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Home My WebLink About185-100MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, September 15, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3C-09 KUPARUK RIV UNIT 3C-09 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/15/2025 3C-09 50-029-21355-00-00 185-100-0 W SPT 6316 1851000 1579 2900 2900 2900 2900 50 130 130 130 4YRTST P Austin McLeod 8/2/2025 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3C-09 Inspection Date: Tubing OA Packer Depth 470 2010 1960 1955IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250803180830 BBL Pumped:1.4 BBL Returned:1.3 Monday, September 15, 2025 Page 1 of 1 9 9 9 9 9 9 9 99 999 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.09.15 12:05:10 -08'00' MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Brian Bixby Petroleum Inspector Well Name KUPARUK RIV UNIT 3C-09 Insp Num: mitBDB210821164556 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 25, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3C-09 KUPARUK RIV UNIT 3C-09 Sre: Inspector Reviewed By: P.I. Supry Comm API Well Number 50-029-21355-00-00 Inspector Name: Brian Bixby Permit Number: 185-100-0 Inspection Date: 8/21/2021 - Packer Depth Well 3C-09 Type Inj W TVD 6316 I Tubing PTD - 1851000 ' !Type Test, SPT' Test psi 1579 IA BBL Pumped: _ 1 1.3 BBL Returned: 1.3 OA Intervala 's P/F P Notes: Pretest Initial 15 Min 30 Min 45 Min 60 Min 2710 2710 - 2710 2710- 710410 4102000 1960 1955 20 40 50 50 — — — Wednesday, August 25, 2021 Page 1 of 1 • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: J Regg 7 q DATE: Thursday,August 10,2017 P.I.Supervisor ,V,�jc/ V(Z4(1 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 3C-09 FROM: Chuck Scheve KUPARUK RIV UNIT 3C-09 Petroleum Inspector Src: Inspector Reviewed B-y:} P.I.Supry eJL3(2— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3C-09 API Well Number 50-029-21355-00-00 Inspector Name: Chuck Scheve Permit Number: 185-100-0 Inspection Date: 8/3/2017 - Insp Num: mitCS170806084223 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3C-09 ' Type Inj W TVD 6316 Tubing 2910 2910 2910 2910 PTD 1851000 -Type Test SPT Test psi 1579 IA 400 2000 - 1950 1950 - BBL Pumped: 1.8 - BBL Returned: 1.8 - OA 200 350 . 350 - 350 - - ------ --- Interval 4YRTST P/F P ✓ Notes: Thursday,August 10,2017 Page 1 of 1 PTD /B5'=/6v ConocoPhiIIips Time Log & Summary Wellview 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 ea , i D�tilfE Rig Release: 3/30/2014 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 33/13/2014 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 03/15/2014 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 1 of 12 Time Logs Date From To Dur S. Depth E. Death 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 2 of 12 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 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 RPEQP1ELNE 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 mit,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 03/19/2014 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 C_L Date From To Dur S. Depth 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 1000Ibs 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. Ne w PTD. """"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. """"Office!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. 1.41bpm 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 03/22/2014 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. Depth E. Depth 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 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 33/23/2014 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 8.235'. 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 33/24/2014 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 03/25/2014 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 L/D 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 Ll 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 03/29/2014 Run Ll 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. Death 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 Imag~roject Well History File' Cover ~age 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. L _~ ~'"- _/ O ~) Well History File Identifier RESCAN DIGITAL DATA n Color items: r~ Diskettes, No, [] Grayscale items: ' [] Other, No/Type [] Poor Quality Originals: .~ [] Other: NOTES: BY: BREN VINCENT SHERYL MARIA LOWELl. OVERSIZED (Scannable) Ma ps: [3 Other items scanna Lie by large scanner OVERSIZED (Non-Scanna Lie) ~'~ Logs of various,kinds [] Other D,,TE:// 'S' Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl_ DATE: /SI Scanning Preparation ~ x 30 : '~:? ~ + /~) : TOTAL PAGES BY: (BREN VINCENT SHERYL MARIA LOWELL Production Scanning Stage I PAGE COUNT FROM SCANNED F~LE: ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: /~. YES NO BY: ~BREN VINCENT SHERYL MARIA LOWELL Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY~ BEVERLY BREN VINCEN~ARIA LOWELL DATE://~~o,'S' ReScanned (individual page [special attention] scanning completed) RESCANNEDBY; BEVERLY E~REN VINCENT SHERYL MARIA LOWELL DATE: /S/ General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3NOTScartned.wpd • „OF ? • • .,„\ i//7„-.. THE STATE Alaska Oil and Gas N��'r►�t- °f s v ti issi _ ALASI�:A GOVERNOR SEAN PARNELL 333 West Seventh Avenue � Anchorage, Alaska 99501-3572 ALASY' Main: 907.279.1433 Fax: 907.276.7542 Brett Packer c'NNED i'10!' . 3 2013 Wells Engineer li " �/�� ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3C-09 Sundry Number: 313-530 Dear Mr. Parker: 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, Cathy P oerster Chair, Commissioner DATED this /7 day of October, 2013. Encl. • STATE OF ALASKA Q� ALCA OIL AND GAS CONSERVATION COMN�ION V �`�� /, APPLICATION FOR SUNDRY APPROVALS ID 20 AAC 25.280 1.Type of Request: Abandon fl Rug for Redrill r Perforate New Fool r Repair w ell 17 i Change Approved Program IT Suspend f' Rug Perforations r Perforate N'°' Pull Tubing p' , Time Extension Operational Shutdown fl Re-enter Susp.Well I Stimulate gW""" After casing r Other: F 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development IT 185-100 3.Address: 6.API Number: Stratigraphic r Service ri. P.O. Box 100360,Anchorage,Alaska 99510 50-029-21355-00 ■ 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? gam ¢ Will planned perforations require spacing exception? Yes No F 3C-09 ■ i p r - ,I D 9.Property Designation(Lease Number): 10.Field/Pool(s): 0]"' i& ///% ADL 25634,25629 Kuparuk River Field/Kuparuk River Oil Pool . OCT 0 9.2 n 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measure AOGC 8315 . 6785 . none '920' x✓ 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 7659 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER FHL RETRIEVABLE PACKER MD=7666 TVD=6317 • PACKER-BAKER F-1 PERMANENT PRODUCTION PACKER MD=7804 TVD=6413 • SSSV-CAMCO TRMAXX-CMT-SR-5 SCSSV MD=1822 TVD=1822 . 12.Attachments: Description Summary of Proposal ..17: 13. Well Class after proposed work: Detailed Operations Program N"' BOP Sketch r Exploratory r Stratigraphic I Development r Service Ri, 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/2/2013 Oil r Gas r WDSPL r- Suspended 16.Verbal Approval: Date: WINJ r% GINJ IT WAG r Abandoned r Commission Representative: GSTOR r SPLUG f 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer©265-6845 Email: J.Brett.Packeraconocophillips.com Printed Name Brett Paacckker^ Title: Wells Engineer Signature --w� Phone:265-6845 Date /047//3 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness .3 . 5.30 Plug Integrity fT BOP Test 17 Mechanical Integrity Test fT Location Clearance I Other: g r lJ �r5 f f U 570 0 19 5 / Spacing Exception Required? Yes LI No Subsequent Form Required: /o...... .4_U 4 APPROVED BY Approved by:a7/(24(A44 COMMISSIONER THE COMMISSION Date:1 —/y-1 pproved application Is valid tor 12 months trom the date of approval. Form 10-403(Revised 10/2012) Submit Form and Attachments in Duplicate t.tLr- 1 / ORIGINAL io/9/)3 1 , RBI OCT 16 l� • • �✓ RECEIVED conocoPhulhps OCT 0 9 2013 Alaska P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 October 8,2013 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 Sundry Approval to workover Kuparuk Injector 3C-09(PTD# 185-100). 3C-09 was originally drilled & completed as a 2 '/8" selective single A&C sand pre-produced injector in 1985. It was on production for a couple years initially before it was converted to an injector. 3C-09 along with its paired producer(3C-10)have both been chosen as CTD candidates to be drilled into adjacent fault blocks that were identified as lacking adequate offtake points and injection support. This well was SI in August 2012 in an effort to reduce the reservoir pressure in this area prior to CT drilling. A workover was successfully performed in April of this year to prep the well for the upcoming CT drilling. CT drilling commenced in June, and during the CT drilling, their 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 completion has the B-sand & tubing tail cemented off, the C-sand isolated behind the selective, and the A-sand open below. The well has 2" coil inside the tubing from 920' MD out into the lateral at 10,745' MD. The proposed workover plans are to pull the 3 %2'tubing,recover the coil& stuck BHA, and re-run the tubing. Ultimately, if we are unable to pull the stuck BHA, the backup plan is to just cut the coil outside the window. Either outcome will allow CTD to set another whipstock above the current whipstock and make another attempt to sidetrack this well. If you have any questions or require any further information,please contact me at 265-6845. Sincerely, Brett Packer Wells Engineer CPAI Drilling and Wells KUP . 3C-09 ConocoPhillips 0160 Well Attributes Malt Angle&Mp, TO I11t, Wellbore API/UWI Field Name Wellbore Status Inc((°) MD(ftKB) Act Btm(ftKB) 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 ••• Well Confq:-3C.09,8/7/201311x13'13 AM SSSV:TRDP Last WO: 5/10/2013 34.59 7/12/1985 _ Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:CTMD 8,205.0 6/6/2013 Rev Reason:ADD PLUGBACK LATERALS osborl 8/1/2013 HANGER,26 " °- Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)... String Wt...String... String Top Thrd I 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(f...Set Depth(TVD)...String Wt...String...String Top Thrd 4 SURFACE g 9 5/8 8.921 34.7 3,943.0 3,748.3 36.00 J-55 BTC Casin Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd ' WINDOW 71/2 6.000 7,835.0 7,845.0 6,441.6 26.00 J-55 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 CONDUCTOR, Tubing Strings 35118 Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd TUBING WO 31/2 2.992 26.3 7,658.5 6,311.2 9.30 LOU EUE8rd iCompletion Details SAFETY VLV, 'Top Depth I 1,822 (ND) Top Inc! Nom(... 1.t;. Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 26.3 26.3. -0.15 HANGER CAMERON TUBING HANGER 2.860 I .. 1,822.3 1,822.3 0.55 SAFETY VLV CAMCO TRMAXX-CMT-SR-5 SCSSV w/2.813"X-Profile(`1822) 2.812 GAS LIFT, 2,521 -II : 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 Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(WD)...String Wt..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 SURFACE, Completion Details 353,943 Top Depth (TVD) Top Inc! Nerd... Top(ftKB) (ftKB) (°) Item Description Comment ID(in) GAS LIFT, 7,643.3 6,300.8 46.38 PBR 20'PBR SEAL ASSEMBLY(pinned to 40k Ibs to shear) 2.990 4,189 7,666.4 6,316.8 45.47 PACKER BAKER FHL RETRIEVABLE PACKER(Min ID=3",60k lbs shear) 2.900 a"`' 7,719.5 6,353.9 46.17 NIPPLE HES'X'NIPPLE 2.812 GAS LIFT, j 7,801.7 6,411.3 45.76 LOCATOR BAKER LOCATOR 2.992 5'784 7,802.5 6,411.9 45.75 SEAL ASSY BAKER GBH-22 BONDED SEAL ASSEMBLY(80-40) 2.980 CDR COIL FISH,920 Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd LOWER PACKER 3 1/2 2.992 7,803.5 7,920.0 6,494.8 9.30 L-80 EUE8rd ASSY GAS LIFT, 6,932 Completion Details Top Depth Il I (TVD) Top Inc! Nomi... 9 Top(ftKB) (ftKB) 11 Item Description Comment ID(in) GAS LIFT. -I 7,803.5 6,412.6 45.74 PACKER BAKER F-1 PERMANENT PRODUCTION PACKER 4.000 7580 7,806.9 6,414.9 45.70 SBR BAKER 80-40 SEAL BORE EXTENSION,5'long 4.000 1 .. 7,919.3 6,494.3 44.64 SOS SOLID SEAL SHEAR OUT SUB(pinned to 3500 psi) 3.000 LOCATOR, 1 Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) 7,636 al W Top Depth 1 ' (WD) Top Ind SEAL ASSY, .161 =j Top(ftKB) (ftKB) (°) Description Comment Run Date ID(in) 7.637 1= R4 920.0 920.0 0.13 CDR COIL L1-01 LATERAL 2"CTD COIL CUT @ 920'MD;E-LINE 6/2/2013 0.000 AB FISH CABLE INSIDE COIL @ 1100'MD.BHA AT END OF COIL - STUCK AT 10745' • P 7,813.0 6,419.1 45.63 TBG TUBING PUNCHES FOR PRE-CTD CEMENTING-CMT 5/29/2013 2.992 I ' PUNCHES PLUG 7813-7940' 1 7,837.0 6,436.0 45.35 WHIPSTOCK WEATHERFORD STARTBURST HOLLOW WHIPSTOCK 6/11/2013 1.250 4 ANCHOR TRAY FOR CTD SIDETRACKS I Perforations&Slots Shot Top(WD) Btm(TVD) Dens INJECTION, Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (oh... Type Comment 7,773\ IPERF, 7,774.0 7,789.0 6,391.8 6,402.3 C-1,3C-09 8/1/1985 12.0 IPERF 51/2'Csg Gun,120 deg.phasing ___.. 7'774-7'709 I7,838.0 7,850.0 6,436.7 6,445.1 UNIT B,3C-09 8/1/1985 12.0 CMT A-SAND PERFS CEMENT SQZ SQUEEZED PRE-CTD 2013-5 12" , 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 PACKER,7,804 -- - 3C-09 'I 11--yr 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 SBR,7.807 a w AI NW Notes:General&Safety TBG End Date Annotation PUNCHES, 1 7/12/2013 NOTE:View Schematic w/Alaska Schematic9.0 7,813 7/12/2013 NOTE:L1-01 lateral drilled,renamed L1-01 PB1 w17950'of 2'Coil/BHA left downhole,them cut @ 920' 7/12/2013 NOTE:L1 lateral drilled/liner set,not accessible,renamed L1PB1;WORKOVER PLANNED WHIPSTOCK 7,837 CMT SOZ, 7,8357,850 WINDOW, - 7,835-7,845 Mandrel Details Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run .. N...Top(ftKB) (ftKB) (°) Make Model (in) Sew Type Type )m) (psi) Run Date Com... 505,7,919 yr 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 soz, 2 4,189.2 3,913.6 47.49 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 5/9/2013 7,813 3 5,793.6 5,010.5 46.11 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 5/9/2013 IPERF. 4 6,932.3 5,813.6 46.85 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 5/9/2013 7849-7,998 - 5 7,580.2 6,257.3 46.44 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 5262013 IPERF' _ 8,o70-e,040 6 7,772.6 6,390.8 45.63 CAMCO MMG 1 12 INJ DMY RK 0.000 0.0 5/9/2013 PRODUCTION, 28-8,299 TD(3C-09). 8,315 • • 3C-09 Proposed Completion Post-RWO 16"65#H-40 shoe @ 116'MD ® TRMAXX-CMT-5-SR @ 1800'ND 9-5/8"36#J-55 shoe @ 3750'MD 13-1/2"GLMs @ TBD 3-1/2"9.3#L-80 EUE-Mod Tbg =j 4 Baker'FHL'Packer @ 7,666'MD 2.813"X Nipple @ 7,720'MD C-sand perfs — * �_- Injection Mandrel @ 7,773'MD 7774'-7789'MD — �-- ta Baker Model F-1 Packer @ 7,804'MD B-sand perfs — 7838'-7850'MD — - �— — WFT Whipstock Anchor Tray _ - 3-1/2"Shear-out Sub(sheared)@ 7,919'MD A-sand perfs ` 7949'-7996'MD 8018'-8040'MD — �"" 7"26.0#J-55 shoe @ 8299'MD • 3C-09 Rig Workover Pull Tubing, Fish Stuck Coil, Re-Run Tubing (PTD #: 185-100) Current Status: This well has been SI since 8/10/12. The well has 2"coil inside the tubing from 920' MD down to the stuck BHA at 10,745'MD. Scope of Work: Pull the 3 '/2"tubing,recover the coil&stuck BHA,re-run the tubing. General Well info: Well Type: Injector MPS P: 1,500 psi using max stabilized SITP on 6/11/13. p g Reservoir Pressure/TVD: 3,904 psi/6,445' TVD(11.6 ppg)from Panex gauges on 5/26/13. 44/75P.17.2 52_ 001 Wellhead type/pressure rating: CIW Gen 4,7-1/16"5M psi top flange U. voted^ BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: MIT-IA passed on 5/9/13,MIT-OA passed on 3/31/13. Earliest Estimated Start Date: November 2,2013 Production Engineer: Suzanne Short/Toon Changklungdee Workover Engineer: Brett Packer(265-6845/j.brett.packer @cop.com) Pre-Rig Work 1. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure 1. MIRU. 2. Pull BPV. Bullhead KWF down tubing. Set BPV. 3. ND tree,NU BOPE,install tree test plug,test BOP's. Pull tree test plug. Pull BPV. 4. Install landing joint&MU top drive to landing joint,pull tubing hanger to rig floor,close upper pipe rams or annular on tubing. 5. Circulate KWF around taking diesel&inhibited seawater returns out the IA to tiger tank. Continue to circulate until KWF is at surface. Shut down pumps,monitor well for NFT. 6. POOH standing back 3 V2"tubing. a. During TOH,hang off storm packer w/tubing below. PT storm packer. b. ND BOP,remove packoffs,stretch 7"casing and re-land in slips. c. Install new FMC packoff and retrofit wellhead to FMC 11"5K. d. NU BOP stack,test tubing head break and shell test BOP stack. e. Pull storm packer&continue POOH w/tubing. 7. MU coiled tubing cutter&washpipe,RIH swallowing the coiled tubing,cut the coiled tubing—10 ft above the PBR. 8. POOH w/washpipe until coiled tubing appears at the rig floor,MU tubing hanger to washpipe and re-land tubing hanger leaving coil sticking out above the rig floor. 9. RU handling equipment for 2"coil. Begin POOH w/coiled tubing cutting every 10'—15'. 10. RU Slickline: RIH w/wire grab and fish e-line cable from inside the washpipe. RD Slickline. 11. POOH laying down washpipe. • 3C-09 Ri g Workover •Pull Tubing, Fish Stuck Coil, Re-Run Tubing (PTD #: 185-100) —Procedure Continued 12. MU cut-lip guide&overshot w/grapple for 2"coil,Baker Rattler assembly,bumper jars,oil jars,drill collars. RIH on drillpipe to top of coiled tubing. Record up/down weights. Slide over top of coiled tubing and engage grapple. Attempt to jar&vibrate coil tubing&BHA free. a. If unable to pull coil tubing,release overshot&POOH standing back drillpipe. b. RBIH w/just overshot&grapple(no Rattler or jars),latch onto coiled tubing and pull in tension,set the drillpipe in the slips. c. RU E-line: RIH w/coil cutter,drift down through coil as far as possible outside the window,cut the coil. POOH&RD E-line. 13. POOH standing back drillpipe. Lay down collars and BHA. 14. RU handling equipment for 2"coil. Repeat same process as earlier cutting coil every 10'–15' feet until coil is out of well. 15. RIH w/3 'h"tubing completion and sting into PBR, space out 7 ft,mark the pipe and pull out of PBR. 16. Space out w/pups,MU hanger. Circulate well full of corrosion inhibited brine. Land the hanger,RILDS. 17. PT the IA,ramp up pressure to shear the SOV. 18. Install BPV,ND BOPE,NU tree. Pull BPV,install tree test plug&test tree. Pull tree test plug. 19. Freeze protect through the SOV,set BPV. 20. RDMO. Post-Rig Work 1. Reset well house(s)and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: Set plug in`X'nipple below FHL packer,set catcher sub on top of plug. Pull SOV,run DV. PT tubing to 3,000 psi,pull catcher sub,pull plug. 4. Turn well over to operations/CTD. ij 'i s i d STATE OF ALASKA AL.A OIL AND GAS CONSERVATION COASION n 1.` ! -= REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon E Repair w ell j°" Rug Perforations j""` Perforate i Other Alter Casing r Pull Tubing lW • Stimulate - Frac r Waiver i Time Extension l""` Change Approved Program EOperat. Shutdow n im Stimulate - Other r Re -enter Suspended Well f 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. ' Development ( Exploratory f 185 -100 • 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service l 50 029 - 21355 - 00 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25629, 25634 3C - 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 8315 . feet Plugs (measured) none true vertical 6785 feet Junk (measured) none Effective Depth measured 8217 feet Packer (measured) 7666, 7804 true vertical 6711 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 SCANNED JUL 0 8 2013 Perforation depth: Measured depth: 7774 -7789, 7838 -7850, 7949 -7996, 8018 -8040 True Vertical Depth: 6392 -6402, 6437 -6445, 6515 -6549, 6565 -6581 Tubing (size, grade, MD, and TVD) 3.5, L - 80, 7920 MD, 6495 TVD 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' TVD 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 - Subsequent to operation shut -in 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory i" Development f Service f - Stratigraphic r 16. Well Status after work: Oil I Gas E WDSPL F " Daily Report of Well Operations XXX GSTOR I — WIND r WAG j;i . GINJ r SUSP J"" 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: 313 -169 Contact Brett Packer @ 265 -6845 Email J.Brett.Packer@conocoohillips.com Printed Name Brett Packer Title Staff Wells Engineer Signature i /�T � 7e Phone: 265 -6845 Date e 7/O / 3 Lr /o/M/5 RBDMS JUN 11 2O Form 10 -404 Revised 10/2012 Submit Original Only a ar■a or le sr _�ieb, . • KUP • 3C -09 ConocoPhilhps 111 Well Attributes Max Angle & MD TD Alaska. Inc. Wellbore APW WI Field Name Well Status Intl (°) MD (ftKB) Act Btm (kKB) 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 Well coma: - 3c -09, 613/201365212 AM SSSV: TRDP I Last WO: 5/10/2013 34.59 7/12/1985 schematic -Anual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: TOC 7,812.0 6/1/2013 Rev Reason: TOC 7812 RKB osborl 6/3/2013 HANGER,26 Casing Strings Casing Description String 0... String ID ... Top (kKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String _. String Top Thrd CONDUCTOR 16 15.062 36.0 116.0 116.0 65.00 H - 40 WELDED Cng Description String 0... Siring ID ... Top (kKB) Set Depth (f... Set Depth (ND) ... g 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 (kKB) Set Depth (f... Set Depth (TVD) ... Strin String Wt... String ... String Top Thrd v . PRODUCTION 7 6.276 28.0 8,298.8 6,772.8 26.00 J -55 BTC Ell Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING WO 1 3 1/2 2.992 26.3 7,658.5 6,311.3 9.30 L -80 I EUE8rd CONDUCTOR, Completion Details 36 -118 Top Depth (TVD) Top Intl Noml.,, SAFETY VLV, " Top (kKB) (kKB) ( °) Item Description Comment ID (in) 1,822 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 7,636.1 6,295.9 46.37 LOCATOR BAKER SEAL LOCATOR 2.992 IIIIII GAS LIFT, ] 7,637.11 6,296.5 46.37 SEAL ASSY BAKER 80-40 PBR SEAL ASSEMBLY 2.980 2,521 Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd IN UPPER PACKER 3 1/2 2.992 7,643.3 7,808.8 6,416.2 9.30 L -80 EUE ASSY Completion Details Top Depth (ND) Top Intl Noml... SURFACE, Top(ftKB) (ftKB) (°) Item Description Comment ID (in) 35 -3,943 7,643.3 6,300.8 46.38 PBR 20' PBR SEAL ASSEMBLY (pinned to 40k Ibs to shear) 2.990 7,666.4 6,316.8 45.49 PACKER BAKER FHL RETRIEVABLE PACKER (Min ID =3 ", 60k Ibs shear) 2.900 GAS4 9 7,719.5 6,353.9 46.03 NIPPLE HES'X' NIPPLE 2.812 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 GAS LIFT, , .. Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... 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 IIIII ASSY all Completion Details Top Depth GAS LIFT. (TVD) Top Inc! Nomi... 6,932 Top (ftKB) (ftKB) r Item Description Comment ID (!n) ,.al 7,803.5 6,412.5 45.48 PACKER BAKER F -1 PERMANENT PRODUCTION PACKER 4.000 7,806.9 6,414.8 45.48 SBR BAKER 80-40 SEAL BORE EXTENSION, 5' long 4.000 UM 7,919.3 6,494.3 44.56 SOS SOLID SEAL SHEAR OUT SUB (pinned to 3500 psi) 3.000 GAS LIFT,1._. 7.580 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) r Top Depth (TVD) Top Intl 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 5/29/2013 2.992 Nur 7,636 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 illi Perforations & Slots Shot "1 ‘°1 Top (ND) Btm (TVD) Dens - Top (ftKB) Btm (RKB) (RKB) (RKB) Zone Date (sh•.. 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 CMT A -SAND PERFS CEMENT ME SQZ SQUEEZED PRE -CTD 2013 - 5 1/2" Csg Gun, 120 deg. phasing NM 7,949.0 7,996.0 6,515.4 6,549.0 A-5-09 , A-4, A -3, 8/1/1985 4.0 IPERF 4" HJ II, 90 deg. phasing IIIII 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, 7,7747,788 - End Date Annotation 22 7/15/2010 NOTE: View Schematic w / Alaska Schematic9.0 or Mt- PACKER, 7,804 _ I SBR, 7,807 TB0 PUNCHES, 7,813 CMT 502, 7,838 -7,850 Mandrel Details Top Depth Top Port (ND) Inc' OD Valve Latch Size TRO Run N ... Top (RKB) (RKB) (°) Make Model (in) Sets Type Type ON (psi) Run Date Com... SOS, 7,919 1 2,520.6 2,520.2 5.48 CAMCO MMG 1 1/2 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 1/2 GAS LIFT DMY RK 0.000 0.0 5/9/2013 7,813 ; :', 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 SAND PLUG, 7,5477 t 3h z = €: 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 IPERF, 5 7,580.2 6,257.3 46.44 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/26/2013 IPERF, 6 7,772.6 6,390.8 45.63 CAMCO MMG 1 1/2 INJ DMY RK 0.000 0.0 5/9/2013 8,018 -8,040 PRODUCTION, 28.8,299 TD,8,315 ♦ 3C -09 Pre -Rig Well Work Summa DATE SUMMARY • 2/28/2013 TAGGED @ 8013' SLM. DRIFTED TBG TO 2.29" TO D NIPPLE @ 7905' RKB. IN PROGRESS. 3/1/2013 SET 2.25" CA -2 PLUG WITH GAUGES IN D NIPPLE @ 7905' RKB. RETURN IN 3 DAYS FOR C SAND BHP. 3/4/2013 WEATHER DELAYED START. MEASURED BHP @ 7734' RKB: 3836 PSI. IN PROGRESS. 3/7/2013 PULL CA -2 PLUG WITH PANEX GAUGES @ 7906' RKB. COMPLETE. 3/31/2013 (PRE -RWO): RIG WORK - MITIA (PASSED) @ 2510 PSI, MITOA (PASSED) @ 1800 PSI, T POT (PASSED), T PPPOT (PASSED), IC POT (PASSED), IC PPPOT (PASSED), FUNCTION TEST LDS (ALL FUNCTIONED PROPERLY). 4/7/2013 LOCKED OUT TRDP -IA -SSA @ 1796' RKB; PULLED DV @ 7567' RKB. READY FOR E -LINE. 4/10/2013 SUCCESSFULLY SHOT STRING SHOT FROM 7751' TO 7755' TO CLEAR SCALE FOR TUBING CUT. RAN IN HOLE WITH RCT TO CUT TUBING @ 7755'. SUCCESSFULLY FIRED RCT @ 7756'. CCL TO CUTTER LENGTH: 9.5', CCL STOP DEPTH: 7746.5', RAN VERIFICATION PASS TO CONFIRM TOOL HAD FIRED. 4/11/2013 RIH WITH STRING SHOT, TAGGED @ 7660', CAME UP AND FIRED STRING SHOT FROM 7587' TO 7591', CCL STOP DEPTH 7584.5', CCL TO TOP OF STRING SHOT: 2.5', RIH W/ RCT CUTTER TOOL, PUSHED SOMETHING DOWNHOLE FROM 6800 FEET TO BELOW CUTTING DEPTH, CUT TUBING @ 7591', CCL TO CUTTER DEPTH: 9.5', CCL STOP DEPTH @ 7581.5', TOOL FIRED SUCCESSFULLY • • Conoc ©Phillips Time Log & Summary W'e!Mew web Reporting Report Well Name: 3C - 09 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 4/27/2013 12:00:00 PM Rig Release: 5/10/2013 6 :00:00 AM Time :Logs_ Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/26/2013 24 hr Summary 4 rig mods moved to 2M pad. Sub, pipe shed, RW moved to 3C location. Spot sub over well. Con't moving components. 12:00 00:00 12.00 0 0 MIRU MOVE TRNS P Move Substructure, pipe shed and rock washer from Cassin #6 to 3C -09. Spot new tree in cellar area, arrange for scaffolders first thing in AM. 04/27/2013 MIRU and accept rig @ 12:00. R/U and kill well w/ 11.8 ppg brine, bullhead 25 bbl to formation and observe 30 min, well is dead. 00:00 01:30 1.50 0 0 MIRU MOVE TRNS P Spot sub over well, lay mats for power pack. (Took pictures of tree orientation within cellar) 01:30 04:00 2.50 0 0 MIRU MOVE TRNS P Mobilize power pack f /2M pad t/3C pad. 04:00 08:00 4.00 0 0 MIRU MOVE TRNS P Spot power pack, rock washer and pipe sheds. 08:00 09:30 1.50 0 0 MIRU MOVE TRNS P Hook up electrical, steam, water, glycol fuel and air lines. SIMOPS- berm up rock washer and envirovac unit. 09:30 12:00 2.50 0 0 MIRU MOVE RURD P Continue working on rig acceptance checklist. Rig accepted at 12:00 hrs. 12:00 14:00 2.00 0 0 MIRU WHDBO RURD P PJSM and set up scaffolding in cellar, take on H2O to rig tanks, prep callar for well kill operations. 14:00 17:00 3.00 0 0 MIRU WHDBO RURD P R/U double IA valves and pump in flange on tree. Take on 11.8 ppg NaCI /NaBr brine to rig pits. R/U hard line to choke skid /flowback tank, test gas alarms. Stage cellar tank in cellar, prime mud pumps. 17:00 20:00 3.00 0 7,591 MIRU WHDBO KLWL P PJSM- R/U U pull BPV. R/U and test lubricator U 1000 psi. pull BPV, R/D lubricator. Tubing =1400 psi, IA =100 psi, OA =160 psi. 20:00 00:00 4.00 7,591 7,591 MIRU WELCTL KLWL P PJSM on well kill ops, (Filled out kill sheet with crew and held real time kill drill - similated kick). Blow air through lines, fill lines with H2O and test U 2500 psi. Kill well @ 2bpm w/ 11.8 ppg NaCI /NaBr brine with pump down schedule. ICP =1900 psi, FCP 490 psi. Pumped until good 11.8 ppg brine at tank, 3200 stks (336 bbl). No recordable losses during kill ops. 04/28/2013 Bullhead 25 bbl, N/D tree, N/U BOPE and test. Pull tubing from cut @ 7591', LID 103 jts. Pagel of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:30 0.50 7,591 7,591 MIRU WELCTL KLWL P PJSM and Bullhead 25 bbl of 11.8 ppg brine down tubing to formation @ 1 bpm. ICP =920 psi, FCP =1130 psi. 00:30 01:00 0.50 7,591 7,591 MIRU WELCTL OWFF P Monitor well from tubing and annulus - Static 01:00 01:15 0.25 7,591 7,591 MIRU WHDBO SEQP P Set BPV as per Cameron rep. 01:15 02:00 0.75 7,591 7,951 MIRU WHDBO RURD P Blow down lines in cellar. R/D lines and scaffolding. 02:00 02:15 0.25 7,591 7,591 MIRU WHDBO SFTY P PJSM on N/D tree and N/U BOPE. 02:15 04:15 2.00 7,591 7,591 MIRU WHDBO NUND P N/D tree, secure SSSV lines. (Check all lock down screws per Cameron rep.) 04:15 08:00 3.75 7,591 7,591 MIRU WHDBO NUND P N/U adapter spools and BOPE. 08:00 08:45 0.75 7,591 7,591 MIRU WHDBO RURD P R/U to test BOPE. 08:45 09:00 0.25 7,591 7,591 MIRU WHDBO SFTY P PJSM on testing BOPE. 09:00 11:00 2.00 7,591 7,591 MIRU WHDBO BOPE P Test with 2.875" test jt, annular and bottom rams 2.875" x 5 ". Test V 250 psi /3500 psi 5 minutes. 11:00 12:00 1.00 7,591 7,591 MIRU WHDBO BOPE P Drain stack, change out test jts f/ 2.875"V 4" XT -39 and refill stack. 12:00 16:00 4.00 7,591 7,591 MIRU WHDBO BOPE P Test BOPE w/ 4" jt, 250/3500 psi 5 min. #1 top pipe rams, valve 1,12,13,14 and manual kill. #2 upper IBOP, HCR kill, valves 9,11. #3 lower IBOP, valves 5,8 and 10. #4 Dart valve, valves 4,6,7. #5 floor valve & valve 2. #6 HCR choke, 4" kill line Demco valve, #7 manual choke valve, HCR kill. #8 annular preventer. #9 lower pipe rams, #10 blind rams, valve 3. 16:00 16:15 0.25 7,591 7,591 MIRU WHDBO BOPE P Accumulator test; system pressure 3000 psi, pressure after closing all 1800 psi. 200 psi attained 47 sec. Full pressure attained 182 seconds. N2 bottle average 2100 psi. AOGCC Jeff Jones waived witness of test. 16:15 17:00 0.75 7,591 7,591 MIRU WHDBO RURD P R/D test equipment, blow down choke, choke and kill lines, vac out stack. 17:00 18:00 1.00 7,591 7,591 COMPZ RPCOM RURD P PJSM- Pull TWC and dart from tubing hanger. M/U landing joint with circ hose, BOLDS. 18:00 19:15 1.25 7,591 7,563 COMPZ RPCOM PULL P Pull hanger to rig floor, pull 73K to free from hanger, P/U 70k (blocks 35k) Reverse circulate 44 bbl @ 2 bpm 325 psi. Monitor well slight losses. Total loss after filling stack 6 bbl. 19:15 20:00 0.75 7,563 7,563 COMPZ RPCOM RURD P R/U t UD 2.875" tubing and control line. LID tubing hanger and landing joint. 20:00 21:45 1.75 7,563 5,763 COMPZ RPCOM PULL P PJSM, LID 2.875" tubing and control line. Page 2 of 17 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:45 22:30 0.75 5,763 5,763 COMPZ RPCOM RURD P UD SSSV and R/D control line spooler. Recovered all 32 SS bands. 22:30 00:00 1.50 5,763 4,396 COMPZ RPCOM PULL P Continute laying down 2.875" tubing, UD 103 jts. Calc Fill =6.6 bbl, Actual fill 12.75 bbl. Losses 2.5 -3 bph. No damage noted to tubing string while POOH, no excess corrosion or scaling noted. Lightly oil coated, draining in pipe shed. 04/29/2013 L/D 2.875" tubing and OEJ -SBR. M/U overshot and single in hole, engage fish and jar loose. Lay down 11' fish, no packer. 00:00 03:00 3.00 4,396 45 COMPZ RPCOM PULL P PJSM and UD 2.875" tubing (Total 241 jts plus OEJ -SBR) Calc fill =11.14 bbl, Actual fill= 18.87. 03:00 03:30 0.50 45 0 COMPZ RPCOM PULL P Observed partially cut tubing, break off and UD cut jt. 03:30 05:00 1.50 0 0 COMPZ RPCOM RURD P R/D power tongs. Break OEJ -SBR, SIMOPS- strap tubing in pipe shed. (7591') 05:00 05:30 0.50 0 0 COMPZ RPCOM RURD P Clean and clear rig floor. SIMOPS- Stuff tubing with absorb at both ends before sending out. 05:30 05:45 0.25 0 0 COMPZ RPCOM SEQP P Set 6.1875" wear bushing. 05:45 06:15 0.50 0 0 COMPZ RPCOM RURD P Unload 2.875" tubing from pipeshed. (Tubing was later NORM'd and hauled to junk yard) 06:15 06:30 0.25 0 0 COMPZ RPCOM SFTY P PJSM on P/U and M/U overshot assy. 06:30 07:30 1.00 0 144 COMPZ RPCOM PULD P P/U Baker tools f/ beaver slide and M/U overshot BHA per Baker rep. 07:30 08:30 1.00 144 422 COMPZ RPCOM PULD P P/U 9jts 4.75" drill collars and intensifier. 08:30 12:00 3.50 422 4,093 COMPZ RPCOM TRIP P Single in the hole w/ 4" XT -39 Drill pipe f/ 315' MD t/ 4093' MD. Calc disp =27.01 bbl, Actual disp =21.25 bbl. Total losses this tour =13.68 bbl 12:00 14:00 2.00 4,093 7,585 COMPZ RPCOM TRIP P PJSM and cont single in hole w/ 4" XT -39 f/ 4093' MD t/ 7585' MD 14:00 14:30 0.50 7,585 7,018 COMPZ RPCOM TRIP P POOH t/ 7018', rack back 6 stds. 14:30 15:00 0.50 7,018 7,584 COMPZ RPCOM PULD P Continue single in V 7584' 15:00 15:15 0.25 7,584 7,584 COMPZ RPCOM CIRC P Break circ, get SPR. B/D top drive. Pick up working single. P /U= 135k, S /0 =102k. 15:15 15:45 0.50 7,584 7,597 COMPZ RPCOM FISH P RIH and tag top of fish on depth @ 7597' MD. Set 8k WOB, Jar @ 40k & 65k over p/u wt. Monitor well, (slight losses observed). 15:45 17:00 1.25 7,597 7,597 COMPZ RPCOM CIRC P CBU @ 4 bpm, 450 psi, 40% Flow out. Monitor well (static). UD single and B/D TD. Page 3 of 17 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 21:00 4.00 7,597 0 COMPZ RPCOM TRIP P PJSM and POOH f/ 7597' t/ 315' with fish. Monitor well at collars (slight loss), continue POOH. UD intensifier jars, rack back collars, break service connections and pull fish to rig floor. 21:00 21:30 0.50 0 0 COMPZ RPCOM PULL T Clean and clear rig floor. Break fish out of overshot, recovered 11' of slickstick. 21:30 23:15 1.75 0 0 COMPZ RPCOM SVRG T PJSM and slip and cut 52' of drilling line. Service rig. Monitor well on trip tank, losing 1 bph. 23:15 00:00 0.75 0 0 COMPZ RPCOM SFTY T Table top well control exercise. Reviewed the kick while tripping drill performed at 19:40 and reviewed (7 -2 and 7 -3, Problems while killing a Well) from Well Control Manual with Drilling Supervisor and all crew members. Total losses this tour =10.03 bbl, total for day= 23.71 bbl. 04/30/2013 M/U Overshot and RIH t/ 7608'. Engage fish and jar free. CBU and POOH w/ fish. Recovered 2.90' of fish. M/U BHA #3, overshot. RIH t/ 7611', attempt to engage fish, pushed down t/ 7625'. Stack 15K, CBU and POOH. No fish in overshot, mobilize Baker tools to rig. 00:00 00:30 0.50 0 315 COMPZ RPCOM PULD T PJSM, M/U BHA #2 over shot as per Baker rep. Pick up 3 stands of drill collars. 00:30 02:45 2.25 315 7,608 COMPZ RPCOM TRIP T RIH w/ 4" drill pipe f/ 315' to 7608'. Actual displacement= 45.22 bbls, Calculated displacement= 46.99 bbls. 02:45 03:00 0.25 7,608 7,612 COMPZ RPCOM FISH T Engage fish @ 7608', swallow 4.5' to 7612.5'. P /U= 132K, S /0 =102K. Pick up to 175K, fire jars 2 times @ 175K. Pick up to 200K, fire jars 4 times. Observe weight drop off to 132K, pick up w/ slight drag. RIH t/ 7612' set down 10K. P/U and observe 168K over pull. Weight fell off to 132K. P/U w/ slight drag. Decision made to CBU. 03:00 04:00 1.00 7,612 7,612 COMPZ RPCOM CIRC T CBU @ 4 BPM= 450 PSI, 40% flow. Monitor well, slight losses. 04:00 04:15 0.25 7,612 7,612 COMPZ RPCOM FISH T RIH f/ 7584' to 7612', set down 5K, P/U w/ same 132K up weight w/ 5 K drag. 04:15 04:30 0.25 7,612 7,584 COMPZ RPCOM PULD T UD working single, blow down top drive and monitor well. 04:30 07:30 3.00 7,584 315 COMPZ RPCOM TRIP T POOH f/ 7584' to 315'. Actual displacement= 50.64 bbls, Calculated displacement= 46.99 bbls, Monitor well, slight losses. 07:30 07:45 0.25 315 0 COMPZ RPCOM PULD T UD Intensifier and stand back 3 stands of drill collars. 07:45 08:45 1.00 0 0 COMPZ RPCOM PULD T UD Overshot, fish and jars as per Baker rep. Recovered 2.90' of fish. 08:45 09:00 0.25 0 0 COMPZ RPCOM PULD T Clean and clear rig floor. Page 4of17 • • Time Logs Date From To Cur S. Depth E. Death Phase Code Subcode T Comment 09:00 09:30 0.50 0 0 COMPZ RPCOM SVRG T Service rig. 09:30 10:00 0.50 0 0 COMPZ RPCOM SFTY T Perform post jarring derrick inspection. Held table top well control, discussed problems faced while killing a well. 10:00 10:45 0.75 0 115 COMPZ RPCOM PULD T PJSM, P/U Baker tools from beaver slide and M/U overshot BHA #3 as per Baker. 10:45 11:00 0.25 115 310 COMPZ RPCOM TRIP T RIH w/ 3 stands of drill collars and M/U Intensifier. 11:00 13:30 2.50 310 7,589 COMPZ RPCOM TRIP T RIH f/ 310' to 7487'. P/U 10' pup and 1 stand, RIH t/ 7589' and M/U working single. P /U= 135K, S /O= 105K. Actual displacement= 41.82 bbls, Calculated displacement= 46.99 bbls. 13:30 14:00 0.50 7,589 7,625 COMPZ RPCOM FISH T RIH to 7611', tag fish and attempt to stack weight, fish moving down hole. Pick up 2nd single and push fish down to 7625'. Stack 15K on fish. P/U on string, 4 -7 drag observed. 14:00 15:30 1.50 7,625 7,625 COMPZ RPCOM CIRC T CBU @ 3 BPM= 350 PSI, 40% flow. Monitor well, static. Blow down top drive and UD single. Observed 20K overpull, S/O down to down weight. P/U to 200K three times, pulled free. OWFF. 15:30 19:45 4.25 7,625 310 COMPZ RPCOM TRIP T POOH f/ 7589' to 310, Monitor well @ drill collars, static. Stand back drill collars and UD overshot. No fish in overshot. After inspecting overshot, it looked like the fish only entered 1/4" into the grapple. 19:45 00:00 4.25 0 0 COMPZ RPCOM OTHR T Discuss options for next run with town staff. Mob Baker fishing tools to rig from Deadhorse. Clean and clear rig floor and service rig. SIMOPS, process new tubing in pipe shed. Total losses for the day are 14.55 bbls. 05/01/2013 M/U BHA #4 and RIH to 7628'. Set down 15K, unable to grab fish. POOH and UD BHA. R/U HES Slick line and RIH w/ impression block. M/U BHA #5, overshot dressed with 3 -3/8" grapple. RIH and catch fish. POOH and UD packer assy. 00:00 01:00 1.00 0 0 COMPZ RPCOM OTHR T PJSM, Mobilize Baker tools to rig for next run. SIMOPS, prep new tubing in pipe shed. 01:00 01:45 0.75 0 55 COMPZ RPCOM PULD T Bring Baker fishing tools to rig floor and strap /tally. M/U BHA #4 SC overshot w/ extension as per Baker rep. 01:45 02:00 0.25 55 313 COMPZ RPCOM TRIP T RIH w/ 3 stands of drill collars and intensifier. 02:00 04:00 2.00 313 7,628 COMPZ RPCOM TRIP T RIH f/ 313' to 7628'. P /U= 135K, S /O= 102K. Actual displacement= 45.73 bbls, Calculated displacement= 47.11 bbls. Page 5of17 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 04:30 0.50 7,628 7,628 COMPZ RPCOM FISH T Set down 15K on fish @ 7628' several times. No change in pick up weight. Decision made to POOH w/ no fish. 04:30 04:45 0.25 7,628 7,582 COMPZ RPCOM OWFF T Monitor well, slight losses. UD two working singles to 7582'. 04:45 07:15 2.50 7,582 313 COMPZ RPCOM TRIP T POOH f/ 7582' to 313'. Actual displacement= 49.98 bbls, Calculated displacement= 46.93 bbls. Monitor well @ collars, slight losses. 07:15 07:30 0.25 313 55 COMPZ RPCOM TRIP T Stand back 3 stands of drill collars and Intensifier. 07:30 08:00 0.50 55 0 COMPZ RPCOM PULD T Break overshot apart and change grapple. UO Oil jars and LSB as per Baker rep, 08:00 08:30 0.50 0 0 COMPZ RPCOM PULD T Clean and clear rig floor. 08:30 09:00 0.50 0 0 COMPZ RPCOM SVRG T Service rig. 09:00 10:30 1.50 0 0 COMPZ RPCOM RURD T Spot Halliburton slick line truck. P/U Halliburton tools and R/U slick line. 10:30 12:45 2.25 0 0 COMPZ RPCOM SLKL T RIH w/ impression block on slick line. R/D HES slick line. Impression block showed 3.0" OD by 2.0" ID 12:45 16:15 3.50 0 7,582 COMPZ RPCOM TRIP T PJSM, M/U BHA #5, overshot dressed w/ 3 -3/8" grapple. RIH to 7582'. P /U= 134K, S /O= 104K, ROT= 120K @ 20 RPM w/ 2.5K Tq. Actual displacement= 45.39 bbls, Calculated displacement= 46.99 bbls. 16:15 16:30 0.25 7,582 7,627 COMPZ RPCOM FISH T RIH and tag TOF @ 7627' pumping @ 3 BPM, observed pressure increase. P/U ROT @ 10 RPM, observed Tq increase. P/U to 7585' and RIH to 7611', tagged twice. 16:30 17:30 1.00 7,627 7,611 COMPZ RPCOM CIRC T CBU @ 3.5 BPM =450 PSI, 38% flow. Monitor well, static. 17:30 18:30 1.00 7,611 7,585 COMPZ RPCOM FISH T Attempt to pick up, observed 20K overpull @ 7611'. Cont to P/U to 55K overpull, jar up @ 185K and straight pull to 200K three times. Cont to jar up @ 195K and straight pull to 210K five times. Jar down twice. Work torque down hole @ slack off weight, observed weight increase. Pull up to 7585' and pulled pipe free. RIH to confirm fish on. POOH to 7585', monitor well, observed slight flow and bubbling. Decision made to CBU. 18:30 20:00 1.50 7,585 7,585 COMPZ RPCOM CIRC T CBU @ 4 BPM= 450 PSI, 40% flow. Monitor well, static. SIMOPS, preform post jarring derrick inspection. Page 6 of 17 • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 20:00 00:00 4.00 7,585 55 COMPZ RPCOM TRIP T PJSM, POOH to 315'. Monitor well @ drill collars, static. Cont POOH standing back drill collars. Pull overshot to floor, recovered fish. Recovered Packer assy, 3 full joints of 2 -7/8" tubing, 2 GLM's and cut joint. 133.94' total. Cut joint was damaged, the last 5' was split open and appeared to be missing a piece. 05/02/2013 UD Packer assy, 133.94' of fish. M/U BHA #6, washpipe. RIH and wash over blast joints, CBU X2 and POOH. POOH and UD BHA. M/U BHA # 7, T -Dog overshot and RIH. Latch onto fish and pull 25K over, appeared to get fish. POOH, no fish on. 00:00 00:30 0.50 0 0 COMPZ RPCOM PULD P UD fish, recovered Packer assy, 3 full joints of 2 -7/8" tubing, 2 GLM's and cut joint. 133.94' total. Cut joint was damaged, the last 5' was split open and appeared to be missing a piece. 00:30 01:00 0.50 0 0 COMPZ RPCOM PULD P P/U Packer assy, break off grapple as per Baker rep. 01:00 01:30 0.50 0 0 COMPZ RPCOM PULD P Clean and clear floor, re- install wear bushing. 01:30 01:45 0.25 0 0 COMPZ RPCOM SFTY P Hold PJSM on M/U BHA #6. 01:45 03:00 1.25 0 188 COMPZ RPCOM PULD P M/U BHA #6, washover assy as per Baker rep. 03:00 07:00 4.00 188 7,691 COMPZ RPCOM TRIP P RIH w/ 3 stands of drill collars and 4" drill pipe to 7691'. Actual displacement= 44.69 bbls, Calculated displacement= 48.39 bbls. 07:00 07:15 0.25 7,691 7,691 COMPZ RPCOM WASH P Establish parameters, break circulation @ 6 BPM= 950 PSI, 44% flow. P /U= 125K, S /0= 100, ROT= 112K. Obtain SPR's. 07:15 08:30 1.25 7,691 7,866 COMPZ RPCOM WASH P Wash over blast joints, wash down f/ 7691' to 7866' @ 6 -8 BPM= 1000 -1900 PSI. Set down 4K © 7744', TOF. P/U and work back down, do not take weight. Cont to wash down to 7758', set down 7K, P/U and work past, Cont to wash down to 7866', take 5 -10K. Picking up at times to clear fill from wash pipe. 08:30 09:30 1.00 7,866 7,866 COMPZ RPCOM CIRC P CBU X 2 @ 5 BPM =900 PSI, 42% flow. Hole taking — 5 BPH 09:30 10:00 0.50 7,866 7,866 COMPZ RPCOM OWFF P Monitor well, breathing then slight loss. 10:00 13:30 3.50 7,866 422 COMPZ RPCOM TRIP P Blow down top drive. POOH f/ 7866' to 422'. Actual displacement= 47.6 bbls, Calculated displacement= 48.93 bbls. Monitor well @ collars. 13:30 14:30 1.00 422 0 COMPZ RPCOM PULD P Stand back drill collars and UD wash pipe and jars. 14:30 15:15 0.75 0 125 COMPZ RPCOM PULD P PJSM, M/U BHA #7, T -Dog and flush ID shoe, wash pipe and boot basket. Page 7 of 17 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:15 16:00 0.75 125 125 COMPZ RPCOM SVRG P PJSM, Adjust draw works brakes. 16:00 20:00 4.00 125 7,702 COMPZ RPCOM TRIP P RIH w/ drill collars and 4" drill pipe to 7702' Actual displacement= 46.41 bbls, Calculated displacement= 46.31 bbls.. Establish parameters, P /U= 130K, S /O= 108K, ROT= 120K, Pump @ 3 BPM= 300 PSI. 20:00 20:15 0.25 7,702 7,702 COMPZ RPCOM FISH P RIH to 7767', stack 5K on shoe, P/U to 25K over. Observed weight drop off. P/U to 7702' with 3 -8K drag. 20:15 21:00 0.75 7,702 7,702 COMPZ RPCOM OWFF P Monitor well, slight losses. Blow down top drive. 21:00 00:00 3.00 7,702 2,984 COMPZ RPCOM TRIP P PJSM, POOH f/ 7702' to 2984'. Actual displacement= 28.74 bbls, Calculated displacement= 27.0 bbls. 05/03/2013 POOH w/ no fish. M/U BHA #8, washpipe and T -Dog overshot. RIH and swallow fish. CBU and POOH. UD BHA and fish, recovered all of fish 136.39'. M/U BHA #9, packer mill. 00:00 00:45 0.75 2,984 339 COMPZ RPCOM TRIP P Cont POOH f/ 2984' to 339'. Actual displacement= 21.61 bbls, Calculated displacement= 20.21 bbls. 00:45 01:00 0.25 339 339 COMPZ RPCOM TRIP P Monitor well, slight losses. 01:00 01:15 0.25 339 0 COMPZ RPCOM TRIP P Stand back drill collars in derrick. 01:15 01:30 0.25 0 0 COMPZ RPCOM PULD P UD BHA as per Baker rep. 01:30 02:00 0.50 0 0 COMPZ RPCOM OTHR T No fish, consult with town staff on next move forward. All indications appear that the fish was pulled from seal bore. Mobilize Baker tools to rig that will allow the fish to be swallowed by wash pipe and latched with the T -Dog on the lower GLM collar. 02:00 02:30 0.50 0 0 COMPZ RPCOM PULD T Clean and clear rig floor. 02:30 04:00 1.50 0 0 COMPZ RPCOM SLPC P Hold PJSM, slip and cut 9 wraps (59') of drilling line. 04:00 04:30 0.50 0 0 COMPZ RPCOM SVRG P Service rig. 04:30 06:15 1.75 0 130 COMPZ RPCOM PULD T PJSM, M/U BHA #8, T -Dog overshot with wash pipe as per Baker rep. 06:15 06:45 0.50 130 419 COMPZ RPCOM TRIP T RIH w/ drill collars and M/O cross over. 06:45 10:30 3.75 419 7,688 COMPZ RPCOM TRIP T RIH f/ 419' to 7688'. Actual displacement= 45.56 bbls, Calculated displacement= 48.39 bbls. 10:30 11:00 0.50 7,688 7,864 COMPZ RPCOM FISH T Break circulation and establish parameters, pump @ 2 BPM= 150 PSI. P /U= 130K, S /O= 105K. RIH to 7864', set down 15K on fish. P /U, observed 15K over pull w/ 5 K drag. P/U to 7843'. 11:00 11:45 0.75 7,864 7,843 COMPZ RPCOM CIRC T CBU @ 3 BPM =300 PSI, 38% flow. Page 8 of 17 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:45 12:15 0.50 7,843 7,843 COMPZ RPCOM CIRC T Monitor well, slight gas bubbles w/ minor flow. Decision made to CBU @ 3 BPM =300 PSI. 12:15 12:30 0.25 7,843 7,843 COMPZ RPCOM OWFF T Monitor well, slight breathing to static. Blow down top drive. 12:30 16:15 3.75 7,843 450 COMPZ RPCOM TRIP T POOH f/ 7843' to 450'. Actual displacement= 52.19 bbls, Calculated displacement= 51.01 bbls. 16:15 16:30 0.25 450 450 COMPZ RPCOM OWFF T Monitor well, static. 16:30 17:30 1.00 450 150 COMPZ RPCOM PULD T Stand back drill collars, UD jars and bumper sub. 17:30 18:15 0.75 150 150 COMPZ RPCOM PULD P PJSM, break wash pipe and install dog collar on fish. Attempt to pull fish though wash pipe, no go. Decision made to mobilize cutter to rig and cut fish up to remove from wash pipe. 18:15 19:00 0.75 150 150 COMPZ RPCOM PULD P Moblize tubbing cutter to rig. SIMOPS, clean and clear rig floor. 19:00 19:30 0.50 150 150 COMPZ RPCOM SFTY P Hold PJSM on cutting fish out of wash pipe. Fill out HRW, discuss all steps involved and how to safely mitigate all hazards. Document steps in detail for future reference. 19:30 22:30 3.00 150 0 COMPZ RPCOM PULD P UD fish and wash pipe. Recovered 1 cut joint, 2 blast joints, 1 full joint , 1 XO, 2 pups, 1 GLM and seal assy. 136.39' of fish. 22:30 23:30 1.00 0 0 COMPZ RPCOM PULD P UD Baker tools from rig floor. 23:30 00:00 0.50 0 0 COMPZ RPCOM PULD P Clean and clear rig floor. 05/04/2013 Milled Baker packer f/ 7871' to 7872'. CBU and POOH. M/U spear and RIH. Spear packer and CBU and maintain MW @ 11.8 ppg. POOH and UD fish. 00:00 00:30 0.50 0 0 COMPZ RPCOM PULD P Clean and clear rig floor. 00:30 00:45 0.25 0 0 COMPZ RPCOM SFTY P Hold PJSM on packing up BHA #9, packer mill. 00:45 02:00 1.25 0 155 COMPZ RPCOM PULD P P/U Baker tools f/ slide. M/U BHA #9, packer mill as per Baker rep. 02:00 03:30 1.50 155 697 COMPZ RPCOM PULD P Pick up 12 joints of 4" HWDP f/ pipeshed. 03:30 05:00 1.50 697 7,871 COMPZ RPCOM TRIP P RIH f/ 697' to 7871', tagged upon packer, set down 15K. Actual displacement= 50.15 bbls, Calculated displacement= 50.74 bbls. 05:00 05:15 0.25 7,871 7,871 COMPZ RPCOM MILL P Establish parameters, P /U= 135K, S /0= 110K, ROT= 120K, 80 RPM w/ 2.5K Tq. Obtain SPR's 05:15 07:45 2.50 7,871 7,872 COMPZ RPCOM MILL P Mill Baker DB packer f/ 7871' to 7872'. Mill @ 6 BPM= 1200 PSI, 48% flow, 80 RPM w/ 5 -12K Tq. 07:45 08:45 1.00 7,872 8,015 COMPZ RPCOM MILL P Push packer down f/ 7872' to 8015', set down 20K several time with no additional movement. Packer appears to be sitting on lower perfs. Page 9 of 17 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:45 09:45 1.00 8,015 8,015 COMPZ RPCOM CIRC P Circulate 27 bbls Super Sweep around @ 6 BPM= 1200 PSI, 48% flow, 50 RPM w/ 4K Tq 09:45 10:45 1.00 8,015 7,997 COMPZ RPCOM TRIP P Stand back one stand to 7997'. Monitor well, slight flow then static. Blow down top drive. 10:45 13:30 2.75 7,997 697 COMPZ RPCOM TRIP P POOH f/ 7997' to 697', slight over pull @ 7940'. Monitor well @ HWDP. 13:30 13:45 0.25 697 155 COMPZ RPCOM TRIP P Stand back HWDP and drill collars in derrick. 13:45 14:45 1.00 155 0 COMPZ RPCOM PULD P UD BHA #9, packer mill. Clean magnets, recovered 10 Ibs of metal. Actual displacement= 51.46 bbls. Calculated displacement= 52.19 bbls. 14:45 15:00 0.25 0 0 COMPZ RPCOM PULD P Clean and clear rig floor. 15:00 15:15 0.25 0 0 COMPZ RPCOM PULD P P/U Baker tools f/ beaver slide. 15:15 15:45 0.50 0 304 COMPZ RPCOM PULD P M/U BHA #10, spear as per Baker rep. 15:45 18:30 2.75 304 7,950 COMPZ RPCOM TRIP P RIH f/ 304' to 7950', Actual displacement= 48.5 bbls, Calculated displacement= 50.14 bbls. 18:30 19:00 0.50 7,950 7,950 COMPZ RPCOM FISH P Wash down f/ 7950' to 8014' @ 2 BPM= 500 PSI. P /U= 142K, S /O= 108K. Tag fish and set down 10K, P/U w/ 5K over pull. P/U 10' and hung up on collar, P/U 38K over. Ran back to 8014' and set 5K down, P/U to 7950' w/ 5 -10K over pull. Stand back one stand. 19:00 20:30 1.50 7,950 7,950 COMPZ RPCOM CIRC P CBU © 3.5 BPM= 1325 PSI. 20:30 22:30 2.00 7,950 7,950 COMPZ RPCOM CIRC P Monitor well, flowing slighty. Fluid weight was decreased to 11.6+ due to crude below packer. Circulate and condition brine, raised weight back to 11.8 ppg. Obtain SPR's. 22:30 23:00 0.50 7,950 7,950 COMPZ RPCOM OWFF P Monitor well, static. Blow down top drive. 23:00 00:00 1.00 7,950 7,384 COMPZ RPCOM TRIP P POOH f/ 7950' to 7384'. 05/05/2013 Cont POOH w/ fish. UD packer and tail pipe. M/U clean out BHA and RIH t/ 8209', tight hole f/ 7940' to 7960'. Pump sweep and circulate hole clean. POOH and UD BHA. Test BOPE t/ 250/3500 PSI, AOGCC rep Chuck Scheve witnessed test. M/U scraper BHA and RIH. 00:00 02:30 2.50 7,384 304 COMPZ RPCOM TRIP P POOH f/ 7384' to 304'. Actual displacement= 55.30, Calculated displacement= 48.54 bbls. 02:30 03:00 0.50 304 0 COMPZ RPCOM TRIP P Stand back drill collars. UD BHA, recovered packer and tail pipe= 25.02' of fish. 03:00 03:30 0.50 0 0 COMPZ WELLPF OTHR P Clean and clear floor. 03:30 03:45 0.25 0 0 COMPZ WELLPF SFTY P Hold PJSM on M/U clean out BHA. 03:45 04:15 0.50 0 120 COMPZ WELLPF PULD P M/U BHA # 11 as per Baker rep. 04:15 04:30 0.25 120 341 COMPZ WELLPFTRIP P RIH w/ 3 stands of drill collars. Page 10 of 17 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 06:45 2.25 341 7,954 COMPZ WELLPF TRIP P RIH w/ clean out BHA f/ 341' to 7954'. P /U= 135K, S /O= 110K. Actual displacement= 47.45 bbls, Calculated displacement= 49.81 bbls. 06:45 07:45 1.00 7,954 8,209 COMPZ WELLPF WASH P Wash and ream f/ 7954' to 8209' @ 5 BPM= 750 PSI, 46% flow, 60 RPM w/ 3 -5K Tq. Work through tight spot f/ 7940' to 7960' 07:45 09:00 1.25 8,209 8,209 COMPZ WELLPF CIRC P Pump super sweep @ 5 BPM= 800 PSI, 46% flow. 09:00 09:15 0.25 8,209 8,176 COMPZ WELLPF PULD P UD two singles f/ 8209' to 8176'. Blow down top drive. 09:15 09:45 0.50 8,176 8,176 COMPZ WELLPF OWFF P Monitor well, slight flow to static. 09:45 12:45 3.00 8,176 341 COMPZ WELLPF TRIP P POOH f/ 8176' to 341'. Work through tight spot f/ 7960' to 7040' w/ 20K overpull. Monitor well @ collars. Actual displacement= 53.35 bbls, Calculated displacement= 51.87 bbls. 12:45 13:30 0.75 341 0 COMPZ WELLPF PULD P UD clean out BHA. Clean magnets, recovered 29 Ibs of metal off magnets. 13:30 14:00 0.50 0 0 COMPZ WHDBO OTHR P Pull wear bushing and drain stack. 14:00 14:45 0.75 0 0 COMPZ WHDBO CIRC P R/U and wash metal from BOP stack with stack washer. Blow down top drive. 14:45 15:30 0.75 0 0 COMPZ WHDBO RURD P PJSM, rig up to test BOPE. 15:30 22:00 6.50 0 0 COMPZ WHDBO BOPE P Test BOPE w/ 3 -1/2" and 4" test joint to 250/3500 PSI for 5 minutes each. Test #1: Top pipe rams, CV 1,12,13,14, and manual kill. Test #2: Upper IBOP, HCR kill, CV 9 and 11. Test #3: Lower IBOP, CV 5,8, and 10. ( Fail on CV #5, steam packing. Re- tested, good.) Test #4: Dart valve, CV 4,6 and 7. Test #5: Floor valve and CV 6. ( Floor valve failed. Replaced valve and re- tested, good.) Test #6: HCR choke and 4" kill line demco. Test #7: Manual choke and HCR kill. Test #8: Annular preventer ( Annular preventer, function and re -test, good.) Test #9: Lower pipe rams. Test #10 Blind rams and CV 3. Replace casing gauge battery on super choke. Accumulator test: system pressure= 3000 PSI, pressure after closing= 1650, 200 PSI attained after 39 seconds, full pressure attained after 197 seconds. Nitrogen bottle avg= 2050 PSI. AOGCC rep Chuck Scheve witnessed the test. 22:00 22:30 0.50 0 0 COMPZ WHDBO RURD P R/D testing equipment and blow down choke /kill lines. Page 11 of 17 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 23:00 0.50 0 0 COMPZ WELLPF PULD P Clean and clear rig floor. 23:00 23:15 0.25 0 0 COMPZ WELLPF SFTY P Hold PJSM on M/U BHA, scraper. 23:15 00:00 0.75 0 0 COMPZ WELLPF PULD P M/U BHA #12 as per Baker rep. 05/06/2013 RIH w/ 7" casing scraper t/ 7918'. Pump sweep around and reverse circ hole clean. POOH and UD BHA. R/U HES E -line. RIH w/ packer assy on E -line t/ 7920'. Pulled out of E -line rope socket w/ 1200 Ibs over pull. R/D E -line. M/U fishing BHA and RIH t/ fish packer assy. Tagged packer assy @ 7921'. POOH w/ packer assy. 00:00 02:45 2.75 120 7,792 COMPZ WELLPF TRIP P PJSM, M/U 3 stands of drill collars and RIH w/ 7" casing scraper t/ 7792'. Work scraper twice f/ 7000' to 7792'. Actual displacement= 47.09 bbls, Calculated displacement= 49.27 bbls. 02:45 03:30 0.75 7,792 7,918 COMPZ WELLPF WASH P Wash and ream f/ 7792' to 7918' @ 5 BPM= 800 PSI, 42% flow, 30 RPM w/ 2 -3K Tq. P /U= 135K, S /0= 110K, ROT= 125K. Work twice f/ 7792' to 7886'. 03:30 04:30 1.00 7,918 7,918 COMPZ WELLPFCIRC P Pump around Super Sweep © 5 BPM= 800 PSI, 42% flow. Work string @ 30 RPM w/ 2 -3K. 04:30 05:00 0.50 7,918 7,918 COMPZ WELLPF RURD P Blow down top drive and R/U to reverse circulate. 05:00 05:45 0.75 7,918 7,918 COMPZ WELLPF CIRC P Reverse circulate hole clean @ 6 BPM =1000 PSI. 05:45 06:15 0.50 7,918 7,918 COMPZ WELLPF CIRC P Break lines, well out of balance. Circulated down DP to balance well, pump @ 5 BPM =800 PSI. 06:15 06:30 0.25 7,918 7,887 COMPZ WELLPF OWFF P UD single and monitor well, slight flow to static. 06:30 09:00 2.50 7,887 337 COMPZ WELLPF TRIP P POOH f/ 7887' to 337'. Monitor well @ drill collars. Actual displacement= 51.42 bbls, Calculated displacement= 49.27 bbls. 09:00 09:30 0.50 337 120 COMPZ WELLPF PULD P UD 12 joints of drill collars. 09:30 10:00 0.50 120 0 COMPZ WELLPF PULD P UD BHA #12 as per Baker rep. 10:00 10:45 0.75 0 0 COMPZ WELLPF PULD P Clean and clear rig floor. Remove Baker tools from rig floor and send down slide. 10:45 12:00 1.25 0 0 COMPZ RPCOM RURD P Spot Halliburton E -Line trucks and prep tools. R/U power tongs. 12:00 12:45 0.75 0 97 COMPZ RPCOM RCST P PJSM, P/U lower packer assy as follows. Solid seat SO pinned @ 3500, 15' XO pup, 2 40' joints of 3 -1/2" IBTM tubing, Baker 80-40 SBE and F -1 permanent packer. 12:45 13:30 0.75 97 97 COMPZ RPCOM RURD P R/U HES E -line and M/U packer setting tools. 13:30 13:45 0.25 97 97 COMPZ RPCOM ELOG P M/U E -line tools on packer assy. Page 12 of 17 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:45 15:30 1.75 97 7,920 COMPZ RPCOM ELOG P RIH w/ packer assy on E -line @ 120 ft/min, packer became hung up @ 7920' while tying into maker joint. Pulled 1,200 Ibs over and pulled out of rope socket. Rope socket disconnected prematurely w/ 1,200 Ibs over. 15:30 16:00 0.50 7,920 0 COMPZ RPCOM ELOG T POOH w/ E -line f/ 7920' to surface. 16:00 16:45 0.75 0 0 COMPZ RPCOM RURD T R/D HES E -line. 16:45 17:45 1.00 0 0 COMPZ RPCOM OTHR T Clean and clear rig floor. 17:45 19:00 1.25 0 0 COMPZ RPCOM PULD T PJSM, pick up drill collars and stand back in derrick. 19:00 19:30 0.50 0 0 COMPZ RPCOM PULD T PJSM, P/U Baker tools from beaver slide. 19:30 20:15 0.75 0 290 COMPZ RPCOM PULD T P/U BHA, overshot as per Baker rep. 20:15 20:45 0.50 290 1,528 COMPZ RPCOM TRIP T RIH f/ 290' to 1528'. Observed bad box on drill pipe. 20:45 21:00 0.25 1,528 1,528 COMPZ RPCOM PULD T C/O bad joint of 4" drill pipe. 21:00 22:45 1.75 1,528 7,851 COMPZ RPCOM TRIP T Cont RIH w/ overshot f/ 1528' to 7851'. P /U= 131K, S /0= 110K. Actual displacement= 48.11 bbls, Calculated displacement= 48.34 bbls. 22:45 23:30 0.75 7,851 7,851 COMPZ RPCOM FISH T Wash down f/ 7851' to 7921' @ 2.5 BPM= 175 PSI. Observed pump pressure increase of 60 PSI and set down 4K on fish. P/U observing 5K drag confirming fish on. POOH to 7851'. 23:30 00:00 0.50 7,851 7,851 COMPZ RPCOM OWFF T Monitor well, static. 05/07/2013 UD fish (packer assy) M/U BHA # 14, string mills and RIH to 7941'. Work mills in 7" casing f/ 7941' to 7955', cleaned up tight spot. Work string down to 8207'. Circulate hole clean and POOH to run lower packer assy. 00:00 05:00 5.00 7,551 299 COMPZ RPCOM TRIP T PJSM, POOH f/ 7551' to 299'. Actual displacement= 51.34 bbls, Calculated displacement= 48.88 bbls. Monitor well @ collars, static. 05:00 06:00 1.00 299 299 COMPZ RPCOM SFTY T Hold PJSM and fill out HRW and HRC on doing non - routine task, laying down E -line running tool and packer assy. 06:00 07:30 1.50 299 0 COMPZ RPCOM PULD T UD fish, E -line tools, 2 joints of 3 -1/2" IBTM tubing, packer assy, 15' pup and shear out sub. 07:30 08:00 0.50 0 0 COMPZ WELLPF PULD T R/D power tongs, clean and clear floor. 08:00 08:15 0.25 0 0 COMPZ WELLPF SFTY T Hold PJSM on M/U clean out BHA. 08:15 09:00 0.75 0 75 COMPZ WELLPF PULD T M/U BHA #14, clean out string mills, as per Baker rep. 09:00 12:00 3.00 75 6,959 COMPZ WELLPF TRIP T RIH w/ 3 stands of drill collars and 4" drill pipe to 6959'. Actual displacement= 44.03 bbls, Calculated displacement= 44.09 bbls. Page 13 of 17 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 12:00 12:15 0.25 6,959 6,959 COMPZ WELLPF SFTY T Hold PJSM on slip and cut drilling line. 12:15 13:15 1.00 6,959 6,959 COMPZ WELLPF SLPC T Slip and cut 75' of drilling line. 13:15 13:45 0.50 6,959 6,959 COMPZ WELLPF SVRG T Service rig. 13:45 14:30 0.75 6,959 7,903 COMPZ WELLPF TRIP T Cont RIH f/ 6959' to 7903'. 14:30 14:45 0.25 7,903 7,941 COMPZ WELLPF REAM T Establish parameters, P /U= 138K, S /O= 114K, ROT= 129K, ROT @ 50 RPM w/ 3K Tq. Wash down f/ 7903' to 7941', observed 2K Tq increase, ream down to 7944' and Tq increased to 8K and stalled out. Release Tq and P/U to 7941'. 14:45 17:30 2.75 7,941 7,955 COMPZ WELLPF REAM T Ream 7" casing w/ string mills f/ 7941' to 7955', start @ 50 RPM increasing to 120 RPM w/ 3 -6K Tq, pumping @ 5 BPM. Worked mills until no torque was observed in tight spot. 17:30 18:45 1.25 7,955 8,207 COMPZ WELLPF REAM T Cont reaming in the hole f/ 7951' to 8207' @ 5 BPM= 650 PSI, 50 RPM. Set down 7K © 8207'. 18:45 20:00 1.25 8,207 8,180 COMPZ WELLPFCIRC T P/U to 8180'. Reverse circulate hole clean @ 5 BPM= 1100 PSI. 20:00 20:15 0.25 8,180 8,180 COMPZ WELLPF RURD T R/D reverse circulating hoses. Well flowing up drill pipe. 20:15 20:30 0.25 8,180 8,180 COMPZ WELLPF CIRC T Circulate to balance well, pump @ 5 BPM= 650 PSI. 20:30 20:45 0.25 8,180 8,180 COMPZ WELLPF CIRC T Obtain SPR's w/ 11.8 ppg fluid. 20:45 22:00 1.25 8,180 8,180 COMPZ WELLPF OWFF T Monitor well, slight flow. Wait until flow stopped. 22:00 23:00 1.00 8,180 7,933 COMPZ WELLPF TRIP T POOH f/ 8090' to 7335'. Improper hole fill, RIH to 7933' to CBU. 23:00 00:00 1.00 7,933 7,933 COMPZ WELLPF CIRC T CBU @ 5 BPM= 650 PSI, observed bubbling @ BU. P /U= 137K, S /0= 114K. 05/08/2013 POOH and UD clean out BHA. M/U lower packer assy and RIH on E -line. Set F -1 packer @ 7803.53'. R/D E -line. R/U and RIH w/ 3 -1/2" completion as per detail. 00:00 00:45 0.75 7,933 7,933 COMPZ WELLPF OWFF T Monitor well, slight flow to static. Blow down top drive. 00:45 03:00 2.25 7,933 351 COMPZ WELLPF TRIP T POOH f/ 7933' to 351'. Monitor well @ collars, static. Actual displacement= 50.49 bbls, Calculated displacement= 49.49 bbls. 03:00 03:15 0.25 351 120 COMPZ WELLPFTRIP T Stand back 3 stands of drill collars. 03:15 04:00 0.75 120 0 COMPZ WELLPF PULD T UD BHA as per Baker rep. 04:00 04:30 0.50 0 0 COMPZ RPCOM OTHR T Clean and clear rig floor. Send Baker tools down the beaver slide. 04:30 04:45 0.25 0 0 COMPZ RPCOM RURD T Spot E -line trucks and R/U power tongs on rig floor. 04:45 05:00 0.25 0 0 COMPZ RPCOM SFTY T Hold PJSM on P/U lower packer assy. Page 14 of 17 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 05:45 0.75 0 119 COMPZ RPCOM RCST T M/U lower packer assy, shear out sub w/ 15' pup, 2 40' joints of IBTM tubing and packer assy. 05:45 06:00 0.25 119 119 COMPZ RPCOM SFTY T Hold PJSM on R/U HES E -line and making up tools. 06:00 08:30 2.50 119 119 COMPZ RPCOM RURD T R/U HES E -line and M/U tools to packer assy. 08:30 10:30 2.00 119 7,803 COMPZ RPCOM ELOG T Run lower packer assy on E -line @ 150' FPM. Set Baker F -1 packer @ 7803.53' orignal KB, CTD kick off joints f/ 7821.73' to 7904'. 10:30 12:00 1.50 7,803 0 COMPZ RPCOM ELOG P POOH w/ E -line. 12:00 12:15 0.25 0 0 COMPZ RPCOM RURD P R/D HES E -line as per Halliburton rep. 12:15 12:45 0.50 0 0 COMPZ RPCOM SFTY P Hold PJSM on running 3 -1/2" completion. 12:45 19:00 6.25 0 5,977 COMPZ RPCOM RCST P RIH w/ 3 -1/2" 9.3 ppf L -80 completion string as per detail to 5977'. 19:00 19:30 0.50 5,977 5,977 COMPZ RPCOM RURD P P/U control line tools f/ beaver slide. 19:30 20:30 1.00 5,977 5,977 COMPZ RPCOM SSSV P PJSM, R/U control line to Camco SSSV and test line to 6000 PSI f/ 15 minutes. 20:30 00:00 3.50 5,977 7,672 COMPZ RPCOM RCST P Cont RIH w/ 3 -1/2" completion string as per detail. P /U= 86K, S /O= 76K. Actual displacement= 24.13 bbls, Calculated displacement= 25.04 bbls. 05/09/2013 Cont to run 3 -1/2" completion. Locate and set FHL packer 1' off located. Shear PBR and space out. Land 3 -1/2" tubing 6.24' of located position. Test tubing and packer and shear SOS. N/D BOPE and N/U tress. Test tree to 250/5000 PSI. Displace well to Inhibited sea water and diesel. U -Tube freeze protect. 00:00 00:15 0.25 7,672 7,804 COMPZ RPCOM RCST P Run 3 -1/2" tubing f/ 7672' to 7803'. P/U 87K, S /0= 77K. 00:15 01:00 0.75 7,804 7,793 COMPZ RPCOM RCST P L/D 1 joint of tubing and M/U 5 pup joint, re -tag top of F -1 packer @ 7803.53 setting down 5K. 01:00 01:15 0.25 7,793 7,793 COMPZ RPCOM RURD P R/U to circulate and re -tag w/ charge pump running. Pull seals out of seal bore. 01:15 02:00 0.75 7,793 7,793 COMPZ RPCOM DISP P Spot 25 bbls of 11.8 ppg Inhibited brine f/ seals assy up to SOV 02:00 02:45 0.75 7,793 7,637 COMPZ RPCOM PACK P S/O and locate, P/U to string weight plus 1'. Pressure up tubing to 1800 PSI setting FHL packer. Bring tubing pressure up t/ 2500 PSI and hold for 5 minutes, good. Bleed tubing down to 1000 PSI and pressure up IA to 1500 PSI for 10 minutes, good. Bleed off pressure, P/U to shear out PBR. Observed shear out @ 30K over, 117K. 02:45 03:30 0.75 7,637 7,637 COMPZ RPCOM HOSO P Space out. L/D 5' pup joint. P/U space out pups, 10.24', 10.26' and 2.43'. Page 15 of 17 ` • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 05:00 1.50 7,637 7,659 COMPZ RPCOM THGR P M/U tubing hanger and landing joint. Land hanger 6.24' off fully located position. Run in lock downs. 62 SS bands ran in the hole. 05:00 07:15 2.25 7,659 0 COMPZ RPCOM PRTS P Test tubing to 3000 PSI f/ 10 min on chart, change out leaking valve. Re -test, good. Bleed tubing pressure down to 2500 PSI and pressure up IA t/ 3500 PSI, hold test for 30 min, good. 07:15 07:30 0.25 0 0 COMPZ RPCOM PRTS P Increased tubing pressure to 4000 PSI, observed tubing shear out sub open. Pressure bled off confirming SOS opened. 07:30 08:00 0.50 0 0 COMPZ RPCOM OWFF P Monitor well, static. 08:00 08:15 0.25 0 0 COMPZ WHDBO RURD P R/D circulating equipment, landing joint. Cut and cap control line. 08:15 08:30 0.25 0 0 COMPZ WHDBO SEQP P Install BPV as per Cameron rep. 08:30 09:30 1.00 0 0 COMPZ WHDBO OTHR P Clean and clear floor, SIMOPS blow down kill and choke lines. 09:30 09:45 0.25 0 0 COMPZ WHDBO SFTY P Hold PJSM on N/D BOPE 09:45 11:00 1.25 0 0 COMPZ WHDBO NUND P N/D BOPE 11:00 13:30 2.50 0 0 COMPZ WHDBO NUND P Install dart on BPV, making BPV a TWC as per Cameron rep. Prep well head to install tree. N/U Tree 13:30 14:15 0.75 0 0 COMPZ WHDBO PRTS P Test tubing hanger pack -off to 250/5000 PSI f/ 30 min, good. 14:15 15:00 0.75 0 0 COMPZ WHDBO PRTS P R/U and test tree to 250/5000 PSI f/ 5 min, good. 15:00 16:00 1.00 0 0 COMPZ WHDBO RURD P R/U scaffolding in cellar, SIMOPS R/U to UD drill pipe. 16:00 16:30 0.50 0 0 COMPZ WHDBO SEQP P Remove TWC as per Cameron rep. 16:30 17:00 0.50 0 0 COMPZ WHDBO RURD P R/U circulating lines in cellar f/ displacement. 17:00 17:15 0.25 0 0 COMPZ WHDBO SFTY P Hold PJSM on UD 4" drill pipe f/ derrick. 17:15 18:15 1.00 0 0 COMPZ WHDBO PULD P UD 4" drill pipe while LRS mobilizing to location. 18:15 18:45 0.50 0 0 COMPZ WHDBO RURD P R/U LRS to pump sea water and diesel. 18:45 19:00 0.25 0 0 COMPZ WHDBO SFTY P Hold PJSM w/ crew and LRS on displacing well. 19:00 22:00 3.00 0 0 COMPZ WHDBO DISP P Displace well f/ 11.8 ppg brine to Inhibited sea water and diesel through choke @ 1.5 BPM, ICP= 150 PSI, FCP= 2000 PSI. Pumped a total of 208 bbls of Inhibited brine and 70 bbls of diesel. Lost 11 bbls of fluid during displacement. SIMOPS, cont t/ UD 4" drill pipe while displacing. 22:00 00:00 2.00 0 0 COMPZ WHDBO FRZP P Allow freeze protect to U -tube. SIMOPS, cont to UD 4" drill pipe. 05/10/2013 Set BPV. UD drill pipe and rig down. Release rig @ 6:00 hrs Page 16 of 17 Time Logs • • Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 01:00 1.00 0 0 COMPZ WHDBO PULD P PJSM, cont to L/D 4" drill pipe. 01:00 01:15 0.25 0 0 COMPZ WHDBO SFTY P Hold PJSM on P/U lubricator and setting BPV 01:15 01:45 0.50 0 0 COMPZ WHDBO RURD P Blow down lines in cellar. SIMOPS, clean pits and R/D glycol lines. 01:45 03:30 1.75 0 0 COMPZ WHDBO SEQP P Pressure test lubricator to 2000 PSI. Set BPV as per Cameron rep. Tubing pressure= 1200 PSI and IA pressure 1160 PSI. Secure well and clean cellar. 03:30 04:30 1.00 0 0 COMPZ MOVE PULD P Cont. to L/D drill pipe from derrick. 04:30 05:00 0.50 0 0 COMPZ MOVE DMOB P L/D mouse hole, clean drip pan and pull skate. 05:00 05:15 0.25 0 0 COMPZ MOVE SFTY P Hold PJSM on R/D and move rig. 05:15 06:00 0.75 0 0 COMPZ MOVE DMOB P Remove scaffolding in cellar. Release rig @ 6:00 hrs. Page 17 of 17 3C -09 Post 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 Ibs 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. • OF Ti P' \\ \I %% THE STATE Alaska and Gas ALASKA servation Commission � GOVERNOR SEAN PARNELL 333 West Seventh Avenue 0.A � Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 James Ohlinger Senior CTD Engineer ' s- 10 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3C -09 MAY 2 �� Sundry Number: 313 -242 SCANNED Dear Mr. Ohlinger: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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. Sin ere , dl �an Commissioner DATED this 7/f day of May, 2013. Encl. STATE OF ALASKA E r'. AA OIL AND GAS CONSERVATION COMIIIION APPLICATION FOR SUNDRY APPROVALS M " 1 4- 20 20 AAC 25.280 1. Type of Request: Abandon I- Rug for Redrill 9 • Perforate New Pool j'"" Repair w ell f Change A W{"" Suspend E Plug FZ'rforations 9 • Perforate I""" Rill Tubing i°"" Time Extension ("`°' Operational Shutdow n E Re -enter Susp. Well E Stimulate f Alter casing r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r`° Exploratory I- 185 -100 ' 3. Address: Stratigraphic I — Service )y . 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 21355 -00 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 9 3C - • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25629, 25634 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 8217' 6711' none none 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, 7838 -7850, 7949 -7996, 8018 -8040 6392 -6402, 6437 -6445, 6515 -6549, 6565 -6581 3.5 L -80 7659 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER FHL RETRIEVABLE PACKER ' MD= 7666 TVD= 6317 PACKER - BAKER F -1 PERMANENT PACKER , MD= 7804 TVD= 6413 SSSV - CAMCO TRMAXX- CMT -SR5 SSSV , MD =1822 TVD =1822 12. Attachments: Description Summary of Proposal 9 13. Well Class after proposed work: Detailed Operations Program f BOP Sketch r Exploratory E Stratigraphic I"" Development r Service 9, 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/1/2013 Oil 1 — Gas r WDSPL r Suspended 9 16. Verbal Approval: Date: WINJ E GINJ r WAG r Abandoned E Commission Representative: GSTOR 1 SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James Ohlinger @ 265 -1102 Email: James.J.Ohlinoerecop.com Printed Name James Ohlin r Title: Senior CTD Engineer Signature -.0...s* Z��_ __ ` -.1 Phone: 265-1102 Date 5 �.3/� ' Commission Use Only Sundry Number: 51 3 - 2, q 2. Conditions of approval: Notify Commission so that a representative may witness ✓ / `� Plug Integrity f BOP Test Mechanical Integrity Test I Location Clearance r RBDMS MAY 2 1 2018\ Other: ,SG'P ,tre5 f fo 1 p 5. c. /llit-rr�a! p) p1, 4.5 cr�ch A. ppro VC G p� ..0 AA 25 ,l1Zl�� Spacing Exception Required? Yes ❑ N. / MIS$IONER Subsequent Form Required: / — 42 Approved by: THE COMMISSION Date: Approve • • 1 . i • is vale for !2 months from the date of approval. �FQrm 1 0- 403 wise lO ��I,� 1 . IGINAL J ( r 1 Submit Form a Ate Duplicate � � �,�, 5 2 13 06 5 tb • • KRU 3C -09 CTD Summary for Perforating & Plugging Sundry (10 -403) Summary of Operations: Well 3C -09 is a Kuparuk A-sand/B-sand injection well equipped with 3'/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 existing B -sand perfs in 3C -09 will be plugged V with cement to provide a means to kick out of the 3 -1/2" and 7" casing. The existing A -sand perfs will be plugged off with a packer in the tubing tail. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A & B -sand perfs in this manner. After plugging off the existing B -sand perfs with cement, a mechanical whipstock will be placed in the 3 -1/2" tubing tail at the planned kickoff points. The mechanical whipstock will be attached to the packer below and isolate the existing A -sand perforations. 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 CTD Drill and Complete 3C -09 Laterals: June 2013 Pre -CTD Work 1,-) 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 5. RU Eline: GR/CCL for jewelry correlation log 6. RU Eline: Perforate tubing tail at 7827 -7832' RKB 7. RU coil: Place sand plug from PBTD up to the tubing tail. 8. RU coil: Cement Squeeze B -sand perforations. 9. RU slickline. Tag top of cement and pressure test. RD slickline. 10. RU coil: Mill out cement in the 3 -1/2" tubing down to the tubing tail. 11. RU coil: Fill clean out of the sand plug in the 7" casing 12. RU Eline: Set Packer /Whipstock 13. Prep site for Nabors CDR2 -AC, including setting BPV et -r COAGvr . ,b c C, ' v; f $4v /' f /NP(ovt ft4vO/r � V � 0 * 074 To /t'• /°' Gt �NG� gad I , i �'f /'C CQvC'rw -from j�t�'S fr/ti i y *5 Page 1 of 2 5/8/2013 • • • • Rig Work 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7- 1/16" BOPE, test. p TD 2. 3C -09L1 Sidetrack (A3 sand, south) a. Mill 2.80" window at 7,855' 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 3'h" tubing tail 4. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2 -AC. Post -Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Return to injection Page 2 of 2 5/8/2013 • KUP • 3C -09 - Conoc 031 Well Attributes Max Angle & MD TD Alaska, Inc. Wellborn API/UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) Goiax 500292135500 KUPARUK RIVER UNIT INJ 49.25 4,825.00 8,315.0 °° Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: TRDP Last WO: 5/10/2013 34.59 7/12/1985 Well Confer - 32-09, 5/102013 1:Oa:41 PM Schematic - 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,26 f 1 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (8... Set Depth (TVD) .. String Wt... String String Top Thrd CONDUCTOR 16 15.062 36.0 116.0 116.0 65.00 H -40 WELDED I Casing Description String 0... String ID ... Top (51(8) 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 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 Tu bing String Tu bing De String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrtl TU BING WO I 3 1/2 I 2.992 I 26 7 6 9 L -80 EUESrd CONDUCTOR, Completion Details 36 -116 Top Depth (TVD) Top Intl Nomi... Top (ftKB) (ftKB) r) Item Description Comment ID (in) SAFETY VLV, ,G. 1 26.3 26.3 - 0.15 HANGER CAMERON TUBING HANGER 2.860 1,822 MI 1,822.3 1,822.3 0.55 SAFETY VLV CAMCO TRMAXX- CMT -SR -5 SCSSV w/ 2.813" X- Profile ('1822) 2.812 IIIII 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 LIFT, ;: Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 2.521 UPPER PACKER 3 1/2 2.992 7,643.3 7,808.8 6,416.2 9.30 L -80 EUE ASSY Completion Details Top Depth (TVD) Top Inc' Nomi... Top (ftKB) (ftKB) (1 Item Description Comment ID (in) SURFACE, __ 7,643.3 6,300.8 46.38 PBR 20 PBR SEAL ASSEMBLY (pinned to 40k Ibs to shear) 2.990 L 35 - 3,943 , 7,666.4 6,316.8 45.49 PACKER BAKER FHL RETRIEVABLE PACKER (Min ID =3 ", 60k Ibs shear) 2.900 I 7,719.5 6,353.9 46.03 NIPPLE HES 'X' NIPPLE 2.812 GAS LIFT, ` 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 ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LOWER PACKER 3 1/2 2.992 7,803.5 7,920.0 6,494.8 9.30 L - 80 EUE8rd GAS LIFT, ASSY 5,794 j Completion Details Top Depth (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) 1 Item Description Comment ID (in) GAS LIFT, f: 7,803.5 6,412.5 45.48 PACKER BAKER F - 1 PERMANENT PRODUCTION PACKER 4.000 6,932 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, , Perforations & 7,580 i Shot Top (TVD) Btm(TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (eft.. 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, _ _ 7,949,0 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 SEAL ASSY, ,637 7,637 , 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 Notes: General & Safety End Date Annotation IMI 7/15/2010 NOTE: View Schematic w/ Alaska Schematic9.0 MI In INJECTION, 7,773 IPERF, _ 7,7747,789 - ® . m _ PACKER, 7,804- - _,i I 685, 7,807 IPERF, - 7,838 -7,850 Mandrel Details _ Top Depth Top Port S... (ND) Inc! OD Valve Latch Size TRO Run N... Top (ftKB) (ftKB) (°) Make Model (!n) Sew Type Type (!nl (pad) Run Date Com... 1 2,520.6 2,520.2 5.48 Camco MMG I 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/9/2013 SOS, 7,919 i 2 4,189.2 3,913.6 47.49 CAMCO MMG 1 1/2 GAS LIFT 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, ill 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 - 7,998 5 7,580.2 6,257.3 46.44 CAMCO MMG 1 1/2 GAS LIFT SOV DCR 0.000 0.0 5/9/2013 IPERF. . 6 7,772.6 6,390.8 45.63 CAMCO MMG 1 12 INJ DMY RK 0.000 0.0 5/9/2013 8,018 -6,040 -. PRODUCTION, 28-8,299 ■ TD,8.315 • • 3C -09 Proposed CTD Sidetrack CD 16" 65# H -40 ■ shoe @ 116' TRMAXX- CMT -5 -SR @ 1822' TVD 9 -5/8" 36# J -55 shoe @ 3943' MD I3 -1 /2" GLMs @ 2521 , 4189 , 5794 , 6932 , 75801 (Baker PBR @ 7643' RKB; 2.99" IDI Baker FHL Packer @ 7666' RKB; 2.90" IDI 12.813" X Nipple @ 7720' 7773' - Injection mandrel C -sand perfs Baker F -1 Packer @ 7804' mg 7774' -7789' MD .- Baker 80-40 SBE © 7807' Tubing Tail Perforations B -sand perts 7838' -7850' MD ° i n" w I "\!5*. 3 -1/2" Weatherford Starburst Hollow WS tray @ anchored w/ WSR -BB ' * pe rf'd post -CTD to regain existing pert injection A3 south Tubing Tail @ 7919' MD` • � � iS TD @ 10700' MD i Billet @ 8600' MD i A -sand perts s '4' ii. Iiiiir 7949' - 7996' MD * , 8018' - 8040' MD litWillitN, -„, iii., --------- _ ----- ____ ----- _-- --------------------------- 3C- 09L1 -01 , � Existing perfs covered with A2 north a - sand prior to plugback (or RWO). Mill out cement in TD @ 11250' MD 7" 26# J -55 shoe ? 3 -1/2" TT and perform FCO @ 8299' MD '' prior to setting WS. • • Ferguson, Victoria L (DOA) From: Ohlinger, James J < James .J.Ohlinger @conocophillips.com> Sent: Tuesday, May 21, 2013 12:25 PM To: Ferguson, Victoria L (DOA) Subject: RE: 3C -09 Sundry I'm finishing the PTD currently. I was waiting on the new jewelry log to confirm the kick of location and directional I plans. I expect to move to 3C -09 June 14th, with Pre -Rig (Sundry work) to start immediately. Thanks 1. 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 maxipum pressure m 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. 2. 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. From: Ferguson, Victoria L (DOA) [mailto :victoria.ferguson ©alaska.gov] Sent: Tuesday, May 21, 2013 12:12 PM To: Ohlinger, James J Subject: [EXTERNAL]RE: 3C -09 Sundry I will need a MPSP and a BOP test pressure - From: Ferguson, Victoria L (DOA) Sent: Tuesday, May 21, 2013 11:56 AM To: 'Ohlinger, James 3' Subject: RE: 3C -09 Sundry It's in review. I haven't seen the PTDs for the laterals? I s June 1, 2013 still the date for commencing operations? 1 • Page 1 of I Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS ( IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art f or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. • • o l \ \I A+ THE STATE Alaska Oil and Gas Fes '�' OJALAS� Conservation Commission OF R GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAg� ' Main: 907.279.1433 Fax: 907.276.7542 Brett Packer Wells Engineer t � ConocoPhillips Alaska, Inc. u 0 P.O. Box 100360 v Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3C -09 Sundry Number: 313 -169 Dear Mr. Packer: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, Cathy P. oerster Chair DATED this l I da y of April, 2013. Encl. ` STATE OF ALASKA AA OIL AND GAS CONSERVATION COMMON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon E Rug for Redrill 1 Perforate New Pool j"" Repair w ell f T Change Approved Program [ Suspend r Rug Perforations E Perforate E Rill Tubing 9" s Time Extension E Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing E Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development I Exploratory 1- 185 - 100 . 3. Address: 6. API Number: Stratigraphic r Service {�• . P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21355 - 00 • 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 E No Wo 3C - 9. Property Designation (Lease Number): PI 10. Field /Pool(s): ADL 25629 J 1 'tl 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 8217' 6711' • 7905' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 116' 116' SURFACE 3908 9.625 3943' 3748' PRODUCTION 8271 7 8299' 6773' 1 i.,:. ' ., ,,,., s., T! ' — Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7774 - 7789, 7838 - 7850, 7949 - 7996, 8018 - 8040 6392 - 6402, 6437 -6445, 6515 -6549, 6565 -6581 2.875 J - _ 7913 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - CAMCO HRP -1 -SP PACKER MD= 7626 TVD= 6289 PACKER - BAKER DB PACKER MD= 7885 TVD= 6470 SSSV - CAMCO TRDP -1A -SSA SSSV MD =1797 TVD =1796 - 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program BOP Sketch r Exploratory E Stratigraphic I" Development F Service W. - 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/4/2013 Oil E Gas i — WDSPL J Suspended f 16. Verbal Approval: Date: WINJ r GINJ r' WAG R%- Abandoned E Commission Representative: GSTOR E SPLUG F 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer © 265 -6845 Email: J.Brett.Packer(conocophilligs.com Printed Name Brett Packer Title: Wells Engineer Signature 'i -c-,--G`_ Phone: 265-6845 Date y.�® 3 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3 / 3_./ & I Plug Integrity E BOP Test Mechanical Integrity Test E Location Clearance t •,.. Other: 0,0 p 3 S. Ps ' � �` �� APR 1 �f `+II►- r 1- M 20 Spacing Exception Required? Yes ❑ No [/ Subsequent Form Required: / G - T,% 4 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: /1 _- /i /---, A pp oved application is valid tor 12 months from the date of approval. F Rt ( ve 201 ) L 17/-4;: Submit Form and Attachments in Duplicate '6 ply ° 1 '3 - fW5 v\�,`� • • ConocoPhillips ' ` Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 April 3, 2013 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to workover Kuparuk Injector 3C -09 (PTD# 185 -100). 3C -09 was originally drilled & completed as a 2 ' /8" selective single A &C sand pre - produced injector in 1985. It was on production for a couple years initially before it was converted to an injector. Other than being down for a couple years between 2002 -2004 waiting on a flowline repair, this well has been a good injector averaging -700 BWIPD. 3C -09 along with its paired producer (3C -10) have both been chosen as CTD candidates to be drilled into adjacent fault blocks that were identified as lacking adequate offtake points and injection support. Both wells require RWO's to upsize the tubing to 3 ' /2" for CTD. This well was SI in August 2012 in an effort to reduce the reservoir pressure in this area prior to CTD drilling. The current completion has the A -sands isolated from the Unit B & C -sands behind the selective. The proposed workover plans are simply to pull the current 2 '/8" selective and replace it with a 3 - /2" selective, except placing the bottom packer between the Unit B & C -sands so that the C- sand only is isolated behind the selective. The future CTD plans are to kick off below the bottom packer in the B -sands and target the A -2 & A -3 sands. If you have any questions or require any further information, please contact me at 265 -6845. Sincerely, Brett Packer Wells Engineer CPAI Drilling and Wells KUP • 3C -09 •ConocoPhiflips We ll We ll Attributes Max Angle & MD TD 7daSka Inc Well bore APUUWI Field Name Well Status Intl ( °) MD (ftKB) Act Btm (ftKB) anso,o.'tot9p9 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 • "' SSSV: TRDP Last WO: 34.59 7/12/1985 Well Coffin: - 3C -09, 3/8/2013 3'.12:27 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 8,013.0 2/28/2013 Rev Reason: TAG, SET PLUG haggea 3/8/2013 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 36.0 116.0 116.0 65.00 H - 40 WELDED • HANGER, 34 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 - BTC • • Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... 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 (TVD) ... String Wt... String ... String Top Thrd TUBING I 2 7/8 I 2.441 I 33.6 I 7,913.4 I 6,490.1 I 6.50 I J -55 8RD EUE ' CONDUCTOR. Completion Details 3 8-116 Top Depth - -- (TVD) Top Intl Nemi... SAFETY VLV, ° Top (kKB) RKB) ( °) Item Description Comment ID (in) 1,796 - 33.6 33.6 - 0.02 HANGER CAMERON TUBING HANGER 2.875 GAS LIFT. 1,796.5 1,796.4 0.51 SAFETY VLV CAMCO TRDP -1A -SSA 2.310 1,838 IIII 7,608.0 6,276.5 46.34 SBR CAMCO OEJ SBR 2.297 GAS LIFT. 7,625.5 6,288.6 46.36 PACKER CAMCO HRP -1 -SP PACKER 2.441 3,292 7,772.6 6,390.8 45.63 BLAST RINGS CARBIDE BLAST RING (1) 2.441 II 7,834.3 6,434.1 45.38 BLAST RINGS CARBIDE BLAST RING (1) 2.441 7,883.4 6,468.7 44.89 LOCATOR BAKER LOCATOR SUB w/ 9.40' SEALS IN PACKER 3.000 7,885.4 6,470.1 44.83 PACKER BAKER DB PACKER 3.250 S 353,943 7,889.1 6,472.7 44.71 SBE BAKER SEAL BORE EXTENSION 2.437 GAS LIFT. 7,905.3 6,484.3 44.68 NIPPLE CAMCO D NIPPLE NO GO 2.250 4,571 7,912.7 6,489.6 44.66 SOS CAMCO SHEAROUT SUB 2.375 IIIII GAS LIFT. Other In Hole (Wirellne retrievable plugs, valves, pumps, fish, etc.) 5.327 Top Depth .___ (TVD) Top Intl GAS LIFT, Top (ftKB) (ftKB) 1°I Description Comment Run Date ID (in) 5,671 7,905.3 6,484.3 44.68 PLUG 2.25" CA -2 PLUG w /GAUGES (OAL =13.6) IN NIPPLE 3/1 /2013 0.000 El GAS LIFT Perforations & Slots 6,051 Shot M I Top (TVD) Btm (TVD) Dens GAS LIFT, _.. !� Top (ftKB) Btm (MKS) (ftKB) )kKB) Zone Date (• Type Comment 6,430 ��[` 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 GAS LIFT, 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 8,870 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 GAS LIFT, 7,218 ° 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 GAS LIFT, Notes: General & Safety 7587 End Date Annotation 1-1 7/15/2010 NOTE: View Schematic w/ Alaska Schematic9.0 SBR, 7.608 }I-!I 10/17/2012 NOTE: RIGS' DIFFERENT RKBs ACCOUNT FOR TUBING/CASING TOPS PACKER, 7,828 � �l�,Ij , INJECTION, 7,665 INJECTION. r 7,734 IPERF, a .J., i :,,:::,: 7,7747,789 IPERF, T 7,838 -7,850 - , I - .t ii • INJECTION. 7,871 LOCATOR. 7,883 PACKER. 7,885 ( SBE, 7,889 II NIPPLE, 7,905 a3= Mandr D etails PLUG, 7,905 .t /' Top Depth Top Port L (TVD) Intl OD Valve Latch Size TRO Run N... Top MB) (ftKB) PI Make Model (in) Sery Type Type (in) (psi) Run Date Com... SOS. 7.913 1 1,836.1 1,836.0 0.60 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 8/4/1985 2 3,292.3 3,248.3 30.00 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 8/4/1985 3 4,571.3 4,168.0 48.32 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 8/4/1985 7,949 -7,998 4 5,326.6 4,681.3 44.76 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 8/4/1985 5 5,671.3 4,924.9 44.97 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 8/4/1985 IPERF, Ull 8.018A,040 6 6,051.1 5,191.6 46.43 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.08/14/1985 7 6,429.5 5,461.7 45.15 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 8/4/1985 8 6,869.7 5,770.2 45.22 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 8/4/1985 9 7,217.5 6,009.5 48.68 MERLA KBMG 1 GAS LIFT DMY BK 0.000 0.0 8/4/1985 PRODUCTION, 28 - 6299N 4 10 7,567.0 6,248.2 46.46 CAMCO TGPD 1 1/2 GAS LIFT DMY TG 0.000 0.0 2/23/1988 TD, 8,315 KUP • 3C -09 ConocoPhillips ; Alaska, Inc. • KB -Grd (ft) Rig Release Date •" _ 34.59 7/12/1985 Well Confiq: - 3C-09,318/2013 3:12:27 PM Schematic - Actual 1 " HANGER, 34 , CONDUCTOR, 36-116 I.:.... –..—, SAFETY VL 1,796 GAS LIFT, 1,836 GAS LIFT, 3,292 SURFACE, ,I L. 35 -3,943 GAS LIFT, 4,571 GAS LIFT,.,. 5,327 GAS LIFT, 5,877 GAS LIFT, 6,051 GAS LIFT, 6,430 GAS LIFT, _ 6,870 P1 GAS LIFT, I'... 7.218 f GAS LIFT, _ 7,567 SBR,7,608 v. � p PACKER, 7,628 INJECTION, 7,665 INJECTION, 7,734 IPERF, 7,774'7,769 IPERF, 7,838 -7,850 .. j I li INJECTION, 6; 7,871 LOCATOR, (.. j.. 7,883 T I PACKER, 7,885 SBE, 7,889 NIPPLE, 7,905 Mandrel Details PLUG, 7,905 Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run N... Top (ftKB) (ftKB) (9 Make Model (in) Sery Type Type (in) (psi) Run Data Com... SOS, 7,913 11 7,664.7 6,315.6 45.45 CAMCO KBMG 1 INJ DPCV BEK 0.000 0.0 8/18/2009 12 7,734.1 6,364.0 45.96 CAMCO KBMG 1 INJ DPCV BEK 0.000 0.0 8/18/2009 13 7,870.9 6,459.9 45.29 CAMCO KBMG 1 INJ DPCV BEK 0.000 0.0 8/18/2009 IPERF, 7,949 -7,996 _.._ IPERF, E_`= 8,018-8,040 PRODUCTION, 28 -8,299 N., A TD, 8,3151 • • 3C-09 Rig Workover Pull 2'/8" Selective, Install 3 1 /2" Selective (PTD #: 185 -100) Current Status: This well has been SI since 8/10/12 in order to reduce the reservoir pressure in the area due to upcoming CTD drilling. This well along with 3C -10 have been selected as a CTD candidates, but require rig workovers to upsize the tubing to 3 'A". Scope of Work: Pull the current 2 ' /8" selective and install a 3 ' /2" selective. General Well info: Well Type: Injector MPSP: 1,800 psi using max recent SITP on 2/28/13. Reservoir Pressure /TVD: 3,942 psi / 6,484' TVD (11.7 ppg) from Panex gauges on 3/7/13. Wellhead type /pressure rating: CIW Gen 4, 7- 1/16" 5M psi top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: MIT -IA & MIT -OA passed on 3/31/13. Earliest Estimated Start Date: May 4, 2013 Production Engineer: Suzanne Short/ Toon Changklungdee Workover Engineer: Brett Packer (265 -6845 / j.brett.packer @cop.com) Pre -Rig Work 1. RU Slickline: a. Lock out SSSV. b. Pull DV @ 7,567' MD and leave pocket open. 2. RU E -line: a. RIH & fire a string shot at 7,755' MD. POOH. b. RIH & fire a string shot at 7,591' MD. POOH. c. RIH w/ RCT cutter and cut the tubing at 7,755' MD. POOH. d. RIH w/ RCT cutter and cut the tubing at 7,591' MD. POOH, RDMO. 3. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure 1. MIRU. 2. Pull BPV. Kill Well. ND tree, NU BOPE & test. 3. POOH laying down 2 -7/8" tubing. 4. MU overshot and RIH to fish OEJ free from slickstick. 5. RBIH w/ overshot and fish HRP -1 -SP packer. 6. RBIH w/ T -dog sub and 110' of washpipe to washover blast rings, latch onto tubing collar below blast rings and pull seal assembly from SBE. 7. RIH w/ packer mill and mill the Baker DB packer at 7885' MD. 8. MU spear and RIH to retrieve DB packer. 9. RIH w/ cleanout assy. and c/o to float collar at 8217' MD. 10. RIH w/ RCJB, boot baskets, and casing scraper to 8217' MD. 11. MU F -1 packer & tailpipe assembly and set in the slips. -09 Rig Workover • 3C g Pull 2 Selective, Install 3 1 /2" Selective (PTD #: 185 -100) --Procedure Continued-- 12. RU E -line: Run packer on depth, set packer at 7,815' MD, RD E -line. 13. MU seal assembly and FHL selective completion, RIH on drillpipe to just above the F -1 packer. 14. Spot corrosion inhibited brine in the IA below the FHL packer. 15. Sting into SBE, pressure up to set the FHL packer. PT IA to 3,000 psi. Bleed pressure off. Shear the PBR. a. On TOH, if packoffs need replaced, set a storm packer, NDBOP & Tbg head, replace packoffs & tubing head, NU BOP & test, release storm packer. 16. RIH w/ new 3 -1/2" completion and sting into PBR, space out 7 ft, mark the pipe and pull out of PBR. 17. Space out w/ pups, MU hanger. Circulate well full of corrosion inhibited seawater. Land the hanger, RILDS. 18. PT the tubing & IA, shear the SOV. 19. Install two -way check, ND BOPE, NU and test tree. Pull two -way check. 20. Freeze protect through the SOV, set BPV. 21. RDMO. Post -Rig Work 1. Reset well house(s) and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: Pull SOV, run DV. 4. Turn well over to operations /CTD. • • 3C -09 Proposed RWO setup for CTD 16" 65# H-40 shoe @ 116' MD sv TRMAXX- CMT -5 -SR @ 1800' TVD J 9 -5/8" 36# J -55 shoe @ 3750' MD 3 -1/2" GLMs @ TBD 3 -1/2" EUETbg Upper Straddle Packer 2.813" X Nipple - Injection mandrel or sliding sleeve C - sand perfs _ 7774' - 7789' MD — Lower Straddle Packer /SBE @ 7815' MD B -sand perfs = I 1 - -- _- 7838' -7850' MD 2.813" X Nipple 3 -1/2" WLEG A -sand perfs 11 - 7949' - 7996' MD 9018' - 8040' MD = - - - 7" 26.0# J -55 shoe @ 8299' MD WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 3C-09 Run Date: 12/8/2009 December 15, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3C-09 Digital Data in LAS format, Digital Log Image file, Interpretation Report 50-029-21355-00 Injection Profile Log ~ ~. R?1~~~~ ~F d ~ ~' 1 ~'1~' 50-029-21355-00 1 CD Rom 1 Color Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating ~= C Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@,haJlihurton.com - __, ~ ~~ r'~ Date: ~~~~9 Signed: • ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhillips Alaska Inc. FIELD / UNIT / PAD: Kuparuk / KRU / 3C ~e~~ ~I 17 ~°! i O~ DATE: 08/09/09 l~ D b ~ OPERATOR REP: Bates / Hurley / Phillips - AES ~~ ~' ~ AOGCC REP: Chuck Scheve waived right to be present ~~ Packer Depth Pretest Initial 15 Min. 30 Min. Well 3C-12 Type Inj. W TVD 6,257' Tubin 2,900 2,900 2,900 2,900 Interval 4 P.T.D. 1850990 T pe test P Test psi 1564 Casin 1,000 2,000 1,950 1,950 P/F P Notes: OA 450 550 580 580 Well 3C-09 Type Inj. W ND 6,290' Tubin 2,900 2,900 2,900 2,900 Interval 4 P.T.D. 1851000 Type test P Test psi 1573 Casin 575 ' 2,000 1,940 1,940 P/F P Notes: OA 240 410 410 410 Well 3C-07 Type Inj. W TVD 6,262' Tubing 2,875 2,875 2,875 2,875 Interval 4 P.T.D. 1851560 Type test P Test psi 1566 Casing 1,030 1,980 1,940 1,930 P/F P Notes: OA 530 650 650 650 Well 3C-05 Type Inj. N TVD 6,326' Tubing 760 760 760 760 Interval 4 P.T.D. 1851540 Type test P Test psi 1582 Casing 550 2,000 1,900 1,870 P/F P Notes: OA 230 420 420 420 Well Type Inj. ND Tubin Interval P.T.D. T pe test Test psi Casing P~F Notes: OA Well Type Inj. Tl/D Tubing Interval P.T.D. Type test Test psi Casing P~F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casin P~F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test P Test psi Casing P~F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test P Test psi Casing P~F Notes: OA / TYPE INJ Codes D = Drilling Waste G=Gas I = Industriai Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R= Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test ~., . ''"?~ _ ^.'~C+ . %11~~~~ INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Va~iance T = Test during Workover O = Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 3C pad 08-09-09.xis ~ ' ' : ~ ~ . . ConocoPh i I I ~ ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 3, 20Q9 Mr. Tom Maunder ~;~;;'~`~~~,,: ~ ~ s_ ~ ° ` ~ t~ u ~ Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ ~~~~IVE~ ~ ~uL o ~ Zoo9 ~las~a tlil ~ Gas Cons. Commissi~n ~r~ch~s ~~~ $sf ~d~ ~ 3G~ ~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion i.nhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification tha.t the trealments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped June 16~' & 26~', 2009 and the corrosion inhibitor/sealant was pumped June 23rd & 30~', 2009. The attached spread.sheet presents the well name, top of cement depth prior to filling, and volumes used on each conduotor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, .~~ ~%~~ c~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/3/09 3 C PAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ seafant date ft bbls ft al 3C-01 500292141300 1851870 22' 2.3 28" 6/26/2009 5.9 6/30/2009 3G02 500292141400 1851880 76' 10.0 22" 6/26/2009 5.1 6/30/2009 3C-03 500292141500 1851890 5' 1.0 21" 6/26/2009 5.1 6/30/2009 3C-04A 500292141601 2020570 4' 1.0 23" 6/26/2009 5.1 6/30/2009 3C-05 500292138900 1851540 24" Na 24" n/a 4.25 6/23/2009 3G06 500292109600 1840420 6" n/a 6" n/a 7.65 6/23/2009 3C-07 500292139100 1851560 37' 5.00 25" 6/16/2009 5.52 6/23l2009 3C-08 500292139000 1851550 12' 2.00 22" 6l16/2009 3.4 6/23/2009 3G09 500292135500 1851000 20" n/a 20" n/a 2.55 6/23l2009 3C-10 500292135600 1851010 30' 4.10 24" 6/16/2009 4.25 6/23/2009 3C-12 500292135400 1850990 45' 9.30 26" 6/26/2009 4.3 6/30/2009 3C-13 500292142400 1851980 20" n/a 20" Na 2.12 6/23/2009 3C-14A 500292142501 2071750 3' Na 3' Na 8.07 6/23/2009 3C-15A 500292142601 2080810 31' 4.40 26" 6l16/2009 2.75 6/23/2009 3C-16 500292142700 1852010 20" n/a 20" Na 2.12 6/23/2009 3C-17 500292338900 2080590 2'6" n/a 2'6" n/a 8.92 6/23/2009 ) MEMORANDUM TO: Jim Regg ,--7 Q( 1.-' P.I. Supervisor ~. ( 1[,,0") FROM: Jeff Jones Petroleum Inspector Well Name: KUPARUK RIV UNIT 3C-09 Insp Num: mitJJ050909114408 Rei Insp N urn Packer -w';ïï-1 3C-09 I~ T!.R~fuj ~ : P.T. L,l,.~~~,~~_¡TypeTest I Interval 4YRTST __._____P/F P Notes 2.7 BBLS diesel pumped, 1 well house inspected; no exceptions noted. Monday, September 12,2005 State of Alaska ) Alaska Oil and Gas Conservation Commission DATE: Monday, September 12,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHlLLIPS ALASKA fNC 3C-09 KUPARUK RIV UNIT 3C-09 Src: Inspector NON-CONFIDENTIAL API Well Number 50-029-21355-00-00 Permit Number: 185-100-0 Depth 6290 Pretest 1572. 5 I !~_h_ ______8~~, I OA 175 Tubing 2900 Initial 15 Min. 'r 345~_j, 3390 I 200 I 200 ¡ 290~.L__._.~~.~~ Š / \ 0° \Cù Reviewed By: P.I. Suprv '-~ Comm Inspector Name: Jeff Jones Inspection Date: 8/30/2005 30 Min. 45 Min. 60 Min. , -·-T------ 3:0: ! ---r---- 2900 ,l--·----- ._~---_..---- i ; ._________ ¡ 1;' """:"" ' i.l".' r: ~)) 7.'. fl' 'l,CI n~~,', 5Ç,hN~~t.L ,\ L. j, Page I of 1 MEMORANDUM TO: Julie Heusser Chairman ~, SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder .~.~-~..~c~ Phillips P.I. Supervisor~.~ '~"'~ ~ ~ 3C Pad FROM: Chuck Scheve Kuparuk Petroleum Inspector NON~ CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 15, 2001 Packer Depth Pretest Initial 15 Min. 30 Min. 3c-o2 JType,nj.I 'S 1 f:V.D;I So~-2 I Tubingl 3'25o '1 .3250 1.32.~. !'3250 llntervad 4 ~85-'i8~ ITypet=l .~; "lT~psil ~5!S '1,~=.~'1 ~350. I 2~80' I 2!00 I 2.~.°° I P/F I P 3C-05 i Type Inj. I 'S i i:.V.d. I ~ I'Tubing ! 2~ '1 2~0 I 28.~0.. I' 28.~. l,,te,,ad 4 ~s5-~54 IType'testl. 'P ITest.~l ~ I'Ca.~.Oi ~2ooI '2oso! 2.o4ol 2~ .I P/F I PI 3C-07 I Type~nj.I 'N I T:V.D. I' S'Z~2 l Tua"g I' 175~ I' ~7501 ~ I 1750 I* ~.r~l 4 ~r~ IT~. t~! ,P .. IT~.~I.. ~,~. l'c~.~'l ~'o0 I ~ol 2~ I. 2~o°1 ~F I _" 3c~ I T~pe'.j.! S IT:V-D- I s2~JO Itu~"l 2~01 2~-~0 i,~ I 2~0 I,.t~,l 4' ~oo ITvpetest. I' P ' ITestpSil"!~3 ,I.c~.~l .~100 I '.2~so ! 2~501 2~50, I P,/F ! 3c-~ i~-~-,,j.! ' s I ~-.~,.o. I' ~ '1 ~'u~"",l ~'1 ~"~°° 1'3°~ I 30oo"1,~il 4 'm5-o99 ITypetestl. P. i'restps~l '~.5~4 .IC'~s~.gl....450. I 2050 !..2000 I :~000 I .P/F I P 3C-i4 I Typ~ inj. I ' s" 1 T.V.b. I' ~3~s I Tubing I 3000 I '~x~O I 3000 I 3000. I~nte,v,,d 4 '~~'lTyPetestl P' IT~psil' ~5'7~ I Ca~n~l ~r~l 2r:,50 I 26251 2s25'1 'P/F I PI Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test IntervaJ I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to 3C Pad in the Kuparuk River Field and witnessed the 4 year Mechanical Integrity Test on 6 injection wells. The pretest pressures were observed and found to be stable. The standard annulus pressure tests were then performed with all 6 wells demonstrating good mechanical integrity. M.I.T.'s performed: _6 Attachments: Number of Failures: Total Time during tests: _5 c.c; MIT report form 5/12/00 L.G. MIT KRU 3C Pad 7-15-01 CS.xls 8/8/01 STATE OF ALASKA "-- ALASh,,~ OIL AND GAS CONSERVATION COMN,,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other [~ 2. Name of Operator ARCO Alaska, Inc At top of productive interval 1516' FSL, 1276' FWL, Sec. 12, At effective dap. th 1793' FSL, 1507' FWL, Sec. 12, ,~tl depth FS'L, 1553' FWL, Sec.12, Address PO Box 100360, Anchorage, AK 99510 Location of well at surface 1060' FNL, 901' FEL, Sec.!4, T12N, RgE, UH T12N, RgE, UM T12N, R9E, UM T12N, R9E, UM 11. Present well condition summary, Total depth: measured 8299' ND feet true vertical6775' TVD feet 5. Datum elevation (DF or KB) RKB 85' 6. Unit or Property name Kuparuk Riv~_r Unit 7. Well number 3C-9 t~ ~ ~,~or~ 8. Approval number #7-182 9. APl number 50-- 029-21355 10. Pool Kuparuk River 0il Pool Plugs (measured~(One Feet Effective depth: measured 8217' MD feet true vertical6711' TVD feet Junk (measured)Vanrl Gun @ 9264' Casing Length Size Structural Conductor 116' 16" Surface 3943' 9-5/8" xxx2:~X~cti~te Production 8299' 7" xxx~Xxxxx Perforation depth: measured Cemented Measured depth True Vertical depth 220 SX CSII 116' MD 116' TVD 1150 SX ASIII 3943' MD 3749' TVD & 300 SX Class G Top job w/lO0 SX ASI 400 SX Class G 8299' MD 6775' TVD & 180 SX Permafrost C 7774'-7789' MD, 7838'-7850' MD, 7949'-7996' MD, 8018'-8040 MD true vertical6393'-6403' TVD, 6438'-6446' TVD, 6516' -6550 TVD, 6566'-6582 TVD Tubing (size, grade and measured depth) 2-7/8", ,1-55, 6.5 lb/ft Tail ~ 7905' MD-RKB c Packersa[~d ~S~S~SV~(ty..p..e. _an~d measured deRth) amco HRP-Ibv L~ /bi/ ; Baker DB @ 7877'; Camco TRDP-1A SSA @ 1788' MD 12. Stimulation or cement squeeze summary ~ I\L~LI ¥ !.,I./ N/A Intervals treated (measured) Treatment description including volumes used and final pressure JUN 2 2 ]988 Alaska 011 & Gas Cons. Commission 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Anchorage Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 157 BOPD 203 MCFPD 0 BWPD 1625 psig 110 psig 0 BOPD 0 MCFPD 1159 BWPD 1000 psig 1600 psig 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,,./~(.~ /'~ .~~~'~ Form 10-4d4 'Rev. 12¢-88 Title Sr. Operations Engineer Date CL~ 7/~ Submit in uuplicate AAI KUPARUK RIVER UNIT MECHANICAL INTEGRITY TEST Location: ~z~,*~ ~V~,~ START I 15 HIN. I 30 HIN. I I TI~ I TT~ I ?~ I PR~ I I , COMMENTS I ,~(.~s- I ~ I ~ I__.?~p.~.~;s_ I ~1 I I I I I I I I I I I I I I l I I I I I I I l ,,,l I I I I I I l I I I I I I I I P : Produce Water In[. 3 : ~dklt Water Tn[. H -- le.i~lble Tn[. a : age Iai. I : lot Annular Fluid: Dle~el Glycol 3alt Water Drilling Mud Other Other Gradient: Company Rep. Signature: 11/20/86 . . ARCO Alaska, Inc. Post Office Bo.. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 17, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton- Attached in triplicate is an intent notice on Kuparuk Well 3C-9' Well Action Anticipated Start Date 3C-9 : Conversion } April 15, 1987 If you have any questions, please call me at 265-6840. Sincerely, G. B.~Smallwood Senior Operations Engineer GBS:pg:O080 Attachments cc: File KOE1.4-9 RECEIVED Oi~ & Gas Cons. Oom?.iss~on ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK._ ,3IL AND GAS CONSERVATION COMrv,. 51ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other ~ 5. Datum elevation (DF or KB). 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360: Anchorage: AK 99510 4. Location of well at surface 1060' .FNL, 9.01'. FEL, Sec. 1_4 T1_2N RgE UM At top ct proouctlve interva-~ ' ' ' 1516' FSL, 1_276' FWL, Sec. 12, T12N, RgE, UN At effective depth 1_793' FSL, 1_507' FWL, Sec.1.2, TI_2N, RgE, UN At total depth 1848' FSL; 1553' FWL: S~c.12= T1 ?N= RgE; IIM 11. Present well condition summary Total depth: measured 8299' MD feet true vertical 6775' MD feet RKB 85 6. Unit or Property name Kuparuk River Unit. 7. Well number 3C-9 8. Permit number Permit #85-100 9. APl number 50-- 029-21355 10. Pool Klinarm~k River ~il Ponl ! Plugs (measured)None feet Effective depth: measured 8217' HD feet true vertical feet 6711' MD Casing Structural Conductor Surface xx xk~tcx~c, te Production xxx kS xxxx Perforation depth: Junk (measured)Vann Gun (a 9264' Length Size Cemented Measured depth True Vertical depth 116' 3943' 8299' measured 16" 220 SX CSII 116' MD 116' TVD 9-5/8" 1150 SX ASIII 3943' MD 3749' TVD & 300 SX Class G Top job w/lO0 SX ASI 7" 400 SX Class G 8299' MD 6775' TVD & 180 SX Permafrost C 7774'-7789' MD, 7838'-7850' MD, 7949'-7996' MD, 8018'-8040' MD true vertica16393'-6403' TVD, 6438'-6446' TVD, 6516'-6550' TVD, 6566'-6582' RECEIVED Tubing (size, grade and measured depth) 2-7/8", J-55, 6.5 lb/ft Tail @ 7905' MD-RKB ,....,~,~,]l~'~"~ 9 ~..!~t7 .... Packers and SSSV (type and measured depth) ............. ~ ~..~, ~ ~ · ~, , ~ v ,.~ m, m ~., ,~, , , x~..,, ~.~ ,,.~ ~.~ ~ ~ - 12.Attachments Description summary of proposal [] Detailed operations program [] BOt:~.J~.etgh, [] Convert well from ell nrnduc~r tn water ~njertor 13. Estimated date for commencing operation Apri 1 15 ~ 1.987 Sut::c~c~ ;;'~,~-k ~t~r[ed o~ 14. If proposal was verbally approved ~orm No../,,o''': ~_ ~__._ ,_~_/, ¢OWDated/--/~ ~,__~ Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ,t,e Sr. 0,erat ons n ,eer Signed if// Commission Use Only Date3/17/87 Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approwd Cowy B~ LlMMIE C. [~11~ .. 'ommissioner i Approval by order of the commission Datej ~(-,~ "~7 /D Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Alaska,. Inc. Pos! Office Box 100360 Anchorage. 'Alaska 99510-0360 Telephone 907 276 1215 Date: March 7, 1988 Transmittal # 7115 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~3C-12 ~- 3C-5 3C-15 ~ ~..3C~-9 Bottom-Hole Pressure Survey(Injection Profile) Bottom-Hole Pressure Survey(Injection Profile) Bottom-Hole Pressure Survey Kuparuk Well Pressure Report(Otis) 6-25-86 6-24-86 8-26-87 1-4-88 Receipt Acknowledged: DISTRIBUTION: D & M State:of'~Alaska ' Chevron Mobil SAPC Unocal ARCO Alaska, Inc. Post Office b,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 13, 1987 Mr. C.V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 3C-15 Dear Mr. Chatterton. Enclosed is a copy of the Well History (completion details) to include with the 3C-15 Well Completion Report, dated 3-31-86. If you have any questions please call me at 263-4944. ' Sincerely, Gruber Associate Engineer JG'db GRU1/52 Enclosure xc- 3C-15 Well File RECEIVED JAN20 ~'"~' Alaska Oit & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Oil and Gas Co~, ~ny '~, = Daily Well History-Final Report Instructions: Prepare and submit the "Final Reporl" on the first We~dnesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District I County or Parish J Stale Alaska North Slope Borough Alaska Field IL .... or Unit I Well no. Kuparuk River ADL 25634 3C-15 Auth. or W.O. no. ~Title AFE 604941 I Completion Nordic #1 API 50-029-21426 Operator [ A.R.Co. ARco Alaska, Inc. Spudded or W.O. begun I Date I Complete Date and depth as of 8:00 a.m. 10/31/85 il/Ol/85 Old TD 11/02/85 Complete record for each day reported 7" @ 7826' W.I. 56.24% lo/31/85 Iotal number of wells (active or inactive) on thisI est center prior to plugging and I bandonment of this well our Prior status if a W.O, 0015 hrs. 7745' PBTD, Tallying 2-7/8" 10.1 ppg NaC1/NaBr A~qept rig .@ 0015 hfs, 10/31/85. Drift & tally 2-7/8" tbg. ND tree, NU & tst BOPE. 7" @ 7826' 7745' PBTD, Prep to rn 2-7/8" compl 10.0+ ppg NaC1/NaBr Fin tallying tbg. RIH w/bit & 7" scrprs, tag PBTD @ 7745', rev circ& filter hole cln, POOH. RU Schl, perf w/4" guns, 4 SPF, 90° phasing f/7567'-7582' & 7542'-7547'. Perf w/5" guns, 12 SPF, 120° phasing f/7346'-7362'. Rn JB w/6-1/8" gauge ring to 7738'-WLM. RIH, set 7" W-D permanent pkr w/top @ 7439' WLM, RD Schl. RU 'to rn 2-7/8" compl string. 7" @ 7826' 7745' PBTD, RR 6.8 ppg Diesel in tbg & ann RIH w/2-7/8" tbg & compl equip. PU SSSV & tst to 5000 psi. Fin RIH w/2-7/8" tbg compl assembly, space out & lnd tbg. Drop ball, set pkr & tst tbg to 2500 psi. Shear off OEJ, re-lnd tbg. Tst ann & pkr @ 2500 psi. Tst SSSV; OK. Shear out ball, bled press. ND BOPE, NU & tst tree to 5000 psi. Displ well to diesel. Tst tbg & orifice vlv; OK. Bled tbg to 550 psi. Set BPV. RR @ 2330 hrs, 11/1/85. WD Pkr @ 7349', "D" Nipple @ 7457'. SSSV @ 1800', tail @ 7465', HRP-1SP pkr @ 7196'. New TO Released rig Date 2330 hrs. Classificalions {oil, gas, etc.) 0il Producing method Flowing Potential test data PB Depth IK nd Of rg 11/1/85 IType completion (single, dual, etc.) - Single Offi(~ial reservoir name(s) Kuparuk Sands 7745' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test lime Produclion [Oil on test Gas per day · Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity AlloWable Effective date The above is correct Signature For form preparation an~ distribution, see Procedures Manual, Section Drilling, Pages 86 and 87. a~ pnnq ddmmi~ion Anchorage Drillin$ Superintendent ARCO Alaska, Inc. ' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 10, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 3C-9 Dear Mr. Chatterton. Enclosed is a copy of the 3C-9 Well History to include with the Well Completion Report, dated 09/10/85. If you have any questions please call me at 263-4944. ' Sincerely, . Gruber Associate Engineer JG/tw GRU13/L78 Enclosure RECEIVED F L iL.; 1 ~:~ lg 8 Alaska Oil & G?,s Cons. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AtlanticRichfieldCompany ,~ Daily Well History-Initial Report hlstrectlons: Prepare and submit the *'Initial R~rl" on the first Wednesday after a well is spudded or workover operetlons are started. Daily work prior to el)uddlng should be summarized on the form giving inclusive dates only. North Slope Borough IState Alaska no. 3C-9 District ~ County or Padsh Alaska I Field ILease or Unit Kuparuk River I ADL 25629 Auth. or W.O. rio. ITItle AFE 604887 I Drill Parker 191 AP1 50-029-21355 Operator ARCO Alaska, Inc. Spudded or W.O. begun IDate Spudded I Date and depth as of 8:00 a.m. 7/04/85 thru 7/05/85 7/06/85 thru 7/08/85 7/09/85 7/10/85 Complete record for each day reported A.R.Co's W.I. Hour Prior stalus f a W.O. 56.24% 16" @ 116' ~.,~O~i 2721' (~, POH WT. 9.8, PV 17, YP 13 PH 9.5, WL 14, Sol 10 Accept Rig @ 0100 hrs~ 7-4-85.gNU diverter &tst. PU BHA & drl to 2398' TOH, PU DD. TIH, drl to 2721'. POOH f/washout. 480', .8°, N70.5W, 479.98 TVD, -1.33 VS, N1.12, W3.16 966', .~o, S25W, 965.94 TVD, -6.66 VS, S2.01, W7.61 1477', .2e, N21.9W, 1476.93 TVD, -8.96 VS, S2.55, W10.42 2001', 1.5°, N68E, 2000.86 TVD, -2.38 VS, N3.89, W7.68 2511', 4.3°, N50.1E, 2510.60 TVD, 8.71VS, N6.05, E6.29 9-5/8" @ ~' ~ ~.~* ~ ' 5533' (2812'), Drlg ~L~ Wt. 9.2+, PV 10, YP 5, PH 10.0, WL 10~0, Sol 3 DD, drl & surv to 3960', short trip,/C&C hole f/csg. RU & rn 91 its, 36#, J-55, BTC 9-5/8" csg.//Cmt w/llSO sx AS III4 +7300 sx Cl "G" @ 15.8 ppg, FS @ ~, FC @ 3852'. Lost rtns bbls short of displm't. Displ using rig pmp, bump plug. ND diverter. Perform top job w/100 sx AS I. NU &tst BOPE. TIH, tst 9-5/8" csg. DO cmt, flt equip + 10' new formation. Conduct formation tst to 11.5 ppg EMW. Drl & surv 8½" hole to 5533'. 2918', 15.0°, N36.7E, 3141', 23.5°, N43.6E, 3662', 40.0°, N41E, 4117', 46.6", N40.TE, 4444', 47.3°, N44.1E, 4743', 47.8°, N40.5E, 5057', 46.1°, N40.2E, 9-5/8" 7403', Wt. 10. Rotary 5428', 6214', 6863', 2814.03 TVD, 58.79 VS, 42.65N, 40.47E 3117.68 TVD, 164.98 VS, 121.29N, 111.84E 3556.25 TVD, 444.02 VS, 323.38N, 304.28E 3875.86 TVD, 767.04 VS, 569.28N, 514.20E 4099.08 TVD, 1005.95 VS, 745.72N, 675.30E 4300.89 TVD, 1226.52 VS, 908.87N, ~23.7GE~.'~ 4515.23 TVD, 1455.73 VS, 1083.73N, 972.32E (1870'), Drlg O, PV 13, YP 12, PH 9.5, WL 6.9, Sol 7 & turbine drl 8½" hole to 7403'. 44.7°, N40.9E, 4775 TVD, 1719.66 VS, 1284.44N, 1144.05E 44.0°, N42.2E, 5332.07 TVD, 2274.46 VS, 1704.14N, 1507.45E 41.6°, N39.8E, 5790.50 TVD, 2733.46 VS, 2051.53N, 1807.92E 9-5/8" @~,~z,.3~/2' 8117', (714'), Drlg Wt. 10.2+, PV 10, YP 7, PH 9.5, WL 6.2, Sol 7 Drl 8½" hole to 8117'. 7364', 46.9°, N38.SE, 6135.36 TVD, 3096.06 VS, 2333.34N, 2037.36E 7861', 45.1°, N39.7E, 6480.59 TVD, 3452.74 VS, 2610.77N, 2262.82E The above is correct Signature L~ ~ ~'[D~" For form preparation and distribution, -- Drill ng, Pages 86 and 87. A~aska Oil & Bas Cons. Commission An chorage ^.~.4~..,-8 IDate/~ / J Title Drilling Superintendent Number all daily well hislory forms conseculively as they are prepared for each well. iPageln°. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of lime. On workovers when an official lest is r~ot required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District ICounty or Parish J Stale Alaska Alaska North Slope Borough Kuparuk River ADL 25629 3C-9 Auth. or W.O. no. ~Title AFE 604887 I Drill Parker 191 API 50-029-21355 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded IA.R.Co. W.I. 56.24% I Date 7/4/85 Complete record for each day reported Date and depth as of 8:00 a.m. Iotal number of wells (active or inactive) on this Dst center prior to plugging and ~ bandonment of this well I our (-~ J Prior stalus if e W.O. I 7/11/85 7/12/85 7/13/85 thru 7/15/85 Old TD Released rig 9-5/8" @ 8315', (198'), TOH to rn 7" Wt. 10.2, PV 13, YP 6, PH 9.0, WL 5.8, Sol 9 Drl to 8315', 20 std short trip, CBU, TOH to log. RU & rn DIL/FDC/CNL/GR f/8312' - surf. TIH, cond mud, POH, LD DP to rn 7'! , 7- @ .~e~ 8315', (0'), ND BOPE ? ~ / Wt. 10.2, PV 13, YP 6, PH 9.0, WL 5.8, Sol 9 TOH, LD DP. RU & rn 208 jts, 7", 26# BTC csg w/FS @ FC @ 8217'. Cmt w/440 sx Cl "G" w/3% KCl, .8% D-60 & .2% D-46. Displ using rig pmps, bump plug. Set 7" csg slips. ND BOPE. 8315~, (0~), ~ Dressed 7" csg stub. NU & tst tbg head & tree. Ninterlzed w/diesel. / Classifications (oil, gas, etc.} 0il J New TO ! PB Depth Date 8315 (7/10/85) K nd ct rig 1000 hrs 7/12/85 Rotary Type completion (single. dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P_ Water % GOR Gravily Allowable Effective dale · corrected The above is correct Signature ~Date ! lTitle ~ ~~ I °c//'~'/~'-~' I Drilling Superintendent For form preparation an~/distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Alaska Oil & Gas Cons. C, ornmissior~ Anchora9o AR3B-459-3-C INumber all daily wall history forms consecutively as they are prepared for each well. iPage no. 2 Dlvldon of AtlsntlcRIchfleldCompany ARCO Alaska, Inc. Post Office B. 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, i/~C, ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 12-19- 85. TRANSMITTAL # 5473 Transmitted hereWith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tape plus listing/ schl/ One copy of each lQ-4/f G3-18-85 Run #1 4570.0-9471.0 ref0' 70997--~ff.~4~~ ~2H-9/~ 12-02-85 Run #1 1800.0-8113.0 ref0 71048 ~2H-10~/ 11-23-85 Run #1 2856.0-7960.0 ref0 71002 '~2H-12 /, 11-07-85 Run #1 2743.0-6829.0 ref0 70947 ~2U-7// 03-19-85 Run 01 3594.5-8179.5 ref0 7095~c~/~~/ ~2V-16// 06-03-85 Run 01 2973.0-7168.0 ref0 70952'f~o~p ~3A-10H 11-09-85 Run 01 3179.0-7014.0 ref0 70960 ~--3A-11/, 11-16-85 Run 01 3208.0-7330.0 ref0 70989 3A-12// 11-23-85 Run 01 3797.0-8006.0 ref# 71003 '~3A-13;~ 12-01-85 ~un 01 1800.0-7597.0 ref0 71047 ~3A-14'/ 12-09-85 Run 01 0144.5-7818.0 ref0 71073 3C-9~ 07-10-85 Ru~ 01 3920.0-8332.5 ref#~70996--~p 3F-8~; 11-09-85 Run 01&2 0115.0-7040.0 ref# 70994 3F-9/ Run #1 3410.0-7770.0 ref# 11-17-85 70990 3F-10~ 11-27-85 Run 01 1800.0-6631.0 ref0 71037 3F-11~ 12-05-85 Run #1 0148.0-8618.5 ref0 71061 3J-9.~/ 11-24-85 Run 01&2 0~91.0-6789.0 ref0 71034 3J-10'~ 12-08-85 Run #1 0096.5-7348.5 ref# 71074 3 t -lq- Receipt Acknowledged: 'STATE OF ALASKA* ARCO Alistcm InC_ tS · Sub$idt/ry of AlllnlicRichllelc~Cot~l~lrly Date: ARCO Alaska, Inc. ~' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 31, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3C-9 Dear Mr. Chatterton: Enclosed is a copy of the 3C-9 Well History (completion details) to include with the Well Completion Report, dated 9/10/85. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU12/L53 Enclosure RECEIVED Alaska Oil & {}as Cons. Commission Ancl'mra~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative lest data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District ICounty or Parish I State Alaska I North Slope Borough J Alaska Field ILease or Unit IWell no. Kuparuk River I ADL 25629 I 3C-9 Auth. or W.O. no. ~Title AFE 604861 I Completion Nordic 1 Operator ARCO Alaska, Inc. Spudded or W.O. begun A.R.Co. Date Complete Date and depth as of 8:00 a.m. Complete record for each day reported Old TD Released rig API 50-029-21355 W.I. rl'otal number of wells (active or inactive) on this Icost center prior to plugging and I 56 · 24~ labandonment of this well IHour I Prior status If a W.O. 7/31/85 ! 1800 hrs. I 8/01/85 8/02/85 8/03/85 thru 8/05/85 1100 hrs. 7" @ 8298' 8216' PBTD, Perforating w/SCHL Move over 3C-9, NU BOPE. Accept Rig @ 1800 hfs, 7-31-85. Tst blind & pipe rams to 3000 psi; OK. Tst Hydril to 1500 psi; OK. RU Schl, tst lubr to 1000 psi; OK. RIH w/gun #1, perf f/8020-8040'. RIH w/gun #2, perf f/8018'-8020' & 7989'-7996'. RIH w/gun #3, perf f/7969'-7989', POOH. RIH w/gun #4, perf f/7949'-7969', top gun misfired, POOH. RIH w/gun #4A, perf f/7949'-7959', POH, misfire. RIH w/gun #4B. Perf f/7949'-7959', POOH. RIH w/gun #5, perf f/7838'-7850'. (Ail perfs done w/4 SPF, 90° phasing.) 7" @ 8298' 8216' PBTD, RU to Displ to Crude Perf f/7838'-7850', & 7774'-7789' w/5½" guns, 12 SPF, rn GR & JB to 8140'. Rn permanent pkr & set @ 7877' WLM. Rn 245 jts 2-7/8", 6.5# J-55, 8rd, EUE, IPC tbg. Stab in pkr. Drop ball, set top pkr TT @ 7913', perm pkr @ 7885' ret pkr @ 7626' SSSV 1796'. Tst tbg, no good. RU WL, rn standing vlv, set in "D" nipple @ 7905'. Tst tbg to 2500 psi; OK. POH, shear SBR, tst SSSV; OK. Set BPV, ND BOPE, NU tree & tst. Pull BPV. 7" @ 8298' 8216' PBTD, RR Displ well to crude/diesel, shear out ball, set BPV. Rig @ 1100 hrs, 8-2-85. Move to 1R-9. I New TO PB Depth Date Kind of rig 812185 Release 8216' PBTD Rotary Classifications (oil, gas, etc.) Oil Prdducing method Flowing Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands RECEIVED Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Productf(~",. ~V J ,~.; Oil on test Gas per day Ala~ {a Oil & ~as C ]ns. Conm~ Anchor Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct S~r,~,~ ,-7:~':~ i ,~, .~: ':~i~':'~:~.[ IDate 10/10/85 ITM Drilling Superintendent · For f_orm p.repara, t. ion a.nd..dis, t. ribu.t?n, ARCO Alaska, Inc. Post Office Box 100360 .%' Anchorage, Alaska 99510-0360 "~ Telephone 907 276 1215 -_ RETURN TO: CO-ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS' CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 DATE:10-31-85 TRANSMITTAL NO:5421 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. FINALS/ $CHL/ CEMENT <ONE * OF EACH> ~lA-3/ CEMEN~ EVALUATION TOOL -lB-4~ .CEMENT EVALdATION TOOL '~lR-9/ CET LOG ,1R-10~ ,CET LOG ~IR-11/CET/CEL -1R-12" CET LOG ~2A-13- CBL/VDL \2A-13/ CET/CEL J2U-3~ CEMENT EVALUATION TOOL ~2U-10 / CEMENT EVALUATION TOOL ~2Z-13/ CET LOG ~2Z-14~ CET LOG ~2Z-15~ CET LOG ~2Z-16-- CET LOG ~3B-4/ CEMENT EVALUATION TOOL ~3B-12-- CET LOG ~B-12/ CEMENT EVALUATION LOG W/ AC ~3B-16/ CEMENT EVALUATION TOOL -3C-9/ CET LOG u3C-10~ CET LOG PLEASE ACKNOWLEDGE 05-04-85 RUN #1 7468-8287 05-28-85 RUN #1 7200-7995 07-17-85 RUN #1 5990-8084 07-16-85 RUN #1 7500-8632 07-25-85 RUN #1 5744-7129 07-26-85 RUN #1 4992-8144 07-13-85 RUN #1 6388-7554 07-24-85 RUN #1 6382-8032 03-26-85 RUN $2 6100-6600 05-19-85 RUN #1 5450-6950 07-09-85 RUN #1 6000-8411 07-09-85 RUN '#1 5500-8173 07-01-85 RUN #1 2700-6617 07-01-85 RUN #1 6100-801! 05-31-85 RUN #'1 6000-7743 07-14-85 RUN S2 6139-8089 07-05-85 RUN #1 5500-8096 05-09-85 RUN #1 6186-7762 07-14-85 kUN #1 7485-8210 07-14-85 RUN #1 8190-8805 RECEIPT ACKNOWLEDGED: DISTkISUTION: BPAE DRILLING*BL W. PASHER B. CUP, KIEK L. J~N~TON ,. ~XXON CHEVRON MOBIL PHILLIPS OIL D & M NSK CLEkK*BL J. RATHMELL sonzo UNION VAULT/~O*FILHS ARCO Alaska, Inc.' Post Office b,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 8, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3C-9 Dear Mr. Chatterton' Enclosed is a copy of the 3C-9 Well History (Completion Details) to include with the Well Completion Report, dated 9/10/85. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU11/L129 Enclosure cc: 3C-9 Well File ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany ARCO Oil and Gas Company Daily Well History-Final Report operation it space is available. Inslructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold, "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an olficial test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire Accounting cost center code District lCounty or Parish State Alaska I North Slope Borough Alaska Field lLease or Unit Well no. Kuparuk River J ADL 25629 3C-9 Auth. or W.O. no. ITitle AFE 604861 I Completion Nordic 1 ARCO Alaska, Inc. Spudded or W.O. begun Complete 8/Ol/85 Date and depth as of 8:00 a.m. 8/02/85 8/03/85 API 50-029-21355 IA.R.Co. W.I. 56.24% IOate 7/31/85 Complete record for each day reported Iotalnumber of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our I Prior status if a W,O. I 1800 hrs. 8216 PBTD, Perforating w/2~CHL Move over 3C-9, NU BOPE~/HU ins. Accept Rig @ 1800 hrs, 7-31-85. Tst blind & ~pe rams to 3000 psi; OK. Tst Hydril to 150-~-~i; OK. RU SCH~, tst lubr to 1000 psi; OK. RIH w/gun #1, perf f/8020-8040/. RIH w/gun #2, perf f/8018'-8020' & 7989'-7996'. RIH w~gun (/3, perf f/7969'-7989', POOH. RIH w/gun #4, perf f/7949'-~)~)2~ POOH, RIH w/gun #4A, perf f/7949'-7959'. POH, misfire. RIH w/gun #4B. Perf f/7949'-7959',POOH. RIH w/gun #5, perf f/7838'-7850'. 7" @ 8298' 8216' PBTD, RU to Displ to Crude Perf f/7838'-7850', & 7774'-7789' w/5½" guns, 12 SPF, rn GR & JB to 8140'. Rn permanent pkr & set @ 7877'. Rn 245 ~ts 2-7/8", 6.5# J-55, 8rd, EUE, IPC tbg. Stab in pkr. Drop ball, set top pkr. TT @ 7913', per~pkr @ 7885', ret pkr @ 7626'. Tst tbg, no good. RU WL, rn standing vlv, set in "D" nipple @ 7905'. tst tbg to 2500 psi; OK. POH, shear SBR, tst SSSV; OK. Set BPV, ND BOPE, NU tree. Pull BPV. ~%~ ~ I~ 7" @ 8298' 8216' PBTD, RR Displ well to crude, shear out ball, set BPV. 1100 hfs, 8-2-85. Move to IR-9 Potential test data Producing method Flowing Classifications (oil, gas, etc.) Oil The above is correct For form preparation and ~istribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, sPM X length Choke size T.P. C.P, Water % GOR Gravity Allowable Effective date corrected i ,LU.riiling= SuPe'ri~eudent Number all daily well history forms consecutively as they are prepared for each well. Page no. Dlvl,aon of AtlantlcRIchfleldCompany o,~o J.e ,D ][P8 Dep,h 8216' PBTD Released rig Date [Kind of rig 1100 hrs. 8/2/85 Rotary ARCO Alaska, Inc. Post Office Bo,, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 19, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3C-9 Dear Mr. Chatterton: Enclosed are the Well Completion Report and gyroscopic survey for 3C-9. I have not yet received copies of the Well Histories. When I do, I will forward them to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/L75 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany <ECEiVED 8£P2 4 ]985 6as ¢ons. Commission Anchorage , ,,J--~ STATE OF ALASKA ALASKA:L ' AND GAS CONSERVATION CC :~llSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~(x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] . 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-100 3. Address 8. APl Number P. 0, Box 100360, Anchorage, AK 99510 50- 029-21355 4. Location of well at surface LOCATIONS 9. Unit or Lease Name 1060' FNL, 901' FEL, Sec.14, T12N, RgE, UN VERIF~.D Kuparuk River Unit At Top Producing Interval Surf..~ 10. Well Number 1516' FSL, 1276' FWL, Sec.12, T12N, R9E, UM B.H. I__~'~ 3C-9 At Total Depth 11. Field and Pool 1846' FSL, 1553' FWL, Sec. 12, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.} I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 82' RKBI ADL 25629 ALK 2562 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8315'MD,6785'TVD 8217'MD,6711 'TVD YES l-~X NO []I 1796 feet MD 1700' (Approx) ,, 22. Type Electric or Other Logs Run DIL/FDC/CNL/GR, CET/GR, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 116' 24" 202 sx CS II 9-5/8" 36.0# J-55 Surf 3943' 12-1/4" 1150 sx AS III & 300 sx Class G Performed top job w/100 sx AS I 7" 26.0# J-55 Surf 8299' 8-1/2" 440 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8018' - 8040' 2-7/8" 7913' 7626' & 7885' 7949' - 7996' w/4 spf, 90° phasing . 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7838' - 7850' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7774' - 7789' N/A 27. N/A PRODUCTION TEST Date First Production t Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESlZE IGAS-OILRATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED .1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Alaska Oil &. Gas COns. AnChorage Form 10-407 * NOTE: Tubing was run and well perforated 8/2/85. TEMP2/WC04 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH · GOR, and time of.each phase. _. Top.Upper Sand 7690~ . 6333~ N/A ~se Upper'Sand 7789~ 6~02~ Top Lower Sand · .79~~ 6511~ Base LOwer Sand 8112~.. 6633~ : *t ';, ,¢.}. ' ' ' ..- . ~ · : . . . 31. LIST OF ATTACHMENTS . OyroscoDic Survey (2 CODies)~.Addendum 32. I hereby certify that the forgoing is true and correct to the best of my knowledge . : Signed ~,-~( ~ ~~-~ Title Assoo~a~e E,g~,eeF Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 .and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". WELL v/~5/~5 3C-9 Rn CET/GR £/$210' - 7485' Rn GCT f/pBTD - surE. kECEiVED $,:"u 2 ~, ],985 Alaska 0il & b~$ (;~s b ....... A[~cl~ora0e R~iTUI~N TO: ARCO Alaska, In~.__... Post Offic ~x 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DAT~:: 09-05-85 TRANSMITTAL NO:5332A **CONTINUATION ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED RECEIPT AND SEQUENCE OF 2G-9 ~'- PBU 2G-9~- Pk~U 2G-11j PBU 2G-16 -'~ SBtiP HERB%~ITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RETURN' ONE SIGNED COPY OF THIS TRANS~iITTAL. I.:VENTS FROM WELL SERVICE iiEPOtiTS/PRESSURE; DATA 08-22-85 08-21-85 08-19-85 08-19-85 2h-l-- PBU 08-25-85 2h-1. ~' PBU 08-24-85 2U-lf 'C' SAND PBU 08-23- 2U-lJ END 'C' SAND PBU & I~iISC. 08-24- 2W-7 ~" 'C' SAND PBU 08-17- 2W-7/ 'C' SAND PBU 08-23- 2W-7/~/ 'C' SAND PI~U 08-22- 2X-llj PBU 08-24- 2X-ll / 'C' SAND PBU 08-25- 2X-11/ 'C' S/MND PBU 01~-26- 3C-5-~ BhP & M1SC. 08-29- 3C-7~'~ BHP & lv]ISC. 08-30- 3C-8 / BHP & MISC. 08-31- 3C-9/~ BHP & MISC. 08-09- 3C-10 ~BHP & MISC. 08-10- 85 85 85 85 85 85 85 85 85 85 85 85 85 KUPARUK WELL PRESSURE REPORT ENVELOPE FACE 3C-12/ STATIC 'A' SAND 07-24-85 3C-10~ STATIC 'A' SAND 08-10-85 3C-9 /- STATIC 'A' SAND 08-09-85 2Z-16~ 07-21-85 2Z-15" STATIC 'A' SAND 07-17-85 2Z-14,- STATIC 07-20-8-5 2Z-13" STATIC 'A' SAND 07-17-85 2X-4'~ PBU 08-12-85 2X-4~' PBU 08-13-85 2U-1'~ , 08-24-85 2A- 13~'' STATIC 08-25- 85 1R-10~- STATIC 'A' SAND U8-15-85 1R-9 ~ STATIC 'A' SAND 01~-14-85 S: CAHC O OTIS OTIS OTIS OTIS OTIS OTIS CAHCO CAMCO OTIS CAMCO CAIvICO CAMCO RECEIPT ACKN(JWLEDGED: DISTRISUTION: SPAE* DRILLING W. PAS~ER B. CURRIER L. JOHNSTON EXXON CHEVRON* ~IOBIL*' PHILLIPS OIL* % & M* NSK CLERK J. KAT~MELL* ~,~ . '~' ./;:. STATE OF ~ASKA*:?.'.--.;... : SOHIO* UNION* K. TULIN/VAULT ARCO Alaska. Inc. is a Subsidiary of AllanticRichfieldCompany ARCO Alaska, Ir'""-, Post Offi. ,Jox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-30-85 TRANSMITTAL NO:5214 KETURN TO: A~CO aLASKA, INC. KUPAitUK OPEk~TIuNb ~NGINL~ING kE[JORD5 CLERK ATO-1115t3' P.O. SOX 100360 ANCH~h/~E, At< 9~510 TKAN~[.IITTt~D HEREWITh Ak~ THE FOLLOWING I'i'l~ldS. PLEASE ACKNOWLEbGE tt~C~IPT AND RETURN ON~ SIGNLD COPY UF This TIiAN$~]ITTAL. OPLN hOLE FI[-4ALS/SCt~L/ONE * 3C- 1 ~--"-' 2" DIL/MFL-GR ~ ~5" .DIL/~FL-GR ~--~2" DEN/NEU-GR RAW '"') '--5" PEN/N SU-GR [~ -- 5" DEN/NEU-GR -'- -- 2." DEN/NEU-GR '~- ,_/ C'YDERLOOK ~-- x~. 2" DIL/bFL-GR ~ [ 2" DEN/NLU PORO -- ,,"' 5" DEN/NEU RAW ~ 2" DEN/NEU RAW CYB E icl RAW PORO RAW PO RO PORO 07-02-85 RUN #1 1786-8962 07-02-85 RUN #l 17~6-~962 07-02-~5 liUN #1 8290-~937 07-02-85 RUN ~1 7468-8937 07-02-85 RUN #1 8290-8937 07-02-85 ItUN #1 8290-~937 07-02-85 RUN #1 8500-~900 06-16-85 RUN #1 3772-7569 06-16-85 }{UN #1 3772-7569 06-16-85 RUN #1 6000-7543 06-16-85 RUN #1 6000-7543 06-16-85 RUN #1 6000-7543 06-16-85 RUN #1 6000-7543 06-16-85 t{UN #1 6000-7520 07-10-85 RUN #1 4500-8279 07-10-85 t<UN #l 3942-8304 07-10-85 RUN #1 3942-8304 07-10-85 RUN #1 4500-8279 07-10-85 RUN #1 4500-8279 07-10-85 RUN #1 4500-8279 07-10-85 RUN #1 4500- ~279 06-23-85 RUN #1 4473-8854 06-23-85 RUN #1 4473-8854 06-23-85 RUN #1 8100-882~ 06-23-85 RUN #1 8100-8828 06-23-85 RUN #1 8100-8828 06-23-85 RUN #1 8100-~2~ 06-23-85 R~:C~:IPT ACKNOWLEDGED: DIST~IDUTION: SPAE DRILLING*BL - W. PASHER CURRIER L. jOHNSTON EXXON CHEVRUN MOBIL PHILLIPS OIL M*DL N~K CLERK*DL J. RAT}~ELL*BL RUN #1 ~100-8~05 / ,oki..~,, ~ ~as Cons. Com~missior~ UNION K.TULIN/VAULT*FILM ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieloCompany ~ STATE OF ALASKA -". ~ ALASKA ulL AND GAS CONSERVATION CL, MMISSION ~: WELL COMPLETION OR RECOMPLETION REPORT AND LOG - 11 1. Status of Well Classification of Service Well / OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] _ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85~100 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21355 4, Location of well at surface 9. Unit or Lease Name 1060' FNL, 901' FEL, Sec.14, T12N, RgE, UN Kuparuk River Unil; At Top Producing Interval 10. Well Number 1516' FSL, 1276' FWL, Sec.12, T12N, R9E, UM 3C-9 At Total Depth 11. Field and Pool 1846' FSL, 155:3' FWL, Sec.12~ T12N~ RgE~ UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.)16.Lease Designation and Serial No. Kuparuk River 0i 1 Pool 82' RKBI ADL 25629 ALK 2562 · 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 07/04/85 07/10/85 07/11/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I'VD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8315'MD,6785'TVD 8217'MD~6711 'TVD YE~j~ NO [] 1796 feetMDI 1700' {Approx) 22. Type Electric or Other Logs Run D I L/FDC/CNL/GR, CET/GR, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-/~O .q~rf 11¢;' 9/~" ';n9 c,, cc: ~ 9-5/8" 36.0# J-55 SHrf ~94%' 12-1/~" 11~n ~ ~ ~ z ~nn c~ r~=~. n. .7" 26.0# J-55 Surf 8299' 8-1/2" 4b, O .~x £1~_~_~ C. & 1R¢) .~× PermaCrost C . 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8018 ' - 8040 ' ~-7/R" 7913 ' 752~ ' & 7995 ' 7949' - 7996' w/4 spf, 90° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7838' - 7850' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7774' - 7789' N/A . 27N/A PRODUCTION TEST I ' Date First Production Method of Operation {Flowing, gas lift, etc. I Date of Test' ' HoUr~Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED.~. OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press, 24-HOUR RATE 28. CORE DATA Brief description 'of lithol°gy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE --~ * NOTE: Tubing was run & well perforated 8/02/85. JG/WCI:104 Form 10-407 Submit in duplicate, Rev. 7-1-80 CONTINUED ON REVERSE SIDE _ GEOL~OGiCMARKERS.- : ?' "' ' ' ' FORMATION TESTS · . ': NAME " Include interval tested, Pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE YERT. DEPTH GOR, and time of each pliase. Top Upper Sand 7690' 6333' N/A Base Upper Sand 7789' ' ' 6402' .. Top Lower Sand 7944' 6511 ' Base Lower Sand -8112' 6633' ,. ; .- 31. LIST OF ATTACHMENTS Addendum (Dated 8-06-86) 32. I hereby certify that the foregoing ~S true and correct to the best of my knowledge Signed //~~)/~ ~ Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in .item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM wELL: 8/02/86 3C-9 Arctic Pak w/30 bbls PF "C", followed by 54 bbls Arctic Pak. Drilling Supervisor ~7~/g~ SUB. SURFACE DIRECTIONAL SURVEY :~.UIDAN'CE [~ONTINUOUS ~ r'~=lOoL Company Well Name Field/Local~ien ATLANTIC RICHFIELD COMPANY , ...3(;-c.:.) 106Q' ~"~q'L. qOl' ?'F.T,, .ql/,. q"l?M_ RqF- TTM%. ,KUPAR, UK~ NORTH SLQPE, ALASKA , Job Reference Ng. 70678 Looaed ,BT. Date · 24-JULY-1985 c:.'.:'~-~ ~?~ ,-~.~,-- ns. Comrnisskm . ~nchoraos GCT O~R~CTION~L SURVEY CUSTOMER LISTING FOR ARCO ALASKAt INC- 3C -9 KUPARU~ NORTH SLOPE~ALASKA SURVEY DATE: 1~ JUL 85 ENGINEER: M. MCBRIDE METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. 2IST. PROJECTED ONTO A TARGET AZ£MUT~ OF NORTH 4Z OE~ ~? MIN EAST ARCO ALASKA, [NC. 3g-9. KUPARUK NGR,TH SLD~E~ALASKA CDMPUTATIDN .DATE: 25-JUL-~5 TRUE SUa-SEA CDURSE EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG M'~N PAGE DATE OF SURVEY~ L~ J~L 85 ' KELLY BUSHIN~ ELEVATION:. 82.00' FT ENGiNeeR: M. MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH V~RTICAL OOGLEG RECTANGULAR C~RDiNATES H'ORIZ.'DEPARTUR6 SECTION SEVERITY NO,RTH/SOU~H~EA$IYWEST DIST' AZIMUTh' FE~T OEG/IO0 O.O0 0.00 -82.00 ZOO.DO 100.00 1~.00 ZO0.O0 ZO0.O0 llB.O0 300.00 300.00 Zl~,.O0 ~00.00 ~00.00 31a.oo 500.00 500.00 ~18.00 bO0.O0 600.00 518.00 700.00 700.00 61B.O0 800.00 800.00 718.00 gO0.O0 900.00 818.00 FEET FEET lO00.O0 [000.00 glS.00 llO0.~)O llO0.O0 1018.00 1200.00 1200.00 1118.00 1300..00 1300.00 12.1~.00 lq. O0.O0 1~00.00 1313.00 1500.00 [499.99 1~17.99 15,00.00 15~9.9g 1517.99 1700.00 1699.99 1617.9g 1800.00 1799.9~ 1717.98 1900.00 1899.97 1,817.97 0 0 N 0 ~ ; O.O0 0.00 0.00 I~ 0.00 0 5 S ;~8 3 ~: 0.02 0.16 0.02 S O.O6'E 0 4 N :51 37 W 0.,07 0.11 0.03 N 0.0~ 0 5 N 73 53 W 0.01 0.08 0.06 N 0.05 0 6 N 59 25 W -0.04 0.10 0.1~ N 0.20 0 5 N 81 1~ W -0.10 O.ll 0.22 N 0.3a W 0 ~ S 53 15 W -O.ZO O.19 0.23 N 0.53 0 6 S 24 18 W -0.35 0.05 O.Oa N 0.61 0 4, S 71 37 W -,8.52 0.30 0.10 S 0.66 0 5 a 18 4'7 E '-0.~6 0.08 0.01 S 0.67 o , -o. oo.oa o.l o s -o.,.l o.o o. o o s zo o.o, 0 27 S Z8 4~ E -[.06 0-20 1-89 0 34 S 61 2t E -1.05 0.16 3.19 S 1.,8~ 0 41 :S 82 11 f -0.54 0.~9 3.55 S 2.87 ZO00.O0 1999.96 1:~17.96 0 50 2100.00 Z099.95 2017.95 0 59 2200.00 Z199.94 2117.94 0 56 2300.00 1299.93 2217.93 1 0 2¢00=00 2399.90 1317.90 1 55 2500.00 2499.7Z 24.17.72 4 ~2 2600.00 2599.I1 2517.11 7 ~7 2700.00 2697.75 2615.75 11 7 2a00.00 2795.21 2713.21 14 36 2~00.00 ZS-~l.l,~ 280~.i~ 17 4~ N 57 CZ E 0.41 0.43 3.34, S 4.19 N 51 8 E 1.96 '0.32 2.49 S 5.55 N '~l 30 ~ 3.63 O.Oa ~.30 S 6.73 N 61 32 E 5.24 0.75 0.22 S 7.gZ N 69 3~ E 7.22 1.97 0.~9 M 10.06 N 53 30 f 12.71 3.00 3.~2 N 1~.99 N ~5 15 f 23.~7 3-23 10.68 ~ 22.98 N ~0 ~'7 E 39.'8~ 3.52 22.55 N 3~.2~ N 36 35 E 62.06 3.57 ~0.07 N ~8.0~ N 38 G5 ~ 89.91 3.2B 62.~2 N b~.9O N 4,0 13 f 123.16 3 N 40 4,0 E 161.90 3.15 N 4,1 35 E 205.¢0 3.11 N ~1 47 E 253.62 2.73 N ¢2 21 E 306.15 2.97 N 42 15 E 362.82 2.89 N ~1 4,5 E 423.81 2.87 N 4,1 21 E ~88.55 3.01 N 4,1 a E 557.07 3.04 N ,~0 50 E 629.20 2.05 3000.00 2985.46 2!)03.4,6 21 1~ 3100-00 30'77.63 2995.63 24 18 3Z00-90 3167.64, 3085.64 27 18 3300.00 3255.22 3173.22 30 13 3600=~)0 33~,0.30 3258.30 33 3 3500.00 3427.67 3340.57 36 6 3600.30 3501.89 3~19.89 38 58 3700.00 357B.07 34,96.07 41 51 3800=00 3650-86 3568.86 44 41 3900.00 3720.05 3638.05 47 lb FEeT 0.60 N 77 16 N 0.57 N 63 2~, W 0".48 N, 59 34 W 0.29 N 82 15, W 0.51 S 6 21 W 1..21 S ~ 24 E 1.94 S I"~' 4 E 2.8Z S 2;l 7 E 3.?0 S 3~ 37 E 4.57: .S 38 56 E 5.36 S 51 25 f 6.08 S 65 51 E 6.85 S 79 1 E 7.92 S 8B 26 E 10.07 N 8Z 11 E 15.37. N 77 9 E 25.3~ N 65 5 E ¢1.00 N 56 37 f ) 62.56 N 50 10 E 90.05 N 46 7 E 87.93 N a6.29 E 123.20 N 44, 27 E 117.46 N 111.43 E 161.90 N 43 29 E 150.25 N 14,0.05 E 205.40 N 42 59 E 186.24 N 172.1~ E 253.62 N 42 44 E 225.20 N 207.40 E 306.15 N 42 38 E 267.11 N 2¢5.55 E 362.83 N 42 35 E 312.40 N 286,40 f 423.82 N 42 30 E 360.87 N 329.36 E 488.58 N 42 23 f 412.42 N' 374.5~ f 557.11 N 42 1~ E ~66.88' ~ 421.90 E 629.2? N 42 6 E £OMPU'TATION DATE: 25-JUL-85 PAGE' AR£O ALASAAs INC. 3g-9 KOPAR~K NORTH SLOPE,ALASKA TRUE SUB-SEA C~URSE IEASUREO VERTICAL VERTICAL D.EVIATI~N A.ZZMUTH DEPTH DEPTH OEPTH DEG MIN DEG MIN ~O00-DO 3787.06 3'705.06' ~7 45 ~100.~0 385~,.35 3'772.35 4ZOO.O0 3921.42 3839.~2 ~7 59 4300.00 3988.31 3906.31 ~8 3 ~00.20 ~054.99 3972.99 ~8 15 4500. D0 ~1~7.61 ~105.61 ~8 ~'~ ~?O0.DO ½253.37 4171.37 ~8 58 ~800.DO ~318.96 ~236.96 48 52 4~00o00 %385.70 4303.70 46 5000.~0 &~54.82 4372.82 ~6 15 5[00.00 %523.72 %441.72 46 33 5200.00 ~592.50 4510.~0 ~5 59 5300.00 %663.06 ~581.06 44 42 5eO0.O0 %734.07 465Z=07 44 53 5500.D0 %804.82 4722.82 %5 5 5bO0.~O 6875.2% 4793.24 45 18 5700.~0 ~9~5.39 4863.,3~ 45 35 5800.00 5015.2& 4933.26 45 51 5~00.00 50~4.77 5002.77 46 2 6000.00 $154.48 5072.4~ 64 53 6100.00 5226.25 514~.25 43 50 6200.00 5299.26 5216.26 ~4 10 6300.D0 5359.63 5287.03 ~4 42 6400.~0 5440.55 5358.55 ~4 53 6500.D0 5511.29 5429.29 ~5 7 6600.00 5581.6~ 5499.69 45 20 6?00.00 5651.8~ 5569.86 %5 35 6800.00 5721.56 5639.~6 46 6~00.00 5790.75 5708.75 ~6 23 ?O00.DO 5859.67 5777.67 46 33 7LO0.O0 5928.27 5845.27 G6 50 7200.~0 5996.57 591%.57 46 52 7300.00 ~ObS.01 5983.01 46 50 7%00.00 5133.25 6051.25 47 7500.00 $201..48 6119.4~ 46 46 7600.~0 52'70.20 6188.20 46 18 7700o~0 5359.57 6257.57 45 51 7800.00 6409.35 6327.35 45 30 7300.00 5479.90 6397.90 44 41 OATE OF SURVEY:" 14 JJL 85 KEL.LI BUSHING ELEVATION:" a:2...O 0 FT NeO 25 E 2159.2~ N 41 58 E 222~.84 N 41 49 E 2298.21 N ~.1 32 E 2368.25 N 41 I. E 243~.71 N ~0 27 E 2509.35 N ~0 15 ~ 2580.29 N 39 57 5 2723.07 N 39 4~ ~ N 39 32 j 2867.50 N 39 19 E 2940.12 N 3~ i3 E 3013.01 N 38 45 E 3085.75 N 38 2.~ E 3158.63 N 38 1~1 ~. 323~.51 N 38 22 E 3303.91 N 39 1~ E 3375.75 N 39 16 E 3447.23 N ~9 2~ ~ 35~.96 N 39 39 E 1%45.73 N 39 22 E 1518.07 N .39 40 E 1599.51 N 41 ? E 1561. 30 N 41 1 E 1731.68 N ,%0 3~ E 1,~02.30 N 40 9 E la73.23 N 4.0 ,5 E 1946.40 N 40 7 ~ 2015.86 N 39 47 ~ 2087.65 0.75 0.3'9 0.12 0 0.34 0.47 0.62 0.87 O. 89 3.47 0.56 0.¢5 2.3~ 0.70 0.25 0.46 0.25 0.51 0.50 2.87 0.62 0.55 0.43 0.45 0.38 0.17 0.46 0.40 0.50 0.38 0.33 0.4~ 0.62 0.42 0.82 0.65 0.70 0.98 693=32 N 613.66 ~ 925,88 N 41 30 E 750.49 N 6~1.43 E 1000,.3~.':N 41 23 E 8,08'.11 N 708.9~ E 1075.0"4,~ N 41 15 E 856.40 N 756.18, E 1149.,98, 'N 41 6 ~ 925.56 N 892.83 e 1225.23 "N 40 56 985.74 ~ 8%8.40 E ~300.56 ,N 40 ~3 ~ 1065.25 N 893.16 ~ 1374.86 N 40 30 E 1101.26 N 938.80 E 1447.11 N 40 26 ~ 1157.16 N 9i:14.93 E 1519.57 N 40 24 E 1213.31 N 1030.92 E 1592.15 N 40 2I E 1267.16 N 1076.97 E 16613.00 N 4'3 21 E 1320.16 N 1123-33 E 1733.40 N 40 23 E 1373.64 N 1169.52 E 1804.07 N 40 24 E 1~27.71 N 12~5.5~ E 1~'75.07 N ~ Z~ E 1~2.21 N 12~1.~5 ~ 19~6.33 N ~0 23 E 1536.92 ~ 13D7.~5 E Z017.87 N ~0 23 E 1591.9~ ~ 1~3.77 ~ Z089.7~ N ~0 22 E 1647.09 N 1339.613 E 2161.45 N 40 21 E 1699.2a N 14¢5.72 E 2231.06 N 40 23 E 1750.88 N 1492.10 E 2300.43 N 40 26 E 1803.20 N 1538.6~ E 2370.46 N 40 28 E 1856.13 N 1585.2~ E 2440.95 N 40 29 E 1909.72 N 1631o. 3~ E 2511.63 N 40 30 E 1963.83 N 1677.3½ E 2582.65 N 43 30 F 2018.Z~ N 1723.33 E 2653.89 N 40 29 2073.14 N 17~9.4~ E 2725.60 N 40 28 b 2128.59 N 1815.70 E 2797.80 N 40 27 E 2184.37 N 18:,1.95 E 2870.25 N 40 26 E 2260.59 N /9~8.13 E 2942.99 N 40 25 E 2297.15 N 195~.36 E 3016.02 N 40 23 E 2353.84 N 2000.2~ E 3088.91 N 40 21 E 2410.96 N 2065.81 E 3161.97 N 40 Ia E 2468.28 N 2091.20 E 3235.06 N 40 16 E 2525.28 N 2136.22 E 3307.64 N 40 13 E 2581.49 N 2~a~,27 E 3379.65 N 40 ~ E 2636.92 N 2226.63 ~ 345~.27 N 40 ~0 E 269~.73 N 2271.57 5 3522.14 N 40 9 E N 40 22 E 103.37 N /,0 11 P. 777.26 N 40 3 E 851.35 N 39 5~ E 925.56 N 39 46 E lO00.O0 N 39 15 E 107%.58 N 38 42 E 1149.139 N 37 39 E N 36 ~5 E 1299.57 N 37 57 E 1373.62 ENGINEER: M. HC~R,I'DE' INTERPOLATED VALUES FOR EVEN 100 FEET OF ~EASURED DEPTH VERTICAL DOGLEG RECTANGULAR C~ORDINATES H,,DR~,Z.. DEPARTUR5 S~CTION SEVERITY NORTH/SOUTH EAST/WEST DI, ST ', A,iZIMUTH~ FEET DES/LO0 FEET FEET FE'ET~i,;; D.EG MIN ~RC8 ALASKA, ZNCo 3g-g ~UPARgK ~gRTH SLDPE~ALASKA COMPUTATION D.AT~.: 2!5-JUL-85 PAG~ DATE OF SURVEY: 14 J'~L 85 KELLY ~USH~N$ ELEV'AT,[ON: ENGINEEr: M. MCBRIDE INTERPOLATED VALUES FOR EVEN XO0 FEET OF MEASURED DEPTH TRUE SU~-SEA COURSE ~ASURED VERTICAL VE2TICAL DEVIATION AZIMUTH OEPT~ DEPTH DEPTH DEG:MIN D~G M[N 82.00 FT N 39 3} E 3587.59 N 40 5 ~ 3,555.28 N '~1 29 6 372.3.10 N ~l 23 £ 3789.~1 N ~1 29 ~ 3799.35 1.36 1 0.00 0.00 0,00 , FEET FE~T FEET 2745,53 N Z3~6,10 E 3591.,97' ..N 40 9 E 2848.82 N Z~D3.8~ ~ 3727.5'3" N ~0 9 E 2898.50 N Z4~7.83 E 3~93'83', N 40 Z905.95 N 2a~4.4Z ~ 3803.78 N F6ET OEG/IO0 VERT£CAL DOGLEG RECTANGULAR C~ORDINAT~S HgRXZ, DEPARTUR~ SECTION SEVERITY NDRTH/SCIUTH EAST/'WF..ST D[ST," . AZIMLJT~ [RCD RLASKA, INC. aDRTH SLOPE~ALASKA C~MPUTATI~N OATE: ~5-JUL-B5 PAGE ' :~ DATE O'F SURVEY: 14:d~L 8~ KELLY 8USH~.NG EL~¥,ATIDN: aZ.O0 FT ENGI, NEE.R: M. MCBRIDE INTERPOLATED VALUES FOR EVEN 1000 FEET DF MEASURED DEPT 'VERTICAL DOGLEG R~CTANGULAR .COORD~NATES HDRZ',Z*: DEPARTURE' SECTION SEVERITY NDRTH/SDU'TH EAST/.EST DIST., 'AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG HIM TRUE SU'~- SEA COURSE ~ASURED VERTICAL VERTICAL DEVIA'TION AZIMUTH DEPTH D~.PTH DEPTH OEG HIM DEG MIN '., O.O0 0.00 -8Z.O0 O' '0 .000. O0 1.000.00 91~.00 0 5 ~.000o O0 1.999.96 1917.96 0 50 1000.00 i985.4& 2~03.,~6 21 14 ;O00.O0 ~.454.8Z 4372.82 46 15 ~000.~0 5154.48 5072.48 4** 53 ?O00.DO 585'9.67 5777.67 46 33 tO00.OO 5551.45 6469.45 43 52 t315.00 5784.5~ 6702.54 41 32 N 0 0 ~ O.O0 N 26 43 E -0.30 N 6'7 42 N ~0 13 E 123.16 N ~0 22 E 703.37 N 39 3i) f 1,~45.73 N ~.0 25 iE 215~.24 N 39 32 E 2867.50 N 39 3~ E 3,~BZ.69 N 4~ 29 ~ 3799.35 0.00 0.~3 3.24 0.75 0.54 2.87 1.35 0.00 0.00 ~ 0.00 f 0.0'0 'N 0 0 E . .60 N 77 16 W 0.13 ~ 0 59 ~ 0 1101.26 ~ 938-80 E ~'7.~'1 "'N ,0 26 E ARC'.,3 .ALASKAs [NC, 3 C-3 KUPARiJK N~R'TH SLOPEsALASKA TRUE SUB-SEA EASURED VERTICAL VERTICAL DEPT~ DEPTH COHPUTATI3N,DATE: 25-JUL-85 PAGE S DATE OF SURVEY: 14 JUL 85 KELLY 8USH, ZN~ ELEVATION: INTERPOLATED VALU£S FOR EVEN 100 FEET,OF SUB-SEA DEPTH COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ.' DEPARTURE DEVIATION AZIMU?H SECTION SEVERITY NORTH/SOUTH EAST/~EST DI:$T.,'~'~ AZIMUT~ DEG MiN FEET OEG/[O0 FEET FEET FEET ' QEG ~IN 0.00 0.00 82.00 82.00 18Z.00 182.00 100.00 282.30 2~2.00 200.00 382.00 382.00 300.00 ,½8Z.O0 482.00 ~00.00 582,00 582.00 500.00 682.00 6~2.00 600.00 782.00 7,~2.00 700.00 882.00 882.00 800.00 -82.oo o"'o 0.00 ,0' 6 N 0 O E 0.00 0.00 S 69 13 E 0.01 0.23 0 3 N ~6 10 W 0.07 0.06 :0 5 N 30 11 ~ 0,02 ,O.Ob 0 6 N 58 5~ ~ -0.03 0.06 0 5 N 79 1Z ~ -0.08 0.14 0' 4 S b9 13 W -0.18 0.1'7 0 6 S 26 39 ~ -0.31 0.05 0 5 S ~0 32 ~ -~.50 0.29 0 /+ N 1.2 57 E -0.~9 0.07 982.00 982.00 900.00 1082.00 1082.00 1000.00 1182-D0 11~2.00 1100.00 1:'82.00 1282.00 1200.00 1t82.00 t3,:12. O0 1300.00 1~,82.01 1482.00 1400.00 1.582.D1 1582.00 1500.00 1682.01 1682.00 1600.00 1782..02 .1732.00 1700.00 1882.02 1882.00 1800.00 0 5 0 0 11 0 23 0 25 0 26 0 34. 0 3~. 0 39 2.8 5½ E -0.33 0.10 44 29 E -0.19 0.08 58 13 E -0.10 0.09 18 55 E -0.14 0.20 20 52 E -0.35 0.09 19 47 E -0.69 0.05 26 2~ E -1.01 0.1~ ~ 13 E -1.18 0.16 58 53 E -1.09' 0.1~ 76 5Z ~ -0.74 0.39 71 4L E 0.17 0.43 53 2B E /.66 0.30 ~2 2L E 3.34 0.11 55 ~9 E ¢.95 0,73 55 53 f 11.33 2.98 ~5 52 f 21.19 3.1Z ~1 k7 E 36.90 37 3 E 5~.67 3.70 38 2~ a 86.92 3.30 , ~0 13 E 121.85 3.31 ~0 ~2 f 163.86 3.1~ ~1 43 f Z1Z.90 3.17 ~1 59 f 269.61 2.60 ~2 18 E 33~,05 3.15 41 5~ E 107.87 2.92 11 23 E ~91.02 3.02 ~1 I E 58~.62 2.99 ~0 2~ E 697.77 0.75 ~0 ~ E 807.71 0.35 1982.03 19~2.00 1900.00 0 ~9 2082.05 2082.00 2000.00 0 56 2182.06 2181.00 2100.00 0 56 2281.07 2182.00 2,2.00.00 0 5b 1382.10 2381.00 2300,00 1 40 2~82.22 2482.00 24.00.00 4 13 2582.73 2582.00 2500.00 7 13 2683.98 2682.00 2600.00 lO 36 1786.35 ?.792.00 2700.00 14 7 2890.33 2882.00 2:~00.00 17 32 2996,30 2982.00 2900.00 21 6 3104.80 3082.00 3000.00 24 28 3216.Z0 3181.00 3100.00 27 48 3331.19 3282.00 3ZO0.O0 31 9 3½50.18 3382.00 3.300.00 34 34 3574.$0 34.82.00 3~00.00 38 14 370~.24 35~1.00 3500.00 42 0 384.%.34 3682.00 3600.00 46 2. 3992.45 3782.00 3700.00 47 48 4,141.15 3882.00 3dO0.O0 4.7 51 ,0.00 O.OZ 0.0! 0.05 O.1Z O.2Z O. 23 O.1Z 0.08 0.04 0.00 0.04 0.09 0.03 0.35 0.51 0.59 0.65 0.68 82.,0~ FT' 0.10 0.24 0.25 0.10 0.39 1.07 1.76 2.49 0.59 W 0.53 W 0.43 W 0.32 W 0.10 W 0.13 E 0.41 E 3.10 S . 1.7.3 E 3.50 S 2.67 f 0.60 N 80 3 0.58 N 65 4-7 W 0.50 N 59 16 W 0.3,3 N 0.40 S 1'~ 22 1.08 S 6 ~2 E 1.8! S 13 13 2.66 S 20 35 E 3.55 S 29 i0 E 4.40 S 3! 20. E 3.4,4 $ 2.67 S 1.53 S 0.36 S 0.35 N 2.59' N 9.01 N ZO. 3'? Al 37.32. N 60.09 Al 3.95 E 5.30 E 6.5~ E 7.65 E 9.59 E 13.8½ E Z1.35 E 32.18 E 46.01 f 65.0! E 5.23 S 43 54 E 5.94 S 63 15 6.,71 S 75 51 E 7.66 S 87 70 E 9.6'0 N 87 53 E 14.08 N 79 2.3 E 23.10 N 66 59 E 38.17 N 57 44 E 59.1¢ N 50 56 E 87.07 N 45 ll E 86.93 N 85.45 E 111.89 N 44 30 E 118.95 Al 111.71 E 163.87 N 43 2.7 e 155.85 ~1 lr+S.05 E 212.90 N 4Z 56 E 198.1~ ~ 182.83 E Z69.61 N 42 41 ~ 245.82 N ZZ6.19 f 334.05 N 42 37 E 300.51 ~ 215.7~ E 407.88 N 42 32 E 363.47 ~ 331.65 E 492.04 N 42 22 E 436.Z~ ~ 395.28 ~ 5~8.67 N 4~ 10 e 518.9~ N 4~6.5~ ~ 697.88 N 4~ 57 ~ 602.97 N 537.70 ~ 807.89 N ~i 43 E CDMPUTA'TISN.DATE: 25-JUL-85 PAGE' 6 ARCO J~LAS~Ae INC. .37,-9 KUPARL~K NORTH SLOPE,ALASKA DAI'E OF SURVEY: 14' JLJL 85 KELLY ~USH.[NG ELEVATION: ENGINEER: M. MCBRIDE a2.0D FT INTERPOLATED VALUES F3R EVEN 100 FEET OF SU?-$EA DEPTH TRUE ,SUS-SEA COURSE EASURED' VERTICAL VERTICAL DEVIATigN AZIMUTh OEPTH DEPTH DEPTH DEG'MIN DfG M£N VERTICAL DOGLEG RECTANGULAR CgDRDINATES HDRIZ. DEPA:RTURE SEC'TIDN SEVERI'T¥ NDRTH/SOUTH EAST/wEST DIST.. ~,, A;ZIMU'T~ FEET DEG/ZOO FEET FE~T FEET, DEG MIN 4290.56 3982.00 3900.00 48 2 4e40.$0. 6082.00 4000.00: 48 19 4591o~9 ~132.00 4100.00 48 42 4743.b4 ~282.00 4200.00 4.9 1 4894.56 ~382o00 4300.00 47 5 503g.~0 6482.00 4400.O0 46 2~ 5iB.4.32 ~582.00 4500.00 46 13 5326. ~2 ~682.00 4600.00 44 41 5667.71 ~7,~2.0~ 4700.00 ~4 5~09.~2 ~882.00 4800.00 ~5 19 N 39 59 E 918.57 N .39 3~ E 1030.26 N 38 45 E 1143.01 N 37 li f 1257.26 N 37 48 E 1369.65 N .39 3~ "~ 1'~7½.19 N 39 .90 E 1579.57 N 41 13 E 16BO.O0 N 40 4~ ~ 1~?~-4~ N ~0 8 E 1~80.06 0.15 0.39 0.56 0.80 3.4! 0.44 1 0.3~ 0.4~ 0.27 687.94 N 6O9.13 E 9,18.86 773.82 N 660.7,6 E 1030.66 861.41 N. 752'1~1 E 1143.,59: :~N 41 ? E 951.71 N 822.85 E. 1258.11" ':N 40 50 E 1042,09 hi 890.71 E 1370.,88 N 40 31 E 1123.22 N 956.98 E 1475.62 N 40 1204.85 1281.23 1356.31 1432.94 ~ 1219.94 E 1881.9~ N 40 24 E 5?52°35 ~982.00 4'900.00 ~5 40 5896.00 5062.00 5000.00 46 2 6038.55 51~2.00 5100.00 44 14 6177.36 5282.00 5200.00 44 3 631'7. ~1 5382.00 5300.00 44 46 6~58-53 54,~2. O0 5400.00 4.4 59 6500.63 5582.00 5500.00 45 20 6743.15 5682.00 5500.00 45 4? 6887.30 5782.00 5700,00 ~6 21 7032.S0 5882.00 5~00.00 ~.6 37 N 40 7 f 19BI.78 N 39 48 E 2086.7B N 41 15 E 2186.21 N ~1 52 f 2282.46 N 41 29 f 2380.50 N ~,0 3~ E 2480.02 N 40 15 E 2580.60 N ~0 2 E 2682.29 N 39 43 a 2785.97 N 39 2~ f 2891.08 0.2 ! 0.54 1.82 0.51 0.40 0.54 0.48 0.63 0.2~ 1:510.84 N 12135.55 E 1983.75 N 40 23 E 1589.77 N 1351.93 E 2086.88 N 40 2.2 E 1667.49 N 1417.31 E 2188.44 N 40 21 E 1739.15. N 1481.59 E 22t34,68' N 40 25 E 1812.37 N 1566.t32 E: 23~2.7! N 40 28 E' 1887.41 N 161.2.27 E 2482.28 .N 40 30 E 1964.06 N 1677.54, f 2582.96 N 40 30 E Z0~1.86 N J. 7~3.20 E 268~.77 N ~0 29 E 2121.50 N 1809.82 E 2788.59 N 40 28 E 2202.60 M 18Z6.9~ E 2893.86 N 40 Z6 E 7178o~7 .5982.00 5900.00 4.6 54 7324°86 5082.00 6000.00 ~.6 53 7,,~71.53 5182.00 6100.00 ~.6 53 7517.04 5282.00 6200.00 46 13 7763..88 5382.00 6300.00 45 4.3 7902.96 5432.00 6400.00 ~,4 39 8042.19 5582.00 6500.00 .~3 30 8177.99 5662.00 6600.00 41 32 8311.bi $782.00 6700.00 41 32 8315.00 5784.54. 6702.54 41 32 N 39 11. E 2997.47 N 38 41 f 3103.84 N 38 20 E 3210.82 N 38 27 E 331,5.17 N 39 17 E 3~19.31 N 39 23 ~ 3520.03 N 39 43 E 361~.76 N ~1 2.9 E 370~.51 N 41 29 rZ 3797.11 N :,I 2.~ f 3799.35 0.26 0.38 0 0.49 0.56 0.97 0.25 0.00 0.00 0.00 2285.08 I~ 1964.50 E 3000.45 N 40 23 E 2368.00 hi 2011.55 E 3107.05 N 40 ZO E 2451.98 N 2078.33 ~. 3214.29 N 40 17 E 2534.93 N 214,3.85 E 3319.94, N 40 13 E 2615.2T N 2208.92 E 342.3.30 N 40 ii E 2693.33 ~ 2272.8~9 E 3524.21 N 40 9 E 2767.96 N 2334.69 E 3621.09 N 40 8 F 2837.8~ ~ 2394.22 E 3712.~3 N 40 9 c 2904.27 N 2452.~3 E 3801.53 N 40 1~ E 2905.95 N 2454.42 E 3803.7~ N 40 i1 E ~RCO ALASKA, INC. ',UPAR'JK iDRTH SLOPE, ALASK& MARKER TOP UPPER SANO :BASE UPPER SAND TDP LOW ER .SAND BASE .LO~IER SAND P~TD TD COMPUT.ATION DATE: 2LS-JUL-a5 INTERPOLATED VALUES FOR CHOSEN HORIZONS PAGE DATE OF SURVEy:.' [~ .J~L, 85 KELLY 8USHIN:G ELEVAT'ION: MEASURED DEPTH 7690.00 7789.00 8112.00 8217.00 SURFACE LOC~'TION DRIGIN= 1060' TVD RECTANGULAR CDDRDZNAT'ES FROM KB SUm-SEA 6332.61 6250.6[ 6~01.5~ 6319.6~ 651:[.29 5~Zg.2g 6632.94 6,5'50.94 6711.19 6629o~9 6784.5~ 6T02.5~ ~RCD ALAS(Ac INC,. (UPARUK tDRTH SLOPEsALASKA COMPUTATION DATE: 25-JUL-85 DATE OF SURVEY: 16 JgL 85 ~ELLY ~USHING ELEVATION,.: ENG/NEER:, M. HC~RIDE 8Z..OO FT MARKSR TOP UPPER S,O, NC) BASE UPPER SAND TOP LOWER SAND BASE LONER SAND. PSTg T~) MEASUREO DEPTH ~ELOW K8 7690.00 7789.0D ?944.00 811Z.OO 8217.00 8315.00 SURFAC~ COCAT%ON ORIGIN,: 1060' FNL,90i' FEL,S~C ~.TIZNpRgE.UH TVD R~CTANGULAR CQDRDINAT" FRaM KB SOS-SeA 6332.51 6250,.6L 6e0,1.. 6~ 6319o64 651.1.29 5429.29 6632.94 '6550.ge 671~.19 ~629.1g 678¢.54 670Z.5~, 2575.91 N '217'6'o75 2630.85 N 2221.66 2Z1~.49 N 22gI.Z! Z ~04,.. ~6 N 2365.30 2857.26 N 2~I~, I.,,36 2905. ~5 N 2.~5~,.42 FINAL WELL LOCATION AT TO: TRUE SU~-SEA MEASURED YERTICAL VERTICAL OEPTH DEPTH DEPTH 83L5.00 6784.54 6702.5~ HDR[ZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 3803.78 N 40 11 E SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY- ARCO ALASKA INC WELL 3C-9 F I ELD KUPARUK COUNTRY USA RUN ONE DATE LOOOED 14 JUL 85 REFERENCE 0000?06?8 . WELL NAME: 3C-9 SURFACE LOCATION: 1060' FNL, 901' FEL, S14, T12N, R9E, UM VERTICAL PROJECTION -ZOO0 -I000 0 O' 1000 ~000 3000 4000 ~000 GO00 rrl o o 'TI PROJECTION ON VERTICAL PLANE 42. - 222. ~ALED IN VERTICAI.~PT~ HORIZ SCALE = 1/1000 IN/FT , WELL NAME: 3C'9 SURFACE LOCATION: 1060' FNL, 901 FEL, S14, T12N, R9E, UM · HORIZONTAL PRojEcTION NORTH ~t500 REF 000070~78 SCI:ILE = 1/500 IN/FT 2OOO 1500 1000 500 SOUTH -SOO I i' ' ii I I _ I . .: : i : : : : : [ : [ : : .......... - j · t , ~ : ~i i ! 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T'"i'"~-'?-'?T'T"?-T'"-': ,~: --'"'t-~-:~-.:'--t''' F-:~"-'-t-. ?'"I"T-?-T-"T'' 'T?-?-I":t-T"?-"?"'?~' "-?'-'?'?"?-!-?"'?-?'? '- '%i'-H-"~";'"h"' "U'"%'i ....... ~"'~ .......... !--.?-.:'--d--::--?-?+--r.;.t---h~ i-t~-t.--~-~:.-+i-~r-?~j~?-?-~,i-?i-+-~ ...... ?+% - 1000 -500 0 500 1000 I SOO 2000 2500 3000 NEST Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. 'OP'ER~TOR, WEL~NAblE AND NUMBER Reports and Materials to be received by:~. --/?"/' ~ ..... ~.~.~t~. "Date Required Date Received Remarks Completion Report Registered Survey Plat ,:~}:~ % ~ ~ ~ -: ...~ Inclination Survey .: Directional Survey / Dr~ll Stem Test Reports Production Test Reports / Digitized Data STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: RE: Receipt of the following material which was . transmitted via is hereby acknowledged: QUANTITY DESCRIPTION DATED: Copy sent YES to sender STATE OF ALASKA ALASKA oiL AND GAS CONSERVATION CO,.,{ISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: JJ~as~ka Of.l and Gas Conservation '"' ' · ~-O~SS1OD O001 Porcupine Drive Ancboru~e bJaska ~501 Receipt of the following material which was transmitted via /~// is hereby acknowledged: ~OANTITY _/Y~/:'~/" ~Ji"_ DESCRIPTION Copy sent to sender YES NO _~ STATE OF ALASKA ALASKA oiL AND GAS CONSERVATION CO~..,,ISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 State o~ .ilaska TAO~ka 0~I and Cas Consen, aficn Commission SO01 Porcupine Anc~m_-a~e, Ai~ka ~'-2501 Receipt of the following material which was transmitted via is hereby acknowledged: ~UANTITY Copy sent to sender YES N0 ~__ STATE OF ALASKA ALASKA oiL AND GAS CONSERVATION CO',.,IISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: State of >3aska Alaska Oil and G:~: Cm:sev:ation Commission 3~01 Porcupine Drive Anchorage.., Maska 99501 RE: /A:?~t Receipt of the following material which was transmitted via ..~ / / is hereby acknowledged: QUANTITY DES CRI PT I ON / '~. . - ~.,~ ~.~ ? ~ ~. ~ . /£-7-,~I~.,,~; ~ ~ ~ ~ ~, ~ RECEIVED: DATED: Copy sent YES ,, to sender ARCO Alaska, Inc. Post Ollice Box 100360 Anchorage, Alaska 99510.-0360 Telephone 907 276 1215 DATE: 08-0 ~-85 TRANSHITTAL NO: 5285 ~ETUP, N TO: ARCO-ALASKA, INC. KUPAI~UK OPERATIONS }JNGINEEHING t~ECOal)s CL~kK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 I'KANSMITTED HERE~4ITH ARE THE FOLLOWING IT}/4S. '"PLEASE ACKNO~¢LEDGE ~ECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. iN BOX 1 OF 2: 3PEN ~OLE LIS TAPES PLUS LISYING$ (ONE COPY OF EACH) 3C-11 06-23.-85 RUN #1 4427.5-8881.5 REF 970597 3C-10"' 07-02-85 RUN ~1 1785.0-8987.5 ~EF #70620 3C-9~' 07-10-85 HUN ~1 3920.0-8332.5 REF #70642 ~C-7~ 07-31-85 RUN #1 4617.5-8747.5 REF #70706 3B-14-- 03-20-85 RUN #2 3280.0-6~03.5 R~F #70229 3B-12-- 07-03-~5 RUN 91 4021.5-8261.5 REF #70641 3B-11~ 06-26-85 RUN ~1 2190.5-9257.0 REF #70598 3B-10' U6-17-85 RUN #1 3273.0-7270.5 i~EF #70555 3B-9--" 06-10-85 RUN #1 2092.0-8415.0 REF #70634 2Z-15" 06-19-85 RUN %1 2658.0-6620.0 REF #70562 2Z-14-' 06-28-85 RUN #1 3876.0-8334.0 REF #70600 2Z-13' 07-05-85 RUN #1 4180.0-8538.5 REF #70639 2Z-12-- 07-20-85 RUN #1 4409.0-9412.5 REF #70661 ~Z-11~ 07-27-85 [{UN #1 3531.5-7534.0 KEF #70704 tN ~OX 2 OF 2: ~PJiN_~__HO. LE LIS TAPES PLUS LISTINGS (ONE C~)PY OF :w-16~/ 01-28-85 RUN #1 3116.U-7038.5 REF ~V-14''/ 05-16-85 RUN %1 3047.0-7086.5 REF ~V-12~ 04-22-85 RUN %1 3960.0-9265.0 REF .U-10z// 04-11-85 RUN %1 2972.0-7063.0 I~EF .U-7w~ 03-1-9-85 RUN #1 3594.b-8179.5 REF A-13w'~ 07-16-~5 RUN ~1 7649.5-8160.0 I~EF R-13'/ 07-27-85 kUN #1 3940.0-8578.0 REF _R-12~''~ 07-20-85 RUN #1 3935.0-8277.5 REF .R-11'-~'-' 07-13-85 RUN #1 3810.0-7213.5 REF _R-10~'''~ 07-06-~5 RUN #1 2991.0-8738.0 I<EF .R-9'~./ 06-28-85 RUN #1 3991.5-8131.0 REF ~{-7~'O U6-04-Sb RUN #1&3 0045.5-7103.0 kEF EACH) # 70436--- REVISED # 7 U 614---REVISED # 70613---HEVISED ~- # 70612---kEri SED -- # 70505---~{SVISED "-' #70645 #70702 #70660 %70643 #70640 #70601 #70509 ECEIPT ACKNO~4LEDGED: DISTi~,IBUTION: PAE D~ILLING W. PASHER . CURRIER L. JOHNSTON EXXON _4EVRON ~JOBIL PHILLIPS OIL & M NSK CLERK J. RATHMELL DATE: ~.l~,~,.~ ~ ~ , , -- ~ Cons. Commission STATE OF ALASKA*' ' SOHIO UNION K.TULIN/VAULT ARCO Alaska, Inc. ,.----.. Post Office Bc J0360 Anchorage, AlaSka 99510 Telephone 907 276 1215 August 14, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton- Enclosed are the July monthly reports for the following wells' 2A-13 3C-10 2Z-11 WSP-20 11-11 2A-14 1R-10 2Z-12 9-31 12-3 (workover) 3B-12 1R-11 2Z-13 9-32 12-5 (workover) 3C-8 1R-12 2Z-WS#1 9-33 14-3 (workover) 3C-9 1R-13 WSP-9 (2) 11-10 14-5 (workover) L1-14 L2-20 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU10/L120 Enclosures RECEIVED AUG ! 1!ttl5 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRIchHeldCompany STATE OF ALASKA ~* ALASKA O,~ AND GAS CONSERVATION CON..,IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wel~(~] Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 4. Location of Well at surface 99510 1060' FNL, 895' FEL, Sec.14, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 82' RKB 6. Lease Designation and Serial No. ADL 25629 ALK 2562 7. Permit No. 85-100 8. APl Number 50- 029-21 355 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3C-9 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of July ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0530 hfs, 07/4/85. Drld 12-1/4" hole to 3960'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 8315'TD (7/10/85). Ran, cmtd, & tstd 7" csg. PBTD = 8215'. Secured well & RR @ 1000 hrs, 7/12/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40 weld conductor set ~ 116'. Cmtd w/202 sx CS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe @ 3943'. Cmtd w/1150 sx AS Ill & 300 sx Class G. w/lO0 sx AS I. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 8299'. Cmtd w/440 sx Class "G". Performed top job 14. Coringresumeand briefdescription None 15. Logs run and depth where run DIL/FDC/CNL/GR f/8312' - surface CET/GR f/8210' - 7485' GCT (Gyro) f/TD to surface 1 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED /~ .,~'~,1,,, f~ ~ ~,/l,(,4./,~.J~, TITLE Associate Engineer DATE ~.14-,~_~ NOTE--Report~bn//this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. ........... DRH/MR09 R,~hmit in duolicate MEMORANDUM TO: THRU FROM: State of Alaska ALASKA OIL A/:~I)' GAS CONSERVATION CO}~iISSION .~..~a~t ~ C. t rton DATE: Cha% F,,E NO: Lonnie C. smith / · Commis 8 loner TELEPHONE NO: Edgar W. $:i. ppie, , r~~~_~~ SUBJECT: Petroleum inspecto July 9, 1985 D.EWS.48 BOPE Test ARCO's KRU, 3C-9, Permit No. 85-100, Kuparuk River Field. Saturday, July 7, 1985: i traveled this date from ARCO's Kuparuk C~F #i,-(subject' of 'another report), to ARCO's Kuparuk 3C-9, P~rker Rig 191, to witness a BOPE test. The drilling contractor was zn the process of finishing the hole.. Sunday, July 8, 1985: The BOPE test comenced at 12:30 am and was con~i~ded"at"2:55 am. There was one failures. The upper Kelly valve, it was replaced and tested to 3,000 pounds satisfactorily. I filled out the AOGCC BOPE inspection report which is attached to this report. In summary, I witnessed the BOPE test on ARCO's Kuparuk 3C-9, Parker Rig 191. Attachment 02-00IA(Rev. 10i79) O&G #4 ,5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Operator Well Location: Sec /~ Drillin~ Contractor Location, General General Housekeeping ~ Rig Reserve Pit Mud Systems Trip Tank Pit Gauge Flow Monitor R$6 Well Sign Visual Audio Gas Detectors BOPE Stack An~u~ar Preventer PiPe ~ams Blind Rams Test Pressure 3000 Ch6~e, Line Valves ~. ~. R. Valve Kil~-~'L{~ Valves ~ Check Valve, /~3 Test Results: Failures ..---1 Representative ~, Permit # fY~ Casing Set @ ~gq~ ft.~O Ri #t~I Representative V~. ~J~ ACCUMULATOR SYSTEM Full Charge Pressure ~O..~O psig 3~~ Pressure After Closure ! R~O psig ~O Pump incr. clos. pres. 200 psig O min~Ssec. Full~ e~Charge Pr~sure Attained: ~ min/g, sec. N~~~)__ ~/,, %/~ psig Controls: Master ~/~ ~~4 Remote y~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly~,{t~ Test Pressure , Lower Kelly OK ~est Pressure Ball Type .0~ ~est Pressure Inside BOP ~~t Pressure _~ Choke Manifold O~Test Pressure va ve Z No. flanges ~ Adjustable Chokes ~ Hydrauically operated choke ~ Test Time ~hrs. ~ Repair or Replacement of failed equipment to-be made within A//~ days and Inspector/ Commission office notified. Remarks: 0[_ ~~~ · ~o._~i~_ ~/*,[, ~ oo'~.! ~..t_ ~.~~'~ ' ~- ~[~ ~F~, .pr~,~9, ~,.~ { ~r~, DistribUtion orig. - AO&gCC cc - Operator cc - Supervisor ARCO Alaska, Inc'~ Post Office ,-,,.)x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 'May 20, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 3C Pad Wells 1-16 Dear Elaine' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer J G/tw GRU6/L113 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Y: 5~995~835.15 Let. : 70023'58.955" SEC.~ WELL I ×- 528,205.68 Long.: ~ SEC. 14 596"FNL~ 1366'FEL N O R T H - Y = 5,995,893.73 Lot. = 70°23'59.532" WELL 2 x= 528,193.14 ~ne.=149°46'13.983' 537' FNL~ 1378'FEL Y = 5~995~952.43 L~t. = 70°24'~.110" WELL 3 x= 528,180.60 Lon~= 149°46'i4.343' 478'FNL~ 1390'FEL Y=5~996~011.07 Lot. = 70°24'~.687' ~* WELL4 X= 528,168.12 Long.= 149046. 14.703" 420' FNL~ 1402'FEL ~ ~~ ~ ~.~ ~ ,=~,~,o~.~ ~,,.= ~oo~.o,.~,~., ~ '~'~ ~ ~ ' ~ WELL5 X=528,520.16 Long.= 149°46'04.3~' 346' FNL ~ 1050'FEL ~ = 5~996~027.76 Let. = 70°24'00.837~ WELL 6' x=528,532.83 Long.-' 149°~'~.015" 404' FNL ~ 10~' FEL Y= 5~995~969.11 L~f. = 70°24'00.260'' WELL 7 x=528,~5.24 Long.= 149046'03.658" 463'FNL ~ 1025' FEL ~ Y= 5~995,910.44 Lot. = 70°23'59.685" ~ WELL 8 x= 528,557.71 Long.--149°46'03.299" 5~'FNL ~ 1013'FEL Y= 5~995~372.49 L~t. = 7~25'54.~7" WELL 9 x= 528,672.61 Long.-' 149°45'59.995" . ~ ,~ ~o'~,~, 9o~'~ 3 Y= 5~995,314.06 Lot. = 70°23'5~.812" WELL 10 x= ~8,ss~.o~ 1119'FNL ~ 889' FEL Y = 5~995,255.22 Lat. = ~°23'53.233" WELL '11 x=528,697.61 ~n~= 149°45'59.274" 1177~FNL~ 876'FEL Y = 5~995~ 196.51 Let. = 70°23'52.6~" WELL 12 x= szs,7~o.~ Lo,~.= pRILL SITE 3"C . .c~:,'=.oo' ,.~'~.~. ~'~ AS-BUILT CONDUCTOR LOCATIONS ~=5,995,121.53 Let. = 70°23'51.929" WELL 13 x= 52e,35e.~0 ~ng.= ~49°~'09.235' WITHIN SECTION 14~ TI2N~ 'E9E~ U.M.~ ALASKA 1310'FNL~ 1217'FEL NOTE: Y= 5,995,180.01 Let. = 70°23'52.5~" WELL 14 x=528,3~.63 Long.= 149o46'09.594" COORDINATES ARE ALASKA STATE PLANE ZONE 4. 1251'~L ~ 1229' F~ SECTION LINE DISTANCES ARE TRUE. Y= ~995~238.66 LoL = 7~23'53.084" HORIZONTAL POSITION PER LH9 6 ASS~. MONUM~S 19-1 ~ 19-2. WELL 15 X= 528,333.07 Long.= 149o46'09.956" VERTICAL POSITION PER LHD 6 ASSOC. TBM OPI6~ 6 DOC. 125. 1193'FNL~ 1241'FEL · WELL NO. 6 INFORMATION PER DWG. NO. NSK 9.05.303dl. Y= 5~5~297.32 Let. = 70°23'53.661" WELL 16 x= ~e,~zo.55 11~4' FNL~ 1253'FEL CERTIFICATE OF SURVEYOR ~ I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTIC~ LAND SURVEYING IN THE STATE OF ALASKA ~D THAT ~-~ O~ THIS PLAT REPRESENTS A LOCATION SURVEY ~%~ eeeeeee-;~l~. MADE BY ME OR UNDER MY SUPERVISION, AND ~.e ~ ~. THAT ALL DIMENSIONS AND OTHER DETAILS ' ' ,~- ~'-.' ~ ~.11 ;~ - SURVEYED 0R: ARCO Alesko, Inc. ~.,~ .: ~~~~~ I~11 ~ : D~,~ MAY I~, 1~85 "': ' ' '?. ~ P. ~OSE~T BELL ~ nopnn ~.~. J. DAVIS ~REPARED F~: ALASKA OILFIELD . ~.'.,.,.; ~, A",. ,o, 3252~ CHECKED J. HERMAN ~ ESSI0I~ 3340 Arctic Boulevard, Suite 201, Anchorage, Alaska 39503 JoB ~ 85029 May 17, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3C-9 ARCO Alaska, Inc. Permit No. 85-100 Sur. Loc. 1060'FF~, 895'FEL, Sec. 14, T12N, R9E, UM. Btmhole Loc. !656'FSL, 1633'FI~IL, Sec. 12, T12N, RgE, I~4. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AJ~C 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys, Many rivers in Alaska and their, drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated'thereunder (Title 18, Alaska Administrative Code, Chapter 70) and bv the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. Kewin Kuparuk River Unit 3C-9 -2- May 17, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, ~1~ 0~1 ~ 0~ ~o~~~o~ ~o~~o~ BY ORDER OF THE CO~ISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. ~"~'" Post Office E,. ~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 10, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 3C-9 Dear Mr. Chatterton. Enclosed are' An application for Permit to Drill Kuparuk 3C-9, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore ° A proximity plat A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment We estimate spudding this well on June 28, 1985. If you have any questions, please call me at 263-4970. Sincerely, Area Drilling Engineer JBK/LWK/tw PD/L87 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompany STATE OF ALASKA ALASKA [.r,L AND GAS CONSERVATION CO,.,~vllSSION PERMIT TO DRILL ^^c DEVELOPMENT OIL ~X SINGLE ZONE DEVELOPMENT GAS la. Type of work. DRILL REDRILL DEEPEN 2. Name of operator ARCO Alaska, Irc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1060' FNL, 895' FEL, Sec.14, T12N, RDE, UM At top of proposed producing interval 1185' FSL, 1195' FWL, Sec.12, T12N, RDE, UM At total depth 1656' FSL, 1633' FWL, Seco12, T12N, RDE, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 83', PAD 48' 6. Lease designation and serial no. ADL 25629 ALK 2562 9. Unit or lease name Kuparuk River Unit 10. Well number 3C-9 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 1060' feet 3C-lOwell 60' ~ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 8187' MD, 6798' TVD feet 2560 06/28/85 19. If deviated (see 20AAC25.050) 120. Anticipated pressures 298/; psig@ 80OF Surface KICK OFF POINT 2400 feet. MAXIMUM HOLE ANGLE 45 oI (see 20 AAC 25.035 (c) (2) 3427 psig@ 6656 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program r SIZE SETTING DEPTH QUANTITY OF CEMENT Hole '24" Casing Weight 16" 62.5# 112-1/4" 9-5/8" 36.0# 18-1/2" 7" 26.0# 22. Describe proposed program: CASING AND LINER Grade Coupling H-40 Weld J-55 BTC HF-ERW J-55 BTC~_~ HF-ERW Length MD TOP TVD 80' 36' I 36' I 3853' 36' I 36' 8152' 35' I 35' MD BOTTOM TVD 1161 116' 3889' I 3743' I 8187' 6798' I (include stage data) ± 200 cf 690 sx Arctic Set III & 300 sx Class G blend 300 sx Class G blend ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8187' MD (6798' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-.,5J~" ~f¢ce..oiDe._J~ will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (..v~ psi ~t'~r an~i;d~a~.~Expected¢~'/f~ - z,~-;_,_ ~ ~ maximum surface pressure is 2984 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested ~o 3000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3C-9 will be 60' away from 3C-10 at surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process~.T~..w~.~l.~.b~.c~m~l~te~_(~e attached sheet) · 23. I hereby ce~fy that the foregoing is true and correct to the ~est~ k~~¢/¢~ ¢~ ~ ~¢~2 ~ ~~ SIGNED TITLE Area Drillin~ Engineer DATE The spa~o~ ~r ~o¢is~ u~'- " CONDITIONS OF APPROVAL Sampies required [] YES ~!.O Permit number APPROVED BY// ?// Form 10401 (LWK) PD/PD87 Mud log required []YES ~ Approval date ....., .,.,05J 17./85 / Directional Survey required APl number J~ES I~/NO 50- ¢ Q.-9 ~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE :May 17, 1985 by order of the Commission Submit in triplicate PERMIT TO DRILL 3C-9 by the workover rig using 3-1/2", 9.2#/ft, J-55, 8rd tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED Oil & Gars Cons. Commission Anchorage ,. ,,- : ._.. : : : ~ ~___~_L ~ : . ~ -" ~ : ~. ~ ; · . ~ : . ·,.._',__._! ....... __+_ ...... ~ .... , : · ~ : ~' ',: :: :fi', : ~ ..--~..---~---~._. , ~ ~ ~. ~ .. :. -_._ ,~ ..... · _ ~_~_:_~L%~-.~-~---~.., BASE-PER~ROS~-T~D~lZ ~0_~-~ . ..... : ~ .~ : ~ ~ ; ~ ...:--~-~.~~ 7 '7 ..... t ~;..~ ...... , - · ~ .... .'_~_~'~----~ .... --~--~---~-' T~ ~:-' . , ~. '. i ~ :: : , . ~ ;- . FI, ELD,, 4NOR-TH- [PSTOCK~-I _, ! · -I j ' . - ...... , . : . ; . : ~ : :-!_: ~-~--.-:-=-:~ ......... I ...... ------'--~ ' ' ; :'i ~ "~ '-' ~ ......... ' .... ..... . : ._ ~_-J.-7'~-:--:--i:~-- _~_:::_~:..,,c::.._' ........ 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J-J ; ;4 ' ' '-,-~--;-~-' ---F~-~--~--- '--: - ;. ;- -f--~-i-~--- :-'~"~'~- -~]--7-~-?~'.= ~-~'-~-~'" ..... .... , ~ - - : ' :--t :'~ ~.' ~ --~ .... ~ .......... ~=----= .... = ......... ~ ............................................... ~-:1-- .......... , , .... .... : ..... , ...... . . _... . , , . , , . . , . ..... . .... · '-'- : ' "- -+': .... : -~ ..... : ' ~ ; ' - !" - ::'i -- ~ -'; ~ :T~ "i :-4 - : j - :- ~'i_-~_'_---'-'-T---- j ' . · ' : - · . _' · ~: ": ' = ~. .... : ~ ' ~ ' ' ' ' __~_~_~ -L ...... --~ --~ --~- ~ - J .... ~--' - IlI · RECEIVED Alaska Oil & Gas 'Cons. Commissiori Anchorao~ i7 o. , A~ATC::R CAPAC~[~'~ TEST I. C3-ECX .aN:) FILL ~ ~ THAT ACOJQJ. AT'~ ~ IS tO(ID PSI WITH I.~DO P~I DON~T~_..~ 3. ~ TII~... T~ ~ ~ ~ SIXThlY 5 4 '7. '_RE EIVED 14. Gas. cons. commission 1~-5/8' ECP STACK T~$T FILL al3D S'T,/lCX AND CH:X[ NeNIFCLD WITH AI~'TIC DIE.ND_ CI-ECX THAT ALL LCO,C {DDN4 SC:RE~ 1N ~_...LI-F_~ ARE FLL.LY i:~"r~ SE_AT TEST PLUG IN ~_._Li,,EAD ~TH RLNNIhG J'r N,,D i;a.N IN LCX:D,O:3:I~ SC~t~6. Lib[ VALVES AJ:U~ TO BaD STAO, L ALL F4~SSLI~ I.~ TO ~0 PSI AND MaD F'CDR I0 I,~N. IN,- ~ 14~?~_J:~ TO ~OO PSI AND ~ F'~ I0 laIN. ~ ~r'r~ ~ TO 0 PSI. (IN KILL AN:) C3-K],O[ TE~'r TO ~50 PSI Ah,D 3¢00 PSI kS IN STEP 4. C~INI.~ TES'rlI~ AlL VALVE..~ LINES. ~ ~'ITH A ~50 PSI LO~' AND 3¢X30 PSI HlOH. TEST A~ IN hOT A FULL O_O5IhG POSITIVE SE~i. O..Z;~, ChLY ~ T~ PII~ ~ ~ID O.~ BO'ig~ PIP~ P.A~. TI~T BOT'r~ PIPE RA~ TO ~DO PS] AhD ~XDO PSI. ~I~ ~ ~ V~ IN ~1~I~ ~ITI~ ~ ~I. 54 5100~,00 f Lease & Well CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE 1. Is 2. Is 3. Is 4. Is 5. Is '6. Is "t ,/1 c" '~ ,'(8) ,."' ,,' ..... 'g-t. ¥; 9. (3) Admin ~,~'--. "' ~' '"" (~thru 12) , 10. ~r/,.' ,,-~.,,"[., ,:..,'"' .c: .... . ,.~ :,,',.~' ... ........... 11 (10 and 1'2)"' 12. Company YES NO the permit fee attached ......... ................... :~--,, ~ ,:,//>, .,.'. ............. (13 th'ru ~1)/' 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... well to be located in a defined pool ................. '""': well located proper distance from property line ................. well located proper distance from other wells ................... sufficient undedicated acreage available in this pool ........... well to be deviated and is wellbore plat included ................ ~/~ 13. 14. 1.5. 16. 17. 18. 19. 20. 21. Does operator have a bond in force .................................. Is a conservation order needed . ~ .................................... Is administrative approval needed ................................... . ~'~-~ Is the lease number appropriate ........ ............................. Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing.wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed eeeeeeeeeeee.eeeeeeeeeeeeeee,,-., REMARKS (5) BOPE .... ':."~.],, (22 thru 26) 22. 23. 24. 25. 26. 27. Is a diverter system required ........................................ ...:.. Are necessary diagrams of diverter and BOP equipment attached ....... ' .... Does BOPE have sufficient pressure rating Test to ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............ ~ ................................. 0 Geology;. Engi, neering: w-v~ ~rrM >~'- HJH '~,'.,:?" JAL ~-- rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. RECEIVED Alaska 0il &, Gas Cons. Commi,~sion LVP OIO,HO~ VERIFICATION LISTING PA~E 1 SERVICE NAME {EDIT ORIGIN : CONTTNUA?I~N ~ :01 PREVIOUS RgET,, : COMMENTS : DATE OR~GIN :0000 TAPE NRM~ 10642 CONTINUATION # 101 PREVIOUS TAP~ COMMENTS rILE NAM~ ;~D~ ,001 SERVTCE NAME l VERSION # I DATE t ~XIMU~ LENGTH { 1024 FILE TYPF { PReViOUS FZL~ : UNIT TYPB CATE 8lEE CODE 007 oo ~N ~ KUPARUK R~NG~ 9E 0 O0 065 ~BCT~ 1,4 000 000 00~ 065 ~OUN~ N,SLOP~ 000 000 STaT~ AbASKA 000 000 006 065 CTRYt USA 000 000 003 06.5 MN~M CONTENTS UNiT TYPE CATE 8X~E CODE PR~S.t ~ 000 000 001 065 ** COMMENTS *.* ********************************************************************************** · TING C~N g **** ****************************************************** ~Tb~NTIC RICHFIEbD COMP~N COUPON¥ ~ 3C-q U' STAT~ JOB NUUOER AT ~CCI 70642~ ,~O~ #ONE, D'A~rE bOGgED: o. JUL.,95 bOP: C~ = 6:~5" g 36.00' T¥~E FLUT[, = vlScns~T¥ = 5 2,800 I ~0,0 DF 2,2~0 70,0 DF ~,~ ~ ~°'°o% 1,373 150, r RECEIVe!) Alaska Oil & Gas Cons. Comm~ssb~ LVP O10.H02 VErIFiCATION LISTING PACE 3 , * ~O~h INDIIC?ION SPHERICALLY FOCUSED * FORMATION,DENSITY COMP~NSATE~ LOG * CONPENSA?E~ NEUTRON I,,0~ (FDN) , , , , , , , , · , , , , , · , , , · ** D~TA FO~T RECORD gNTRY BLOCKS TYPE SIZE REPR CODE 2 1 66 0 4 I 66 $ 4 73 60 9 4 65 ,lIN 16 ! 66 0 1 66 0 ID ORDER ,# DEPT SP DI'b RHOB FDN DRHO FDN NRAT FDN ~NRA FDN NPHI AP1 bOG FT O0 OHMM O0 OHMM O0 ,:'! AP1 APE FILE SI~E Smb REPR ~0 O0 ~V O0 0 ~API O0 CAPI O0 ~N O0 C/Ci O0 ;0 oo PU O0 I 1 1 1 1 1 I 6e PROCESS CODE COCT~b) 68 000o0000000000 68 00000000000000 68 00000000000000 68 0000000000'0000 68 00000000000000 6'8 )0'000'0:0'0000000 68 I0000000000000 68 0000000000000 68 ,0000000000000 0 ~0 o CPS O0 O0 330 31 0 0 4 330 ~0 0 0 4 ! 68 00000000000000 68 00000000000000 DEPT 8332.5000 8Ft, U SP -t4.4844 GR ~HOB -999.2500 DRHO NPHI -999,2500 NCNb DEPT SP NPHI 8.300,0000 ,bFt, U 126,5313 GR 46~9 DRHO DEPT SP ~PHI 8200 700500 SFLU oo 2,4609 DRHO 32.~125 NCNb DEPT SP NPHI 8100I~ 0000 SFLU 36' 031 3 GR 4316 DRHO 41 O645 NCN6 DEPT SP RHOB 80.,00,0000 8FLU 33.03i3 OR 32. lqCNb SP RHOB SP.. NpH! DEPT 'RHOB NPHI ooo , ~CNb SP HOB 7700,,0000 SFLU '4].:28!63 GR ..474 DRHO 31.4453 ~CNb 7~00 -g99 ,0000 SFLU · ~500 HO 02,9492,/ IbD 2.6953 ]ibm ,.oooo ?,, .2500 NRA[ -,99, O0 RNRA 9q.2500 FCN -q99.~500 ],2520 ~bD {,09943 Tbt~ 107,0000 GR 10 , O0 CAb! 0 ,~lg2 .RAT 1.8887 RNRA 2616; 000 FCNb 93 .0000 50O ~R 2500 o 2 7578 2070 0000 XbD 2.8516 ~R ~0{.0000 CA~I NRAT 3 4609 RNRA FCNb 662' ,5000 9 ,1875 O, 0317 2~64.0000 ~75 FCN[ ~ 000 7.3789 XbD 81,0000 OR oooo 8,.. 2070 CAb! I020, 000 6,2i0:5 Ila:D 8?,6 50 ~R O: I6) CAbI IR'NRA 30 3'87t:~ CAbI . R NRA 7'96, O0 GR 195 ~,0000 ?CNL 621~, RN:RA 1,6816 [bD t21.,9375 gR '999.2500 NRAT I 6807 IbM .12~:93:75 CAI,! 999.2500 RNPA 2.6504 -999,2500 -999,2500 2,9629 .8281 ,BOOB 8, 844 2,87 50 9 37'5 3 t 230 2~955i ,6719 ~:,' 842,6 3,5703 , 844 3,1:523 1,7305 10,0547 -999,2500 [JVP 010.H09 VERIFICATION LISTING PAGE 5 ~PHI -999,2500 ~CNb DgPT 7a00 0000 ~FLU SP -44:03~$ ~R RHOB '999,2500 DRHO OEPT 7]00.0000 ~FLU SP '4~,2813 ~HOB 'a99,2500 DRHO ~PHI "999.2500 NCNb 7200.0000 -49.~813 -999,2500 DRHO -999.2500 NCNb 7[00.0000 ._40.53i3 ~R .999,2500 DRNO 999,2500 NCNb 7000,0000 SF[.U -9~.2500 OReO 6900,0000 .-42'5000 999'~500 DRHO ~999,2~00 6800.000~ "44.03~, ~R DR'HO 6700.00 0 ,999,~$ DRHO "999,2500 .NCNb 6~::00,.:0000 ,42,3125 .999;2500 DRHO '999.9500 NCNb 6500'0000 .-44,03~3 GR g999.~50 999,~500 NCN~ 6~00.0000 45.53~3 DEPT Sp RHOB SP, RHOB NPHI SP OEPT RHOB ~PHI OEPT RHOB NPHI SP, R'HOB SP.. RHOB ~PHI RHOB D~PT -099.2500 FCNb .,2813 99.25~0 rCNb 2.5352 - 9,2500 -999.~500 2, ? -999.~500 -999.2500 1 ~13,.2500 '999,2500 '99q,2500 106,5000 -~99.2500 2,~14~4 102;9175 -999,2500 -999,2500 -999 2 .096 .99 '999 2500 -999.:~500 -o99,2500 2.:1680 -099:.2500 GR FCNb TbD gR NRAT gR NRAT FC~L GR rCNb .TkD trCNb gR I.LD GR NRAT -999.2500 2,2246 122.3750 -999.{500 -999. 500 O0 -999 2500 2,~031 228, 250 -999,2500 -999,2500 ~!,9473 ! ,~500 -9 ..,2500 -999.2500 2.1523 1 6. , O0 ~.15~3 2 .:~9 -9~.9 2500 -9'99 ! 0 CALI RNRA RNRA IbM CALX RNRA CAb ! RNRA RNRA IbM CAbl RNRA .bM¸ RNRA EALI RNRA RNRA 9, 8 -999, 0 1~,3516 'g9 ,2500 ,-% ,.-. ~.~ : '"" ":' "' ~-."~-..t, ,3 ~; 2,2617 AiaskaOii & ~ 9.9453 ' 2,0742 9,6406 -999,2500 2,2051 9. 8906 -999. 2500 -999,2'500 2, :4~44 999,2 0T -q~g O0 2,2656 9,9:I'4~ '999.2~00 LVP 010,H0? V£RIFICATION hYSTfNG PAGE 6 NPHI RHOB D£PT NpH! SP SP RHOB ~999 :?500 999:25no 6300,0000 .4n.0000 '999,2500 -999.2500 -48, 25 -999 2500 -999~2500 6100.0000 . .999, O0 -999.2500 6000,0000 -51.0000 -999.~500 -999' 500 5900 O00O -999. O0 '999,2500 5~00 0000 -53 ~813 57o0,0o00 -5:6i$000 -999,2500 560~ -5'1 '9'9 lO0 -9 iO0 5~oo,Oo0o ;999,=50 999,~00 oooo 2500 "99~ 5000 "99... 2500 5300.0000 ~C~b SFLU SFLU DRHO ~CN~ 8FLU ~0 ~CNL 8Ft. U ~CNL SFLU DRHO SFt. U ~R DRHO S~F~LU DR:HO ,C',~ SF~U DRHO S'F~U DRHO Srt.~U -990.25o0 -999.2500 1 9936 112;5625 -999,2500 -999.2500 2.6387 97.2500 '999, 500 3.i465 103.2500 -999,~500 'q99.'2500 2.4238 99,6875 '999,2500 "999.2500 3 5723 115 i250 -9 2500 ,1,,250 ,o}:,sooo '999,2500 '999,2500 2,5410 98,!250 :~9~,~50o 999..2500 -999, O0 =999. O0 2.9980 09, )0 : 99. .99., 3,2832 ~)RAT I I~D OR NRAT F'CNI., I~RA~ FCNL., OR ~RAT C,R NRA'[' OR NRAT :R A T I~R'AT PCNL T'LD GE ~RAT PCN~ Iq R :A T :999.2500 999.2500 t.8857 ~2500 "999,2500 2.6953 -999,2500 ~999.2500 999.2500 3,1152 o999,2500 '999,2500 -999.2500 .99~'44~4 .999,2500 =999 *2590 .2500 .! oo .-999; O0 -~99'' O0 : 2793 -09! 2500 500 5'O0 '9'99 773 · )~ I0 -99'9 '0 ,4004 -99' .2500 3.,~086 RNRA RNRA CAbI RNRA RNRA RNRA RNRA RNRA RNRA IbM RNRA -999,2500 1 8867 , , 99,2500 2 .'/266 '999.22~00 -999. O0 3'i504 -999, 500 -999,500 .99~'44 3'i809 -999, 500 '999, 500 2'598 :,25oo -999.2500 2.6504 :999.;5oo q99,2500 ;{512 ..9'99,2500 3 ..2i02 099 g 3,36'/2 '999,2500 'q99. 2500 3.6055 ~P -5~ 5000 RHOB -999:2500 ~PHI -q99.~500 DEPT 5200 0000 SFLU SP -60:o000 ~a RHOB -999.~500 nRHO ~PHI -999.2500 DEPT 5~00 0000 SP -60:0000 RHOB -999.2500 DRHO NPH! -999.2500 ~CNb DEOT '500~ 0000 8FLU SP -6~'7500 OR HHOB -999:2500 DRHO NPHI -999.~500 DEPT 4900,0000 SP. ~66.~500 OR HHOB -999.~500 DRHO ~PH! 35.4950 NCN~ 2988 . RN~ 40.5762 DEPT 4~00.0000 SFLU ~ -69,7500 ~OB ~,29~8 ~PHI 38.7207 NCNb DEPT 4~00.0000 SFLU Sp. 69.2500 OR RHOB 2'330! D:RHO ~I 43,0664 NCN~ OEPT 4~00.0000 SFLU ~PH! 39,6484 DEPT. 4~00.0000 SP.. '74.2500 -999,~500 DRHO ~HOBpHi -990,~500 N'CNh DEP~ 4300.0000 $FLU -?,7500 ,H~B -99 .2500 OR.O NPHI -999.~500 102.7500 GR -990.'~500 NRAT -999.~500 FCNb ~.1,875 iUD 102.3125 OR -999,~$00 NR~T -~99.~500 FCNU 2.7813 IUD 105.1875 OR -999,2500 NRAT -999.2500 rCNb 2.'4980 ~UO 105.0000 OR -999.2500 NR~T -999,2500 FCNb ~,$445 110.68~5 GR "999.25 0 NRAT -999,~500 FCN~ oo::s2so OR 0,0063 NRR~ 2~32.0000 rCNb 2,7734 1050.3~25 OR Or?6 NRAT 204~:0000 -999* -999. .D RAT 1,4785 IbD -999, NRAT "99'9,2500 FCN~a :999.2500 999.2500 -990.2500 2.5352 -999.2500 -999 s°°soo ,, 2,9805 999. 2500 -999. O0 ,.999. -999.2500 -999.2500 2,9199 '99'9..:~500 -999,2500 '999. 2500 2.2363 ,62]0 10~,.52 ,~ 61~.0000 655'00 2 604 CALl RNRA CALI RN'RA IbM CALl HNRA ALI RNRA RNRA CALl RNRA RNRA CALl RNRA RNRA RNR:A CA:b ! RNRA -999.2500 -999,2500 2.4707 -999,2500 -999,2500 2,9121 -999,2500 -999.2500 2 48 '999:;~00 '999,2500 2,8477 .999,~$00 999, 500 o 10 3: '999,~500 ! 739 ' 50 999. 0 LVP 010,HO~ VgRIrI~A?ION L~$~ING PA~B DE:PT 4~00 0000 SFLU SP -?S:5000 ~a ~n~ -q99.2500 DRHO NPHI -q99.9~500 NCNL 2 ,3027 TbD 95'5625 GR 'q99,2500 NRRT -999,2500 rCNb 3.7266 IbD 102.3750 OR -999.2500 NRRT -999.2500 PCNb NpHI 4000 0000 ~FLU "89,7500 GR '999,2500 DRHO -q99.~500 NCN5 7 1250 OR -999,2500 NRRT -999,2500 FCNb DEPT 3.O20,0000 SFt, U SP -'52.2'500 OR RHOB :999.2500 DRHO NpH! 999,2500 NCNb 2000.0000 IbD -999 0 NRRT -999 "' 2500 FCMb ** F'IbE ?RIlLER FIBE NRME :~D~T ,001 ~E~V~CE NA~'E DATE~: ~AXI UM LENGTH ~ i024 NEXT 2.8359 -99 .2500 4,i 1 IbM -999, 500 RNRh · ,99~,. 500 '~. 5 ]:bM · ,99'9. 2500 RNRA -999.2500 2 7109 -999:2500 -999.2500 3,,8848 :999,2500 999,2500 7,0820 :g99,2500 99'9,2500 -99'9,2500 CALl 2,500 -999,2500 RNI~A 99 2500 -999,2500 DATE 185/il/~0 ORIGIN I0007 TA~E NA~E .,0642_ CONT'INU,A~IO:N # N~Xt W~PE NAME ~ COMMEN?$ ~ OR~GIN ~ ~DN~NUA?ION ~ N~X? R~BL NAN~ : LVP OIn,RO~ VERIFICATION L~STIMG PAGE 9 EOF ****~*~*~*