WHP pressures up and holds pressure to 1000PSI with no change in BHA annular pressure.Attemp dumping WHP while working pipe Page 11 of 16 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:39 10:39 2.00 10,749 10,749 PROD2 DRILL TRIP T Line up down coil and attempt to circulate. Rate in changes rate out. Look to be circulating. Some circulation appears coming from L1 10:39 11:03 0.40 10,749 10,749 PROD2 DRILL TRIP T Work Pipe, looking for sign of 12.0PPG fluid in returns. 11:03 12:03 1.00 10,749 10,749 PROD2 DRILL TRIP T Start LVT down coil, 15.2 BBIs 12:03 15:03 3.00 10,749 10,749 PROD2 DRILL TRIP T 4 BBIs out of coil, S/D pump and soak,Work pipe 15:03 15:33 0.50 10,749 10,749 PROD2 DRILL SFTY T Conference call with town team to formulate options and plan forward 15:33 16:33 1.00 10,749 10,749 PROD2 DRILL CIRC T Perform Pressure test,WHP=615, Pressure up to 800PSI, bled right off to 650 PSI WHP, Pump up to 1000PSI in .5 BBIs Shut C-11 and R-5 to insure fluid leaking off to well, Injecting.25 BPM @ 1300 PSI 16:33 18:18 1.75 10,749 10,749 PROD2 DRILL TRIP T Line up down coil,Try to establish circulation, unable to establish circulation,several different pump rates, shut down pump,well will flow. 18:18 18:48 0.50 10,749 10,749 PROD2 DRILL SFTY T Another conference with town to discuss options. 18:48 22:33 3.75 10,749 10,749 PROD2 DRILL TRIP T Cycle pipe twice to 70K,work pipe, no luck. Open EDC, pump down coil, pressure up annulus from 4,016 psi ti 4,625 psi after.25 bbls, let well relax. 22:33 00:00 1.45 10,749 10,749 PROD2 DRILL TRIP T Continue effort to re-establish circulate,different pump rates,choke setting, annulalus keeps pressuring up. X6/30/2013 Continue to work stuck pipe, make attempts to re-eastablish circulate, no success, make preparations for pipe recovery.Town made decision to release from BHA, no success. Decision made to kill well, bullhead 94 bbls 12.0 ppg fluid down annulus @.5 bpm 1,500 psi, roll coil over to 12.0 ppg fluid,total 43 bbls. No flow check passed. Observe well and maintain hole fill. 00:00 06:00 6.00 10,749 10,749 PROD2 DRILL TRIP T Continue to work pipe sparingly, make attempts to re-establish circulate, no success, make preparation for pipe recovery. 06:00 07:00 1.00 10,749 10,749 PROD2 DRILL TRIP T Crew change, planning meeting, work pipe, 70K to-8K 07:00 07:18 0.30 10,749 10,749 PROD2 DRILL TRIP T Pump down coil, no communication 07:18 08:30 1.20 10,749 10,749 PROD2 DRILL TRIP T Confer with town, release from BHA, work pipe, pressure up and surge backside, pressure up and surge coil and backside, No good. Still have communication with BHA 08:30 13:30 5.00 10,749 10,749 PROD2 DRILL CIRC T Line up and pump 94 BBIs 12.0 Completion fluid down coil X tubing annulas, .5 BPM @ 1500 PSI. Shut down and monitor. No Flo pass 13:30 15:00 1.50 10,749 10,749 PROD2 DRILL CIRC T Roll coil to 12.0, pumped 43 bbls 12.0, Pumped 2 BBIs to ensure backside full Page 12of16 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 15:00 18:00 3.00 10,749 10,749 PROD2 DRILL OWFF T Observe/monitor well/Maintain hole fill 18:00 00:00 6.00 10,749 10,749 PROD2 DRILL OWFF T Continue monitoring well, maintain hole fill, rebuild rig pump#1. 07/01/2013 Monitor well and maintain hole fill, rebuild mud pump#1, gather tools for pipe recovery. MIRU HES E-Line. Start pipe recovery procedure,strip off and hot tap coil,well dead, cut coil, pull 20'wire, continue wire recovery,see UQC wire anchor @ 600 to 700 LBS on 6th cycle,wire parted. MU wire to HES unit and retrieve 1,100'wire. RD HES unit,overshot coil in tree and pull up to desired height,set upper/lower slips, install bowl, slips and collar. Install Baker external slip type connector and pull test to 50K, install 2X2 plug valve, stand by for orders. 00:00 08:00 8.00 10,749 10,749 PROD2 DRILL OWFF T Monitor well and maintain hole fill. Rebuild mud pump#1,gather pipe recovery equipment. 08:00 10:00 2.00 10,749 10,749 PROD2 DRILL ELNE T PJSM, R/U HES E-line/Pump to ensure hole and coil full 10:00 10:30 0.50 10,749 10,749 PROD2 DRILL ELOG T PJSM with rig team, HES, BOT. Go over stuck coil recovery procedure. 10:30 13:30 3.00 10,749 10,749 PROD2 DRILL TRIP T Start working procedure, Set coil in slips and test, manual locks set, Strip off and hot tap coil, Coil slight vac-dead. Cut coil and pull-20 wire out by hand and clamp. Cut wire on reel end and move off injector. Start stripping wire with blocks 13:30 15:00 1.50 10,749 10,749 PROD2 DRILL TRIP T Coil slid through BOP slips, Shut lower set and lock. Coil still above upper set. Continue wire recovery ops. See UQC wire ancor©600 to 700 LBS on 6th cycle 15:00 15:30 0.50 10,749 10,749 PROD2 DRILL ELNE T Make up wire to HES unit and retrieve wire, Pull out 1100'of wire. 15:30 16:30 1.00 10,749 10,749 PROD2 DRILL ELNE T R/D HES E-Line unit 16:30 17:54 1.40 10,749 10,749 PROD2 DRILL CTOP T Overshot coil in tree, Pull up to desired height above rig floor, Set upper and lower slips, install bowl, slips and collar 17:54 19:42 1.80 10,749 10,749 PROD2 DRILL CTOP T Crew change, Lay down overshot, prep end of coil and install Baker external slip type connector. Pull test and tighten, Pull test to 50K over, Repair HMI block hook weight 19:42 20:12 0.50 10,749 10,749 PROD2 DRILL CTOP T Install 2X2 plug valve on top on coil 20:12 00:00 3.80 11 10,749 PROD2 DRILL CTOP T Stand by on orders, monitor well, maintain hole fill, install connector on injector side of coil. 07/02/2013 Prep E-Line equipment for coil tubing cut,stand by go ahead. Made four attempts to perforate coil tubing with 1"tubing punch above end of wire @ 910'with no success. Coil tubing cut in progress. 00:00 03:00 3.00 10,749 10,749 PROD2 DRILL CTOP T Continue to monitor well and hole fill. Call out HES night crew, PJSM,prep E-Line equipment for coil cut. 03:00 13:30 10.50 10,749 10,749 PROD2 DRILL CTOP T Stand by for orders 13:30 14:30 1.00 10,749 10,749 PROD2 DRILL CPBO T Receive plan forward;conduct pre-job safety meeting. begin rigging up eline for tbg punch/cut. Page 13 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 18:00 3.50 10,749 10,749 PROD2 DRILL CPBO T P/T eline pressure equipment to 650 psi-good. Pop back off to make up 1"TS w/tubing punch. RIH and punch tbg at 910',fire punch, POOH, check tool,tool fired,attempt to _circulate, no success. 18:00 00:00 6.00 10,749 10,749 PROD2 DRILL CPBO T Made three additional runs with 1" tubing punch assembly @ 10' intervals 900', 890', and 880',all shots fired and checked at surface to confirm, pressure up coil on each shot to different pressures 500,1200,and 1500 psi. No pressure ,changes after each shot. Decision made to run 1" RCT cutter anyway. 37/03/2013 Two attempts to cut coil @ 870'with HES 1" RCT cutter were unsuccessful. Decision made to run SLB chemical cutter, stand by for SLB E-line equipment from Prudhoe. MIRU SLB equipment, PU tools for dummy run. 00:00 03:00 3.00 10,749 10,749 PROD2 DRILL CPBO T Decision made run 1"RCT cutter. HES MU 1" RCT cutter assembly. RIH w/cutter to 870', pressure coil to 1200 psi, fire cutter, no pressure change, POOH. check tool,tool fired. 03:00 05:30 2.50 10,749 10,749 PROD2 DRILL CPBO T Decision made to make another cutter run. RIH w/same to 870', same parameters,fire cutter, same results as previous run, POOH, check tool,tool fired, LD HES equipment. 05:30 10:30 5.00 10,749 10,749 PROD2 DRILL CPBO T Stand by for direction 10:30 13:00 2.50 10,749 10,749 PROD2 DRILL CPBO T Discuss options with town. SLB Eline truck to be avail this afternoon for chem cut. Demob HES Eline equipment. 13:00 18:30 5.50 10,749 10,749 PROD2 DRILL CPBO T Stand by for SLB Eline crew. 18:30 19:00 0.50 10,749 10,749 PROD2 DRILL CPBO T Gave SLB crew rig orientation 19:00 00:00 5.00 10,749 10,749 PROD2 DRILL CPBO T Spot&RU SLB E-Line unit and equipment. PJSM. Pump 10 bbls 12.0 ppg fluid down annulus @ .5 bpm 925 psi. PU/MU tools for dummy run. 37/04/2013 Made to attempts to cut coil with SLB chemical cutters,first attempt with 1.375"cutter @ 920',cutter misfired. Second attempt with 1.25"cutter at same depth was success, pull test verified coil free, RDMO SLB E-Line. 00:00 02:00 2.00 10,749 10,749 PROD2 DRILL CPBO T PU SLB toolstring for drift run,stab on well,test. Pump 10 bbls 12.0 ppg fluid down coil @ .5 bpm 1,500 psi, RIH w/dummy drift to 970', POOH, no issues. 02:00 03:30 1.50 10,749 10,749 PROD2 DRILL CPBO T Unable to arm chemical cutter due to thunderstorm in area,stand by for thunder to pass. Page 14 of 16 r Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 05:00 1.50 10,749 10,749 PROD2 DRILL CPBO T Resume activity. PJSM.Arm cutter, stab on well. RIH w/cutter to 920', fire ctter, POOH to 500', unable to circulate, POOH to check cutter. 05:00 09:00 4.00 10,749 10,749 PROD2 DRILL CPBO T Chem cut failure due to improper igniter use for the chem cutter. SLB crew"houred out." Secure equipment and make arrangements for them to billet in KRU. Discuss options. 09:00 12:30 3.50 10,749 10,749 PROD2 DRILL CPBO T Second BP Eline crew release to work in KRU. Discover correct igniters are unavailable on the slope for 1-3/8"chem cutter;will have to order from Houston in AM(4th of July issues). Decide to run 1-1/4"chem cutter(undersized for cutting our CT). Wait on SLB crew to arrive. 12:30 14:00 1.50 10,749 10,749 PROD2 DRILL CPBO T SLB Eline on location. Perform rig orientation/tour w/Eline personnel. Conduct pre-job safety meeting with rig/eline crews. 14:00 19:00 5.00 10,749 10,749 PROD2 DRILL CPBO T SLB crew rigging back up/prepping to run 1-1/4"chem cutter. Heat mud in pits. 19:00 21:30 2.50 10,749 10,749 PROD2 DRILL CPBO T Pump 10 bbls down annulus, PU cutter,stab on well, RIH to 200', pump 10 bbls down coil, RIH to 920', fire cutter, PUH to 500',circulate, tbg/annulus communicating, POOH. LD SLB tools. 21:30 23:30 2.00 10,749 10,749 PROD2 DRILL CPBO T Prep to pull coil, PU on coil to 5K, open slips, coil free. 23:30 00:00 0.50 10,749 10,749 1PROD2 DRILL CPBO P RD SLB E-Line equipment. X7/05/2013 Finished rigging down SLB E-Line equipment. Recovered 930'of 2"coil from wellbore, leaving approximately 7950'of coil and 72' BHA in hole,top of fish @ 930'.200'diesel cap and 12.0 ppg fluid in wellbore,set BPV. RDMO CDR2. Rig Release @ 12:00 00:00 01:00 1.00 10,749 10,749 PROD2 DRILL CPBO T Finish RD SLB equipment, prep for coil recovery 01:00 03:00 2.00 10,749 I 10,749 PROD2 DRILL PULL T Cut connector, slide injector, MU splice,dimple connector,zero depth. 03:00 05:30 2.50 10,749 10,749 PROD2 DRILL PULL T Troubleshoot depth counter cable. POOH. Recover 930'of coil, leaving approximately 7950'of coil and 72'of BHA in hole,4398' remaining on reel. 05:30 11:00 ' 5.50 10,749 10,749 DEMOB WELLPF DMOB P 'Begin demob of rig. Blow down reel/ lines. Disconnect. FMC rep delayed @ Doy 141. Cut off bottom 60'of coil for examination later. 11:00 11:30 0.50 10,749 10,749 DEMOB WELLPF DMOB P Prep to set BPV; find dry-rod has been dismantled(homemade tool issue per Nabors). FMC rep has no lubricator. Fab new dry-rod. Continue prep to move. Page 15 of 16 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 12:00 0.50 10,749 10,749 DEMOB WELLPF MPSP P Attempt to set BPV-wrong plug brought to location(drifted thru profile).Wait for FMC rep to bring correct plug to location. On location; set BPV. 10,749 10,749 DEMOB WHDBO NUND P NDBOPE, RDMO XXXXX RIG RELEASE @12:00 XXXXXX Page 16 of 16 RFr;h1Vh13 JuL I b LUi, AOGCC Letter of Transmittal FARM BAKER Date: July 12, 2013 HUGHES To:' From: Makana Bender Carl Ulrich/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 3C-09L1PB1 3C-09L1-01PB1 (2) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Carl.Ulrich, Baker Hughes, Survey Manager Carl.Ulrich • BakerHughes.com �-- v -2 7 is ill `Wp CI N a. 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CL ro 0mrnmrn NmN v C t = R o0 rnrnrno) rn Urnrnrn z co m oC 0 ul - vv CoCoCoCrCoCm Co.- v co v co to Co m to Co Co Co Co a v a v U 2 u-±- c v v v v v v v v v v v + ComNUO NpON N Co N- Co Co N 0 N N UO UO CO NN COL-001V O) V N N0nOQQOQvUN U( V V V N (CV Co N (mV 0 ) CV LC)000 m 0. Y 0 000 0) .1- 0001 CD CO CO uoni c CO 0 00 U 4- (O UO UO UO UD UO UO UD UD UO UO C (0 co co Q '� m (O N 0 N V Q CV UD m m n -0 _ co 0 N u) N UP O) O) N UO Q ..-. Co M M M M M M C a `) a E al Q a Y Y 2 2 0 0 0 R: 8 rn rn o m8 N m 8 8 S U Y Y co coUm 4 C °o) 0 0 0 0 0 0 rn rn rn m NOO mn V n (m0 N rn N NON m o OQ NC C ® g mO OO NNN V Uo O w N 0 m 7 N U a` m 3 3 o rn Ferguson, Victoria L (DOA) From: Ferguson, Victoria L (DOA) Sent: Tuesday, July 09, 2013 11:24 AM To: 'Eller, J Gary'; Ohlinger, James J (James.J.Ohlinger@conocophillips.com) Subject: 3C-09(PTD 185-100), 3C-09L1(PTD 213-076), 3C-09L1-01(PTD 213-077) Gary,James, Please prepare the following: 3C-09 PTD 185-100, Sundry 313-242: Submit 10-404 for plug perforations. 3C-09L1 PTD 213-076:Submit 10-404 Operations Shutdown with all work to date 3C-09L1-01 PTD 213-077: Submit 10-404 Operations Shutdown with all work to date Submit new 10-403 for workover when planned. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W. 7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferquson[�alaska.gov From: Eller, J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Friday, July 05, 2013 9:05 AM To: Ferguson, Victoria L (DOA); Bashford, Karen; Skufca, Jason M Cc: Ohlinger, James J; Gantt, Lamar L; Robinson, Shon D; Venhaus, Dan E; Starck, Kai; Burke, Jason Subject: RE: Stuck 2" Coiled Tubing in KRU 3C-09 Folks—We successfully cut the stuck 2" coiled tubing in well 3C-09 last night, and we have recovered the coiled tubing above the cut point of 930' MD. We're now in the process of rigging down the Nabors CDR2 rig and discussing what to do with well 3C-09. The well is not in an operable condition, so as indicated previously it will be classified as 'Suspended' until we either conduct a workover or begin plugging operations. Please call me if you have any questions. -Gary Eller From: Eller, J Gary Sent: Wednesday, July 03, 2013 12:25 PF1 To: Ferguson, Victoria L(DOA) (victoria.f rguson@alaska.gov) Cc: Ohlinger, James J; Gantt, Lamar L; Robinson, Shon D; Venhaus, Dan E; Starck, Kai; Burke, Jason Subject: Stuck 2" Coiled Tubing in KRU 3C-09 Victoria—As we discussed on the phone, I wanted to keep you apprised of our status on well KRU 3C-09 (PTD#213- 076). I've attached a schematic which shows that we have 2" coiled tubing stuck & packed off down in the L1-01 lateral. We have made our surface cut of the 2" coiled tubing and attempted to recover the a-line cable. Unfortunately, instead of pulling the e-line at the anchor at the BHA, we parted the cable at 1100'. This means that we're forced to cut 1 the coiled tubing somewhere above 1100'. Thus far we have been unsuccessful at making a cut at 900', but we continue to run different styles of cutters to accomplish that objective. We are well situated from a well control standpoint. The coiled tubing BHA is equipped with a set of double check valves, and we have installed a 2" plug valve at the surface. We have loaded both the inside and outside of the coiled tubing with over-balancing 12.0 ppg NaBr brine, and the fluid level is holding steady. Our BOP stack is equipped with 2 sets of 2" pipe/slip rams, 2 sets of blind/shear rams, and a 5K annular preventer. This is a through-tubing drilling operation, so the completion is fully competent with relatively new 3-1/2"tubing, packer, and tree. After we get our coiled tubing cut and recovered from 900', our forward plan is to classify 3C-09 as a `Suspended'water injection well until a workover rig can pull the completion and recover the stuck coiled tubing or possibly plug the well for abandonment. Please let me know if you have any questions. <<OLE Object:Picture(Device Independent Bitmap)» 3. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 fax: 907-265-1158 2 3C-09 Current Schen atic 2"OD,0.203"v;a ,07-9X cc;ed tubing -Coil is cut at sure ace and equlj ped w Bogen connection. s set'n hard sit -P pe dr tied o.th 1.313"ba lir rg r 1 ;32" e `necab aparedat11X 4:`het! _,.....magi - ► out cr BN:. as ' i gab a Inas a rated breakng strength r hae s called with 12.2.ppg t'daBr br'ne. VIII TRIM :, 1;1 T -SRI tc the co edtubing. ,@ 1822 T'D: I -We s dead _.nom; 1 - Can bu,head down co-ed tub rg or ci I canna crcu ate I [3-1 2 Gills kg 2E21 »189. 794',6932, 75801 I. . I immur iii �E3i<erPER L W 73 Rh;E. 2.99 ID =t 1E3F;er FHL Pac:er @ 7.365 R1;.E: 2.90 ID ;- i ■ • • 1-278-1-3- ---rJipie(n- 7Ll } I 1 7773 -Infection marvel C-sandports -- v I I 'Baker F1Packer@7804 7774-77891.1D jBaker8i-4ISBE781( If--; 7,.x:1 B-sand perfs 1 — --te —...: 7838-788;0 MD - - ._:- 3-1 eatherrorc StarJurst Holly)* '.';S tra, @ 7847 MD ,i — x 3nitl3red wi V.:SR-BB pac^:er - -A. �` Y 7 / I 3C-09L !Turing Tail @ 7920 1,1D J "'._ J •/,'+`r 3C --bR U I1D Jy a'3Billet 7949 - 799,3 MD 8018 - 8040 1,1D --_ J If-3Z '7 213,-;!J-EE shoe J. Gary Eller Wells Engineer ConocoPhillips - Alaska 2 1.4 OF O ��s7 THE STATE Alaska Oil and Gas °fALAsKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue oF �b Anchorage, Alaska 99501-3572 Main 907.279.1433 Fax• 907.276.7542 Lamar Gantt Coiled Tubing Drilling Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3C-09L1-01 ConocoPhillips Alaska, Inc. Permit No: 213-077 Surface Location: 1060' FNL, 901' FEL, SEC. 14, T12N, R9E, UM Bottomhole Location: 1914' FNL, 2177' FEL, SEC. 12, T12N, R9E, UM Dear Mr. Gantt: Enclosed is the approved application for permit to redrill the above referenced service well. The permit is for a new wellbore segment of existing well Permit No. 185-100, API No. 50-029- 21355-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, se, Daniel T. eamount, Jr. Commissioner DATED this I) day of June, 2013. RECEIVED STATE OF ALASKA MAY 2 9 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL ?IQ \i, A000C 20 AAC 25.005 CI 1 a.Type of Work: 1 b Proposed Well Class: Development-Oil ❑ Service-Win) 0• Single Zone Q 1c.Specify if well is proposed for Drill ❑ • Lateral ❑✓ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Rednll ❑ Reentry❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name 5. Bond. U Blanket u Single Well 11 Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180- 3C-09L1-01. 3 Address 6.Proposed Depth. 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 11250'• TVDSS: 6563' • Kuparuk River Field. 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number) Surface: 1060'FNL,901'FEL,Sec. 14,T12N, R9E,UM. ADL 25634,25629 Kuparuk River Oil Pool - Top of Productive Horizon 8 Land Use Permit: 13 Approximate Spud Date: 3673'FNL,3928'FEL,Sec. 12,T12N, R9E, UM 2567,2562 6/10/2013 - Total Depth 9 Acres in Property. P 14 Distance to 1914'FNL,2177'FEL,Sec. 12,T12N,R9E, UM . g•61 c s�3o113-2668- Nearest Property: 9500 • 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 82 feet 15 Distance to Nearest Well Open Surface'x- 528673 y- 5995373 Zone- 4 • GL Elevation above MSL • 47 feet to Same Pool 3C-08,1150' 16 Deviated wells: Kickoff depth- •8600 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole Angle . 90° deg Downhole:5065 psig • Surface:4417 psig - 18 Casing Program. Specifications Top - Setting Depth -Bottom Cement Quantity,c.f or sacks Hole Casing Weight Grade Coupling Length MD TVDSS MD TVDSS (including stage data) 3" 2.375" 4.7# L-80 ST-L 3405' 7845' 6360' 11250' 6563' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft) Plugs(measured) Effective Depth MD(ft) Effective Depth TVD(ft) Junk(measured) 8315 6785 none 8217 6711 none Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 202 sx CS II 116' 116' Surface 3908' 9.625" 1150 sx AS III,300 sx CI G 3943' 3748' Intermediate Production 8271' 7" 440 sx Class G,180 sx PF C 8299' 6773' Perforation Depth MD(ft): Perforation Depth TVD(ft): 7774'-7789', 7838'-7850', 7949'-7996', 8018'-8040' 6392'-6402', 6437'-6445', 6515'-6549', 6565'-6581' 20 Attachments Property Plat❑ BOP Sketch❑ Drilling Prograrr ❑• Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑✓ • 20 AAC 25 050 requirements Q 21 Verbal Approval Commission Representative Date f/�8/3 pO 22. I hereby certify that the foregoing is true and correct Contact James Ohlinger @ 5-1102 Email James.J.Ohlinger@conocophillips.corr Printed Name Lamar Gantt Title Coiled Tubing Drilling Supervisor Signature [ 1/'i4A. dY-i:il4 Phone:263-4021 Date SA:':;11...:' Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number a 13 O?4 50- O 9— lI 3S S —() _co Date �'1 I for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales E✓ Other: ' dP frs f fp 45-6 ) l,..,S t Samples req'd: Yes ❑ No Q Mud log req'd• Yes❑ No Q H2S measures: Yes 2" No ❑ Directional svy req'd. Yes f No❑ Spacing exception req'd: Yes ❑ No 21 Inclination-only svy req'd:� Yes❑ No 2' n 1-1 1 apfilol BY0"H� COMMSSIO SIJ/ /J ! L Approved b ER p , " �` coMM1 SIGN 1, Date: 'C, / Form 10-401 (Revised 10/2012) This permit is valid for 24"mL hs�frb1n thel'dBti of ellOMval(20 AAC 25.005(g)) �L� , (tj Vi_F L///7/3 � 5\� G RECEIVED ConocoPhillips MAY 2 9 2013 Alaska A0300 P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 20, 2013 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 an application for permits to drill a dual-lateral out of the Kuparuk Well 3C-09 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin in June 2013. The CTD objective will be to drill dual-laterals(3C-09L1 and 3C- 09L1-01), targeting the A sand intervals. The original B-sand perforations will have been cemented off before CTD operations commence. The C-sand perforations are isolated with the Straddle/Selective completion. Attached to this application are the following documents: — Permit to Drill Application Form for 3C-09L1 and 3C-09L1-01 — Detailed Summary of Operations — Directional Plans — Proposed Schematic If you have any questions or require additional information please contact me at 907-265-1102. Sincerely, James J. Ohlinger Coiled Tubing Drilling Engineer Kuparuk CTD Laterals NABORS ALASKA p 3C-09L1, & 3C-09L1-01 CDA ConocaFIZips Application for Permit to Drill Document 2AC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 3 (Requirements of 20 AAC 25.005(c)(5)) 3 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 5 (Requirements of 20 AAC 25.005(c)(13)) 5 Summary of Operations.. 5 Pressure Deployment of BHA 6 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Quarter Mile Injection Review(for injection wells only) 7 (Requirements of 20 AAC 25.402) 7 17. Attachments 7 Attachment 1: Directional Plans for 3C-09L1 &3C-09L1-01 7 Attachment 2: Current Well Schematic for 3C-09 7 Attachment 3: Proposed Well Schematic for 3C-09L1 &3C-09L1-01 7 Page 1 of 7 5/21/2013 P PTD Application: 3C-09L1, & 3C-09L1-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are 3C-09L1 &3C-09L1-01. Both laterals will be classified as "Service"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This wellbore is planned to be a lateral targeting the A sand package in the Kuparuk reservoir. Location at Surface 1060' FNL, 901' FEL, Sec 14, T12N, R09E, UM NAD 1927 RKB Elevation 82 AMSL Northings: 5,995,372 Eastings: 528,673 Pad Elevation 47 AMSL 3C-09L1 (API 50-029-21355-60) Location at Top of Productive Horizon 3794' FNL, 3327' FEL, Sec 12, T12N, R09E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 8,600' Northings: 5,997,930 Eastings: 531,514 Total Vertical Depth, SS: 6,433' Location at Total Depth 412' FNL, 3415' FEL, Sec 13, T12N, R09E, UM NAD 1927 Measured Depth, RKB: 10,700' Northings: 5,996,032 Eastings: 531,435 Total Vertical Depth, SS: 6,458 3C-09L1-01 (API 50-029-21355-61) Location at Top of Productive Horizon 3673' FNL, 3928' FEL, Sec 12, T12N, R09E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 7,855' Northings: 5,998,048 Eastings: 530,913 Total Vertical Depth, SS: 6,367 Location at Total Depth 1914' FNL, 2177' FEL, Sec 12, T12N, R09E, UM NAD 1927 Measured Depth, RKB: 11,250' Northings: 5,999,814 Eastings: 532,655 Total Vertical Depth, SS: 6,563 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference blowout prevention (BOP)schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036, for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4500 psi. (Using the maximum pressure in the area of 5065 psi,the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 4417 psi. See the"Drilling Hazards Information and Reservoir Pressure" section for more details.) — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) A static bottom hole pressure of 3C-09 in March 2013 indicated a reservoir pressure of 3925 psi or 11.6 ppg equivalent mud weight. The maximum down hole pressure in the 3C-09 pattern is at injector 3C-07 with 5065 ,/ psi. It is not expected that reservoir pressure as high as 3C-07 well will be encountered while drilling the 3C-09 laterals because of offset distance and faulting. Using the 3C-07 pressure as the maximum possible in 3C- 09,the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 4417 psi. Page 2 of 7 5/21/2013 PTD Application: 3C-09L1, & 3C-09L1-01 Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled. 3C Pad hasn't had any MI injection, however the neighboring 1R Pad has but the last amount was injected in 2009. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The largest, expected risk of hole problems in the 3C-09 laterals will be drilling an extended distance in the B- interval and crossing a fault into a lower pressurized reservoir block and experiencing losses. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. According to 20 AAC 25.030(t), thru-tubing drilling operations need not perform additional formation integrity tests. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS 3C-09L1 8600' 10700' 6433' 6458' 23/8', 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 3C-09L1-01 7845' 11250' 6360' 6563' 23/ , 4.7#, L 80, ST-L slotted liner; deployment sleeve on top. Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm Top Btm Burst Collapse (P130MD TVD TVD psi psi Conductor 16" 65 H-40 Welded 36' 116' 0' 116' 1640 630 Surface 9-5/8" 36 J-55 BTC 35' 3943' 0' 3748' 3520 2020 Casing 7" 26 J-55 BTC 28' 8299' 0' 6773' 4980 4330 Tubing 3-1/2 " 9.3 L-80 EUE8rd 26' 7920 0' 6495' 10,160 10,540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based Flo-Pro FloVis mud (9.6 ppg) Page 3 of 7 ,. ! L:1tg t 5/28/2013 PTD Application: 3C-09L1, & 3C-09L1-01 — Drilling operations: Chloride-based Flo-Pro FloVis mud (9.6 ppg). While this mud weight may not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: 3C-09 does contain a subsurface safety valve (SSSV). This could be used to deploy the slotted liner completion. If the SSSV fails to operate and provide a secure barrier, the well will be loaded with 12.0 ppg Sodium Bromide completion fluid in order to maintain managed pressure on open reservoir while running completions. — Emergency Kill Weight fluid: Two well bore volumes(-200 bbl)of 13.1 ppg emergency kill weight fluid will be within a short drive to the rig during drilling operations. In this situation, a"wellbore volume" is defined as the tubing volume plus the volume of the longest lateral. Managed Pressure Drilling Practice Managed pressure drilling (MPD)techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing an overbalance on the reservoir. Through experience with drilling CTD laterals in the Kuparuk sands, 11.8 ppg has been identified as the minimum EMW to ensure stability of shale sections. Since this well is proposed as an infield development candidate in an actively water flooded field, expected reservoir pressures can be difficult to estimate. In this case, however, a constant BHP of 11.8 ppg will be initially targeted at the window based on the recent static bottom hole pressure. The constant BHP target will be adjusted to maintain overbalanced conditions if increased reservoir pressure is encountered during drilling. The constant BHP target will be maintained utilizing the surface choke. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Page 4 of 7 5/21/2013 PTD Application: 3C-09L1, & 3C-09L1-01 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 3C-09 is a Kuparuk A-sand/B-sand injection well equipped with 31/2"tubing and 7"production casing with the C-sand behind a straddled selective. The well was recently worked over by removing the original 2-7/8"tubing and replacing it with a 3-1/2"completion. Two proposed A-sand CTD laterals will increase reservoir exposure in adjacent fault blocks. Prior to drilling,the A-sand perforations will be protected with sand and the tailpipe will be cemented in place across the B-sand perforations. The sand will be cleaned out below the tailpipe and a packer/hollow whipstock will be run for a 2-string casing exit. The 3C-09L1 sidetrack will exit through the 3-1/2"tubing and 7"casing at 7,855' MD and will target the A3 sand south of the existing well with a 2845' lateral. The hole will be completed with a 2-%"slotted liner to the TD of 10,700' MD with an aluminum billet at 8,600' MD. The 3C-09L1-01 lateral will kick off from the aluminum billet at 8,600' MD and will target the A2 sand north of the existing well with a 2650' lateral. The hole will be completed with a 2%"slotted liner to the TD of 11,250'MD with the liner top located inside the 3'/2"tubing at 7,850' MD. After the CTD sidetrack and a flowback period,the hollow whipstock can be perforated to re-establish communication to the existing A-sand perforations. Pre-Rig Work (As per submitted Sundry) 1. Positive pressure and drawdown tests on MV and SV. 2. Test Packoffs—T&IC 3. MIT-IA 4. RU slickline. Tag fill,replace SOV with DV,obtain SBHP 5. RU coil:Place sand plug from PBTD up to the tubing tail. 6. RU slickline. Tag fill 7. RU Eline:GR/CCL for jewelry correlation log 8. RU Eline:Perforate tubing tail at 7827-7832'RKB 9. RU coil:Cement Squeeze B-sand perforations. 10. RU slickline. Tag top of cement and pressure test. 11. RU coil:Mill out cement in the 3-1/2"tubing down to the tubing tail. 12. RU coil:Fill clean out of the sand plug in the 7"casing 13. RU Eline: Set Packer/Whipstock 14. Prep site for Nabors CDR2-AC,including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 3C-09L1 Sidetrack(A3 sand,south) a. Mill 2.80"window at 7,850' MD. b. Drill 2.70"x 3.0"bi-center lateral to TD of 10,700'MD c. Run 2%"slotted liner with an aluminum billet from TD up to 8,600' MD 3. 3C-09L1-01 Lateral(A2 sand, north) a. Kick off of the aluminum billet at 8,600'MD b. Drill 2.70"x 3.0"bi-center lateral to TD of 11,250'MD c. Run 2%"slotted liner from TD up to 7,850'MD,inside the 31/2"tubing tail 4. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Page 5 of 7 !! 5/21/2013 �, rw h PTD Application: 3C-09L1, & 3C-09L1-01 Post-Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Return to pre-production before injection Pressure Deployment of BHA The planned bottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slickline lubricator. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The 3C-09 CTD laterals will only be displaced to an overbalancing fluid (12 ppg Na-Br) prior to running liner if the SSSV fails to function or losses are more than acceptable while the SSSV is closed. See the"Drilling Fluids"section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%"liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) — No annular injection on this well. — Class II liquids to KRU 1R Pad Class II disposal well — Class II drill solids to Grind&Inject at PBU Drill site 4 — Class I wastes will go to Pad 3 for disposal. Page 6 of 7 '" ° . 5/21/2013 PTD Application: 3C-09L1, & 3C-09L1-01 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. ✓ — Distance to Nearest Property Line(measured to KPA boundary at closest point) Lateral Name Distance 3C-09L1 14,050 3C-09L1-01 9,500 / — Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Well 3C-09L1 1010 3C-12 3C-09L1-01 1150 3C-08 /16. Quarter Mile Injection Review(for injection wells only) (Requirements of 20 AAC 25.402) The only wells that lie within %-mile of the proposed 3C-09 CTD laterals are the 3C-09 motherbore, 3C-08, 3C- 10, and 3C-12. The casing and cementing of 3C-09 is described below. 3C-09 Mother Bore Well 3C-09 was drilled and completed in 1985. The 7", 26 ppf, J-55, BTC-Mod production casing was set at 8,299' MD/6,773'TVD in the Miluveach. 3C-09 is a Service well with a"Normal Well"Ann-Comm status,was capable of injecting to the Kuparuk B, C&A sands with a straddle completion. The C-sand perforations are isolated by a straddle/selective completion. The B-sand perforations will be cemented off,with the A-sand perforations plugged off via the whipstock/packer assembly. The A-sand perforations can be re-obtained after the CTD laterals are completed, by perforating the whipstock tray. See the attached schematic for clarification. 3C-08 Well 3C-08 was drilled and completed in 1985. The 7", 26 ppf, J-55, BTC-Mod production casing was set at 10,258' MD/6,841'TVD. 3C-08 is a Producing well with a"Normal Well"Ann-Comm status. The only perforations are in the A-sand interval. 3C-10 Well 3C-10 was drilled and completed in 1985. The 7", 26 ppf, J-55, BTC-Mod production casing was set at 8,974' MD/6,736'TVD. 3C-10 is a Producing well and had a"Problem Well"Ann-Comm status, however the well has recently had a rig work-over. The well is planned for CTD sidetracks later this year and will be the producer paired to 3C-09. 3C-12 Well 3C-12 was drilled and completed in 1985. The 7", 26 ppf, J-55, BTC-Mod production casing was set at 7,567' MD/6,759'TVD. 3C-12 is a Service well with a"Normal Well"Ann-Comm status, capable of injecting to the Kuparuk C &A sands with a straddle completion. 17. Attachments Attachment 1: Directional Plans for 3C-09L1 & 3C-09L1-01 Attachment 2: Current Well Schematic for 3C-09 Attachment 3: Proposed Well Schematic for 3C-09L1 & 3C-09L1-01 Page 7 of 7 ` q 6ait§ 5/21/2013 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) The only wells that lie within 1/4-mile of the proposed 3C-09 CTD laterals are the 3C-09 motherbore, 3C-08, 3C-10, and 3C-12. The casing and cementing of 3C-09 is described below. 3C-09 Mother Bore Well 3C-09 was drilled and completed in 1985. The 7", 26 ppf, J-55, BTC-Mod production casing was set at 8,299' MD/6,773'TVD in the Miluveach. 3C-09 is a Service (Water Injection only)well with a "Normal Well"Ann-Comm status, was capable of injecting to the Kuparuk B, C &A sands with a straddle completion. The C-sand perforations are isolated by a straddle/selective completion. The B- sand perforations have been squeezed off, and the A-sand perforations plugged off via the whipstock/packer assembly. The A-sand perforations can be re-obtained after the CTD laterals are completed, by perforating the whipstock tray. See the attached schematic for clarification. The 3C-09 7"—26#casing was cemented in with 440 sacks (15.8 ppg) of Class G cement. f he Schlumberger CET Log from 7/14/85 shows competent cement to 50' (and higher) above the C-sand perforations at 7774' MD, and an additional 70' above the B-sand perforations at 7838' MD. The B- sand perforations have recently been cemented-off and are in the zone of the kickoff-point for the 3C- 09L1 Lateral at 7847' MD. Putting over 120' of cement above the window through the 7" casing. 3C-09 has been in active injective injection service since 1987. 3C-08 (Producer) Well 3C-08 was drilled and completed in 1985. The 7", 26 ppf, J-55, BTC-Mod production casing was set at 10,258' MD/6,841' TVD. 3C-08 is a Producing well with a "Normal Well"Ann-Comm status. The only perforations are in the A-sand interval. 3C-08 utilized 450 sacks (15.8 ppg) of Class G cement for the 7"—26#casing. The Schlumberger CET Log from 8/04/85 shows competent cement from TD to more than 500' above the A-sand perforations at 9,904' MD. 3C-10 (Producer Well 3C-10 was drilled and completed in 1985. The 7", 26 ppf, J-55, BTC-Mod production casing was set at 8,974' MD/6,736' TVD. 3C-10 is a Producing well and had a "Problem Well"Ann-Comm status, however the well has recently had a rig work-over. The well is planned for CTD sidetracks later this year and will be the producer paired to 3C-09. 77 barrels of 15.8 ppg Mass G cement was used for the 7"—26#casing, and shows competent cement from TD to well over 200' above the A and C-sand perforations according to the Schlumberger CET Log from 7/14/85. 3C-10 is planned for the 3 Coiled Tubing laterals and will be the offset producer for 3C-09L1 and L1-01. 3C-12 (Injector) Well 3C-12 was drilled and completed in 1985. The 7", 26 ppf, J-55, BTC-Mod production casing was set at 7,567' MD/6,759' TVD. 3C-12 is a Service well with a "Normal Well"Ann-Comm status, capable of injecting to the Kuparuk C &A sands with a straddle completion. The 3C-12 7"—26#casing was cemented in with 350 sacks of Class G cement, and noted 100% returns throughout the operation. 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'i:.I __:: I -z s: . :. > UU: :';:■•s:: : l - Hung f:c:l- g - - r .�.. li 111111 .t:: 4:11141, g� 1 I: 1 T--1'- o p 11111 1 1111111 lil\ S191f1iN111 _ql HI ! 1 B !`. �` _ 1111111 i:. u11 I 14 1, i I r I 1 1 i I Ek C [� . r b - vPi N N O Q O tom: M N n .a. : ' Es OU 0 iivo.frt��I/�-)uinoS 3C-09 Proposed CTD Sidetrack ® 16"65#H-40 shoe @ 116' TRMAXX-CMT-5-SR @ 1822'TVD 9-5/8"36#J-55 shoe 13-1/2"GLMs @ 2521',4189',5794',6932',7580' @ 3943'MD m Y 4 r Baker PBR @ 7643'RKB;2.99"ID (Baker FHL Packer @ 7666'RKB;2.90"ID y t1.4— 2.813"X Nipple @ 7720' 7773'-Injection mandrel C-sand perfs Baker F-1 Packer @ 7804' 7774'-7789'MD —Baker 80-40 SBE @ 7807' ,iF <� y .y,;c Tubing Tail Perforations k.B-sand perfs 7838'-7850'MD � ' d: 3-1/2"Weatherford Starburst Hollow WS tray @ )'MD d *anchored w/WSR-BB *perf'd post-CTD to regain existing perf injection 3C-09L1 �• ? k.,,t• ss A3 south Tubing Tail @ 7920'MD il *` TD @ 10700'MD Y Billet @ 8600'MD s., A-sand perfs 7949'-7996'MD A "-::: , , 8018'-8040'MD Existing perfs covered with 3C-09L1-01 A2 C-09L1-01A2 north sand prior to plugback(or TD @ 11250'MD RWO). Mill out cement in 7"26#J-55 shoe 3-1/2"TT and perform FCO @ 8299'MD __ prior to setting WS. 01 C' I N A L lieKUP 3C-09 ConocoPhillips -''}W Well Attributes Max Angle&MD TD 'h... Wellbore API/UWI Field Name Well Status Incl(') MD(ftKB) Act Btm(ftKB) Alaska,k)c. CoromRulups 500292135500 KUPARUK RIVER UNIT INJ 49.25 4,825.00 8,315.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Wet Conk; -3C-09,5/10/3013 1.00:41 PM SSSV:TRDP Last WO: 5/10/2013 34.59 7/12/1985 Scnemalic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 8,013.0 2/28/2013 Rev Reason:WORKOVER PRE-CTD osborl 5/10/2013 HANGER._T f 1 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd I ' CONDUCTOR 16 15.062 36.0 116.0 116.0 65.00 H-00 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd SURFACE 95/8 8.921 34.7 3,943.0 3,748.3 36.00 J-55 BTC 1 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd PRODUCTION 7 6.276 28.0 8,298.8 6,772.8 26.00 J-55 BTC Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd TUBING WO 3 1/2 2.992 26.3 7,658.5 6,311.3 9.30 L-80 EUE8rd CONDUCTOR, Completion Details 36.116 Top Depth (ND) Top Incl Nomi... Tap(ftKB) MKS) Item Description Comment ID(in) SAFETY VLV, I o I ' 26.3 26.3 -0.15 HANGER CAMERON TUBING HANGER 2.860 • 1,922 L 1 1,822.3 1,822.3 0.55 SAFETY VLV CAMCO TRMAXX-CMT-SR-5 SCSSV w/2.813"X-Profile(-1822) 2.812 7,636.1 6,295.9 46.37 LOCATOR BAKER SEAL LOCATOR 2.992 7,637.1 6,296.5 46.37 SEAL ASSY BAKER 80-40 PBR SEAL ASSEMBLY 2.980 GAS LIF7, Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd 2.s21 UPPER PACKER 3 1/2 2.992 7,643.3 7,808.8 6,416.2 9.30 L-80 EUE ASSY 1 1 Completion Details Top Depth (TVD) Top Incl Nomi... Top(ftKB) (ftKB) (") Item Description Comment ID(In) SURFACE, _.11 L 7,643.3 6,300.8 46.38 PBR 20'PBR SEAL ASSEMBLY(pinned to 40k lbs to shear) 2.990 35-3,943 i 7,666.4 6,316.8 45.49 PACKER BAKER FHL RETRIEVABLE PACKER(Min 1003",60k lbs shear) 2.900 7,719.5 6,353.9 46.03 NIPPLE HES'X'NIPPLE 2.812 GAS LIFT, 4,169 -1 7,801.7 6,411.2 45.48 LOCATOR BAKER LOCATOR 2.992 7,802.5 6,411.8 45.48 SEAL ASSY BAKER GBH-22 BONDED SEAL ASSEMBLY(80 40) 2.980 Tubing Description String 0... String soy. Top(RKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd LOWER PACKER 31/2 2.992 7,803.5 7,920.0 6,494.8 9.30 L-80 EUE8rd GAS LIFT, _ r ASSY 5,794 ) Completion Details Top Depth (TVD) Top Inc) Nomi... Top(ftKB) (ftKB) (0) Item Description Comment ID(in) GAS LIFT. 7,803.5 6,412.5 45.48 PACKER BAKER F-1 PERMANENT PRODUCTION PACKER 4.000 8.932 7,806.9 6,414.8 45.48 SBR BAKER 80-40 SEAL BORE EXTENSION,5'long 4.000 lili . 7,919.3 6,494.3 44.56 SOS SOLID SEAL SHEAR OUT SUB(pinned to 3500 psi) 3.000 GAS LIFT. Perforations&Slots 7,550 '_ Shot Top(TVD) Btm(TVD) Dens Top MKS)Btm(ftKB) (ftKB) (ftKB) Zone Date (sit... Type Comment 7,774.0 7,789.0 6,391.8 6,402.3 C-1,3C-09 8/1/1985 12.0 IPERF 5 1/2'Csg Gun,120 deg.phasing 7,838.0 7,850.0 6,436.7 6,445.1 UNIT B,3C-09 8/1/1985 12.0 IPERF 5 1/2'Csg Gun,120 deg.phasing LOCATOR, 7,638 7,949.0 7,996.0 6,515.4 6,549.0 A-5,A-4,A-3, 8/1/1985 4.0 IPERF 4"HJ II,90 deg.phasing SEAL ASSY, 3C-09 7.637 8,018.0 8,040.0 6,564.9 6,581.2 A-2,3C-09 &1/1985 4.0 IPERF 4"HJ II,90 deg.phasing Notes:General&Safety End Date Annotation 7/15/2010 NOTE:View Schematic w/Alaska Schematic9.0 INJECTION, l± 7,773 11" IPERF, 7,774-7,769 _ PACKER.7,804 -� S00,]007 r 1 1 IPERF. InA 7838-7,850Mandrel Details Top Depth Top Port (ND) Incl OD Valve Latch Size TRO Run N...Top(BKS) (OKB) Pt Make Model (in) Sery Type Type lin) (psi) Run Date Corn... SOS.7.919 1-- 1 2,520.6 Z520.2 5.48 Camco MMG 1 12 GAS UFT DMY RK 0.000 0.0 5/9/2013 2 4,189.2 3,913.6 47.49 CAMCO MMG 1 1/2 GAS UFT DMY RK 0.000 0.0 5/9/2013 3 5,793.6 5,010.5 46.11 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/9/2013 IPERF, 4 6,932.3 5,813.5 46.36 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/9/2013 7,949-7,998III 5 7,580.2 6,257.3 46.44 CAMCO MMG 7 1/2 GAS LIFT SOV DCR 0.000 0.0 5/9/2013 III (PERF, 6 7,772.6 6,390.8 45.63 CAMCO MMG 1 1/2 INJ DMY RK 0.000 0.0 5/9/2013 8,0108,040 (&1 PRODUCTION, 1 1 4 1 ,S' , 1 0,8,399 + /- i k� ill �I TO,6,315 { ` �•i g pLai ConocoPhil l i s p Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3C Pad 3C-09 3C-09L1-01 Plan: 3C-09L1-01_wp02 Standard Planning Report 10 May, 2013 r' 1 BAKER HUGHES IP-- Baker Hughes INTEQIn' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3C-09 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3C-09 @ 82.00ft(3C-09) Site: Kuparuk 3C Pad North Reference: True Well: 3C-09 Survey Calculation Method: Minimum Curvature Wellbore: 3C-09L1-01 Design: 3C-09L1-01_wp02 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3C Pad Site Position: Northing: 5,995,835.15ft Latitude: 70°23'58.955 N From: Map Easting: 528,205.68ft Longitude: 149°46'13.622 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.22° Well 3C-09 Well Position +N/-S 0.00 ft Northing: 5,995,372.49 ft Latitude: 70°23'54.387 N +E/-W 0.00 ft Easting: 528,672.61 ft Longitude: 149°45'59.994 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 47.40 ft Wellbore 3C-09L1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2012 6/30/2013 15.53 79.97 57,366 Design 3C-09L1-01_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,600.00 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) (°l -47.40 0.00 0.00 42.10 Plan Sections Measured ND Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°1100ft) (°l100ft) (°/100ft) (°) Target 8,600.00 81.66 131.91 6,432.58 2,546.97 2,851.76 0.00 0.00 0.00 0.00 9,055.00 82.31 62.89 6,504.76 2,492.79 3,270.73 15.00 0.14 -15.17 265.00 9,166.54 90.00 61.54 6,512.24 2,544.63 3,369.11 7.00 6.89 -1.21 350.00 9,366.54 90.00 47.54 6,512.24 2,660.37 3,531.61 7.00 0.00 -7.00 270.00 9,966.54 86.66 5.65 6,530.56 3,184.62 3,794.28 7.00 -0.56 -6.98 265.00 10,166.54 89.40 351.91 6,537.48 3,383.95 3,790.01 7.00 1.37 -6.87 281.00 10,566.54 89.47 19.91 6,541.52 3,777.86 3,830.80 7.00 0.02 7.00 90.00 10,716.54 87.90 30.30 6,544.97 3,913.47 3,894.33 7.00 -1.05 6.92 98.70 11,250.00 88.33 352.94 6,563.18 4,426.49 3,999.76 7.00 0.08 -7.00 270.00 5/10/2013 3:24:50PM Page 2 COMPASS 2003.16 Build 69 7 5 ✓ Baker Hughes INTEQ PI'" ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3C-09 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3C-09 @ 82.00ft(3C-09) Site: Kuparuk 3C Pad North Reference: True Well: 3C-09 Survey Calculation Method: Minimum Curvature Wellbore: 3C-09L1-01 Design: 3C-09L1-01_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°1 11 (ft) (ff) (ft) (ft) (°/100ft) (°) (ft) (ft) 8,600.00 81.66 131.91 6,432.58 2,546.97 2,851.76 3,801.69 0.00 0.00 5,997,930.12 531,514.30 TIP/KOP 8,700.00 80.65 116.76 6,448.04 2,491.39 2,933.10 3,814.98 15.00 -95.00 5,997,874.87 531,595.84 8,800.00 80.29 101.55 6,464.69 2,459.12 3,025.97 3,853.30 15.00 -92.66 5,997,842.96 531,688.82 8,900.00 80.59 86.34 6,481.40 2,452.36 3,124.04 3,914.03 15.00 -90.13 5,997,836.57 531,786.91 9,000.00 81.54 71.19 6,497.02 2,471.56 3,220.63 3,993.04 15.00 -87.59 5,997,856.14 531,883.42 9,055.00 82.31 62.89 6,504.76 2,492.79 3,270.73 4,042.37 15.00 -85.22 5,997,877.56 531,933.43 Start 15 dls 9,100.00 85.41 62.34 6,509.58 2,513.37 3,310.45 4,084.27 7.00 -10.00 5,997,898.29 531,973.07 9,166.54 90.00 61.54 6,512.24 2,544.63 3,369.11 4,146.80 7.00 -9.94 5,997,929.78 532,031.60 Start 7 dls 9,200.00 90.00 59.20 6,512.24 2,561.17 3,398.19 4,178.56 7.00 -90.00 5,997,946.43 532,060.61 9,300.00 90.00 52.20 6,512.24 2,617.49 3,480.75 4,275.70 7.00 -90.00 5,998,003.06 532,142.94 9,366.54 90.00 47.54 6,512.24 2,660.37 3,531.61 4,341.62 7.00 -90.00 5,998,046.13 532,193.64 4 9,400.00 89.80 45.21 6,512.30 2,683.45 3,555.82 4,374.98 7.00 -95.00 5,998,069.30 532,217.76 9,500.00 89.19 38.23 6,513.18 2,758.04 3,622.33 4,474.91 7.00 -95.00 5,998,144.13 532,283.97 9,600.00 88.59 31.26 6,515.12 2,840.15 3,679.28 4,574.00 7.00 -94.93 5,998,226.45 532,340.60 9,700.00 88.02 24.28 6,518.08 2,928.54 3,725.82 4,670.79 7.00 -94.80 5,998,315.01 532,386.80 9,800.00 87.48 17.29 6,522.01 3,021.90 3,761.26 4,763.82 7.00 -94.59 5,998,408.49 532,421.87 9,900.00 86.97 10.30 6,526.86 3,118.84 3,785.06 4,851.71 7.00 -94.32 5,998,505.51 532,445.31 9,966.54 86.66 5.65 6,530.56 3,184.62 3,794.28 4,906.70 7.00 -93.98 5,998,571.32 532,454.27 5 10,000.00 87.11 3.35 6,532.38 3,217.92 3,796.90 4,933.16 7.00 -79.00 5,998,604.63 532,456.76 10,100.00 88.47 356.48 6,536.24 3,317.78 3,796.74 5,007.15 7.00 -78.87 5,998,704.48 532,456.22 10,166.54 89.40 351.91 6,537.48 3,383.95 3,790.01 5,051.74 7.00 -78.61 5,998,770.62 532,449.24 6 10,200.00 89.40 354.25 6,537.83 3,417.16 3,785.98 5,073.68 7.00 90.00 5,998,803.81 532,445.08 10,300.00 89.41 1.25 6,538.87 3,517.02 3,782.07 5,145.14 7.00 89.98 5,998,903.64 532,440.78 10,400.00 89.42 8.25 6,539.90 3,616.61 3,790.35 5,224.58 7.00 89.90 5,999,003.25 532,448.68 10,500.00 89.45 15.25 6,540.89 3,714.44 3,810.70 5,310.82 7.00 89.83 5,999,101.16 532,468.66 10,566.54 89.47 19.91 6,541.52 3,777.86 3,830.80 5,371.35 7.00 89.76 5,999,164.64 532,488.51 7 10,600.00 89.11 22.23 6,541.93 3,809.07 3,842.82 5,402.57 7.00 98.70 5,999,195.90 532,500.41 10,700.00 88.07 29.15 6,544.39 3,899.11 3,886.13 5,498.41 7.00 98.67 5,999,286.09 532,543.37 10,716.54 87.90 30.30 6,544.97 3,913.47 3,894.33 5,514.56 7.00 98.50 5,999,300.48 532,551.51 8 10,800.00 87.91 24.45 6,548.03 3,987.49 3,932.66 5,595.18 7.00 -90.00 5,999,374.65 532,589.55 10,900.00 87.95 17.45 6,551.65 4,080.77 3,968.36 5,688.33 7.00 -89.79 5,999,468.04 532,624.90 11,000.00 88.02 10.44 6,555.16 4,177.70 3,992.43 5,776.38 7.00 -89.53 5,999,565.06 532,648.59 11,100.00 88.12 3.44 6,558.53 4,276.85 4,004.50 5,858.04 7.00 -89.29 5,999,664.24 532,660.28 11,200.00 88.25 356.44 6,561.69 4,376.73 4,004.39 5,932.08 7.00 -89.05 5,999,764.12 532,659.79 11,250.00 88.33 352.94 6,563.18 4,426.49 3,999.76 5,965.90 7.00 -88.83 5,999,813.86 532,654.97 Planned TD at 11250.00 5/10/2013 3:24:50PM Page 3 COMPASS 2003.16 Build 69 Nor'' Baker Hughes INTEQ Mk ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3C-09 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3C-09 @ 82.00ft(3C-09) Site: Kuparuk 3C Pad North Reference: True Well: 3C-09 Survey Calculation Method: Minimum Curvature Wellbore: 3C-09L1-01 Design: 3C-09L1-01_wp02 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3C-09L1-01_T5 0.00 0.00 6,542.00 3,808.32 3,842.96 5,999,195.15 532,500.56 70°24'31.832 N 149°44'7.362 W -plan hits target center -Point 3C-09L1-01_T3 0.00 0.00 6,514.00 2,797.97 3,652.05 5,998,184.17 532,313.54 70°24'21.896 N 149°44'12.972 W -plan hits target center -Point 3C-09L1-01_T1 0.00 0.00 6,505.00 2,492.41 3,270.84 5,997,877.18 531,933.54 70°24'18.893 N 149°44'24.147 W -plan hits target center -Point 3C-09L1-01 CTD Polygc 0.00 0.00 0.00 2,628.55 2,978.33 5,998,012.19 531,640.54 70°24'20.233 N 149°44'32.717 W -plan misses target center by 6434.35ft at 8600.00ft MD(6432.58 TVD,2546.97 N,2851.76 E) -Polygon Point 1 0.00 2,628.55 2,978.33 5,998,012.19 531,640.54 Point 2 0.00 2,859.96 3,405.25 5,998,245.21 532,066.52 Point 3 0.00 3,635.34 3,591.21 5,999,021.22 532,249.49 Point4 0.00 4,755.37 3,877.47 6,000,142.23 532,531.42 Point 5 0.00 4,646.65 4,329.11 6,000,035.25 532,983.43 Point 6 0.00 2,708.88 3,949.74 5,998,096.23 532,611.54 Point 7 0.00 2,313.36 3,549.20 5,997,699.22 532,212.56 Point 8 0.00 2,154.26 3,040.54 5,997,538.19 531,704.56 Point 9 0.00 2,345.21 2,797.24 5,997,728.18 531,460.55 Point 10 0.00 2,628.55 2,978.33 5,998,012.19 531,640.54 3C-09L1-01_T2 0.00 0.00 6,512.00 2,544.04 3,369.05 5,997,929.18 532,031.54 70°24'19.400 N 149°44'21.269 W -plan hits target center -Point 3C-09L1 CTD Polygon 0.00 0.00 0.00 2,857.36 2,255.13 5,998,238.20 530,916.54 70°24'22.485 N 149°44'53.908 W -plan misses target center by 6467.65ft at 8600.00ft MD(6432.58 TVD,2546.97 N,2851.76 E) -Polygon Point 1 0.00 2,857.36 2,255.13 5,998,238.20 530,916.54 Point2 0.00 2,956.59 2,460.53 5,998,338.20 531,121.54 Point3 0.00 2,828.18 2,831.08 5,998,211.23 531,492.54 Point 4 0.00 2,498.77 3,192.87 5,997,883.24 531,855.55 Point 5 0.00 1,846.85 3,419.43 5,997,232.26 532,084.59 Point6 0.00 836.44 3,234.59 5,996,221.25 531,903.65 Point7 0.00 368.79 2,864.78 5,995,752.23 531,535.67 Point 8 0.00 753.14 2,519.19 5,996,135.21 531,188.64 Point 9 0.00 1,107.05 2,816.57 5,996,490.23 531,484.63 Point 10 0.00 2,093.69 2,939.31 5,997,477.23 531,603.58 Point 11 0.00 2,596.48 2,479.17 5,997,978.20 531,141.56 Point 12 0.00 2,557.02 2,336.00 5,997,938.20 530,998.55 Point 13 0.00 2,857.36 2,255.13 5,998,238.20 530,916.54 3C-09L1-01_T4 0.00 0.00 6,536.00 3,317.46 3,797.07 5,998,704.16 532,456.55 70°24'27.004 N 149°44'8.715 W -plan hits target center -Point 3C-09L1-01_T6 0.00 0.00 6,563.00 4,425.77 4,000.36 5,999,813.14 532,655.56 70°24'37.903 N 149°44'2.740 W -plan hits target center -Point 5/10/2013 3:24:50PM Page 4 g COMPASS 2003.16 Build 69 i' ,�y► b 1. / / A H I. Baker Hughes INTEQ In" ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3C-09 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3C-09 @ 82.00ft(3C-09) Site: Kuparuk 3C Pad North Reference: True Well: 3C-09 Survey Calculation Method: Minimum Curvature Wellbore: 3C-09L1-01 Design: 3C-09L1-01_wp02 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name ("1 (") 3,943.00 3,667.40 9 5/8" 9-5/8 12-1/4 11,250.00 6,563.18 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 8,600.00 6,432.58 2,546.97 2,851.76 TIP/KOP 9,055.00 6,504.76 2,492.79 3,270.73 Start 15 dls 9,166.54 6,512.24 2,544.63 3,369.11 Start 7 dls 9,366.54 6,512.24 2,660.37 3,531.61 4 9,966.54 6,530.56 3,184.62 3,794.28 5 10,166.54 6,537.48 3,383.95 3,790.01 6 10,566.54 6,541.52 3,777.86 3,830.80 7 10,716.54 6,544.97 3,913.47 3,894.33 8 11,250.00 6,563.18 4,426.49 3,999.76 Planned TD at 11250.00 5/10/2013 3:24:50PM Page 5 COMPASS 2003.16 Build 69 o H NU b 0111 8 I uQ r,0 8 C F y g i o ,e M r -74-1- g fi N r Q X Y o ,, 1 , r VVV3 I I , I I g .51 r Q 8 r / $ O i 8 N o 8 + V1;21 y ,Q• yy,JS=2S I I FlrI i �_, W FI __ mun LI .:.I Ia S col u m _ n 0./nir ..! t'..- o & g f g el 74 eu • 00 g J e " ^m r ▪ i':6 ov O ff oN M -EP' (mj 00Z)(+)quoN/-)LRnoSo Q M M a O e U ti OVI o g. ptA a8'8z a�a y 8 g \V s g a m 12 �I v 4 '0 n ,, K 9 3m a- - �a #cs al.fi -- a S ma �n vi .o ____ zM c� J� I- N..c,NN� 2 2 q q ' i20) 8000000 Y Y 66S2'V. 3,=!. .1.=o m^, 0 0 0 8 2 *6 2,-1 oi^ i°f2=� o 37, n e [�V t�+ Mi i� ' ////: 0 J ^ p y OVa. liQ 10 1.31 m^ m M<`Oni,aq R� C ®,�G,�I LLw �j t�yy n 8 Wo DN VNN� ��m $ m N - — �c e M M U n = °"''-'886.442M t / ! en 8 0• • o lanai eeS ueeW O a 3 u/3SL)mdaQeotuan an1I ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 3C Pad 3C-09 3C-09L1-01 3C-09L1-01_wp02 Travelling Cylinder Report 10 May, 2013 r1 BAKER HUGHES ConocoPhillips or its affiliates III&' ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3C-09 Project: Kuparuk River Unit ND Reference: 3C-09 @ 82.00ft(3C-09) Reference Site: Kuparuk 3C Pad MD Reference: 3C-09 @ 82.00ft(3C-09) Site Error: 0.00ft North Reference: True Reference Well: 3C-09 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3C-09L1-01 Database: EDM Alaska Prod v16 Reference Design: 3C-09L1-01_wp02 Offset TVD Reference: Offset Datum Reference 3C-09L1-01_wp02 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 8,600.00 to 11,250.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,321.54ft Error Surface: Elliptical Conic Survey Tool Program Date 5/10/2013 From To (ft) (ft) Survey(Wellbore) Tool Name Description 7,855.00 8,600.00 3C-09L1_wp04(3C-09L1) MWD MWD-Standard 8,600.00 11,250.00 3C-09L1-01_wp02(3C-09L1-01) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 3,943.00 3,749.40 95/8" 9-5/8 12-1/4 11,250.00 6,645.18 2 3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 3C Pad 3C-08-3C-08-3C-08 11,250.55 8,450.00 936.84 269.32 748.81 Pass-Major Risk 3C-09-3C-09L1-3C-09L1_wp04 8,600.00 8,600.00 0.00 0.31 -0.22 FAIL-Major Risk 3C-10-3C-10-3C-10 9,533.05 8,150.00 1,065.91 281.26 793.96 Pass-Major Risk 3C-11-3C-11 -3C-11 Out of range 3C-11 -3C-11A-3C-11A Out of range 3C-11-3C-11AL1 -3C-11AL1 Out of range 3C-12-3C-12-3C-12 Out of range 3C-14-3C-14-3C-14 Out of range 3C-14-3C-14A-3C-14A Out of range 3C-14-3C-14B-3C-14B Out of range 3C-14-3C-14BPB1- 3C-14BPB1 Out of range 3C-15-3C-15-3C-15 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 5/10/2013 2:18:27PM Page 2 of 8 COMPASS 2003.16 Build 69 Bettis, Patricia K (DOA) ? 1J 21307 From: Ohlinger, James J [James.J.Ohlinger@conocophillips.com] Sent: Thursday, May 30, 2013 10:56 AM To: Bettis, Patricia K (DOA) Subject: RE: Permit to Drill Application: KRU 3C-09L1 and 3C-09L1-01 Less than 30 days. From: Bettis, Patricia K (DOA) [ma ilto:patricia.bettis@alaska.gov] Sent: Thursday, May 30, 2013 10:54 AM To: Ohlinger, James 3 Subject: [EXTERNAL]Permit to Drill Application: KRU 3C-09L1 and 3C-09L1-01 Good morning James, I started reviewing the applications for 3C-09L1 and 3C-09L1-01. For these proposed wells, what is the anticipated period for pre-production prior to injection? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME: RU. 3 c.- o4 -Ol PTD: 0213077 Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: R;v1.41- POOL: X 1,,f c„/( Z'jE,t-1 1470c,A.J( Zi AJ o, Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. / 8S/00 , API No. 50- 0Q( -a/ 3SS' - 00 - of.). (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no an ' sample from below the afrost or from ls Dry Ditch Sample wherersampl s0are first caughtaand 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well Well Logging logs are also required for this well: Requirements Revised 5/2013 ! To it a u 0 c -`o co 2 @ U N > a) a. o a. 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