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STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 1E-12 JBR 07/20/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Good test. Closing times, Bag 15 sec., Upper rams 5 sec., Blinds 5 sec., Lower rams 5 sec., Both HCRs 1 sec. Test Results TEST DATA Rig Rep:Kelly CozbyOperator:ConocoPhillips Alaska, Inc.Operator Rep:Dale Rowell Contractor/Rig No.:Nabors 7ES PTD#:1820600 DATE:6/12/2022 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopRCN220613134645 Inspector Bob Noble Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 6.5 MASP: 2330 Sundry No: 322-321 Location Gen.:P Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec.P Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 none NA Annular Preventer 1 13 5/8"P #1 Rams 1 3 1/2" x 5 1/2 P #2 Rams 1 Blinds P #3 Rams 1 2 7/8" x 5"P #4 Rams 0 none NA #5 Rams 0 none NA #6 Rams 0 none NA Choke Ln. Valves 1 3 1/8"P HCR Valves 2 3 1/8"P Kill Line Valves 2 3 1/8" & 2"P Check Valve 0 none NA BOP Misc 0 none NA System Pressure P3050 Pressure After Closure P1500 200 PSI Attained P15 Full Pressure Attained P111 Blind Switch Covers:PAll stations Nitgn. Bottles (avg):P5 @ 1994 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA By Meredith Guhl at 4:12 pm, Jul 18, 2022 Page 1/6 1E-12 Report Printed: 7/7/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/10/2022 12:00 6/10/2022 18:00 6.00 MIRU, MOVE MOB P Load and move rig mats to 1E, Pull Sub off 1J @ 19:30 mob to 1E-12 6/10/2022 18:00 6/11/2022 00:00 6.00 MIRU, MOVE MOB P Sub turned off the Spine Rd, onto the 1E Pad access road. Loader operator install mats around 1E-12 6/11/2022 00:00 6/11/2022 02:00 2.00 MIRU, MOVE MOB P Sub turned off the Spine Rd, onto the 1E Pad access road. Loader operator install mats around 1E-12 0.0 0.0 6/11/2022 02:00 6/11/2022 13:00 11.00 MIRU, MOVE MOB P Sub pulled onto 1E DS, Spot sub over 1E-12. Spot pits to Sub. 0.0 0.0 6/11/2022 13:00 6/11/2022 16:00 3.00 MIRU, MOVE MOB P Spot Tiger Tank, Choke House and RU flowback Iron. Spot Mud Shack. Berm in Rig. 0.0 0.0 6/11/2022 16:00 6/11/2022 16:15 0.25 MIRU, MOVE SFTY P PJSM on MIRU and Raising the Derrick. 0.0 0.0 6/11/2022 16:15 6/11/2022 21:00 4.75 MIRU, MOVE MOB P MIRU on 1E-12. Raise derrick. Bridle down. Hook up Intercom. Turn on steam and ait onto pits. Perform Pre- Acceptance Checklist. R/U Circulating Manifold in cellar and Tiger Tank Line. Spot Cuttings tank. 0.0 0.0 6/11/2022 21:00 6/11/2022 22:30 1.50 MIRU, WELCTL OWFF P ******Rig Accepted @ 21;00 Hrs******* Take on 9.7 brine. Check presures on the Tubing=0 I/A=0 O/A=0 0.0 0.0 6/11/2022 22:30 6/12/2022 00:00 1.50 MIRU, WHDBOP NUND P N/D the adaptor and Tree, verify Movement on LDS, check hanger threads (Good) 0.0 0.0 6/12/2022 00:00 6/12/2022 02:30 2.50 MIRU, WHDBOP NUND P N/U BOPE, Choke & Kill lines, install riser. 0.0 0.0 6/12/2022 02:30 6/12/2022 05:00 2.50 MIRU, WHDBOP RURD P Rig up to Test BOPE 0.0 0.0 6/12/2022 05:00 6/12/2022 10:00 5.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested annular, UVBR's w/ 3 1/2" test joints. Test blinds rams. Choke valves #1 to #16, upper and lower top drive well control valves. Test 3 1/2" HT-38 FOSV and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3000 PSI, after closure=1500 PSI, 200 PSI attained = 15 sec, full recovery attained = 11 sec. UVBR's= 5 sec, Annular= 15 sec. Simulated blinds= 5 sec. Simulated LPR's= 5 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 1994 PSI. Test gas detectors, PVT and flow show. Witness by AOGCC rep Bob Noble. 0.0 6/12/2022 10:00 6/12/2022 10:30 0.50 MIRU, WHDBOP BOPE P BD / BD testing equipment. Drain BOP Stack. RD Test Equipment. 0.0 0.0 6/12/2022 10:30 6/12/2022 11:30 1.00 MIRU, WHDBOP MPSP P Hit pop it on BPV - Check for gas. Pull tree test dart & BPV. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 6/19/2022 Page 2/6 1E-12 Report Printed: 7/7/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/12/2022 11:30 6/12/2022 12:30 1.00 MIRU, WHDBOP PULL P Load Landing Joint to Rig Joint. M/U landing joint into tubing hanger. M/U TD. BOLDS. Unseat Hanger. Worked TBG up from 80k,110k,125 and 150k, no movement. Made a total of 8 cycle, up to 190k with no Movement. Dispatch E-Line for another cut. 6,735.0 6,735.0 6/12/2022 12:30 6/12/2022 13:30 1.00 COMPZN, RPCOMP CIRC P Circulate a Bottoms up until clean 9.7 ppg returned back. 3BPM, 285psi. 6,735.0 6,735.0 6/12/2022 13:30 6/12/2022 17:30 4.00 COMPZN, RPCOMP WAIT T Tubing was not completely cut. Waiting on E-Line Unit 6,735.0 6,735.0 6/12/2022 17:30 6/12/2022 19:30 2.00 COMPZN, RPCOMP RURD T Rig up E-line 6,735.0 6,735.0 6/12/2022 19:30 6/12/2022 22:30 3.00 COMPZN, RPCOMP ELOG T RIH with jet cutter on E-line to 6,610. Cut tubing but no indication that the tubing was cut. 0.0 6,610.0 6/12/2022 22:30 6/12/2022 23:00 0.50 COMPZN, RPCOMP RURD T POOH and set e-line equipment to the side. 6,610.0 0.0 6/12/2022 23:00 6/12/2022 23:30 0.50 COMPZN, RPCOMP THGR P Pull tubing free @ 80k, pull hanger to the floor 6,610.0 6,585.0 6/12/2022 23:30 6/13/2022 00:00 0.50 COMPZN, RPCOMP CIRC P Pump 30 bbl DeepClean pill down TBG up IA until 9.7 ppg NaCl is seen at surface. 6,585.0 6,585.0 6/13/2022 00:00 6/13/2022 00:30 0.50 COMPZN, RPCOMP CIRC P continue Pumping 30 bbl DeepClean pill down TBG up IA until 9.7 ppg NaCl is seen at surface. 6,585.0 6,585.0 6/13/2022 00:30 6/13/2022 01:30 1.00 COMPZN, RPCOMP PULL P L/D tubing hanger. 6,585.0 6,585.0 6/13/2022 01:30 6/13/2022 11:00 9.50 COMPZN, RPCOMP P POOH laying down 3.5 Tubing to from 6,585'. Pulled a total of 207 joints and (1) 8.78' cut section. From Joint 161 to 207, was showed pitting and corrosion on the low side and the collars. Joint 173 had the hole with the leak on it. Recovered metal chunk from joint 181. 6,585.0 6/13/2022 11:00 6/13/2022 12:00 1.00 COMPZN, RPCOMP CLEN P Clean and Clear Rig floor. 0.0 0.0 6/13/2022 12:00 6/13/2022 14:00 2.00 COMPZN, RPCOMP WAIT P Process Junk 3.5" TBG from Pipe Shed. Continue loading 5.5" Line to pipe shed while waiting Baker Multi-String Cutter to arrive from deadhorse. 0.0 0.0 6/13/2022 14:00 6/13/2022 15:00 1.00 COMPZN, RPCOMP BHAH P Load Baker tools to rig floor and MU same. 0.0 20.0 6/13/2022 15:00 6/13/2022 16:00 1.00 COMPZN, RPCOMP CPBO P Cut 5.5" Line at 4 bpm, 420 psi at 60 RPM. Seen good indication with a 40 psi pressure drop. 20.0 0.0 6/13/2022 16:00 6/13/2022 17:00 1.00 COMPZN, RPCOMP BHAH P Pull BHA to surface and L/D same. 0.0 0.0 6/13/2022 17:00 6/13/2022 18:00 1.00 COMPZN, RPCOMP OWFF P Monitor well for flow Static. 0.0 0.0 6/13/2022 18:00 6/13/2022 20:00 2.00 COMPZN, RPCOMP NUND P N/D BOPE and set back on stump 0.0 0.0 6/13/2022 20:00 6/14/2022 00:00 4.00 COMPZN, RPCOMP NUND P N/D Tubing spool, wspool would not freely pull. Steamed it (NO GO) pounded wedges between the flages (NO GO) 6,585.0 0.0 6/14/2022 00:00 6/14/2022 05:00 5.00 COMPZN, RPCOMP NUND P Make up Baker spear on a joint of DP, Screw into top drive, back out pack-off lock downs, work tubing spool free 0.0 6/14/2022 05:00 6/14/2022 07:00 2.00 COMPZN, RPCOMP PULD P Release spear and L/D. Pick up tubing spool with bridge crane, make a cut on the 5.5 casing (about a 12" below the tubing spool. L/D spool and pack-off. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 6/19/2022 Page 3/6 1E-12 Report Printed: 7/7/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/14/2022 07:00 6/14/2022 08:00 1.00 COMPZN, RPCOMP BHAH P LD DP pups and spear 0.0 0.0 6/14/2022 08:00 6/14/2022 10:30 2.50 COMPZN, RPCOMP NUND P LD 5.5" cut joint Clean and inspect wellhead function LDSset test plug 0.0 0.0 6/14/2022 10:30 6/14/2022 16:00 5.50 COMPZN, RPCOMP NUND P NU DSA 11" 3K x 11" 5K, install 11" 5K x 13-5/8" 5K spool install 3-1/8" valve on annulus. NU BOPS set stack torque, C/O rams LPR, installed 4.5" x 7" VBR. UPR installed 3-1/2" x 5-1/2" 0.0 0.0 6/14/2022 16:00 6/14/2022 18:30 2.50 COMPZN, RPCOMP RURD P RU test equipment and donut joint standing valve purge air out of system, mark joint. 0.0 0.0 6/14/2022 18:30 6/14/2022 19:30 1.00 COMPZN, RPCOMP BOPE P BOP's. LPR/UPR on 5-1/2" to 250/2500 PSI. 0.0 0.0 6/14/2022 19:30 6/14/2022 20:00 0.50 COMPZN, RPCOMP RURD P Install wear bushing 0.0 6/14/2022 20:00 6/14/2022 21:30 1.50 COMPZN, RPCOMP FISH P Run in with a 5" spear, attempted to engage fish, (No Go) stacking out right by the wear ring, POOH, set spear off to the side, pick up a jnt. of drill pipe with the wear ring puller, RIH and retrieve the wear ring. L/D wear ring puller & Jnt. of DP. pick up spear, RIH and attempt to spear fish (No Go) the no go ring is too big to fit into the 7" casing. 6/14/2022 21:30 6/14/2022 22:00 0.50 COMPZN, RPCOMP RURD P Install wear ring 6/14/2022 22:00 6/15/2022 00:00 2.00 COMPZN, RPCOMP WAIT P Wait on the right size stop ring. 6/15/2022 00:00 6/15/2022 01:00 1.00 COMPZN, RPCOMP WAIT T Wait on the right size stop ring. 0.0 0.0 6/15/2022 01:00 6/15/2022 02:00 1.00 COMPZN, RPCOMP RURD T Modify Stop ring in the shop 0.0 0.0 6/15/2022 02:00 6/15/2022 04:00 2.00 COMPZN, RPCOMP FISH P RIH, Engage fish, work pick up weight up from 80k - 250k 5.5 came free. 0.0 6,733.0 6/15/2022 04:00 6/15/2022 06:00 2.00 COMPZN, RPCOMP BHAH P Pull 5.5 to the floor and disengage spear and L/D 6,733.0 6,713.0 6/15/2022 06:00 6/15/2022 14:30 8.50 COMPZN, RPCOMP PULL P LD 5-1/2" casing F/6713 T/surface 1/4" hole in casing on joint 110, 10' from the bottom of the joint. 6,713.0 0.0 6/15/2022 14:30 6/15/2022 15:00 0.50 COMPZN, RPCOMP CLEN P Clear floor. 0.0 0.0 6/15/2022 15:00 6/15/2022 15:30 0.50 COMPZN, RPCOMP RURD P L/D GBR casing tongs get the floor set up to start RIH with D.P. 0.0 0.0 6/15/2022 15:30 6/15/2022 20:30 5.00 COMPZN, RPCOMP RURD P Process 215 Joints of 3-1/2" HT38 DP. 0.0 0.0 6/15/2022 20:30 6/15/2022 22:30 2.00 COMPZN, RPCOMP BHAH P Pick up BHA = 6" x 5 3/4" Crown Shoe, WP Extention, TC Bushing Boot Basket, X-O Sub D-Pin, 7" Scaper, Bit Sub, String Mill, 2-7" Extreme Magnet, Hyd Jar NOV, 3 Drill Collars, Jar ACC, X-O 0.0 72.0 6/15/2022 22:30 6/16/2022 00:00 1.50 COMPZN, RPCOMP PULD P Pick up 3.5" DP out of the pipeshed. 72.0 1,840.0 6/16/2022 00:00 6/16/2022 05:00 5.00 COMPZN, RPCOMP PULD P Pick up 3.5" DP out of the pipeshed.F/1840 - T/6,374 1,840.0 6,374.0 Rig: NABORS 7ES RIG RELEASE DATE 6/19/2022 Page 4/6 1E-12 Report Printed: 7/7/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/16/2022 05:00 6/16/2022 07:30 2.50 COMPZN, RPCOMP WASH P Washing W/clean out assy. F/6400' to bottom @ 4BPM 20 RPM Rot tq. between 0 and 1500 wash down to 6760.27. Tagged top of cut rotated on cut at 20 RPM dress off stump with minimal weight PR=4BPM Rot tq. = 1200 Ft/lbs. 6,374.0 6,760.3 6/16/2022 07:30 6/16/2022 09:00 1.50 COMPZN, RPCOMP CIRC P Cirulate 45 BBL's 9.7# NaCl 80 vis sweep to surface @ 6BPM with BHA 5' over top of cut. Sand in returns seen at shakers. Continue to circulate till clean fluid at possum belly 9.7# In and out. 6,758.3 6,758.3 6/16/2022 09:00 6/16/2022 09:30 0.50 COMPZN, RPCOMP OWFF P OWFF for 30 minutes pulled 5 joints well static. 6,758.3 6,758.3 6/16/2022 09:30 6/16/2022 16:00 6.50 COMPZN, RPCOMP PULD P Start POOH F/6758 T/162' 6,758.3 162.0 6/16/2022 16:00 6/16/2022 17:00 1.00 COMPZN, RPCOMP BHAH P LD BHA F/162 to surface. 162.0 0.0 6/16/2022 17:00 6/16/2022 19:30 2.50 COMPZN, RPCOMP RURD P LD BOT tools and clear floor. Rig up floor to RIH w/5-1/2" Hyd 563 15.5# L- 80 casing. Move GBR tongs to floor. 0.0 0.0 6/16/2022 19:30 6/17/2022 00:00 4.50 COMPZN, RPCOMP PUTB P RIH with 15.5# L-80 Hyd 563MS 5.5" liner Torque Turn each connection T/6374' 0.0 6,374.0 6/17/2022 00:00 6/17/2022 06:00 6.00 COMPZN, RPCOMP PUTB P RIH with 15.5# L-80 Hyd 563MS 5.5" liner Torque Turn each connection F/ 1,246' - 5,700' 1,246.0 5,700.0 6/17/2022 06:00 6/17/2022 07:00 1.00 COMPZN, RPCOMP PUTB P Con'tt RIH to tag @ 6760' 7ES RKB. PUW=125K SOW=95K set down 9800K saw tattle tales shear. RIH to tag PU 1' off tag. marked casing joint at the floor. 5,700.0 6/17/2022 07:00 6/17/2022 07:30 0.50 COMPZN, RPCOMP HOSO P Spaced out Laid down joint 158 Picked up 19' pup joint landed out at 6760' picked up 1 foot offf tag 6759' marked casing joint at floor. 6/17/2022 07:30 6/17/2022 08:00 0.50 COMPZN, RPCOMP RURD P Rigged up circulating lines too casing joint tto pump down the IA and take returns up the 5-1/2" casing. R/D GBR casing torque turn. 6/17/2022 08:00 6/17/2022 09:45 1.75 COMPZN, RPCOMP CIRC P Flood lines and pressure test to 2000 PSI. Open 7x5-1/2" to pump down the 7" with 9.7# NaCl with CI. Pump 60 BBL's PR=2BPM Pump Pressure=250 PSI 6/17/2022 09:45 6/17/2022 11:30 1.75 COMPZN, RPCOMP RURD P Slack off casing to set depth. Blow down pump line RU LRS to set packer. RU to set packer purge test lines swap sensors out two times to find sensor that wasn't flat. replace test hose. 6/17/2022 11:30 6/17/2022 13:15 1.75 COMPZN, RPCOMP PACK P LRS pressured up to 3600PSI. bled pressure off. Pressured back up to 5009 PSI to set packer. Isolate at 5-1/2" at floor. 2" 1502 hose started leaking through a pin hole at floor down stream of isolation. Bled pressure off hose ran out the 15 minute setting process. Bled off 5-1/2" casing. LRS suck back lines. Line up for rolling test on the 5--1/2" x 7" casing. PR=1BPM PSI=350 Rig: NABORS 7ES RIG RELEASE DATE 6/19/2022 Page 5/6 1E-12 Report Printed: 7/7/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/17/2022 13:15 6/17/2022 13:30 0.25 COMPZN, RPCOMP PACK P Run rolling test on packer, pump down 7" x 5-1/2" @ 1BPM pump pressure =350 PSI with casing open slight dribble out of the casing that deminished to zero flow while pumping. 6/17/2022 13:30 6/17/2022 14:00 0.50 COMPZN, RPCOMP RURD P RD pump lines and blow down lines. 6/17/2022 14:00 6/17/2022 15:30 1.50 COMPZN, RPCOMP NUND P N/D BOP and lift stack. 6/17/2022 15:30 6/17/2022 16:30 1.00 COMPZN, RPCOMP HOSO P Set slips in exsisting tubing head with 75K over string weight. Blocks=30K PUW=125K String=95K RU Wachs saw and cut casing. 6/17/2022 16:30 6/17/2022 22:00 5.50 COMPZN, RPCOMP NUND P Rack stack back remove spacer spool and DSA install new pack off and tubing head test break to 3000 PSI for 10 Min. 6/17/2022 22:00 6/18/2022 00:00 2.00 COMPZN, RPCOMP NUND P N/U BOPE, Install flow nipple, rig up test equipment, set test plug and test jnt. 6/18/2022 00:00 6/18/2022 02:00 2.00 COMPZN, RPCOMP BOPE P Change out the lower pipe rams to 2 7/8" x 5" VBR's 0.0 0.0 6/18/2022 02:00 6/18/2022 03:30 1.50 COMPZN, RPCOMP RURD P Fill BOPE, attempt to close the lower rams, but the rams were hitting the crossover, swapped out test jnt. to the donut test jnt. 0.0 0.0 6/18/2022 03:30 6/18/2022 04:30 1.00 COMPZN, RPCOMP BOPE P Test the lower rams and the break between the tubing spool and BOPE. rig down testing equipment 0.0 0.0 6/18/2022 04:30 6/18/2022 07:15 2.75 COMPZN, RPCOMP RURD P Break out the 5.5" cut jnt. Rig up to run 3.5 completion 0.0 0.0 6/18/2022 07:15 6/18/2022 17:45 10.50 COMPZN, RPCOMP PUTB P Start RIH w/3-1/2" eue 8rd L80 9.3# completion per tally. F/surface T/6650' Tagged no-go. PUW=80K SOW=70K Blocks=30K. Picked up to 6648' neutral weight. Marked tubing joint and laid down last joint M/U X-O to HT38 to top of last joint. Picked up joint and M.U. to string. screwed into joint with top dirve. RIH to 6633.74 puming at 1 BPM=140PSI to confirm engagement in SBR. Pressure increased to 200PSI. Shut down pump seals engaged in SBR. Bottom of seal assembly at 6632.24' Opened bleeder. RIH to tag at 6650' set down 5K. Picked up to neutral weight at 6649' P.U 2' off tag to 6647' marked tubing. Laid down last joint and 1 more. 0.0 6,650.0 6/18/2022 17:45 6/18/2022 18:45 1.00 COMPZN, RPCOMP CIRC P Circ. 72 bbl. of CI 9.7 NaCl @ 3bpm 700 psi. 6,650.0 6,650.0 6/18/2022 18:45 6/18/2022 19:15 0.50 COMPZN, RPCOMP THGR P Land hanger & RILD Last P/U= 80k S/O=70K 6,650.0 6,650.0 6/18/2022 19:15 6/18/2022 21:15 2.00 COMPZN, RPCOMP PRTS P Test tubing T/ 3000 PSI for 30 Min. Bleed tubing T/ 2000 and test IA T/ 2500 for 30 Min. Good Test. Dump psi on tubing T/ shear out SOV. Good Shear. 6,650.0 6,650.0 6/18/2022 21:15 6/18/2022 22:15 1.00 COMPZN, RPCOMP RURD P Lay down landing jnt., Rig down casing equipment. 6,650.0 6,650.0 6/18/2022 22:15 6/18/2022 23:00 0.75 COMPZN, WHDBOP MPSP P Install BPV with test Dart, Test from below to 1000 psi. (Good Test) 6,650.0 6/18/2022 23:00 6/19/2022 00:00 1.00 COMPZN, WHDBOP NUND P N/D BOPE and set back onto moving pedestal. 6,650.0 0.0 6/19/2022 00:00 6/19/2022 03:00 3.00 COMPZN, WHDBOP NUND P N/U Adaptor and Tree 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 6/19/2022 Page 6/6 1E-12 Report Printed: 7/7/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/19/2022 03:00 6/19/2022 04:00 1.00 COMPZN, WHDBOP PRTS P Test Tree to 5000 psi. (Good Test) 0.0 0.0 6/19/2022 04:00 6/19/2022 06:00 2.00 DEMOB, MOVE MPSP P Pull BPV and secure well, RDMO 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 6/19/2022 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 7,129.0 5/18/2011 1E-12 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Copleted Post Rig Gas Lift, Pull DFCV, & RBP 6/27/2022 1E-12 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.08 Top (ftKB) 32.0 Set Depth (ftKB) 80.0 Set Depth (TVD) 80.0 Wt/Len (lb 65.00 Grade H-40 Top Connection WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 31.2 Set Depth (ftKB) 2,501.4 Set Depth (TVD) 2,500.1 Wt/Len (lb 45.50 Grade K-55 Top Connection BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 31.7 Set Depth (ftKB) 7,510.2 Set Depth (TVD) 6,573.7 Wt/Len (lb 26.00 Grade K-55 Top Connection BTC Casing Description SCAB LINER 5.5"x3.5"@6721' OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 31.7 Set Depth (ftKB) 6,765.3 Set Depth (TVD) 5,959.1 Wt/Len (lb 15.50 Grade L-80 Top Connection 511 Hydril Liner Details: excludes liner, pup, joints, casing, sub , shoe , float... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.7 31.7 0.05 Casing Casing 4.950 6,684.3 5,893.6 36.33 Casing Casing Pup Joint 4.860 6,692.1 5,899.9 36.30 Casing PUP 4.380 6,693.8 5,901.3 36.29 Casing Casing / tubing inner seal bore 4.000 6,712.7 5,916.5 36.16 XO BUSHING CSG TO TBG CROSSOVER BUSHING 3.000 6,763.5 5,957.6 35.74 LOCATOR NO GO LOCATOR w/space out 2.970 Casing Description WINDOW L1-01 OD (in) 5 ID (in) 4.00 Top (ftKB) 7,200.0 Set Depth (ftKB) 7,210.0 Set Depth (TVD) 6,324.1 Wt/Len (lb Grade Top Connection Tubing Strings: string max indicates LONGEST segment of string Tubing Description Tubing Production String 3 1/2 ID (in) 2.99 Top (ftKB) 0.0 Set Depth (ft 6,666.0 Set Depth (TVD 5,878.9 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-M Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model 29.8 29.8 0.05 Hanger 2.900 11.000 FMC Gen 5 1,631.1 1,631.1 1.15 Nipple - Landing 2.831 4.500 Halliburton X Nipple 2,501.5 2,500.2 3.14 Mandrel GAS LIFT 2.818 5.375 SLB KBG 2-9 3,879.4 3,805.7 32.84 Mandrel GAS LIFT 2.818 5.375 SLB KBG 2-9 5,099.3 4,698.4 44.32 Mandrel GAS LIFT 2.818 4.726 SLB KGB 2-9 SOV 6,037.3 5,385.3 40.18 Mandrel GAS LIFT 2.818 5.375 SLB KGB 2-9 6,565.4 5,798.1 36.98 Mandrel GAS LIFT 2.818 5.375 SLB KGB 2-9 6,592.7 5,820.0 36.73 Nipple - Landing 2.992 4.500 Halliburton X Nipple 6,645.7 5,862.6 36.48 Locator 2.990 3.950 Baker GBH-22 Locating seal assy. 6,646.5 5,863.2 36.48 Seal Assembly 2.990 3.500 Tubing Description STRADDLE PACKER String 4 1/2 ID (in) 2.99 Top (ftKB) 6,713.3 Set Depth (ft 7,157.0 Set Depth (TVD 6,280.4 Wt (lb/ft) 9.30 Grade L-80 Top Connection IBT Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model 6,765.3 5,959.1 35.72 PBR 2.970 5.880 Baker 80-48 for 7" Csg 6,779.0 5,970.2 35.61 PACKER 2.930 5.920 Baker FHL Retrievable 6,925.6 6,089.9 34.91 SLEEVE 2.812 4.500 Baker CMU 6,939.2 6,101.1 34.86 BLAST RING 2.990 4.500 Carbide Blast Rings 7,136.7 6,263.8 34.49 PACKER 4.000 5.870 Baker F-1 85-40 7,140.1 6,266.5 34.49 SBE 4.000 5.670 Baker SBE 80-40 7,155.1 6,278.9 34.49 NIPPLE 2.800 4.530 Camco D-profile 7,156.3 6,279.8 34.49 WLEG 3.000 4.500 Baker WLEG Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,157.0 6,280.4 34.50 PILOT HOLE CTD PILOT HOLE 2/22/2010 0.000 7,201.0 6,316.7 34.51 WHIPSTOCK WHIPSTOCK 2/23/2010 0.000 Mandrel Inserts : excludes pulled inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,501.5 2,500.2 3.14 Schlum berger KBG 2- 9 1 GLV BTM 0.188 1,308.0 6/24/2022 2 3,879.4 3,805.7 32.84 Schlum berger KBG 2- 9 1 GLV BTM 0.188 1,299.0 6/24/2022 3 5,099.3 4,698.4 44.32 Schlum berger KBG 2- 9 1 GLV BTM 0.188 1,288.0 6/24/2022 4 6,037.3 5,385.3 40.18 Schlum berger KBG 2- 9 1 OV BTM 0.250 6/23/2022 5 6,565.4 5,798.1 36.98 Schlum berger KBG 2- 9 1 DMY BTM 6/18/2022 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,010.0 7,090.0 6,159.3 6,225.2 C-2, C-3, UNIT B, 1E-12 8/14/1988 8.0 CMT SQZ Squeezed off 3/17/97 7,147.0 7,149.0 6,272.2 6,273.9 UNIT B, 1E-12 1/27/2010 6.0 APERF 2" GUN HMX BH Charges, 60 degree Phasing, 7,200.0 7,209.0 6,315.9 6,323.3 A-5, 1E-12 6/13/1982 4.0 CMT SQZ 1E-12, 7/1/2022 3:04:43 PM Vertical schematic (actual) PRODUCTION; 31.7-7,510.2 CMT SQZ; 7,253.0-7,259.0 CMT SQZ; 7,225.0-7,245.0 CMT SQZ; 7,222.0-7,241.0 FRAC; 7,225.0 CMT SQZ; 7,225.0-7,235.0 PILOT HOLE; 7,157.0 WINDOW L1-01; 7,200.0- 7,210.0 WHIPSTOCK; 7,201.0 CMT SQZ; 7,200.0-7,209.0 CMT SQZ; 7,200.0-7,208.0 L1-01 LINER Slotted (off main wellbore); 7,129.6-8,725.0 SLOTS; 7,130.6-8,723.6 CEMENT SQUEEZE; 7,150.0 ftKB APERF; 7,147.0-7,149.0 PACKER; 7,136.8 Cement; 7,010.0 ftKB CMT SQZ; 7,010.0-7,090.0 PACKER; 6,779.0 SCAB LINER 5.5"x3.5"@6721'; 6,753.7-6,765.3 5-1/2" Scab liner ; 0.0-6,759.4 Nipple - Landing; 6,592.7 Mandrel GAS LIFT; 6,565.4 Mandrel GAS LIFT; 6,037.3 Mandrel GAS LIFT; 5,099.3 Mandrel GAS LIFT; 3,879.4 Mandrel GAS LIFT; 2,501.5 SURFACE; 31.2-2,501.4 Nipple - Landing; 1,631.1 CONDUCTOR; 32.0-80.0 Hanger; 29.8 KUP PROD KB-Grd (ft) 40.71 RR Date 6/13/1982 Other Elev 1E-12 ... TD Act Btm (ftKB) 7,512.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292073600 Wellbore Status PROD Max Angle & MD Incl (°) 46.27 MD (ftKB) 4,500.00 WELLNAME WELLBORE1E-12 Annotation Last WO: End Date 6/10/2022 H2S (ppm) 200 Date 9/10/2016 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,200.0 7,208.0 6,315.9 6,322.5 A-5, 1E-12 5/24/1997 4.0 CMT SQZ 180 deg. Ph; 2 1/8" EJ BH 7,222.0 7,241.0 6,334.0 6,349.7 A-4, 1E-12 5/24/1997 4.0 CMT SQZ 180 deg. Ph; 2 1/8" EJ BH 7,225.0 7,235.0 6,336.5 6,344.8 A-4, 1E-12 10/4/2008 6.0 CMT SQZ 2.5" HYPERJET, 60 deg phase 7,225.0 7,245.0 6,336.5 6,353.0 A-4, 1E-12 6/13/1982 4.0 CMT SQZ 7,253.0 7,259.0 6,359.7 6,364.6 A-4, 1E-12 6/13/1982 4.0 CMT SQZ Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 FRAC 10/7/2008 7,225.0 7,235.0 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,010.0 7,090.0 6,159.3 6,225.2 Cement 7,150.0 7,510.0 6,274.7 6,573.5 CEMENT SQUEEZE PRE-SIDETRACK SQZ 1/28/2010 Notes: General & Safety End Date Annotation 12/13/2019 NOTE: Attempted to set 2 plugs in DS Nipple @ 6926' (Polish Bore Could be Comprimised) 9/18/2008 NOTE: CTD LATERALS L1, L1-01 (off main wellbore), L2, L2-01 9/18/2008 NOTE: VIEW SCHEMATIC w/9.0 & Reference Visio Multi-lat drawing attached 1E-12, 7/1/2022 3:04:44 PM Vertical schematic (actual) PRODUCTION; 31.7-7,510.2 CMT SQZ; 7,253.0-7,259.0 CMT SQZ; 7,225.0-7,245.0 CMT SQZ; 7,222.0-7,241.0 FRAC; 7,225.0 CMT SQZ; 7,225.0-7,235.0 PILOT HOLE; 7,157.0 WINDOW L1-01; 7,200.0- 7,210.0 WHIPSTOCK; 7,201.0 CMT SQZ; 7,200.0-7,209.0 CMT SQZ; 7,200.0-7,208.0 L1-01 LINER Slotted (off main wellbore); 7,129.6-8,725.0 SLOTS; 7,130.6-8,723.6 CEMENT SQUEEZE; 7,150.0 ftKB APERF; 7,147.0-7,149.0 PACKER; 7,136.8 Cement; 7,010.0 ftKB CMT SQZ; 7,010.0-7,090.0 PACKER; 6,779.0 SCAB LINER 5.5"x3.5"@6721'; 6,753.7-6,765.3 5-1/2" Scab liner ; 0.0-6,759.4 Nipple - Landing; 6,592.7 Mandrel GAS LIFT; 6,565.4 Mandrel GAS LIFT; 6,037.3 Mandrel GAS LIFT; 5,099.3 Mandrel GAS LIFT; 3,879.4 Mandrel GAS LIFT; 2,501.5 SURFACE; 31.2-2,501.4 Nipple - Landing; 1,631.1 CONDUCTOR; 32.0-80.0 Hanger; 29.8 KUP PROD 1E-12 ... WELLNAME WELLBORE1E-12 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 7,147.0 2/6/2010 1E-12L1 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: TAG, H2S, SET CATCHER, GLV C/O, PULL CATCHER 9/12/2017 1E-12L1 pproven Casing Strings Casing Description L1 LINER OD (in) 2 3/8 ID (in) 2.00 Top (ftKB) 7,510.5 Set Depth (ftKB) 9,002.0 Set Depth (TVD) 6,387.1 Wt/Len (lb 4.60 Grade L-80 Top Connection STL Liner Details: excludes liner, pup, joints, casing, sub , shoe , float... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,510.5 6,371.6 85.05 DEPLOY BAKER DEPLOYMENT SLEEVE 1.995 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,520.0 8,995.8 6,372.3 6,387.5 A-4, 1E-12L1 3/11/2010 32.0 SLOTS Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends Notes: General & Safety End Date Annotation 3/14/2010 NOTE: CTD LATERALS L1, L1-01 (off main wellbore), L2, L2-01 9/18/2008 NOTE: VIEW SCHEMATIC w/9.0 & Reference Visio Multi-lat drawing attached 1E-12L1, 7/1/2022 3:04:45 PM Vertical schematic (actual) L1 LINER; 7,510.5-9,002.0 SLOTS; 7,520.0-8,995.8 L1-01 LINER Slotted (off main wellbore); 7,129.6-8,725.0 L2-01 LINER; 7,410.0-9,350.0 SLOTS; 7,130.6-8,723.6 L2 LINER; 7,263.0-8,430.0 PRODUCTION; 31.7-7,510.2 WINDOW L1-01; 7,200.0- 7,210.0 PILOT HOLE; 7,157.0 CEMENT SQUEEZE; 7,150.0 ftKB APERF; 7,147.0-7,149.0 PACKER; 7,136.8 Cement; 7,010.0 ftKB CMT SQZ; 7,010.0-7,090.0 PACKER; 6,779.0 SCAB LINER 5.5"x3.5"@6721'; 6,753.7-6,765.3 5-1/2" Scab liner ; 0.0-6,759.4 Nipple - Landing; 6,592.7 Mandrel GAS LIFT; 6,565.4 Mandrel GAS LIFT; 6,037.3 Mandrel GAS LIFT; 5,099.3 Mandrel GAS LIFT; 3,879.4 Mandrel GAS LIFT; 2,501.5 SURFACE; 31.2-2,501.4 Nipple - Landing; 1,631.1 CONDUCTOR; 32.0-80.0 Hanger; 29.8 KUP PROD KB-Grd (ft) 40.71 RR Date 6/13/1982 Other Elev 1E-12L1 ... TD Act Btm (ftKB) 9,002.4 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292073660 Wellbore Status PROD Max Angle & MD Incl (°) 97.95 MD (ftKB) 8,470.37 WELLNAME WELLBORE1E-12 Annotation Last WO: End Date 6/10/2022 H2S (ppm) 200 Date 9/10/2016 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 7,147.0 2/6/2010 1E-12L1-01 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: TAG, H2S, SET CATCHER, GLV C/O, PULL CATCHER 9/12/2017 1E-12L1-01 pproven Casing Strings Casing Description L1-01 LINER Slotted (off main wellbore) OD (in) 2 3/8 ID (in) 2.00 Top (ftKB) 7,129.6 Set Depth (ftKB) 8,725.0 Set Depth (TVD) Wt/Len (lb 4.60 Grade L-80 Top Connection STL Liner Details: excludes liner, pup, joints, casing, sub , shoe , float... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,129.6 6,257.8 34.48 DEPLOY BAKER DEPLOYMENT SLEEVE with G/S Profile 1.995 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,130.6 8,723.6 6,258.6 6,357.9 A-5, 1E-12L1-01 3/13/2010 32.0 SLOTS Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends Notes: General & Safety End Date Annotation 3/14/2010 NOTE: CTD LATERALS L1, L1-01 (off main wellbore), L2, L2-01 9/18/2008 NOTE: VIEW SCHEMATIC w/9.0 & Reference Visio Multi-lat drawing attached 1E-12L1-01, 7/1/2022 3:04:45 PM Vertical schematic (actual) L1-01 LINER Slotted (off main wellbore); 7,129.6-8,725.0 SLOTS; 7,130.6-8,723.6 L2-01 LINER; 7,410.0-9,350.0 L2 LINER; 7,263.0-8,430.0 PRODUCTION; 31.7-7,510.2 WINDOW L1-01; 7,200.0- 7,210.0 PILOT HOLE; 7,157.0 CEMENT SQUEEZE; 7,150.0 ftKB APERF; 7,147.0-7,149.0 PACKER; 7,136.8 Cement; 7,010.0 ftKB CMT SQZ; 7,010.0-7,090.0 PACKER; 6,779.0 SCAB LINER 5.5"x3.5"@6721'; 6,753.7-6,765.3 5-1/2" Scab liner ; 0.0-6,759.4 Nipple - Landing; 6,592.7 Mandrel GAS LIFT; 6,565.4 Mandrel GAS LIFT; 6,037.3 Mandrel GAS LIFT; 5,099.3 Mandrel GAS LIFT; 3,879.4 Mandrel GAS LIFT; 2,501.5 SURFACE; 31.2-2,501.4 Nipple - Landing; 1,631.1 CONDUCTOR; 32.0-80.0 Hanger; 29.8 KUP PROD KB-Grd (ft) 40.71 RR Date 6/13/1982 Other Elev 1E-12L1-01 ... TD Act Btm (ftKB) 8,725.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292073661 Wellbore Status PROD Max Angle & MD Incl (°) 99.23 MD (ftKB) 7,640.42 WELLNAME WELLBORE1E-12 Annotation Last WO: End Date 6/10/2022 H2S (ppm) 200 Date 9/10/2016 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 7,147.0 2/6/2010 1E-12L2 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: TAG, H2S, SET CATCHER, GLV C/O, PULL CATCHER 9/12/2017 1E-12L2 pproven Casing Strings Casing Description L2 LINER OD (in) 2 5/8 ID (in) 2.00 Top (ftKB) 7,263.0 Set Depth (ftKB) 8,430.0 Set Depth (TVD) 6,338.8 Wt/Len (lb 4.70 Grade L-80 Top Connection STL Liner Details: excludes liner, pup, joints, casing, sub , shoe , float... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,263.0 6,359.2 57.52 BILLET 2.625 Alluminum Billet with OH anchor 1.995 7,290.6 6,372.1 66.93 DEPLOY Deployment Sleeve 1.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,290.8 8,428.0 6,372.2 6,338.8 A-5, 1E-12L2 3/1/2010 32.0 SLOTS Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends Notes: General & Safety End Date Annotation 3/14/2010 NOTE: CTD LATERALS L1, L1-01 (off main wellbore), L2, L2-01 9/18/2008 NOTE: VIEW SCHEMATIC w/9.0 & Reference Visio Multi-lat drawing attached 1E-12L2, 7/1/2022 3:04:46 PM Vertical schematic (actual) L2 LINER; 7,263.0-8,430.0 SLOTS; 7,290.8-8,428.0 L1-01 LINER Slotted (off main wellbore); 7,129.6-8,725.0 PRODUCTION; 31.7-7,510.2 WINDOW L1-01; 7,200.0- 7,210.0 SLOTS; 7,130.6-8,723.6 PILOT HOLE; 7,157.0 CEMENT SQUEEZE; 7,150.0 ftKB APERF; 7,147.0-7,149.0 PACKER; 7,136.8 Cement; 7,010.0 ftKB CMT SQZ; 7,010.0-7,090.0 PACKER; 6,779.0 SCAB LINER 5.5"x3.5"@6721'; 6,753.7-6,765.3 5-1/2" Scab liner ; 0.0-6,759.4 Nipple - Landing; 6,592.7 Mandrel GAS LIFT; 6,565.4 Mandrel GAS LIFT; 6,037.3 Mandrel GAS LIFT; 5,099.3 Mandrel GAS LIFT; 3,879.4 Mandrel GAS LIFT; 2,501.5 SURFACE; 31.2-2,501.4 Nipple - Landing; 1,631.1 CONDUCTOR; 32.0-80.0 Hanger; 29.8 KUP PROD KB-Grd (ft) 40.71 RR Date 6/13/1982 Other Elev 1E-12L2 ... TD Act Btm (ftKB) 8,460.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292073662 Wellbore Status PROD Max Angle & MD Incl (°) 97.13 MD (ftKB) 7,920.60 WELLNAME WELLBORE1E-12 Annotation Last WO: End Date 6/10/2022 H2S (ppm) 200 Date 9/10/2016 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 7,147.0 2/6/2010 1E-12L2-01 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: TAG, H2S, SET CATCHER, GLV C/O, PULL CATCHER 9/12/2017 1E-12L2-01 pproven Casing Strings Casing Description 5-1/2" Scab liner OD (in) 5 1/2 ID (in) 4.90 Top (ftKB) 0.0 Set Depth (ftKB) 6,759.4 Set Depth (TVD) 5,954.2 Wt/Len (lb 15.50 Grade L-80 Top Connection HYD 563 Liner Details: excludes liner, pup, joints, casing, sub , shoe , float... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 0.0 0.0 0.00 Nordic 3 RKB 29.80' Nordic 3 RKB 29.80' 0.000 6,646.3 5,862.9 36.49 XO Reducing 5 1/2" Hyd 563 Box x 5" H521 Box xo 4.370 6,648.0 5,864.3 36.48 SBE Baker 80-40 SBR, 5" H521 Pin x 4 1/2" H521 Box 4.000 6,685.3 5,894.3 36.33 Mandrel 3.5 x 1.5 MMG SN# 20819-18 2.920 6,710.3 5,914.5 36.18 Packer SLB Bluepack Packer SN# C21P-1854 2.885 6,730.7 5,930.9 36.01 Nipple - D HES 3.5" x 2.75" D Nipple W/DFCV SN# 4791027692-01-003 2.750 6,752.7 5,948.8 35.83 Overshot Baker Poorboy Tubing Stub Overshot (Bottom of overshot 1' off tag) 2.960 Casing Description L2-01 LINER OD (in) 2 5/8 ID (in) 2.00 Top (ftKB) 7,410.0 Set Depth (ftKB) 9,350.0 Set Depth (TVD) Wt/Len (lb 4.60 Grade L-80 Top Connection STL Liner Details: excludes liner, pup, joints, casing, sub , shoe , float... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,410.0 6,370.4 97.14 BILLET 2.625 Alluminum Billet with OH anchor 1.995 7,433.4 6,367.5 96.71 DEPLOY Deployment Sleeve Baker Torque Thru 1.995 8,244.0 6,384.6 91.83 DEPLOY Deployment Sleeve Baker Torque Thru 1.995 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,434.2 8,224.9 6,367.4 6,385.1 A-4, 1E-12L2-01 3/9/2010 32.0 SLOTS Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends 8,245.4 9,347.3 6,384.6 6,375.9 A-4, 1E-12L2-01 3/9/2010 32.0 SLOTS Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends Notes: General & Safety End Date Annotation 3/14/2010 NOTE: CTD LATERALS L1, L1-01 (off main wellbore), L2, L2-01 1E-12L2-01, 7/1/2022 3:04:47 PM Vertical schematic (actual) L2-01 LINER; 7,410.0-9,350.0 SLOTS; 8,245.4-9,347.3 SLOTS; 7,434.2-8,224.9 L1-01 LINER Slotted (off main wellbore); 7,129.6-8,725.0 SLOTS; 7,130.6-8,723.6 L2 LINER; 7,263.0-8,430.0 PRODUCTION; 31.7-7,510.2 WINDOW L1-01; 7,200.0- 7,210.0 PILOT HOLE; 7,157.0 CEMENT SQUEEZE; 7,150.0 ftKB APERF; 7,147.0-7,149.0 PACKER; 7,136.8 Cement; 7,010.0 ftKB CMT SQZ; 7,010.0-7,090.0 PACKER; 6,779.0 SCAB LINER 5.5"x3.5"@6721'; 6,753.7-6,765.3 5-1/2" Scab liner ; 0.0-6,759.4 Nipple - Landing; 6,592.7 Mandrel GAS LIFT; 6,565.4 Mandrel GAS LIFT; 6,037.3 Mandrel GAS LIFT; 5,099.3 Mandrel GAS LIFT; 3,879.4 Mandrel GAS LIFT; 2,501.5 SURFACE; 31.2-2,501.4 Nipple - Landing; 1,631.1 CONDUCTOR; 32.0-80.0 Hanger; 29.8 KUP PROD KB-Grd (ft) 40.71 RR Date 6/13/1982 Other Elev 1E-12L2-01 ... TD Act Btm (ftKB) 9,350.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292073663 Wellbore Status PROD Max Angle & MD Incl (°) 97.63 MD (ftKB) 7,415.65 WELLNAME WELLBORE1E-12 Annotation Last WO: End Date 6/10/2022 H2S (ppm) 200 Date 9/10/2016 Comment SSSV: NIPPLE ! " # $! % " & $ '" " ( )$ *+ )# , # -.$ /. 0 $ $ " # # ! 1 +1 2 $ 3) 45 $ 6 784 6 ) 9)4 6 ) :)4 6 * #) 9) * #) :) 9 4 6 49)6 ; <49)6 /(&=$ " . 5 < : < :9)4 6:)4 6 & , " !< ) > < *+ )# # '* ) ( !< " .5 .$; ) 5 -:# ) ? ? ? 5@? ?"" #?.$; ! "$ "* " A " #$ ?"" # ! $ . > 9 . 5" ..B9. =12 $ *+ 12 $ :*)>2 # " 99. . $* C* ?"" ) " " * ? * /. # !# ! !# A$ ) ! ) 8")* D D E 437/6&-,%'(&3 ? 9)4 6 <-//3=9)(3/7=:) </,/=9)-&-'=:) :'0&=9)'0&=:) ) :)4 6 A * 5 D 5 D .5$)? " $ * :. $" 99. . $ &7"&(&07 ! " "# $ ! >+77,-7F FD33(7 $ %$ &'!$ $ " <F. ( "$" $8 () *)+ , * -. 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Do not click links or open attachments unless you recognize the sender and know the content is safe. ĚĂŵ͕ ϭ͘ /ŶĐůƵĚĞtĞůů/ŶĨŽƌŵĂƚŝŽŶƐĞĐƚŝŽŶ͘^ĞĞƌĞĐĞŶƚ<ZhZtKƐƵŶĚƌLJƐƵďŵŝƐƐŝŽŶƐĨŽƌĞdžĂŵƉůĞƐ͘ Ϯ͘ EĞĞĚDW^WŽŶĨŽƌŵ͘ ϯ͘ dƵďŝŶŐŶĞĞĚƐƚŽďĞƉƌĞƐƐƵƌĞƚĞƐƚĞĚĨŽƌϯϬŵŝŶƵƚĞƐĂŶĚĐŚĂƌƚĞĚ͘ sŝĐƚŽƌŝĂ Victoria Loepp 6HQLRU3HWUROHXP(QJLQHHU 6WDWHRI$ODVND 2LO *DV&RQVHUYDWLRQ&RPPLVVLRQ :WK$YH $QFKRUDJH$. :RUN 9LFWRULD/RHSS#DODVNDJRY CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov Originated: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS ANC@halliburton.com Delivered to: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above Transmittal Date: RECEIVED APR 2 3 2020 A®GCC 18'0&0 32810 13 -Mar -20 WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # CD # 1 1E-20 2 1E-12 3 1E-12 4 1F-05 11 W93A A 50-029-20895-00 50-029-20736-00 50-029-20736-00 50-029-20807-00 50-029-22200-01 50-029-20882-00 50-029-20132-00 50-029-21729-00 50-029-21527-01 50-029-21836-00 906260886 906207895 906190298 906223186 906228630 906310488 906174377 906210841 906192001 1906193765 Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Shallow Sand Kuparuk Kuparuk Kuparuk jKuparuk Multi Finger Caliper Leak Detect with ACX Plug Setting Record Injection Profile Log Multi Finger Caliper Plug Setting Record Packer Setting Record Leak Detect Log Leak Detect Log Plug Setting Record Field&Proc Processed Final -Field Field&Proc Field&Proc Final -Field Final -Field Final -Field Final -Field Final Field 23 -Jan -20 30 -Dec -19 19 -Dec -19 8 -Jan -20 7 -Jan -20 12 -Feb -20 26 -Dec -19 29 -Dec -19 23 -Dec -19 20 -Dec -19 10 0 0 0 0 0 0 0 0 1 1 1 1 1 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com Date: Signed: 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7,512'NONE Casing Collapse Conductor Surface Production Liner Packers and SSSV Type: 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Dusty Ward Contact Name:Dusty Ward Sr. Wells Engineer Contact Email: Contact Phone:(907) 265-6531 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ConocoPhillips Alaska, Inc.182-060 6806 P. O. Box 100360, Anchorage, Alaska 99510 50-029-20736-00-00 KRU 1E-12 ADL 5651 Kuparuk River Field / Kuparuk River Oil Pool PRESENT WELL CONDITION SUMMARY 6,575' 7427 6504 1160psi Length Size MD TVD Burst 2,470' 10 3/4 2,501' 2,500' 80' 16'' 80' 80' 7,479' 7'' 7,510' 6,573' 7,157' Packers and SSSV MD (ft) and TVD (ft): 6,734' 6'' 6,755' 5,957' Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubin g MD (ft): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 7010-7259 6159-6365 3.500'' L-80 PACKER - BAKER FHL RETRIEVABLE PACKER 47B2-7" 26# PACKER - BAKER F-1 PACKER MD= 6779 TVD= 5970 MD= 7137 TVD= 6264 4/12/2020 Authorized Name: Authorized Title:Dusty.Ward@cop.com Authorized Signature: COMMISSION USE ONLY Form10Ͳ403Revised3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 11:05 am, Apr 02, 2020 320-149 TBD ADL0025651 DLB ---------- X X X DLB 04/02/20 10-404 DSR-4/2/2020 BOP test to 2500 psig Annular preventer test to 2500 psig VTL 4/10/20Comm. n Required? Yes No 4/10/2020 dts 4/10/2020 JLC 4/10/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 2, 2020 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Dusty Ward Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 1E- 12 (PTD# 182-060). Well 1E-12 was drilled and completed in 1982. It was worked over in 2007, when the 7" casing was found to be leaking. A 5.5" tie-back liner was ran and an additional tubing spool was stacked. Then a 3.5" tubing string was ran to re-complete the well. The well was CTD sidetracked to A-sands in 2010. The 5.5" tie-back casing was found to be leaking in 2019 and the well was moved to a RWO list. If you have any questions or require any further information, please contact me at 907-265-6531. The 3-1/2" tubing will be pulled. Then the tubing spool will be nippled down and the 5.5" tie-back casing will be pulled. Then new 5.5" tie-bak casing will be ran, the tubing spool stacked, and new 3.5" tubing ran. 1EͲ12RWOProcedure KuparukProducer PTD#182Ͳ060 Page1of1 RemainingPreͲRigWork 1. TͲPPPOT,TͲPOT,ICͲPPPOT,andICͲPOT. 2. Pullanyplugs,POGLMs,orpatchestomakefulldriftavailablethrutubing.SBHP. 3. Setplugat~6806’RKBtoisolatefromformation.(Notedriftthru2.875”DSͲNipplerequired). 4. ConfirmallGLMsareclosed. 5. MITͲTto3,000psigtoconfirmplugset.Perform30minuteNFTtoconfirmbarriers. 6. OpenGLMat6642’RKBopenforcirculation. 7. Chemcutthetubingat~6672’RKBinthemiddleofthe~31’jointAbovethetopproductionpacker. 8. Circulatewellovertobrine. 9. ShutͲinthewellandmonitorfor30minutestoconfirmnoresidualgasorpressureremainsinthetubingorIA. 10. InstallBPVwithin48hrsofrigarrivalandprepwellforrig. RigWork MIRU 1. MIRUNaborsD142on1EͲ12.PullBPVifneedtocirculate. 2. RecordshutͲinpressuresontheT&IA.Ifthereispressure,bleedoffIAand/ortubingpressureandcomplete 30ͲminuteNFT.Verifywellisdead.CirculateKWFasneeded. 3. SetBPVandconfirmasbarrierifneeded,NDTree,NUBOPEandtestto250/2,500psi.Testannular250/2,500 psi. Retrieve3.5”TubingSection 4. PullBPV,MUlandingjointandBOLDS. 5. Pull3Ͳ1/2”tubingdowntopreͲrigcut(~6672’RKB). NDTubingSpool,PullOld5.5”TieͲBack,Runnew5.5”TieͲback 6. Set5.5”plugandtestasbarrier. 7. NDBOP.NDtubingspool.NUBOPs.Pull5.5”plug. 8. Pull5.5”tieͲbackoutofseals(6696’RKB)andlaydown. 9. Runnew5.5”tieͲbackandstabintoseals.PUandcirculateincorrosioninhibitedfluid.Stabbackintoseals. LandoutandPTpackoffs. 10. Set5.5”plugandtestasbarrier. 11. NDBOP.NUtubingspool.NUBOPs.PTBOPbreak.Pull5.5”Plug. Installnew3Ͳ½”Tubing 12. MU3½”completionwithseals,nipples,andGLMs. 13. Onceondepth,stabintosealsandspaceoutasneeded. 14. PUandcirculateincorrosioninhibitedfluid.Stabbackintoseals. 15. Pressuretesttubingto3000psifor5minutes.PTpackoffs. 16. Pressuretestinnerannulusto2500psifor30minutesonchart. NDBOP,NUTree 17. InstallBPV. 18. NDBOPE.NUtree. 19. PullBPV,freezeprotectwellifneeded,andsetBPVifnecessary. 20. RDMO. PostͲRigWork 21. PullBPV 22. PullplugsetpreͲrig. Doyon 142 BOP & Choke Configuration 2-7/8” x 5” VBR BLIND 3-1/2” x 6” VBR ANNULAR 1E-12 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 80 80 16 15.08 65 H-40 WELDED WELDED Surface 2501.4 2500.1 10.75 9.95 45.5 K-55 BTC BTC Production/Interm ediate 6765.3 5959.1 5.5 4.95 15.5 L-80 511 Hydril 511 Hydril Liner 7210 6324.1 5 4 0 0 0 0 Tubing 6713 5917 3.5 2.992 9.3 L-80 EUE EUE PERF INFO TOP PERF BOTTOM PERF B-2 INTERVAL 7147 7149 CTD A-Sand OctaLa 7262 9350 PROPOSED TIE-BACK CASING COMPLETION 5-1/2" 17.0# L-80 HYD513 to surface 5-1/2" x 3-1/2" Crossover with SBE for 3.5" Tubing 3-1/2" Seals PROPOSED TUBING COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Camco KBG-2-9 gas lift mandrels @ TBD 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Seals REMAINING COMPLETION LEFT IN HOLE FHL Retrievable Packer @ 6779' RKB (2.93" ID) Blast Rings and Cemented off Perfs F-1 Packer @ 7137' RKB (4.00" ID) And 3.5" and CTD completion per current well schematic Surface Casing Production/Intermediate Casing Conductor CTD A-Sand Octa-Lateral Perfs-Cement Squeezed Off Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 7,129.0 5/18/2011 1E-12 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set DV & MITT 12/24/2019 1E-12 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.08 Top (ftKB) 32.0 Set Depth (ftKB) 80.0 Set Depth (TVD) (… 80.0 Wt/Len (l… 65.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 31.2 Set Depth (ftKB) 2,501.4 Set Depth (TVD) (… 2,500.1 Wt/Len (l… 45.50 Grade K-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 31.7 Set Depth (ftKB) 7,510.2 Set Depth (TVD) (… 6,573.7 Wt/Len (l… 26.00 Grade K-55 Top Thread BTC Casing Description SCAB LINER 5.5"x3.5"@6721' OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 31.7 Set Depth (ftKB) 6,765.3 Set Depth (TVD) (… 5,959.1 Wt/Len (l… 15.50 Grade L-80 Top Thread 511 Hydril Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,712.7 5,916.5 36.16 XO BUSHING CSG TO TBG CROSSOVER BUSHING 3.000 6,763.5 5,957.6 35.74 LOCATOR NO GO LOCATOR w/space out 2.970 Casing Description WINDOW L1-01 OD (in) 5 ID (in) 4.00 Top (ftKB) 7,200.0 Set Depth (ftKB) 7,210.0 Set Depth (TVD) (… 6,324.1 Wt/Len (l…Grade Top Thread Tubing Strings Tubing Description TUBING String Max … 3 1/2 ID (in) 2.99 Top (ftKB) 27.8 Set Depth (ft… 6,712.8 Set Depth (TVD) (ft… 5,916.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 27.8 27.8 0.05 HANGER TUBING HANGER 3.500 482.0 482.0 0.09 NIPPLE CAMCO DS NIPPLE 2.875 6,692.5 5,900.2 36.30 LOCATOR BAKER LOCATOR w/ 2.5' of space out 3.000 6,695.8 5,902.9 36.28 SEAL BAKER 80-40 BONDED SEAL ASSEMBLY 3.000 Tubing Description STRADDLE PACKER String Max … 4 1/2 ID (in) 2.99 Top (ftKB) 6,713.3 Set Depth (ft… 7,157.0 Set Depth (TVD) (ft… 6,280.4 Wt (lb/ft) 9.30 Grade L-80 Top Connection IBT Completion Details Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 6,765.3 5,959.1 35.72 PBR BAKER 80-40 PBR 2.970 6,779.0 5,970.2 35.61 PACKER BAKER FHL RETRIEVABLE PACKER 47B2-7" 26# 2.930 6,925.6 6,089.9 34.91 SLEEVE BAKER CMU SLIDING SLEEVE 2.812 6,939.2 6,101.1 34.86 BLAST RING BLAST RINGGS (3) 7,005-7,095' 2.990 7,136.8 6,263.8 34.49 PACKER BAKER F-1 PACKER 4.000 7,140.1 6,266.5 34.49 SBE BAKER SEAL BORE EXTENSION 4.000 7,155.1 6,278.9 34.49 NIPPLE CAMCO 'D' NIPPLE 2.75" - MILLED TO 2.80" 1/27/2010 2.800 7,156.3 6,279.8 34.49 WLEG Baker Wireline Entry Guide 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 6,805.6 5,991.9 35.41 P2P RBP PLUG W/ CATCHER 3 1/2" RBP w/ EQ SUB, FILL EXT SET @ 6808' RKB ME, 7.79" OAL. P2P #CPP35221, EQ VLV #CPEQ35030. 12/19/2019 0.000 7,157.0 6,280.4 34.50 PILOT HOLE CTD PILOT HOLE 2/22/2010 0.000 7,201.0 6,316.7 34.51 WHIPSTOCK WHIPSTOCK 2/23/2010 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,010.0 7,090.0 6,159.3 6,225.2 C-2, C-3, UNIT B, 1E-12 8/14/1988 8.0 CMT SQZ Squeezed off 3/17/97 7,147.0 7,149.0 6,272.2 6,273.9 UNIT B, 1E-12 1/27/2010 6.0 APERF 2" GUN HMX BH Charges, 60 degree Phasing, 7,200.0 7,209.0 6,315.9 6,323.3 A-5, 1E-12 6/13/1982 4.0 CMT SQZ 7,200.0 7,208.0 6,315.9 6,322.5 A-5, 1E-12 5/24/1997 4.0 CMT SQZ 180 deg. Ph; 2 1/8" EJ BH 7,222.0 7,241.0 6,334.0 6,349.7 A-4, 1E-12 5/24/1997 4.0 CMT SQZ 180 deg. Ph; 2 1/8" EJ BH 7,225.0 7,235.0 6,336.5 6,344.8 A-4, 1E-12 10/4/2008 6.0 CMT SQZ 2.5" HYPERJET, 60 deg phase 7,225.0 7,245.0 6,336.5 6,353.0 A-4, 1E-12 6/13/1982 4.0 CMT SQZ 7,253.0 7,259.0 6,359.7 6,364.6 A-4, 1E-12 6/13/1982 4.0 CMT SQZ Frac Summary Start Date 10/7/2008 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 10/7/2008 Top Depth (ftKB) 7,225.0 Btm (ftKB) 7,235.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Start Date Com 7,010.0 7,090.0 6,159.3 6,225.2 Cement Squeeze 3/17/1997 7,150.0 7,510.0 6,274.7 6,573.5 Cement Squeeze 1/28/2010 Mandrel Inserts St ati on No /S Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,489.8 2,488.5 Camco KBG 1 GAS LIFT DMY INT 0.000 0.0 12/13/2019 2 3,817.2 3,753.0 Camco KBG 1 GAS LIFT DMY INT 0.000 0.0 12/13/2019 3 5,087.7 4,690.1 Camco KBG 1 GAS LIFT DMY INT 0.000 0.0 12/10/2019 4 6,114.7 5,445.0 Camco KBG 1 GAS LIFT DMY INT 0.000 0.0 9/11/2017 5 6,641.7 5,859.3 Camco KBG 1 GAS LIFT DMY INT 0.000 0.0 12/24/2019 1E-12, 4/2/2020 7:32:17 AM M D (ft K B) 0.0 28.5 31.8 34.8 35.8 80.1 482.0 489.5 2,419.6 2,489.8 2,499.7 2,541.0 3,441.6 3,817.3 3,832.7 5,087.6 5,103.3 6,114.8 6,130.6 6,641.7 6,657.5 6,686.7 6,692.6 6,695.9 6,712.9 6,713.6 6,763.5 6,778.9 6,800.9 6,813.3 6,925.5 6,939.3 7,009.8 7,054.1 7,072.5 7,077.1 7,089.9 7,098.8 7,128.9 7,130.6 7,136.8 7,144.4 7,146.7 7,149.0 7,155.2 7,157.2 7,185.0 7,200.1 7,208.0 7,210.0 7,222.1 7,234.9 7,245.1 7,258.9 7,274.9 7,312.0 7,426.8 7,508.5 7,510.2 8,723.8 Vertical schematic (actual) BASE …KALU…UPPE… K-1 M…LOWE… KUPA…UNIT …UNIT …C-4 IN…C-4B … C-4A … C-3 IN… C-2 IN… C-1 IN…C-1B …C-1A … UNIT …B-8 IN…B-7 IN…B-6 IN…B-5 IN…B-4 IN… B-3 IN… B-2 IN… B-1 IN… UNIT …A-6 IN… A-5 IN…A5-2 S… A5-1 S… A-4 IN…A4-3 S… A4-2 S… A4-1 S… A-3 IN…A3-3 S… A3-2 S…A-2 IN…A-1 IN…MILUV… SHOE; 7,508.4-7,510.2; 1.80; 5-9; 7.000; 6.276 PROD. CASING; 7,428.3-7,508.4; 80.13; 5-8; 7.000; 6.276 FLOAT COLLAR; 7,426.9-7,428.3; 1.43; 5-7; 7.000; 6.276 PROD. CASING; 7,098.6-7,426.9; 328.29; 5-6; 7.000; 6.276 CMT SQZ; 7,253.0-7,259.0; 6/13/1982 CMT SQZ; 7,225.0-7,245.0; 6/13/1982 CMT SQZ; 7,222.0-7,241.0; 5/24/1997 CMT SQZ; 7,225.0-7,235.0; 10/4/2008 WINDOW L1-01; 7,200.0-7,210.0; 10.00; 4-1; 5.000; 4.000 CMT SQZ; 7,200.0-7,209.0; 6/13/1982 CMT SQZ; 7,200.0-7,208.0; 5/24/1997 SLOTS; 7,130.6-8,723.6; 3/13/2010 Liner - Slotted; 7,130.6-8,723.6; 1,593.04; 7-2; 2.375; 1.995 WLEG; 7,156.3-7,157.0; 0.73; 1-14; 4.500; 3.000 NIPPLE; 7,155.1-7,156.3; 1.14; 1-13; 4.530; 2.800 Tubing; 7,145.0-7,155.1; 10.10; 1-12; 3.500; 2.992 APERF; 7,147.0-7,149.0; 1/27/2010 PUP; 7,144.4-7,145.0; 0.59; 1-11; 3.500; 2.990 SBE; 7,140.1-7,144.4; 4.37; 1-10; 5.670; 4.000 PACKER; 7,136.8-7,140.1; 3.32; 1-9; 5.870; 4.000 Tubing; 7,129.1-7,136.8; 7.69; 1-8; 3.500; 2.992 DEPLOY; 7,129.6-7,130.6; 1.00; 7-1; 2.625; 1.995 PROD. CASING MARKER JT; 7,058.5-7,098.6; 40.12; 5-5; 7.000; 6.276 CMT SQZ; 7,010.0-7,090.0; 8/14/1988 BLAST RING; 6,939.2-7,129.1; 189.91; 1-7; 4.500; 2.990 Tubing; 6,929.5-6,939.2; 9.68; 1-6; 3.500; 2.992 SLEEVE; 6,925.6-6,929.5; 3.91; 1-5; 4.500; 2.812 Tubing; 6,786.3-6,925.6; 139.26; 1-4; 3.500; 2.992 PACKER; 6,779.0-6,786.3; 7.32; 1-3; 5.920; 2.930 PBR; 6,765.3-6,779.0; 13.68; 1-2; 5.880; 2.970 LOCATOR; 6,763.5-6,765.3; 1.82; 3-8; 3.500; 2.970 LINER CASING; 6,757.6-6,763.5; 5.91; 3-7; 3.500; 2.992 LINER CASING; 6,713.7-6,757.6; 43.84; 3-6; 3.500; 2.992 XO BUSHING; 6,712.7-6,713.7; 1.04; 3-5; 5.560; 3.000 SEAL; 6,695.8-6,712.8; 16.96; 2-31; 3.990; 3.000 Casing; 6,693.8-6,712.7; 18.86; 3-4; 4.990; 4.000 LOCATOR; 6,692.5-6,695.8; 3.33; 2-30; 4.500; 3.000 Casing; 6,692.1-6,693.8; 1.73; 3-3; 5.510; 4.380 TUBING PUP; 6,686.6-6,692.5; 5.89; 2-29; 3.500; 2.992 Casing; 6,684.3-6,692.1; 7.76; 3-2; 5.510; 4.860 Tubing; 6,657.4-6,686.6; 29.24; 2-28; 3.500; 2.992 TUBING PUP; 6,648.3-6,657.4; 9.09; 2-27; 3.500; 2.992 GAS LIFT; 6,641.7-6,648.3; 6.63; 2-26; 4.725; 2.900 TUBING PUP; 6,631.9-6,641.7; 9.81; 2-25; 3.500; 2.992 Tubing; 6,130.5-6,631.9; 501.38; 2-24; 3.500; 2.992 TUBING PUP; 6,121.4-6,130.5; 9.06; 2-23; 3.500; 2.992 GAS LIFT; 6,114.7-6,121.4; 6.70; 2-22; 4.725; 2.900 TUBING PUP; 6,104.9-6,114.7; 9.79; 2-21; 3.500; 2.992 Tubing; 5,103.4-6,104.9; 1,001.52; 2-20; 3.500; 2.992 PROD. CASING; 3,441.5-7,058.5; 3,616.95; 5-4; 7.000; 6.276 TUBING PUP; 5,094.3-5,103.4; 9.09; 2-19; 3.500; 2.992 GAS LIFT; 5,087.7-5,094.3; 6.62; 2-18; 4.725; 2.900 TUBING PUP; 5,077.9-5,087.7; 9.81; 2-17; 3.500; 2.992 Tubing; 3,832.8-5,077.9; 1,245.05; 2-16; 3.500; 2.992 TUBING PUP; 3,823.7-3,832.8; 9.17; 2-15; 3.500; 2.992 GAS LIFT; 3,817.2-3,823.7; 6.51; 2-14; 4.725; 2.900 TUBING PUP; 3,807.3-3,817.2; 9.81; 2-13; 3.500; 2.992 PROD. CASING MARKER JT; 3,403.9-3,441.5; 37.58; 5-3; 7.000; 6.276 Casing; 31.7-6,684.3; 6,652.64; 3-1; 5.500; 4.950 Tubing; 2,501.5-3,807.3; 1,305.89; 2-12; 3.500; 2.992 SHOE; 2,499.6-2,501.4; 1.87; 2-5; 10.750; 9.950 TUBING PUP; 2,496.5-2,501.5; 5.00; 2-11; 3.500; 2.992 GAS LIFT; 2,489.8-2,496.5; 6.63; 2-10; 4.725; 2.900 TUBING PUP; 2,484.0-2,489.8; 5.79; 2-9; 3.500; 2.992 SUR. CASING; 2,419.6-2,499.6; 80.02; 2-4; 10.750; 9.950 COLLAR; 2,417.9-2,419.5; 1.60; 2-3; 10.750; 9.950 PROD. CASING; 35.1-3,403.9; 3,368.86; 5-2; 7.000; 6.276 Tubing; 489.5-2,484.0; 1,994.57; 2-8; 3.500; 2.992 SUR. CASING; 34.9-2,417.9; 2,383.05; 2-2; 10.750; 9.950 TUBING PUP; 483.6-489.5; 5.87; 2-7; 3.500; 2.992 NIPPLE; 482.0-483.6; 1.58; 2-6; 4.520; 2.875 TUBING PUP; 475.5-482.0; 6.47; 2-5; 3.500; 2.992 Tubing; 66.4-475.5; 409.14; 2-4; 3.500; 2.992 CONDUCTOR; 32.0-80.0; 48.00; 1-1; 16.000; 15.082 TUBING; 35.6-66.4; 30.79; 2-3; 3.500; 2.992 CASING HANGER; 31.7-35.1; 3.33; 5-1; 10.000; 6.276 HANGER; 31.2-34.9; 3.70; 2-1; 12.000; 9.950 Tubing XO PUP; 28.6-35.6; 7.00; 2-2; 3.500; 2.992 HANGER; 27.8-28.6; 0.85; 2-1; 11.000; 3.500 KUP PROD KB-Grd (ft) 40.71 Rig Release Date 6/13/1982 1E-12 ... TD Act Btm (ftKB) 7,512.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292073600 Wellbore Status PROD Max Angle & MD Incl (°) 46.27 MD (ftKB) 4,500.00 WELLNAME WELLBORE1E-12 H2S (ppm) 200 Date 9/10/2016 Comment SSSV: NIPPLE Annotation Last WO: End Date 10/14/2007 Notes: General & Safety End Date Annotation 12/13/2019 NOTE: Attempted to set 2 plugs in DS Nipple @ 6926' (Polish Bore Could be Comprimised) 9/18/2008 NOTE: CTD LATERALS L1, L1-01 (off main wellbore), L2, L2-01 9/18/2008 NOTE: VIEW SCHEMATIC w/9.0 & Reference Visio Multi-lat drawing attached 1E-12, 4/2/2020 7:32:18 AM M D (ft K B) 0.0 28.5 31.8 34.8 35.8 80.1 482.0 489.5 2,419.6 2,489.8 2,499.7 2,541.0 3,441.6 3,817.3 3,832.7 5,087.6 5,103.3 6,114.8 6,130.6 6,641.7 6,657.5 6,686.7 6,692.6 6,695.9 6,712.9 6,713.6 6,763.5 6,778.9 6,800.9 6,813.3 6,925.5 6,939.3 7,009.8 7,054.1 7,072.5 7,077.1 7,089.9 7,098.8 7,128.9 7,130.6 7,136.8 7,144.4 7,146.7 7,149.0 7,155.2 7,157.2 7,185.0 7,200.1 7,208.0 7,210.0 7,222.1 7,234.9 7,245.1 7,258.9 7,274.9 7,312.0 7,426.8 7,508.5 7,510.2 8,723.8 Vertical schematic (actual) BASE …KALU…UPPE… K-1 M…LOWE… KUPA…UNIT …UNIT …C-4 IN…C-4B … C-4A … C-3 IN… C-2 IN… C-1 IN…C-1B …C-1A … UNIT …B-8 IN…B-7 IN…B-6 IN…B-5 IN…B-4 IN… B-3 IN… B-2 IN… B-1 IN… UNIT …A-6 IN… A-5 IN…A5-2 S… A5-1 S… A-4 IN…A4-3 S… A4-2 S… A4-1 S… A-3 IN…A3-3 S… A3-2 S…A-2 IN…A-1 IN…MILUV… SHOE; 7,508.4-7,510.2; 1.80; 5-9; 7.000; 6.276 PROD. CASING; 7,428.3-7,508.4; 80.13; 5-8; 7.000; 6.276 FLOAT COLLAR; 7,426.9-7,428.3; 1.43; 5-7; 7.000; 6.276 PROD. CASING; 7,098.6-7,426.9; 328.29; 5-6; 7.000; 6.276 CMT SQZ; 7,253.0-7,259.0; 6/13/1982 CMT SQZ; 7,225.0-7,245.0; 6/13/1982 CMT SQZ; 7,222.0-7,241.0; 5/24/1997 CMT SQZ; 7,225.0-7,235.0; 10/4/2008 WINDOW L1-01; 7,200.0-7,210.0; 10.00; 4-1; 5.000; 4.000 CMT SQZ; 7,200.0-7,209.0; 6/13/1982 CMT SQZ; 7,200.0-7,208.0; 5/24/1997 SLOTS; 7,130.6-8,723.6; 3/13/2010 Liner - Slotted; 7,130.6-8,723.6; 1,593.04; 7-2; 2.375; 1.995 WLEG; 7,156.3-7,157.0; 0.73; 1-14; 4.500; 3.000 NIPPLE; 7,155.1-7,156.3; 1.14; 1-13; 4.530; 2.800 Tubing; 7,145.0-7,155.1; 10.10; 1-12; 3.500; 2.992 APERF; 7,147.0-7,149.0; 1/27/2010 PUP; 7,144.4-7,145.0; 0.59; 1-11; 3.500; 2.990 SBE; 7,140.1-7,144.4; 4.37; 1-10; 5.670; 4.000 PACKER; 7,136.8-7,140.1; 3.32; 1-9; 5.870; 4.000 Tubing; 7,129.1-7,136.8; 7.69; 1-8; 3.500; 2.992 DEPLOY; 7,129.6-7,130.6; 1.00; 7-1; 2.625; 1.995 PROD. CASING MARKER JT; 7,058.5-7,098.6; 40.12; 5-5; 7.000; 6.276 CMT SQZ; 7,010.0-7,090.0; 8/14/1988 BLAST RING; 6,939.2-7,129.1; 189.91; 1-7; 4.500; 2.990 Tubing; 6,929.5-6,939.2; 9.68; 1-6; 3.500; 2.992 SLEEVE; 6,925.6-6,929.5; 3.91; 1-5; 4.500; 2.812 Tubing; 6,786.3-6,925.6; 139.26; 1-4; 3.500; 2.992 PACKER; 6,779.0-6,786.3; 7.32; 1-3; 5.920; 2.930 PBR; 6,765.3-6,779.0; 13.68; 1-2; 5.880; 2.970 LOCATOR; 6,763.5-6,765.3; 1.82; 3-8; 3.500; 2.970 LINER CASING; 6,757.6-6,763.5; 5.91; 3-7; 3.500; 2.992 LINER CASING; 6,713.7-6,757.6; 43.84; 3-6; 3.500; 2.992 XO BUSHING; 6,712.7-6,713.7; 1.04; 3-5; 5.560; 3.000 SEAL; 6,695.8-6,712.8; 16.96; 2-31; 3.990; 3.000 Casing; 6,693.8-6,712.7; 18.86; 3-4; 4.990; 4.000 LOCATOR; 6,692.5-6,695.8; 3.33; 2-30; 4.500; 3.000 Casing; 6,692.1-6,693.8; 1.73; 3-3; 5.510; 4.380 TUBING PUP; 6,686.6-6,692.5; 5.89; 2-29; 3.500; 2.992 Casing; 6,684.3-6,692.1; 7.76; 3-2; 5.510; 4.860 Tubing; 6,657.4-6,686.6; 29.24; 2-28; 3.500; 2.992 TUBING PUP; 6,648.3-6,657.4; 9.09; 2-27; 3.500; 2.992 GAS LIFT; 6,641.7-6,648.3; 6.63; 2-26; 4.725; 2.900 TUBING PUP; 6,631.9-6,641.7; 9.81; 2-25; 3.500; 2.992 Tubing; 6,130.5-6,631.9; 501.38; 2-24; 3.500; 2.992 TUBING PUP; 6,121.4-6,130.5; 9.06; 2-23; 3.500; 2.992 GAS LIFT; 6,114.7-6,121.4; 6.70; 2-22; 4.725; 2.900 TUBING PUP; 6,104.9-6,114.7; 9.79; 2-21; 3.500; 2.992 Tubing; 5,103.4-6,104.9; 1,001.52; 2-20; 3.500; 2.992 PROD. CASING; 3,441.5-7,058.5; 3,616.95; 5-4; 7.000; 6.276 TUBING PUP; 5,094.3-5,103.4; 9.09; 2-19; 3.500; 2.992 GAS LIFT; 5,087.7-5,094.3; 6.62; 2-18; 4.725; 2.900 TUBING PUP; 5,077.9-5,087.7; 9.81; 2-17; 3.500; 2.992 Tubing; 3,832.8-5,077.9; 1,245.05; 2-16; 3.500; 2.992 TUBING PUP; 3,823.7-3,832.8; 9.17; 2-15; 3.500; 2.992 GAS LIFT; 3,817.2-3,823.7; 6.51; 2-14; 4.725; 2.900 TUBING PUP; 3,807.3-3,817.2; 9.81; 2-13; 3.500; 2.992 PROD. CASING MARKER JT; 3,403.9-3,441.5; 37.58; 5-3; 7.000; 6.276 Casing; 31.7-6,684.3; 6,652.64; 3-1; 5.500; 4.950 Tubing; 2,501.5-3,807.3; 1,305.89; 2-12; 3.500; 2.992 SHOE; 2,499.6-2,501.4; 1.87; 2-5; 10.750; 9.950 TUBING PUP; 2,496.5-2,501.5; 5.00; 2-11; 3.500; 2.992 GAS LIFT; 2,489.8-2,496.5; 6.63; 2-10; 4.725; 2.900 TUBING PUP; 2,484.0-2,489.8; 5.79; 2-9; 3.500; 2.992 SUR. CASING; 2,419.6-2,499.6; 80.02; 2-4; 10.750; 9.950 COLLAR; 2,417.9-2,419.5; 1.60; 2-3; 10.750; 9.950 PROD. CASING; 35.1-3,403.9; 3,368.86; 5-2; 7.000; 6.276 Tubing; 489.5-2,484.0; 1,994.57; 2-8; 3.500; 2.992 SUR. CASING; 34.9-2,417.9; 2,383.05; 2-2; 10.750; 9.950 TUBING PUP; 483.6-489.5; 5.87; 2-7; 3.500; 2.992 NIPPLE; 482.0-483.6; 1.58; 2-6; 4.520; 2.875 TUBING PUP; 475.5-482.0; 6.47; 2-5; 3.500; 2.992 Tubing; 66.4-475.5; 409.14; 2-4; 3.500; 2.992 CONDUCTOR; 32.0-80.0; 48.00; 1-1; 16.000; 15.082 TUBING; 35.6-66.4; 30.79; 2-3; 3.500; 2.992 CASING HANGER; 31.7-35.1; 3.33; 5-1; 10.000; 6.276 HANGER; 31.2-34.9; 3.70; 2-1; 12.000; 9.950 Tubing XO PUP; 28.6-35.6; 7.00; 2-2; 3.500; 2.992 HANGER; 27.8-28.6; 0.85; 2-1; 11.000; 3.500 KUP PROD 1E-12 ... WELLNAME WELLBORE1E-12 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 7,147.0 2/6/2010 1E-12L1 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: TAG, H2S, SET CATCHER, GLV C/O, PULL CATCHER 9/12/2017 1E-12L1 pproven Casing Strings Casing Description L1 LINER OD (in) 2 3/8 ID (in) 2.00 Top (ftKB) 7,510.5 Set Depth (ftKB) 9,002.0 Set Depth (TVD) (… 6,387.1 Wt/Len (l… 4.60 Grade L-80 Top Thread STL Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,510.5 6,371.6 85.05 DEPLOY BAKER DEPLOYMENT SLEEVE 1.995 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,520.0 8,995.8 6,372.3 6,387.5 A-4, 1E-12L1 3/11/2010 32.0 SLOTS Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends Frac Summary Start Date 10/7/2008 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 10/7/2008 Top Depth (ftKB) 7,225.0 Btm (ftKB) 7,235.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Notes: General & Safety End Date Annotation 3/14/2010 NOTE: CTD LATERALS L1, L1-01 (off main wellbore), L2, L2-01 9/18/2008 NOTE: VIEW SCHEMATIC w/9.0 & Reference Visio Multi-lat drawing attached 1E-12L1, 4/2/2020 7:32:19 AM M D (ft K B) 0.0 28.5 31.8 34.8 35.8 80.1 482.0 489.5 2,419.6 2,489.8 2,499.7 2,541.0 3,441.6 3,817.3 3,832.7 5,087.6 5,103.3 6,114.8 6,130.6 6,641.7 6,657.5 6,686.7 6,692.6 6,695.9 6,712.9 6,713.6 6,763.5 6,778.9 6,800.9 6,813.3 6,925.5 6,939.3 7,009.8 7,054.1 7,072.5 7,077.1 7,089.9 7,098.8 7,128.9 7,130.6 7,136.8 7,144.4 7,146.7 7,149.0 7,155.2 7,157.2 7,185.0 7,200.1 7,217.8 7,265.1 7,350.1 7,409.1 7,426.8 7,509.8 7,512.1 7,683.1 7,899.9 8,460.0 8,724.1 8,996.1 9,002.0 9,350.1 Vertical schematic (actual) BASE …KALU…UPPE… K-1 M…LOWE… KUPA… KUPA… KUPA… KUPA… KUPA… UNIT …UNIT …C-4 IN…C-4B … C-4A …C-3 IN… C-2 IN…C-1 IN…C-1B …C-1A …UNIT …B-8 IN…B-7 IN…B-6 IN…B-5 IN…B-4 IN… B-3 IN… B-2 IN… B-1 IN…UNIT … UNIT … UNIT … UNIT … UNIT … A-6 IN… A-5 IN…A-5 IN… A-5 IN… A5-2 S… A-4 IN… A-4 IN… A-4 IN… A-4 IN… A-4 IN… A-4 IN… SHOE; 9,000.6-9,002.0; 1.36; 8-4; 2.375; 1.000 Solid Liner; 8,995.8-9,000.6; 4.82; 8-3; 2.375; 1.995 SLOTS; 7,520.0-8,995.8; 3/11/2010 Liner - Slotted; 7,520.0-8,995.8; 1,475.87; 8-2; 2.375; 1.995 DEPLOY; 7,510.5-7,520.0; 9.48; 8-1; 2.625; 1.995 Liner - Slotted; 7,130.6-8,723.6; 1,593.04; 7-2; 2.375; 1.995 SLOTS; 7,130.6-8,723.6; 3/13/2010 BILLET; 7,263.0-7,273.6; 10.54; 6-1; 2.625; 1.995 WLEG; 7,156.3-7,157.0; 0.73; 1-14; 4.500; 3.000 NIPPLE; 7,155.1-7,156.3; 1.14; 1-13; 4.530; 2.800 Tubing; 7,145.0-7,155.1; 10.10; 1-12; 3.500; 2.992 PROD. CASING; 7,098.6-7,426.9; 328.29; 5-6; 7.000; 6.276 APERF; 7,147.0-7,149.0; 1/27/2010 PUP; 7,144.4-7,145.0; 0.59; 1-11; 3.500; 2.990 SBE; 7,140.1-7,144.4; 4.37; 1-10; 5.670; 4.000 PACKER; 7,136.8-7,140.1; 3.32; 1-9; 5.870; 4.000 Tubing; 7,129.1-7,136.8; 7.69; 1-8; 3.500; 2.992 DEPLOY; 7,129.6-7,130.6; 1.00; 7-1; 2.625; 1.995 PROD. CASING MARKER JT; 7,058.5-7,098.6; 40.12; 5-5; 7.000; 6.276 CMT SQZ; 7,010.0-7,090.0; 8/14/1988 BLAST RING; 6,939.2-7,129.1; 189.91; 1-7; 4.500; 2.990 Tubing; 6,929.5-6,939.2; 9.68; 1-6; 3.500; 2.992 SLEEVE; 6,925.6-6,929.5; 3.91; 1-5; 4.500; 2.812 Tubing; 6,786.3-6,925.6; 139.26; 1-4; 3.500; 2.992 PACKER; 6,779.0-6,786.3; 7.32; 1-3; 5.920; 2.930 PBR; 6,765.3-6,779.0; 13.68; 1-2; 5.880; 2.970 LOCATOR; 6,763.5-6,765.3; 1.82; 3-8; 3.500; 2.970 LINER CASING; 6,757.6-6,763.5; 5.91; 3-7; 3.500; 2.992 LINER CASING; 6,713.7-6,757.6; 43.84; 3-6; 3.500; 2.992 XO BUSHING; 6,712.7-6,713.7; 1.04; 3-5; 5.560; 3.000 SEAL; 6,695.8-6,712.8; 16.96; 2-31; 3.990; 3.000 Casing; 6,693.8-6,712.7; 18.86; 3-4; 4.990; 4.000 LOCATOR; 6,692.5-6,695.8; 3.33; 2-30; 4.500; 3.000 Casing; 6,692.1-6,693.8; 1.73; 3-3; 5.510; 4.380 TUBING PUP; 6,686.6-6,692.5; 5.89; 2-29; 3.500; 2.992 Casing; 6,684.3-6,692.1; 7.76; 3-2; 5.510; 4.860 Tubing; 6,657.4-6,686.6; 29.24; 2-28; 3.500; 2.992 TUBING PUP; 6,648.3-6,657.4; 9.09; 2-27; 3.500; 2.992 GAS LIFT; 6,641.7-6,648.3; 6.63; 2-26; 4.725; 2.900 TUBING PUP; 6,631.9-6,641.7; 9.81; 2-25; 3.500; 2.992 Tubing; 6,130.5-6,631.9; 501.38; 2-24; 3.500; 2.992 TUBING PUP; 6,121.4-6,130.5; 9.06; 2-23; 3.500; 2.992 GAS LIFT; 6,114.7-6,121.4; 6.70; 2-22; 4.725; 2.900 TUBING PUP; 6,104.9-6,114.7; 9.79; 2-21; 3.500; 2.992 Tubing; 5,103.4-6,104.9; 1,001.52; 2-20; 3.500; 2.992 PROD. CASING; 3,441.5-7,058.5; 3,616.95; 5-4; 7.000; 6.276 TUBING PUP; 5,094.3-5,103.4; 9.09; 2-19; 3.500; 2.992 GAS LIFT; 5,087.7-5,094.3; 6.62; 2-18; 4.725; 2.900 TUBING PUP; 5,077.9-5,087.7; 9.81; 2-17; 3.500; 2.992 Tubing; 3,832.8-5,077.9; 1,245.05; 2-16; 3.500; 2.992 TUBING PUP; 3,823.7-3,832.8; 9.17; 2-15; 3.500; 2.992 GAS LIFT; 3,817.2-3,823.7; 6.51; 2-14; 4.725; 2.900 TUBING PUP; 3,807.3-3,817.2; 9.81; 2-13; 3.500; 2.992 PROD. CASING MARKER JT; 3,403.9-3,441.5; 37.58; 5-3; 7.000; 6.276 Casing; 31.7-6,684.3; 6,652.64; 3-1; 5.500; 4.950 Tubing; 2,501.5-3,807.3; 1,305.89; 2-12; 3.500; 2.992 SHOE; 2,499.6-2,501.4; 1.87; 2-5; 10.750; 9.950 TUBING PUP; 2,496.5-2,501.5; 5.00; 2-11; 3.500; 2.992 GAS LIFT; 2,489.8-2,496.5; 6.63; 2-10; 4.725; 2.900 TUBING PUP; 2,484.0-2,489.8; 5.79; 2-9; 3.500; 2.992 SUR. CASING; 2,419.6-2,499.6; 80.02; 2-4; 10.750; 9.950 COLLAR; 2,417.9-2,419.5; 1.60; 2-3; 10.750; 9.950 PROD. CASING; 35.1-3,403.9; 3,368.86; 5-2; 7.000; 6.276 Tubing; 489.5-2,484.0; 1,994.57; 2-8; 3.500; 2.992 SUR. CASING; 34.9-2,417.9; 2,383.05; 2-2; 10.750; 9.950 TUBING PUP; 483.6-489.5; 5.87; 2-7; 3.500; 2.992 NIPPLE; 482.0-483.6; 1.58; 2-6; 4.520; 2.875 TUBING PUP; 475.5-482.0; 6.47; 2-5; 3.500; 2.992 Tubing; 66.4-475.5; 409.14; 2-4; 3.500; 2.992 CONDUCTOR; 32.0-80.0; 48.00; 1-1; 16.000; 15.082 TUBING; 35.6-66.4; 30.79; 2-3; 3.500; 2.992 CASING HANGER; 31.7-35.1; 3.33; 5-1; 10.000; 6.276 HANGER; 31.2-34.9; 3.70; 2-1; 12.000; 9.950 Tubing XO PUP; 28.6-35.6; 7.00; 2-2; 3.500; 2.992 HANGER; 27.8-28.6; 0.85; 2-1; 11.000; 3.500 KUP PROD KB-Grd (ft) 40.71 Rig Release Date 6/13/1982 1E-12L1 ... TD Act Btm (ftKB) 9,002.4 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292073660 Wellbore Status PROD Max Angle & MD Incl (°) 97.95 MD (ftKB) 8,470.37 WELLNAME WELLBORE1E-12 H2S (ppm) 200 Date 9/10/2016 Comment SSSV: NIPPLE Annotation Last WO: End Date 10/14/2007 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 7,147.0 2/6/2010 1E-12L1-01 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: TAG, H2S, SET CATCHER, GLV C/O, PULL CATCHER 9/12/2017 1E-12L1-01 pproven Casing Strings Casing Description L1-01 LINER Slotted (off main wellbore) OD (in) 2 3/8 ID (in) 2.00 Top (ftKB) 7,129.6 Set Depth (ftKB) 8,725.0 Set Depth (TVD) (… Wt/Len (l… 4.60 Grade L-80 Top Thread STL Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,129.6 6,257.8 34.48 DEPLOY BAKER DEPLOYMENT SLEEVE with G/S Profile 1.995 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,130.6 8,723.6 6,258.6 6,357.9 A-5, 1E-12L1-01 3/13/2010 32.0 SLOTS Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends Frac Summary Start Date 10/7/2008 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 10/7/2008 Top Depth (ftKB) 7,225.0 Btm (ftKB) 7,235.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Notes: General & Safety End Date Annotation 3/14/2010 NOTE: CTD LATERALS L1, L1-01 (off main wellbore), L2, L2-01 9/18/2008 NOTE: VIEW SCHEMATIC w/9.0 & Reference Visio Multi-lat drawing attached 1E-12L1-01, 4/2/2020 7:32:20 AM M D (ft K B) 0.0 28.5 31.8 34.8 35.8 80.1 482.0 489.5 2,419.6 2,489.8 2,499.7 2,541.0 3,441.6 3,817.3 3,832.7 5,087.6 5,103.3 6,114.8 6,130.6 6,641.7 6,657.5 6,686.7 6,692.6 6,695.9 6,712.9 6,713.6 6,763.5 6,778.9 6,800.9 6,813.3 6,925.5 6,939.3 7,009.8 7,054.1 7,072.5 7,077.1 7,089.9 7,098.8 7,128.9 7,130.6 7,136.8 7,144.4 7,146.7 7,149.0 7,155.2 7,157.2 7,185.0 7,200.1 7,217.8 7,265.1 7,350.1 7,409.1 7,426.8 7,509.8 7,683.1 7,899.9 8,723.8 8,725.1 9,350.1 Vertical schematic (actual) BASE …KALU…UPPE… K-1 M…LOWE… KUPA… KUPA… KUPA… KUPA… KUPA… UNIT …UNIT …C-4 IN…C-4B … C-4A … C-3 IN… C-2 IN… C-1 IN…C-1B …C-1A … UNIT …B-8 IN…B-7 IN…B-6 IN…B-5 IN…B-4 IN… B-3 IN… B-2 IN… B-1 IN… UNIT … UNIT … UNIT … UNIT … UNIT … A-6 IN… A-5 IN… A-5 IN… A-5 IN… A5-2 S… A-4 IN… A-4 IN… A-4 IN… A-4 IN… A-4 IN… SHOE; 8,723.6-8,725.0; 1.36; 7-3; 2.375; 1.000 SLOTS; 7,130.6-8,723.6; 3/13/2010 Liner - Slotted; 7,130.6-8,723.6; 1,593.04; 7-2; 2.375; 1.995 BILLET; 7,263.0-7,273.6; 10.54; 6-1; 2.625; 1.995 WLEG; 7,156.3-7,157.0; 0.73; 1-14; 4.500; 3.000 NIPPLE; 7,155.1-7,156.3; 1.14; 1-13; 4.530; 2.800 Tubing; 7,145.0-7,155.1; 10.10; 1-12; 3.500; 2.992 PROD. CASING; 7,098.6-7,426.9; 328.29; 5-6; 7.000; 6.276 APERF; 7,147.0-7,149.0; 1/27/2010 PUP; 7,144.4-7,145.0; 0.59; 1-11; 3.500; 2.990 SBE; 7,140.1-7,144.4; 4.37; 1-10; 5.670; 4.000 PACKER; 7,136.8-7,140.1; 3.32; 1-9; 5.870; 4.000 Tubing; 7,129.1-7,136.8; 7.69; 1-8; 3.500; 2.992 DEPLOY; 7,129.6-7,130.6; 1.00; 7-1; 2.625; 1.995 PROD. CASING MARKER JT; 7,058.5-7,098.6; 40.12; 5-5; 7.000; 6.276 CMT SQZ; 7,010.0-7,090.0; 8/14/1988 BLAST RING; 6,939.2-7,129.1; 189.91; 1-7; 4.500; 2.990 Tubing; 6,929.5-6,939.2; 9.68; 1-6; 3.500; 2.992 SLEEVE; 6,925.6-6,929.5; 3.91; 1-5; 4.500; 2.812 Tubing; 6,786.3-6,925.6; 139.26; 1-4; 3.500; 2.992 PACKER; 6,779.0-6,786.3; 7.32; 1-3; 5.920; 2.930 PBR; 6,765.3-6,779.0; 13.68; 1-2; 5.880; 2.970 LOCATOR; 6,763.5-6,765.3; 1.82; 3-8; 3.500; 2.970 LINER CASING; 6,757.6-6,763.5; 5.91; 3-7; 3.500; 2.992 LINER CASING; 6,713.7-6,757.6; 43.84; 3-6; 3.500; 2.992 XO BUSHING; 6,712.7-6,713.7; 1.04; 3-5; 5.560; 3.000 SEAL; 6,695.8-6,712.8; 16.96; 2-31; 3.990; 3.000Casing; 6,693.8-6,712.7; 18.86; 3-4; 4.990; 4.000 LOCATOR; 6,692.5-6,695.8; 3.33; 2-30; 4.500; 3.000 Casing; 6,692.1-6,693.8; 1.73; 3-3; 5.510; 4.380 TUBING PUP; 6,686.6-6,692.5; 5.89; 2-29; 3.500; 2.992 Casing; 6,684.3-6,692.1; 7.76; 3-2; 5.510; 4.860 Tubing; 6,657.4-6,686.6; 29.24; 2-28; 3.500; 2.992 TUBING PUP; 6,648.3-6,657.4; 9.09; 2-27; 3.500; 2.992 GAS LIFT; 6,641.7-6,648.3; 6.63; 2-26; 4.725; 2.900 TUBING PUP; 6,631.9-6,641.7; 9.81; 2-25; 3.500; 2.992 Tubing; 6,130.5-6,631.9; 501.38; 2-24; 3.500; 2.992 TUBING PUP; 6,121.4-6,130.5; 9.06; 2-23; 3.500; 2.992 GAS LIFT; 6,114.7-6,121.4; 6.70; 2-22; 4.725; 2.900 TUBING PUP; 6,104.9-6,114.7; 9.79; 2-21; 3.500; 2.992 Tubing; 5,103.4-6,104.9; 1,001.52; 2-20; 3.500; 2.992 PROD. CASING; 3,441.5-7,058.5; 3,616.95; 5-4; 7.000; 6.276 TUBING PUP; 5,094.3-5,103.4; 9.09; 2-19; 3.500; 2.992 GAS LIFT; 5,087.7-5,094.3; 6.62; 2-18; 4.725; 2.900 TUBING PUP; 5,077.9-5,087.7; 9.81; 2-17; 3.500; 2.992 Tubing; 3,832.8-5,077.9; 1,245.05; 2-16; 3.500; 2.992 TUBING PUP; 3,823.7-3,832.8; 9.17; 2-15; 3.500; 2.992 GAS LIFT; 3,817.2-3,823.7; 6.51; 2-14; 4.725; 2.900 TUBING PUP; 3,807.3-3,817.2; 9.81; 2-13; 3.500; 2.992 PROD. CASING MARKER JT; 3,403.9-3,441.5; 37.58; 5-3; 7.000; 6.276 Casing; 31.7-6,684.3; 6,652.64; 3-1; 5.500; 4.950 Tubing; 2,501.5-3,807.3; 1,305.89; 2-12; 3.500; 2.992 SHOE; 2,499.6-2,501.4; 1.87; 2-5; 10.750; 9.950 TUBING PUP; 2,496.5-2,501.5; 5.00; 2-11; 3.500; 2.992 GAS LIFT; 2,489.8-2,496.5; 6.63; 2-10; 4.725; 2.900 TUBING PUP; 2,484.0-2,489.8; 5.79; 2-9; 3.500; 2.992 SUR. CASING; 2,419.6-2,499.6; 80.02; 2-4; 10.750; 9.950 COLLAR; 2,417.9-2,419.5; 1.60; 2-3; 10.750; 9.950 PROD. CASING; 35.1-3,403.9; 3,368.86; 5-2; 7.000; 6.276 Tubing; 489.5-2,484.0; 1,994.57; 2-8; 3.500; 2.992 SUR. CASING; 34.9-2,417.9; 2,383.05; 2-2; 10.750; 9.950 TUBING PUP; 483.6-489.5; 5.87; 2-7; 3.500; 2.992 NIPPLE; 482.0-483.6; 1.58; 2-6; 4.520; 2.875 TUBING PUP; 475.5-482.0; 6.47; 2-5; 3.500; 2.992 Tubing; 66.4-475.5; 409.14; 2-4; 3.500; 2.992 CONDUCTOR; 32.0-80.0; 48.00; 1-1; 16.000; 15.082 TUBING; 35.6-66.4; 30.79; 2-3; 3.500; 2.992 CASING HANGER; 31.7-35.1; 3.33; 5-1; 10.000; 6.276 HANGER; 31.2-34.9; 3.70; 2-1; 12.000; 9.950Tubing XO PUP; 28.6-35.6; 7.00; 2-2; 3.500; 2.992 HANGER; 27.8-28.6; 0.85; 2-1; 11.000; 3.500 KUP PROD KB-Grd (ft) 40.71 Rig Release Date 6/13/1982 1E-12L1-01 ... TD Act Btm (ftKB) 8,725.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292073661 Wellbore Status PROD Max Angle & MD Incl (°) 99.23 MD (ftKB) 7,640.42 WELLNAME WELLBORE1E-12 H2S (ppm) 200 Date 9/10/2016 Comment SSSV: NIPPLE Annotation Last WO: End Date 10/14/2007 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 7,147.0 2/6/2010 1E-12L2 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: TAG, H2S, SET CATCHER, GLV C/O, PULL CATCHER 9/12/2017 1E-12L2 pproven Casing Strings Casing Description L2 LINER OD (in) 2 5/8 ID (in) 2.00 Top (ftKB) 7,263.0 Set Depth (ftKB) 8,430.0 Set Depth (TVD) (… 6,338.8 Wt/Len (l… 4.70 Grade L-80 Top Thread STL Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,263.0 6,359.2 57.52 BILLET 2.625 Alluminum Billet with OH anchor 1.995 7,290.6 6,372.1 66.93 DEPLOY Deployment Sleeve 1.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,290.8 8,428.0 6,372.2 6,338.8 A-5, 1E-12L2 3/1/2010 32.0 SLOTS Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends Frac Summary Start Date 10/7/2008 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 10/7/2008 Top Depth (ftKB) 7,225.0 Btm (ftKB) 7,235.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Notes: General & Safety End Date Annotation 3/14/2010 NOTE: CTD LATERALS L1, L1-01 (off main wellbore), L2, L2-01 9/18/2008 NOTE: VIEW SCHEMATIC w/9.0 & Reference Visio Multi-lat drawing attached 1E-12L2, 4/2/2020 7:32:21 AM M D (ft K B) 0.0 28.5 31.8 34.8 35.8 80.1 482.0 489.5 2,419.6 2,489.8 2,499.7 2,541.0 3,441.6 3,817.3 3,832.7 5,087.6 5,103.3 6,114.8 6,130.6 6,641.7 6,657.5 6,686.7 6,692.6 6,695.9 6,712.9 6,713.6 6,763.5 6,778.9 6,800.9 6,813.3 6,925.5 6,939.3 7,009.8 7,054.1 7,072.5 7,077.1 7,089.9 7,098.8 7,128.9 7,130.6 7,136.8 7,144.4 7,146.7 7,149.0 7,155.2 7,157.2 7,185.0 7,200.1 7,217.8 7,265.1 7,289.4 7,291.0 7,379.9 7,492.1 7,512.1 7,895.0 8,428.5 8,460.0 8,724.1 Vertical schematic (actual) BASE …KALU…UPPE… K-1 M…LOWE… KUPA… KUPA… UNIT …UNIT …C-4 IN…C-4B … C-4A … C-3 IN… C-2 IN… C-1 IN…C-1B …C-1A … UNIT …B-8 IN…B-7 IN…B-6 IN…B-5 IN…B-4 IN… B-3 IN… B-2 IN… B-1 IN… UNIT … UNIT … A-6 IN… A-5 IN… A-5 IN… A-5 IN… A5-2 S… A-4 IN… A-4 IN… A-4 IN… A-4 IN… GUIDE SHOE; 8,428.6-8,430.0; 1.36; 6-6; 2.375; 1.000 Slotted Liner; 7,291.4-8,428.6; 1,137.24; 6-5; 2.625; 1.995 SLOTS; 7,290.8-8,428.0; 3/1/2010 DEPLOY; 7,290.6-7,291.4; 0.83; 6-4; 2.625; 1.000 GUIDE SHOE; 7,289.2-7,290.6; 1.36; 6-3; 2.375; 1.000 Solid Liner Pups; 7,273.6-7,289.2; 15.65; 6-2; 2.375; 1.995 BILLET; 7,263.0-7,273.6; 10.54; 6-1; 2.625; 1.995 SLOTS; 7,130.6-8,723.6; 3/13/2010 Liner - Slotted; 7,130.6-8,723.6; 1,593.04; 7-2; 2.375; 1.995 WLEG; 7,156.3-7,157.0; 0.73; 1-14; 4.500; 3.000 NIPPLE; 7,155.1-7,156.3; 1.14; 1-13; 4.530; 2.800 Tubing; 7,145.0-7,155.1; 10.10; 1-12; 3.500; 2.992 PROD. CASING; 7,098.6-7,426.9; 328.29; 5-6; 7.000; 6.276 APERF; 7,147.0-7,149.0; 1/27/2010 PUP; 7,144.4-7,145.0; 0.59; 1-11; 3.500; 2.990 SBE; 7,140.1-7,144.4; 4.37; 1-10; 5.670; 4.000 PACKER; 7,136.8-7,140.1; 3.32; 1-9; 5.870; 4.000 Tubing; 7,129.1-7,136.8; 7.69; 1-8; 3.500; 2.992 DEPLOY; 7,129.6-7,130.6; 1.00; 7-1; 2.625; 1.995 PROD. CASING MARKER JT; 7,058.5-7,098.6; 40.12; 5 -5; 7.000; 6.276 CMT SQZ; 7,010.0-7,090.0; 8/14/1988 BLAST RING; 6,939.2-7,129.1; 189.91; 1-7; 4.500; 2.990 Tubing; 6,929.5-6,939.2; 9.68; 1-6; 3.500; 2.992 SLEEVE; 6,925.6-6,929.5; 3.91; 1-5; 4.500; 2.812 Tubing; 6,786.3-6,925.6; 139.26; 1-4; 3.500; 2.992 PACKER; 6,779.0-6,786.3; 7.32; 1-3; 5.920; 2.930 PBR; 6,765.3-6,779.0; 13.68; 1-2; 5.880; 2.970 LOCATOR; 6,763.5-6,765.3; 1.82; 3-8; 3.500; 2.970 LINER CASING; 6,757.6-6,763.5; 5.91; 3-7; 3.500; 2.992 LINER CASING; 6,713.7-6,757.6; 43.84; 3-6; 3.500; 2.992 XO BUSHING; 6,712.7-6,713.7; 1.04; 3-5; 5.560; 3.000 SEAL; 6,695.8-6,712.8; 16.96; 2-31; 3.990; 3.000 Casing; 6,693.8-6,712.7; 18.86; 3-4; 4.990; 4.000 LOCATOR; 6,692.5-6,695.8; 3.33; 2-30; 4.500; 3.000 Casing; 6,692.1-6,693.8; 1.73; 3-3; 5.510; 4.380 TUBING PUP; 6,686.6-6,692.5; 5.89; 2-29; 3.500; 2.992 Casing; 6,684.3-6,692.1; 7.76; 3-2; 5.510; 4.860 Tubing; 6,657.4-6,686.6; 29.24; 2-28; 3.500; 2.992 TUBING PUP; 6,648.3-6,657.4; 9.09; 2-27; 3.500; 2.992 GAS LIFT; 6,641.7-6,648.3; 6.63; 2-26; 4.725; 2.900 TUBING PUP; 6,631.9-6,641.7; 9.81; 2-25; 3.500; 2.992 Tubing; 6,130.5-6,631.9; 501.38; 2-24; 3.500; 2.992 TUBING PUP; 6,121.4-6,130.5; 9.06; 2-23; 3.500; 2.992 GAS LIFT; 6,114.7-6,121.4; 6.70; 2-22; 4.725; 2.900 TUBING PUP; 6,104.9-6,114.7; 9.79; 2-21; 3.500; 2.992 Tubing; 5,103.4-6,104.9; 1,001.52; 2-20; 3.500; 2.992 PROD. CASING; 3,441.5-7,058.5; 3,616.95; 5-4; 7.000; 6.276 TUBING PUP; 5,094.3-5,103.4; 9.09; 2-19; 3.500; 2.992 GAS LIFT; 5,087.7-5,094.3; 6.62; 2-18; 4.725; 2.900 TUBING PUP; 5,077.9-5,087.7; 9.81; 2-17; 3.500; 2.992 Tubing; 3,832.8-5,077.9; 1,245.05; 2-16; 3.500; 2.992 TUBING PUP; 3,823.7-3,832.8; 9.17; 2-15; 3.500; 2.992 GAS LIFT; 3,817.2-3,823.7; 6.51; 2-14; 4.725; 2.900 TUBING PUP; 3,807.3-3,817.2; 9.81; 2-13; 3.500; 2.992 PROD. CASING MARKER JT; 3,403.9-3,441.5; 37.58; 5-3; 7.000; 6.276 Casing; 31.7-6,684.3; 6,652.64; 3-1; 5.500; 4.950 Tubing; 2,501.5-3,807.3; 1,305.89; 2-12; 3.500; 2.992 SHOE; 2,499.6-2,501.4; 1.87; 2-5; 10.750; 9.950 TUBING PUP; 2,496.5-2,501.5; 5.00; 2-11; 3.500; 2.992 GAS LIFT; 2,489.8-2,496.5; 6.63; 2-10; 4.725; 2.900 TUBING PUP; 2,484.0-2,489.8; 5.79; 2-9; 3.500; 2.992 SUR. CASING; 2,419.6-2,499.6; 80.02; 2-4; 10.750; 9.950 COLLAR; 2,417.9-2,419.5; 1.60; 2-3; 10.750; 9.950 PROD. CASING; 35.1-3,403.9; 3,368.86; 5-2; 7.000; 6.276 Tubing; 489.5-2,484.0; 1,994.57; 2-8; 3.500; 2.992 SUR. CASING; 34.9-2,417.9; 2,383.05; 2-2; 10.750; 9.950 TUBING PUP; 483.6-489.5; 5.87; 2-7; 3.500; 2.992 NIPPLE; 482.0-483.6; 1.58; 2-6; 4.520; 2.875 TUBING PUP; 475.5-482.0; 6.47; 2-5; 3.500; 2.992 Tubing; 66.4-475.5; 409.14; 2-4; 3.500; 2.992 CONDUCTOR; 32.0-80.0; 48.00; 1-1; 16.000; 15.082 TUBING; 35.6-66.4; 30.79; 2-3; 3.500; 2.992 CASING HANGER; 31.7-35.1; 3.33; 5-1; 10.000; 6.276 HANGER; 31.2-34.9; 3.70; 2-1; 12.000; 9.950 Tubing XO PUP; 28.6-35.6; 7.00; 2-2; 3.500; 2.992 HANGER; 27.8-28.6; 0.85; 2-1; 11.000; 3.500 KUP PROD KB-Grd (ft) 40.71 Rig Release Date 6/13/1982 1E-12L2 ... TD Act Btm (ftKB) 8,460.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292073662 Wellbore Status PROD Max Angle & MD Incl (°) 97.13 MD (ftKB) 7,920.60 WELLNAME WELLBORE1E-12 H2S (ppm) 200 Date 9/10/2016 Comment SSSV: NIPPLE Annotation Last WO: End Date 10/14/2007 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 7,147.0 2/6/2010 1E-12L2-01 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: TAG, H2S, SET CATCHER, GLV C/O, PULL CATCHER 9/12/2017 1E-12L2-01 pproven Casing Strings Casing Description L2-01 LINER OD (in) 2 5/8 ID (in) 2.00 Top (ftKB) 7,410.0 Set Depth (ftKB) 9,350.0 Set Depth (TVD) (… Wt/Len (l… 4.60 Grade L-80 Top Thread STL Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,410.0 6,370.4 97.14 BILLET 2.625 Alluminum Billet with OH anchor 1.995 7,433.4 6,367.5 96.71 DEPLOY Deployment Sleeve Baker Torque Thru 1.995 8,244.0 6,384.6 91.83 DEPLOY Deployment Sleeve Baker Torque Thru 1.995 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,434.2 8,224.9 6,367.4 6,385.1 A-4, 1E-12L2-01 3/9/2010 32.0 SLOTS Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends 8,245.4 9,347.3 6,384.6 6,375.9 A-4, 1E-12L2-01 3/9/2010 32.0 SLOTS Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends Frac Summary Start Date 10/7/2008 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 10/7/2008 Top Depth (ftKB) 7,225.0 Btm (ftKB) 7,235.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Notes: General & Safety End Date Annotation 3/14/2010 NOTE: CTD LATERALS L1, L1-01 (off main wellbore), L2, L2-01 9/18/2008 NOTE: VIEW SCHEMATIC w/9.0 & Reference Visio Multi-lat drawing attached 1E-12L2-01, 4/2/2020 7:32:23 AM M D (ft K B) 0.0 28.5 31.8 34.8 35.8 80.1 482.0 489.5 2,419.6 2,489.8 2,499.7 2,541.0 3,441.6 3,817.3 3,832.7 5,087.6 5,103.3 6,114.8 6,130.6 6,641.7 6,657.5 6,686.7 6,692.6 6,695.9 6,712.9 6,713.6 6,763.5 6,778.9 6,800.9 6,813.3 6,925.5 6,939.3 7,009.8 7,054.1 7,072.5 7,077.1 7,089.9 7,098.8 7,128.9 7,130.6 7,136.8 7,144.4 7,146.7 7,149.0 7,155.2 7,157.2 7,185.0 7,200.1 7,217.8 7,265.1 7,350.1 7,409.1 7,420.6 7,432.1 7,434.1 7,512.1 7,680.1 7,899.9 8,225.1 8,240.8 8,244.1 8,245.4 8,723.8 9,347.1 9,347.8 9,350.1 Vertical schematic (actual) BASE …KALU…UPPE… K-1 M…LOWE… KUPA… KUPA… KUPA… KUPA… KUPA… UNIT …UNIT …C-4 IN…C-4B … C-4A …C-3 IN… C-2 IN…C-1 IN…C-1B …C-1A … UNIT …B-8 IN…B-7 IN…B-6 IN…B-5 IN…B-4 IN… B-3 IN… B-2 IN… B-1 IN…UNIT … UNIT … UNIT … UNIT … UNIT … A-6 IN…A-5 IN…A-5 IN…A5-2 S… A-4 IN… A-4 IN… A-4 IN… A-4 IN… A-4 IN… A-4 IN… Guide Shoe; 9,348.6-9,350.0; 1.36; 9-14; 2.375; 1.000 Solid Liner; 9,347.8-9,348.6; 0.81; 9-13; 2.375; 1.995 Bent sub; 9,347.3-9,347.8; 0.49; 9-12; 2.375; 1.000 Slotted liner; 8,245.5-9,347.3; 1,101.89; 9-11; 2.625; 1.995 SLOTS; 8,245.4-9,347.3; 3/9/2010 DEPLOY; 8,244.0-8,245.5; 1.48; 9-10; 2.625; 1.995 Guide Shoe; 8,242.6-8,244.0; 1.36; 9-9; 2.375; 1.000 Solid Liner; 8,240.8-8,242.6; 1.81; 9-8; 2.375; 1.995 Bent sub; 8,240.3-8,240.8; 0.49; 9-7; 2.375; 1.995 Solid Liner; 8,224.9-8,240.3; 15.44; 9-6; 2.375; 1.995 SLOTS; 7,434.2-8,224.9; 3/9/2010 Slotted liner; 7,434.2-8,224.9; 790.68; 9-5; 2.625; 1.995 DEPLOY; 7,433.4-7,434.2; 0.83; 9-4; 2.625; 1.995 Guide Shoe; 7,432.0-7,433.4; 1.36; 9-3; 2.375; 1.000 Solid Liner; 7,420.6-7,432.0; 11.45; 9-2; 2.375; 1.995 BILLET; 7,410.0-7,420.6; 10.55; 9-1; 2.625; 1.995 SLOTS; 7,130.6-8,723.6; 3/13/2010 Liner - Slotted; 7,130.6-8,723.6; 1,593.04; 7-2; 2.375; 1.995 BILLET; 7,263.0-7,273.6; 10.54; 6-1; 2.625; 1.995 WLEG; 7,156.3-7,157.0; 0.73; 1-14; 4.500; 3.000 NIPPLE; 7,155.1-7,156.3; 1.14; 1-13; 4.530; 2.800 Tubing; 7,145.0-7,155.1; 10.10; 1-12; 3.500; 2.992 PROD. CASING; 7,098.6-7,426.9; 328.29; 5-6; 7.000; 6.276 APERF; 7,147.0-7,149.0; 1/27/2010 PUP; 7,144.4-7,145.0; 0.59; 1-11; 3.500; 2.990 SBE; 7,140.1-7,144.4; 4.37; 1-10; 5.670; 4.000 PACKER; 7,136.8-7,140.1; 3.32; 1-9; 5.870; 4.000 Tubing; 7,129.1-7,136.8; 7.69; 1-8; 3.500; 2.992 DEPLOY; 7,129.6-7,130.6; 1.00; 7-1; 2.625; 1.995 PROD. CASING MARKER JT; 7,058.5-7,098.6; 40.12; 5-5; 7.000; 6.276 CMT SQZ; 7,010.0-7,090.0; 8/14/1988 BLAST RING; 6,939.2-7,129.1; 189.91; 1-7; 4.500; 2.990 Tubing; 6,929.5-6,939.2; 9.68; 1-6; 3.500; 2.992 SLEEVE; 6,925.6-6,929.5; 3.91; 1-5; 4.500; 2.812 Tubing; 6,786.3-6,925.6; 139.26; 1-4; 3.500; 2.992 PACKER; 6,779.0-6,786.3; 7.32; 1-3; 5.920; 2.930 PBR; 6,765.3-6,779.0; 13.68; 1-2; 5.880; 2.970 LOCATOR; 6,763.5-6,765.3; 1.82; 3-8; 3.500; 2.970 LINER CASING; 6,757.6-6,763.5; 5.91; 3-7; 3.500; 2.992 LINER CASING; 6,713.7-6,757.6; 43.84; 3-6; 3.500; 2.992 XO BUSHING; 6,712.7-6,713.7; 1.04; 3-5; 5.560; 3.000 SEAL; 6,695.8-6,712.8; 16.96; 2-31; 3.990; 3.000 Casing; 6,693.8-6,712.7; 18.86; 3-4; 4.990; 4.000 LOCATOR; 6,692.5-6,695.8; 3.33; 2-30; 4.500; 3.000 Casing; 6,692.1-6,693.8; 1.73; 3-3; 5.510; 4.380 TUBING PUP; 6,686.6-6,692.5; 5.89; 2-29; 3.500; 2.992 Casing; 6,684.3-6,692.1; 7.76; 3-2; 5.510; 4.860 Tubing; 6,657.4-6,686.6; 29.24; 2-28; 3.500; 2.992 TUBING PUP; 6,648.3-6,657.4; 9.09; 2-27; 3.500; 2.992 GAS LIFT; 6,641.7-6,648.3; 6.63; 2-26; 4.725; 2.900 TUBING PUP; 6,631.9-6,641.7; 9.81; 2-25; 3.500; 2.992 Tubing; 6,130.5-6,631.9; 501.38; 2-24; 3.500; 2.992 TUBING PUP; 6,121.4-6,130.5; 9.06; 2-23; 3.500; 2.992 GAS LIFT; 6,114.7-6,121.4; 6.70; 2-22; 4.725; 2.900 TUBING PUP; 6,104.9-6,114.7; 9.79; 2-21; 3.500; 2.992 Tubing; 5,103.4-6,104.9; 1,001.52; 2-20; 3.500; 2.992 PROD. CASING; 3,441.5-7,058.5; 3,616.95; 5-4; 7.000; 6.276 TUBING PUP; 5,094.3-5,103.4; 9.09; 2-19; 3.500; 2.992 GAS LIFT; 5,087.7-5,094.3; 6.62; 2-18; 4.725; 2.900 TUBING PUP; 5,077.9-5,087.7; 9.81; 2-17; 3.500; 2.992 Tubing; 3,832.8-5,077.9; 1,245.05; 2-16; 3.500; 2.992 TUBING PUP; 3,823.7-3,832.8; 9.17; 2-15; 3.500; 2.992 GAS LIFT; 3,817.2-3,823.7; 6.51; 2-14; 4.725; 2.900 TUBING PUP; 3,807.3-3,817.2; 9.81; 2-13; 3.500; 2.992 PROD. CASING MARKER JT; 3,403.9-3,441.5; 37.58; 5-3; 7.000; 6.276 Casing; 31.7-6,684.3; 6,652.64; 3-1; 5.500; 4.950 Tubing; 2,501.5-3,807.3; 1,305.89; 2-12; 3.500; 2.992 SHOE; 2,499.6-2,501.4; 1.87; 2-5; 10.750; 9.950 TUBING PUP; 2,496.5-2,501.5; 5.00; 2-11; 3.500; 2.992 GAS LIFT; 2,489.8-2,496.5; 6.63; 2-10; 4.725; 2.900 TUBING PUP; 2,484.0-2,489.8; 5.79; 2-9; 3.500; 2.992 SUR. CASING; 2,419.6-2,499.6; 80.02; 2-4; 10.750; 9.950 COLLAR; 2,417.9-2,419.5; 1.60; 2-3; 10.750; 9.950 PROD. CASING; 35.1-3,403.9; 3,368.86; 5-2; 7.000; 6.276 Tubing; 489.5-2,484.0; 1,994.57; 2-8; 3.500; 2.992 SUR. CASING; 34.9-2,417.9; 2,383.05; 2-2; 10.750; 9.950 TUBING PUP; 483.6-489.5; 5.87; 2-7; 3.500; 2.992 NIPPLE; 482.0-483.6; 1.58; 2-6; 4.520; 2.875 TUBING PUP; 475.5-482.0; 6.47; 2-5; 3.500; 2.992 Tubing; 66.4-475.5; 409.14; 2-4; 3.500; 2.992 CONDUCTOR; 32.0-80.0; 48.00; 1-1; 16.000; 15.082 TUBING; 35.6-66.4; 30.79; 2-3; 3.500; 2.992 CASING HANGER; 31.7-35.1; 3.33; 5-1; 10.000; 6.276 HANGER; 31.2-34.9; 3.70; 2-1; 12.000; 9.950 Tubing XO PUP; 28.6-35.6; 7.00; 2-2; 3.500; 2.992 HANGER; 27.8-28.6; 0.85; 2-1; 11.000; 3.500 KUP PROD KB-Grd (ft) 40.71 Rig Release Date 6/13/1982 1E-12L2-01 ... TD Act Btm (ftKB) 9,350.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292073663 Wellbore Status PROD Max Angle & MD Incl (°) 97.63 MD (ftKB) 7,415.65 WELLNAME WELLBORE1E-12 H2S (ppm) 200 Date 9/10/2016 Comment SSSV: NIPPLE Annotation Last WO: End Date 10/14/2007 t ommiPhillips TRANSMITTAL FROM: Sandra D. Lemke, ATO -704 TO: Abby Bell ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 222 W. 711 Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 1E-12 DATE: 02/11/2019 IKuparu Ziebel Cased Hole Mechanical logs - raw data reports (production profile characterization) Transmittal instructions: Transmitted: scan, and e-mail to CC: 1 EE --12 -- e -transmittal well folder I �{ Receipt:1�" 1 Date: 6 ` Alaska/IT-66RErrrI Co no hi ipsAlaska I Office: 907.265.6947, Mobile 907.440.4512 30 35 5 R 1 V FEB I 1 20119 �_�I.,(.,.. PTD 157--060 Loepp, Victoria T (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Monday, December 9, 2019 8:33 AM To: Loepp, Victoria T (CED) Cc: CPA Wells Supt Subject: KRU 1 E-12 (PTD 182-060) Report of Sustained Casing Pressure Attachments: 1 E-12.pdf, 1 E-12 90 day TO 12-9-19.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, KRU gas lifted producer 1E-12 (PTD 182-060) was reported to have an OA pressure at 1140 psi yesterday afternoon. Operations attempted to bleed down the OA pressure, but were unsuccessful. The well was shut in and freeze protected and the OA pressure was bled to 765 psi. Slickline is being mobilized this morning to secure the well and begin diagnostics. A 90 day TIO plot and wellbore schematic are attached. Please let us know if you disagree with this plan or have any questions. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM cor*o Ptaps KUP PROD 1E-12 Wnocornllllp5 Well Attributes ____..- Max Angie SMD 70 Alaska, Inc. " wdmort APnllwl Fiel4 scam. wanemslnm: 5002920]3600 KUPARUK RIVER UNIT FIR nn l•1 MplftNa) qe Blm gots! 4627 4,500.00 ],512.0 Commanl Go(I-) - SSSV: NIPPLE 200 9/1012018 gnnolNlon Entl Oaln LastWO: 10I14I20W KeG.e Rq SIR xol-Dema 40.]1 8119/1982 IE-11.9N1Mn511 n PM er4N... etlum Mnahtion p1M1 Entl WM Mnalallon Lu1 AnO EnO XANGE, R e Last Tag: RICH B 1,129.0 5/182011 Rev Reason: TAG, H2S, SET CATCHER. GLV pO, PULL CATCHER ppmve 9/122017 as rIgStrings Leon. ..0 ion OD (n) IOIin) TOP gU1B1 SN 0.pM (111(8) sN papN (IVp)... WULan 9... GNatla Top TM1rea4 CONDUCTOR 18 15.082 32.0 80.0 80.0 65.00 H40 WELDED Coung Description 00 Den) 10 on Tap ANSI eN-WM1 (aNe) SN oug", )... WULan 11..... Top TM1mtl SURFACE 103/4 9.950 .31.2 2,501.4 2,500.1 45.50 KSS ISTO Goo1q MCNpepn M ID (in) Top BnI MpN BNe) DpN I1V81... WI14n11,. GMa Top TM1netl PRODUCTION ] 62]6 319 7,5102 6,5n7 28.00 K55 BTC cox0UCT0a; 920.808 costn90e.0- (in) ID(e) To, 911®1 sN0W1h (8N81 SN ON (TVpI_. Velon O... G.. Top TM1etl SCAB LINER 512 4.950 319 8,7653 5,959.1 15.50 LAO 511 HytlUl 5.5',0 V@6]21- wPPLE4az.0 Liner Detail$ Top (6KB1 Top OVpI"ge, TOpind(•) Mqp O6a On,n Nn(in) 1p 6,]12.] 5,916.5 38.18 AUUUBHING CSG TO TBG CROS OVER BUSHING 3.000 6,163.5 5,951.6 35.]4 LOCATOR NO GO LOCATOR W/sport out 2.970 GASLIFP, R,gSBA G[In8 DosGiPlian Op Iln) 10 n) TeP I6NB1 Sd BaP1M1 INNB) He GMUR (TPG)... wNten 11... Gratle TOP Threat WINDOW 11-01 5 4000 ],2000 ],2100 6,324.1 Tubing Suing§ sueFACE 512-1.1"', TuLorggos 1puon String Ma...IDOn) op INNS) sN wpm(.. sN p•v1M1 (TPDI (... we(wHll Ontle op Connedbn TUBING 31/2 2.992 2].8 6,]12.8 5,9156 930 LA0 IBTM Completion Data" Top (Me)Tn ITPe)(ft.) Topmd(•) IMm OY Com xmmlilM)I ID 21.8 27.8 0.05 1 PANGER TUBING LAGER 3.500 GASUF1;3,8112 482.0 482.00.09 IP LE C COO NIPPLE 2.875 --5-00-2 6692.5 38.30 LOCATOR BAKER LOCATOR W/2.5'01 spacow . 00 8,8958 ,902.9 36.28 EAL BAKER &0-40 BONDED SEAL ASSEMBLY 3.000 GASLIiT,5081.] TualnO Doam1P11an SWn9 Ma... 1O Cn) TaP BI SN Oopm lft.. 9N goo"'DVp)1._WIImXN GMn top Coensawn STRADDLE PACKER 4112 2990 6,7133 ].15].0 6.2864L80 T CompleSon Daub _ Top IN) Top(T/BIINKB) Top and l•) Num Doo Dere Nommnl ID On) GASLIFT:eI147 -165.3 5,959.1 35.12 PER BAKER 80-00 PAR 2.9]0 8]M.0 5,9)0.2 35.61 PACKER BAKER PHILREIRIEVABLE PACKER 4>B2-]"269 2.930 GAS LFT: 8,541.7 6925.8 6,089.9 34.91 SLEEVE EWRCMU GUMS SLEEVE 2,812 6,9392 8,101.1 .88 BVS RIG BLAST RING S(3) 1,005-7,095' 2,990 1,136.8 6263.8 34.49 PACKER BAKER F-1 PACKER 4.000 1,140.1 6,266.5 34.49 B BAKER SEAL SURE EXTENSION 4.000 7,155.1 6,278.9 30..49 NIP E CGAIW VNIP LE 295' -MILLED TO 2.80"12]12010 2.800 L0cAro8; e.fis26 3 8,279.8 34.49 WLEG Baker Wireline Entry Guide 3.000 sEu:e6PEe Other Mfl0 (WiRill" Ietrbvable Plugs, valves, Pump, flat, atc. Top MIN Tap lnd Top IHNBI1 INNe) 1.1 pe Com sun Wle ID (In) ],15]0 8864 34.50 PILOT HOLE CTDPILOT HOLE 2122/21110 0000 ],2010 6,316.] 345 WHIPSTOCK WH PSTOCK 2/232010 0.00 SceN LINER 5.5-,Ge-0fi721`, PerfemtIO S✓<slats SM1M 0.;e]85] FACKER;6,179.0 Top@Nal 5M HUGH Top II VD) ) &m DVD)ow (KNe) Zona we, 6 'INN,Com SLEEVE 60256 1p O.0 7,090.0 8,159.3 8225.2 U2, C3, W14119M 8.0 CMF SquiemetloN3/171 UNIT 8, IE- SOZ 12 CMT.QZ;],6t6D.10ILD cemp,Dla6. ma ],14].0 ],1490 22]2.2 22]3.9 UNIT B. IE- 12 -1)27TOTO 6.0 APERF 1GUN NNMBH Charges, Wdegnee Phasing, ],200.0 ] 2 80 8315 8 63 .5 A$1 -12 524/199] 4.0 CMF 1803eg, Pp; 21/6• EJ SOZ AH 1,200.0 7.209.0 6,3159 6,323.3 A5. E-12 8/13/1982 4.0 OMT --6T4-97 SOZ PACKERp368 1,222.0 ],241.0 -334.0 TZ 1E-12 2411991 4. CMF 180 tleg. Ph;2118•E3 SBE:].140.1 SCE BH 7.2T570 ],235.0 ,336. 8.344A A4, 1E-2 10/4/2008J4.0 C 2.5•HYPE E -T, seg SOZ phase APERF; 7.147.Y4p49.0�n ],225.0 1,245.0 6,336.5 6,3530 Ad, 1EA2 W13/1982CMT SOZ R111e:1.IHE1 ],253.0 ],259. 8359] 6364.6 Ad, tE-12 511311 82CMT wLEG;],1569 LI n1 LINER6.1dE 'ANN, BM.WN,1509$ NN, MTO=7A00.0d,]a50 CMT SGZ;]j00.0-],1nad SOZ StlmnlatiorlsS paatlilania. ... P,oppanlpnl Btl 8n IIE) Pmppanlln FomlNbn (m) DNa CMTWHIP 111108],201.0 191]/2006 WHIPSTOCK; 1,101.0 StlmulatlonsSTlaatmeMs WINDDW L1L1; ],2p6,0. ]310.0 paOi HOLE; 1+5]n CMT SOL13150-1135.0 s1pR ID( ryNB) BM pnb $pmR,eN FIYM ]^2360 Vo1CWnPump I5ti6 vnl slum loop 1 ],22I 1002008 FRAc:].a1oD Cement Squeezes CMTSD2,111z o ].MLD Top f1VD1 atm (]w) C.T.G' lu6o.]3n5.D TOP INKS BM1n NOES (UNBI (NHBI pe• Stu[0aM Com 7,010.0 7,090.0 6,15.3 B. 2H2 Cum Nft SW sZe N11/1997 C.T8QD:12556-72RQ- 1,TSLU 1,510.0 6,214.1 8573.5 Gueent Squesue 1282010 CEMENT SOUEEZE:],I5a0 MB P0.000C110H; 31.6-1.5163 - KUP PROD 1E-12 wnanvrnnnpb Alaska, Inc 1F1$ 9I12Q01]fi`91'13 PM Vx4e etlwla ecLe NANOER; 216 Mandmllnwrts m .B R Top o (X118) eP MO RRB) 1 MRa Yetlel OD6n1 8— T p Typ 0 (n T Ipep a Run DNa Com 2,488.8 2,488.6 Lamm 103G 1 GAS LIPt IGLV IINT I0.1 1,2]2.0 9I11201> 2 3,01].2 3,]53.0 Camm 1 GAS LI GLV INT 0.108 1,268.0 9111201] cOv0uci0e;3Zeao.6q 3 5,08].] 4,690.1 Cemm KBG 1 GAS LIFT GV INT 0250 00 9/12/201 6,11 ] 5,445.0 Camm Ka 1 GAS L pMY INT 0.000 0. 9/11201] 5 6,641Yj 5,859.3 Camm KBG 1 GAS LIFT DNn INT 0.000 00 9/f 01207] NIPFLE:O820 NOW: iianeml a Entl OW AnnelaEon 9/1&2000 NO : CMLATERALS Lt, L1 1 (08 mein well8are), L2, L2-01 9H 82008 OUrE: VIEW SCHE TICW/9.08 Refemnm Visio lou lai Omwinge ec ed GP9 LIFi:2pa8A SNRFALE; 31 a.5S1. OPSLRT;3917.2 GAOLIFT:5.057.] GA9 LIFL; 6.1107 GAB LIFT: 6,801) LOLATOR;BBa26 SEAL: 8b858 3G LINER 5. Tv. S®MV2 31.16765] PBRE]833 PACKER: 8,]]0.0 9LEEVE:6.915.0 LMT SOZ:],0111, 1 MS PACKER:7.138.8 6B E: ],1401 APERF:1,147.S-7,48.0 NIPPLE:7.155.1 W LSG: 1.1.1, SLOTS: 1.130.68.]29.8 L1.01 LINER. IoM.. mRon):].128.6-8.725.0 CMT SO2; CMTSOE:72W U>¢090 W HIPSTOCK; ],2010 WINDOW L1-01:],200.0. 7.210.0 PKOTHOLE;1,15>0 CMT SOL ]325.0].335.0 FM:7X15.0 CMT ' SEEL , 7.222..0.7,N1.0 CMTSO],2]5.6].N5.0 CMT BDZ 7253,04,2690 CEMENi800EEEE:1,150.0 KB PROOIILTION; 318-7,610 R� Annular Communication Surveillance Bleed 1E-12 12/8/19 1140 1060 80 OUTER GLO 1E-12 12/8/19 1120 1030 90 OUTER GLO 1E-12 12/8/19 1080 600 480 OUTER GLO 1E-12 9/29/18 395 875 -480 INNER GLO Annular Communication Surveillance Well Name: 1E-12 Start Date: 10 -Sep -2019 Days: 90 End Date: 9 -Dec -2019 Injection Rate Summary 600 0 500 I 400 `o 0 S 300 v 0 200 U N - 100 0 m N v 0 ti ®-DGI MGI —PWI SWI —BLPD 1400 Pressure Summary 170 1200 150 1000 Z N 130 d a 800 v v 110 m 600 `v v a n 400 90 F 200 70 0 50 m m m m m m m m m m m m m m rn m m m m m m m m m m m m m m m m •-I �-1 r4 r4 a-1 N r1 rl c1 '}i ri .-I ri N rl e4 N rl ri N .y rl r4 e -I r4 N rl ri ri N �r+l > > > > > > > > V V M M N N N N in O O O O O O O O C?O O O O O O O O O O O v N N O M 1p Ol N Vl OJ ri V h O M Z t0 N tft W ri Z Z Z Z Z Z Z Z Z ci c -I .1 rl N N N e-1 ri ci .-I ry N N M M tD Cl N 111 W N V I� O M l0 Ol —WHP —IAP —OAP ---WHT Injection Rate Summary 600 0 500 I 400 `o 0 S 300 v 0 200 U N - 100 0 m N v 0 ti ®-DGI MGI —PWI SWI —BLPD • K,ff'a I tv I Z Regg, James B (DOA) ,J From: NSK Prod Engr Specialist <n1139@conocophillips.com> e6,11`I)� Sent: Tuesday, January 19, 2016 10:40 AM To: Regg, James B (DOA); Brooks, Phoebe L (DOA) Cc: NSK Fieldwide Operations Supt Subject: Completed Deficiency Reports: 1E-02, 03, 12, & 14 Attachments: 1E-02 AOGCC Deficiency Rpt Complete 01-16.pdf; 1E-03 AOGCC Deficiency Rpt Complete 01-16.pdf; 1E-12 AOGCC Deficiency Rpt Complete 01-16.pdf; 1E-14 AOGCC Deficiency Rpt Complete 01-16.pdf Mr. Regg, Attached are the completed AOGCC Deficiency reports, with documentation, for KRU wells 1E-02,03, 12, & 14. Bob Christensen/ Darrell Humphrey NSK Production Engineering Specialist scAMEQ p i ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7535 Kuparuk Pager: 659.7000;#924 CPAI Internal Mail: NSK-69 This email may contain confidential information. If you receive this e-mail in error, please notify the sender and delete this email immediately. • • • i State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: KRU 1E-12 - Date: 1/1,1/20-1-e- 6��1 I ,fB PTD: 1820600 - Operator: Conoco Phillips Alaska Inc. Type Inspection: SVS Operator Rep: Bob Christensen Inspector: Guy Cook 1 —-Positions--NSK-Production"hngineenng specialist....-- - .__._ -----__ Op.Phone: 907-6594535 Correct by(date): 1/18/2016 Op.Email: n1139fc conocophillips.com Follow Up Required: No Detailed Description of Deficiencies Date Corrected 1E-12 has a lock down screw gland nut leak. Torque should be checked and the void should be pressure tested to confirm integrity. Z e 7 //q) ,i / ► Operator Rep i/i10 J‘ I Signatures x j I � c �/ _ AOGCC Inspector ; *After signing,a copy of tins form is to be left with the operator. I Follow-up Instructions l Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the "Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. j If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must requested and accompanied by justification(Attention:Inspection Supervisor). Failure to provide the required documentation of corrective actions constitutes a violation of 20 AAC 25.300 and is subject i 3 to enforcement action under 20 AAC 25.535 l Revised 3/9/2015 • • ConocoPhillips AOGCC EXCEPTION REPORT Alaska Location: 1 E-12 - Date: 1/9/2016 AOGCC Inspector: Guy Cook AOGCC EXCEPTIONS NOTED: 1E-12: Lacckdown screws leaking Action Taken to Correct Problem: 1E-12: Gland nuts torqued and cleaned. PO test done to verify no leaking. ' Date: 1/14/16 Initials: BAR Date: Initials: Date: Initials: Date: Initials: Date: Initials: Date: Initials: Return completed form to Prod.Engr.Specialist: n 1139{c?conocophillips.com Distribution: CPF DSLT CPF OPS Supv Prod. Engr. Specialist C.C. CPF1&2 Ops Supt CPF3 Ops&DOT Pipelines Supt NSK Fieldwide Operations Supt • . zoic, State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: KRU 1E-12 Date: 1/y1-/2171-6 'Hit" 37 PTD: 1820600 Operator: Conoco Phillips Alaska Inc. Type Inspection: SVS Operator Rep: Bob Christensen Inspector: Guy Cook Position: NSK Production Engineering Specialist Op. Phone: 907-659-7535 Correct by(date): 1/18/2016 Op. Email: n1139aconocophillips.com Follow Up Required: No Detailed Description of Deficiencies Date Corrected 1E-12 has a lock down screw gland nut leak. Torque should be checked and the void should be pressure tested to confirm integrity. Z-4 'V' Signatures: (1 Operator Rep yp/l eP AOGCC Inspector *After signing,a copy of tis form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the "Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must requested and accompanied by justification(Attention:Inspection Supervisor). Failure to provide the required documentation of corrective actions constitutes a violation of 20 AAC 25.300 and is subject to enforcement action under 20 AAC 25.535 Revised 3/9/2015 Ima.c ect Well History File Cover 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. / ~;~ _~- ¢ (~ _~ Well History File Identifier Organizing RESCAN [] Color items: [] Grayscale items: Poor Quality Originals: [] Other: NOTES: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds [] Other BY: BEVERLY ROBIN VINCENT~ MARIA WINDY Project Proofing OBINVINCENT SHERYL MARIA WINDY BY: Scanning Preparation ~- x 30 = ~ ~ OBIN VINCENT SHERYL MARIA WINDY -I- BY: Production Scanning Stage '1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNINe PREPARATION: /~ YES BY: BEVERLY(~VINCENT SHERYL MARIA WINDY DATE: NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES , NO ReScanned (individaal page [.~pecial atte~fl~] ~ca~ming c~mple~ed) RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is~ General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. February 8, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 iNED MAR 9 5 2011 RE: Gas Lift Survey: 1E -12 Run Date: 2/6/2011 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 1E-12 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 20736 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 03.S--?- rafael.barreto @halliburton. com R.Fte—'3A /ED Date: 'l Signed: • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED FFA ~ d ~nm t. operations Pertormed: Abandon "" Repair well ~"" Plug Pbrforations ~' Stimulate ""° Other Alter Casing ~'° Pull Tubing ~ Pbrforate New Fbol Waiver Time 6~ti011B• . Change Approved Program "°' Operat. Shutdow n Fr'rforate Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory ~ 182-060 3. Address: Stratigraphic "" Service .API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20736-00 7. Prop~#v Designation: 8. Well Name and Nu` er: ADL 25651 1 E-12 . Field/Pool(s): Kuparuk River Field /Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 7512 feet Plugs (measured) None true vertical 6575 feet Junk (measured) None Effective Depth measured 7427' feet Packer (measured) 6779, 7137 true vertical 6504' feet (true verucal) 5970, 6264 Casing Length Size MD ND Burst Collapse CONDUCTOR 80 16 80 80' SURFACE 2470 10.75 2501 2500 SCAB LINER 6734 5.5 6765 5957' PRODUCTION 7478 7 7510 6573' Perforation depth: Measured depth: 7200'-7209', 7222'-7245', 7253'-7259' True Vertical Depth: 6316'-6323', 6334'-6353', 6360'-6365' '' ~ ~~~~ ~~~ ~ ~- ~ (~ Tubing (size, grade, MD, and ND) 3.5, L-80, 7157 MD, 6280 TVD Packers & SSSV (type, MD, and TVD) NIPPLE - 3 1/2 X 2.875" CAMCO "DS" NIPPLE @ 482 MD and 482 TVD PACKER -BAKER FHL RETRIEVABLE PACKER 4762-7" 26# @ 6779 MD and 5970 TVD PACKER -BAKER F-1 PACKER @ 7137 MD and 6264 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 7150'-7259' Treatment descriptions including volumes used and final pressure: See attachment 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 55 1215 366 -- 254 Subsequent to operation shut-in 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory "" Development ~ Service .Well Status after work: Oil j/, Gas `` WDSPL ~" Daily Report of Well Operations XXX GSTOR ~ WAG GASINJ WINJ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or Nia, if C. o. Exempt: 310-005 Contact Jill Long ~ 263-4093 Printed Name Jill Lon Title Wel-s Engineer ~ Signature /'`~ Phone: 263-4093 Date L~ ' ~ ,/ ` Form 10-404 R`~vised 7/2009 ~p~s FEQ ~ ~ ~'~ ~~M~ ~ ~-J~1,~Submit Original Only ei <~ ~k • 1 E-12 Well Events Summary • DATE SUMMARY 1/21/10 MEASURED BHP @ 7225' RKB(2456 psi). GRADIENT @ 7104' RKB(2414 psi). JOB COMPLETE. 1/22/10 PRE CTD, T-POT (PASSED ), T-PPPOT (PASSED ), IC-POT (PASSED ), IC-PPPOT PASSED ), LOWER IC-POT (PASSED ), LOWER IC-PPPOT (PASSED ). 1/23/10 DRIFTED TBG WITH 11' X 2.64" DMY GUN & TAG FILL @ 7271' SLM. SET CAT STANDING VLV @ 7155' RKB. TESTED CAT TO 2000#. **PASS**. PULLED GLV'S @ 2490' & 3817' RKB's. REPLACED WITH DMY VLV's. PULLED ORIFICE VLV @ 5087' RKB. CIRC OUT TBG & IA WITH 160 BBLS DIESEL. FP FLOWLINE WITH 50 BBLS 60/40. CALLED VLV CREW TO SERVICE TREE VLV'S. IN PROGRESS. ~ Q~~ 1/24/10 SET DMY VLV w/ INT LATCH @ 5088' RKB. MITIA TO 2500#. ***PASS'`**. PULLED CAT ~{tN STANDING VLV @ 7155' RKB. READY FOR E-LINE. ~ ~,..¢ 1/26/10 PERFORATED TUBING AT INTERVAL 7147.0' TO 7149.0' WITH 2-FT GUN, LOADED 6- CQ, SPF, 60-DEG PHASED, HMX BH CHARGES. 1/27/10 MII 1275" D NIPPLE (~ 7155' RKB TO 2.80", IN PROGRESS. 1/28/10 LOAD WELL WITH HOT SEAWATER AND ESTABISHED A BASE INJECTION RATE OF 380 PSI @ .25 BPM LAY IN 25 BBLS 17 PPG CEMENT PERFORM HESITATION SQZ IN 500 PSI INCREMENTS TO 2000 PSI. FINAL SQZ PRESSURE OF 1720 PSI (1340 PSI OVER BASE INJECTION PRESSURE) CLEAN OUT EXTRA CEMENT & LEAVE TOP @ 7150' RKB. FREEZE PROTECT WELL W/ DIESEL TO 2500' CTMD. 2/6/10 GAUGED TBG TO 2.795" TO 7147' SLM. IN PROGRESS. 2/7/10 TESTED CMT PLUG TO 2000 PSI, GOOD. GAUGED TBG TO CMU @ 6926' RKB, 6938' SLM. TAGGED CEMENT @ 7149' SLM, EST. 7137' RKB. BAILED ~ GAL OF CEMENT OFF HARD PLUG @ 7149' SLM, EST. 7137' RKB. COMPLETE. 2/9/10 PRE-CTD MITOA- PASSED; PT& DD MV- PASSED; PT& DD SV- PASSED; ~- w n WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. _ „ ,.. ,,, _~,, _„ ,.,_, ., _,_ _ . _,.... _January 28, 2010 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 .~ ~- = U RE: Perforating Record: 1E-12 Run Date: 1/26/2010 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 1E-12 Digital Data in LAS format, Digital Log Image file 1 CD Rom SO-029-20736-00 ~ -~a- -~ ~ o ~ a~ ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURh1ING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-327 Fax: 907-273-353 rafael.barreto@halliburton:com Date: ~~ ~~ ' ~I Signed: ~ ' • • SEAN PARNELL, GOVERNOR Lu/[1•a7~ OIL A1~TD rir~ 333 W. 7th AVENUE, SUITE 100 CO~SERQAiiO1s CO~II-7SIO1~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ms. Jill Long Production Engineer ConocoPhillips Alaska Inc. r b P.O. Box 100360 ~ ~~`'~~ ~~~ ~~ ~ ~ ~ ~ i ~' n ~ ~j Anchorage, Alaska 99510 ~~~~ Re: Kuparuk River Field, Kuparuk Oil Pool, 1 E-12 Sundry Number: 310-005 Dear Ms. Long: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Daniel T. Seamount, Jr. Chair DATED this day of January, 2010 Encl. 0 'p STATE OF ALASKA '~'S~ ~~ ` ALAS~ILAND GAS CONSERVATION COMMISS• `,~ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 }.~'~ Y ~i { `i ~' ' ~ Sit.'`;? 1. Type of Request: Abandon ~"` Suspend Operational shutdow n Perforate ~' Re-enter Su8lper~ed l ~'""" After casing ]`"` Repair w ell J•`' Plug Perforations Stimulate ~"`' Other Specify: Change approved program ~ FUII Tubing ~"` Perforate New Pool ("" Time Extension ~"" 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory 182-060 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchors e, Alaska 99510 50-029-20736-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No ~ 1E-12 ' 9. Property Designation: 10. Field/Pool(s): ADL 25651 Kuparuk River Field / Kuparuk Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ff): Effective Depth ND (ft): Plugs (measured): Junk (measured): 7512 6575 7427' 6504' Casing Length Size MD ND Burst Collapse CONDUCTOR g0' 16 80' 80' SURFACE 2470 10.75 2501' 2500' SCAB LINER 6734 5.5" 6765' 5957' PRODUCTION 7478 7 7510' 6573' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7200'-7209', 7222'-7245', 7253'-7259' 6316'-6323', 6334'-6353', 6360'-6365' 3.5 L-80 7157' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ftJ NIPPLE - 3 1/2 X 2.875" CAMCO "DS" NIPPLE MD= 482 ND= 482 PACKER -BAKER FHL RETRIEVABLE PAC KER 4762-7" 26# MD= 6779 ND= 5970 PACKER -BAKER F-1 PACKER MD= 7137 ND= 6264 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ~ Exploratory ~ Development ~' Service "' 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: Februa 1, 2010 Oil ~ ~ WDSPL ~ Plugged ~ • G 16. Verbal Approval: Date: WINJ as GINJ , WAG ~" Abandoned Commission Representative: GSTOR SPLUG j 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Long @ 263-4093 Printed Name JIII Lonp Title: Wells Engineer Signature ~ Phone: 263-4093 Date V Commission Use Onl Sundry N ber: ~~l Conditions of approval: Notify Commission so that a representative may witness j Plug Integrity ~'° BOP Test ~c/ Mechanical Integrity Test "` Location Clearance '`" ~' 3500 ~s~ Oth $d~' s¢- er: ~I' Z.~QO ~o SL ^ l t h. w....~.L ~*--s..~ ~ ~+. ) Subsequent Form Required: ~ /.~ w 11~L~ APPROVED BY ~ / V Approved by: COMMISSIONER THE COMMISSION / Date: (~ ucc ''AAUu ii q /'/y~o ~.~. Y ~ R I G I~ A L ~- . ~~Wh~l 1.0~4t7~F;+e~~ 7/ Submit in Duplicate _> ~~~o ,~ /./~•fCil • • KRU 1 E-12: A-Sand Abandonment Summary of Operations Well History: Well 1E-12 is an A-sand producing, straddle completion well equipped with 3-1/2" tubing (from surface to 7157' MD and a 7" production liner (from surface to 7510' MD). The well was a single completion, A-only producer from 1982-1988. In 1988 the C sand was perforated and the well became and A/C comingled producer. By mid-1997 the WC had increased to 97% (due to the C sand) and so the C sand was cement isolated and the A sand re-perfed. A workover was performed in 2007 to mechanically isolate the C sand via a straddle packer completion after the C-sand cement squeeze was suspected to have failed. Thus, the upper completion consists of a straddle packer completion with five gas lift mandrels, a 2.75" D nipple in the tubing tail, and a 2.875" DS nipple at 482'. Due to a casing leak, there is a 5" scab liner from the surface to the upper packer. Prior to the arrival of the CTD rig, the existing A-sand perforations in the 1E-12 completion will be plugged and abandoned with cement. The two casing exits on this well will be via whipstocks set in a 2.80" cement pilot hole. A Sundry application is attached for the cement work to be completed pre-rig. Oaerational Outline Pre-Rig Work Remaining 1. Tag fill and obtain a SBHP survey 2. Shoot holes in tubing tail to put cement across the tail 3. Mitl out the 2.75" D-nipple at 7155' MD to 2.80" with alert-hand motor 4. Load Tubing 8~ IA w/diesel. Install gas lift valves. Perform MIT-IA. 5. Lay in cement plug from tag depth to the tubing tail. 6. Tag top of cement and then mill cement out of the tubing down to the tubing tail. 7. Prepare wellsite for rig arrival. n ~ Q Rig Work l° ,~~~~ 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU BOPE and test. 2. Mill cement pilot hole. Set bottom whipstock at 7226' MD. Mill 2.74" window at 7226'. 3. 1 E-12 L1 Lateral a. Drill a 2.70" x 3" bi-center lateral to the northwest at a TD of 9150' MD b. Run the 1375' of 2~/" slotted liner from TD to 7775' MD. An aluminum liner top billet will be placed at 7775' MD. 4. 1E-12 L1-01 Lateral a. Kick off of the open-hole aluminum billet at 7775' MD b. Drill a 2.70" x 3" bi-center lateral to the northwest at a TD of 8850' MD c. Run the 1625' of 2'/" slotted liner from TD to 7225' MD. A shorty deployment sleeve will be placed at the top of the liner. 5. Window Milling a. Set the second whipstock at 7200' MD b. Mill 2.74" window off this whipstock 6. 1 E-12 L2 Lateral a. Drill 2.70" x 3" bi-center lateral to the southeast at a TD of 9450' MD b. Run the 1350' of 2~/" slotted liner from TD to 8100'. An aluminum liner top billet will be placed at 8100'. 7. 1 E-12 L2-01 Lateral a. Kick off of the aluminum billet at 8100' MD. b. Drill 2.70" x 3" bi-center lateral to the southeast at a TD of 9225' MD c. Run the 2075' of 23/" slotted liner from TD to just intside the tubing tail (7150' MD). A shorty deployment sleeve will be placed at the top of the liner. $. Freeze protect. ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Obtain SBHP 2. Flowback to tanks for well cleanup 3. Begin production 1 /15/2010 ConacoPhi#lips 't ., ,nu, +Yk_. _We11C fig 1E,-52,,118/ ,_ _ Schemefi~,, Ac HANGER, 28- ... colvDUCroR.__ _ 32-80 NIPPLE, 462 ---- - GAS LIFT, 2,490 SURFACE,- 31-2.501 GAS LIFT,_ __-.. -.. 3,81] GAS LIFT, _ 5,068 GAS LIFT, _ 6,115 GAS LIFT, 6,642 SEAL, SCAR LINER, _ 32-s,]ss -- PBR,6.765- -- PACKER, 6.]79 - SLEEVE. 6,926 BLAST RING. 6,939 APERF.- , 7,010-7,090 Cement, 7,010 PACKER. ],137- - ---- saE, 7,1ao -- NIPPLE. 7,155 --- WLEG, ].156 - - -- RPERF, 7,200-].206 1--~ IPERF, - ],200-7,209 RPERF, ],225-],2351 IPERF,- 7,253-],259 r PRODUCTION, _ 32-7.510 \ TD, 7.512 KUP • 1 E-12 T_ bute W ll Att Max Angle & MD TD n ,_ e Nellbore APUUWI s Field Name __ Well Status htcl (`) ' MD (ftKB) _ Act Btm (ftKB) 500292073600 'IKUPARUK RIVER UNIT ( PROD 46.27 4,500.00 1,512.0 ^ ment SSSV: NIPPLE H2S (ppm) Date 15 ~ 9/26/2004 ipnnotation End Date Last WO: ~ 10!14/2007 iKB-Grd (ft) ~ 40.71 ,Rig Release Dat 6/13/1982 Annotation (Depth (ftKB) ~Entl Date Annotation Last MOd ... /End Date Last Tag: SLM 7,295.0 1 V2 A2009 Rev Reason: lAG ( Imosbor 1128/200 Casing String s C sing De ption String 0... Str g ID ... Top (ftKB) Set D pth (f Set D pth (ND) Sfr g W[...'Strmg Stn ng Top Thrd CONDUCTOR 16 15082 320 800 80.0 6500 H40 PE Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (NDI .-- String Wt... String ... String Top Thrd SURFACE 10 3/4 9.765 31.2 2,501.4 2,500.1 45.50 K-55 _ BTC --__ Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (NDI ... ( String WI... String ... String Top Thrd PRODUCTION 7 6.151 31.7 7,510.2 / 6,573.7 1 26.00 K-55 BTC Casin Descri fion ^,.. 9....~.P Strin 0.,. r9,~ Strin ID ... .9cn To ftKB p'°-°) Set De th f... a~acZ Set De th ND So5o1 ) ~ I 1SSn '.String... Strin ~- I _Rn Sfing Top Thrd 511 Hudril (Liner Details Top Depth ~ Top (ftKB) ND) (ftKB) ToP Inc! (°) ItemD iption Comment N mi... ID (in) 6,712.71 5,916.5 36.161X0 (Casing to tubing cross over 3 OOO b,/b3.J 7y5 /./ 35 /4LVl-HIVn. IN a uuetui p c.c uu~ ~~• Tubing Strings - ~ - --- Tubing De iption . _ Str ng O._ Str g ID ... Top (ftKB) Set D pth (f_. Set Depth (NDI .. String W1... Str g ... Str g T p Thrd TUBING 3 1/2 992 28 0 6 713 O 5 916 7 9.30 L 80 IBTM Coin Ie tion De tails _ TOp Depth - (ND) i Top Inc! N mi... Top (ftKB) (ftKB) (% ItemD ilption Comment _ _ ID Ian) 28.0 28.0 -0.34 HANGER 3 1/2 x 11"tbg hanger 3 500 482.2 4822 0.08 NIPPLE 3 112 x 2.875" Camco "DS" Nipple 2.875 - 6,692.7 1 5,900 4' 36.33 LOCH T OR 4.5" OD Locator w/ 2.5' of space out _-_ __ 3.000 -__ -_. 6,696.0 5,903.1 36.30 SEAL 3.99" OD 80-40 Bontled Seal Assembly 3.000 Tubing Descri ption 'String O... !Strinq lD ... T op (HKB) Set Depth (f... Set Depth(NDI ... String Wt.. . String... String Top Thrd STRADDL E 3112 2.990 6,713.3 7,157.0 6.280.4 9.30 L-80 IBT PACKER `Comple tion De tails Top Depth es __ -~.. (ND) Top Nomi... 6,765-3 5,959.1 35.72 PBR PBR 8040 Baker 3.913 6,779.0 5,970 2 35.61 .. -_ __ PACKER Baker FHL retrievable packer 4782-7" 26# 2.9 6,925.6 6,089.91 1 34.91 SLEEVE -_. _.._ __ Baker Sliding Sleeve CMU , 2.812 6 939 2 6,101.1 34.86 BLAS I PING 3.5" 9 3# L-80 SC IBT W/Blast Rings from 7,005-7,095' ~ ~ 2 990 7,136.8 G,263.8 3449 PACKER Baker F-1 Packer 4.000 7,140.1 6,266.51 3449i SBE __ Seal Bore Extension 4.000!1 7,155.1 6,278.9' 34 491 NIPPLE ___ __. Camco D Profile Nipple 275" 2.750 7,156.3 6,279.81 34.49 WLEG _ Baker Wireline Entry Guide 3.000 op (ftKB) Btm (ftKB) (ftKB) /ftKB) .Zone Date lsh-~ Type ~ Comment 7,010 7,090 6,159.2 6,27.5.2 C-2, C-3, UNIT 8/1 41 7 9 8 8 I 8.0 RPERF Squeezedoff 3/17/97 7,200 7,209 6,315.9 6,323n A-5, 1E-12 ' 6113/1982 4.0 IPERF __ 7,200 7 2081 6,315.9 1=,3221 A-5, tE-12 5/2411997 4.0 RPERF 180 deg. Ph; 2 1/8" EJ BH 7,222 7,241 6,333.8 c."t49 fi A-0, 1E-12 5/24/1997 I 4.0 RPERF 1 180 deg. Ph; 21/8" EJ BH 7,225 7,235 6,336.3 6,:144.6 A-0, 1E-12 10/4!2008 6.0 RPERF 25" HYPERJET, 60 deg phase - 7,225 7245 6,336.3 5.352.9 A4, 1E-12 6/13/1982 4.0 IPERF 7,253 7,259 6,359.6 1`.364.6A-0, 1E-12 6!13/1982 4.0 IPERF stimula tions $ Treatme nts Min Top Max Btm Top Depth Bottom Depth Depth Depth (NDI !TVD) ( ( I (ftKB) /ftKB) Type Date Comment 7,225.0 , 7 235.0 ~~, 6,336.3 6 344.6 FRAC 10/7/2008 A-SAND FRAC -PLACED 146 347# 16/20 CARBOLITE BEHIND PIPE SCREENED OUT w/3,391# OF 9 ppa IN PERFS cement Squeez es ,. t ' Top Depth Bbn Depth _.._ __._ 18/2008 (NOTE: VIEW SCIiEMATIC w/9.0 __ . _.. landrel Details - _ __ Top Depth Top P H (TVD) Inc! OD V l e Lath Srze TRO R n n Top /ftKB) (ftKB) (°) I1 Make Model lint Serv TYpe TYPe (nl (Ps) Run Date ~Com... 1 2490.0 2,488.7 3.19 Camco KBG-2-9 1 Gas Lift GLV INT 0.125 1,301.0 10170/2005 I 21 3,8174, 3,752.3 31.25 Camco KBG-2-9 1 Gas Llft ~GLV INT 0.156 1,3140 10/11/2008 3 5 087.9 4,690.2 44.32 Camco li KBG-2-9 1 Gas Lift OV INT 0.250 0 0 10110/2008 4 6,114.9 5,444.8 38.70.Camco 1KBG-2-9 11Gas Lift DMY INT 0-000 0.01013/2008 5 6641.9 5,859.736JSIICamcD KBG-2-9 1~IGas Lift ~DMY INT 0.000 0.01013/2008 ConocoPhilli s p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 15, 2010 Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: • ConocoPhillips Alaska, Inc. hereby submits a sundry to abandon the A sand perforations of Kuparuk Well 1 E-12 (PTD# 182-060) utilizing cement. The abandonment is being done as part of the pre-rig preparation for upcoming coiled tubing drilling (CTD) operations. The abandonment work is scheduled to begin in late January 2010. The CTD objective will be to drill four A- sand lateral sidetracks. Permit to Drill applications for those laterals have been submitted separately. Attached to this Sundry application is an outline of job operations (including those of the CTD project). If you have any questions or require additional information please contact me at my office 907-263-4093. Sincerely, Jill Long Coiled Tubing Drilling Engineer Page 1 of 1 Schwartz, Guy L (DOA) From: Long, Jill W [JiII.W.Long@conocophillips.com] Sent: Friday, January 15, 2010 11:26 AM To: Schwartz, Guy L (DOA) Cc: Allsup-Drake, Sharon K Subject: 1 E-12 Sundry and Lateral Names Attachments: 1 E-12 CTD Sundry Summary_011510.doc Guy- In response to our phone conversation earlier, I have looked into the status of the C-sand perforations in 1 E-12. The C-sands were cement isolated in 1997 and a straddle packer completion installed in the 2007 RWO. However, the tubing interval between the 2 packers isolating the C sand included a sliding sleeve and blast rings to allow for future stimulation/production if desired. Although there is no plan to produce from the C sand at this time, I believe you are correct in that the 1E-12 laterals should be named 1E-12L1, 1E-12L1-01, 1E-12L2, and 1 E-12L2-01. The name changes are reflected in the attached Sundry letter and will be made in our system. Please let me know if you have questions. Thanks, Jill Long ConocoPhillips Alaska Drilling and Wells Office: 907-263-4093 Cell: 907-230-7550 Fax: 918-662-6330 1/15/2010 Review of Sundry Application 310-005 ConocoPhillips Alaska, Inc. We111E-12 AOGCC Permit 182-060 Requested Action: ConocoPhillips Alaska, Inc. (CPAI) proposes to plug the perforations on this oil producer to prepare it for amulti-lateral coiled tubing drilling sidetrack. Recommendation: I recommend approval of Sundry Application 310-005 to allow CPAI to perform this operation. Discussion: CPAI proposes to plug the perforations in the subject well to prepare it for aquad-lateral redrill. The well began production in February 1982 and produced more or less continuously until June 1996 at which time production attempts became sporadic. When regular production ceased the well was producing less than 300 bopd, with a water cut over 92%, and had cumulative production of over 2.3 million barrels of oil. CPAI has made a couple of attempts, including a cement squeeze in 1997 and mechanical isolation in 2007, to reduce the water production, which they indicate was coming mainly from the Kuparuk C sand, but these attempts provided no improvement in oil production or decrease in water cut. The last period of attempted sustained production was October 2008 through Apri12009, during which time production averaged less than 100 bopd with water cut ranging from 85% to over 95%. Conclusion: The KRU 1 E-12 well appears to have reached the end of its useful life and plugging the existing perforations to prepare the well for amulti-lateral side track represents a prudent course of action. Therefore, I~irecommend approval of the operator's request David S. Roby ~2%y!~ ~~'~~ Sr. Reservoir Engineer January 14, 2010 ~~: PeoAcrive DiAgNOS'<ic SErtvicES, INC. IrV-~~~ L~ia ~/'if-~/ V~IVf~~/~#L To: ao~cc Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 j Caliper Report 27-Nov-09 1_E-12 1 Report / EDE 2) 50-029-20736-00 f~~-~~ U f9d~d Signed : Date Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : - _, _ .,. ~ _ .^ -. _ - ;", _, WEBSITE :? ° ,, _ ~.'.Decumencs and SettingsDiane W'illiams~.Desktep'Transmi[_Cenocc.docx • • Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1E-12 Log Date: November 27, 2009 Field: Prudhoe Bay Log No.: 10606 State: Alaska Run No.: 1 API No.: 50-029-20736-00 Pipet Desc.: 7" 26 Ib. K-55 BTC Top Log Intvl.: 7,156 Ft. (MD) Pipet Use: Production Casing Bot. Log Intvl.: 7,264 Ft. (MD) Inspection Type : Corrosive & Mechanics! Damage Inspection COMMENTS This caliper data is tied into the WLEG @ 7,156'. (Driller's Depth) This log was run to assess the condition of the 7" production casing logged with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 7" production casing logged is in poor condition with respect to corrosive damage. Cross-sectional wall loss from 24% to 55% is recorded throughout the logged interval. Multiple holes are recorded between the 3.5" WLEG and the perforation interval that begins at 7,200'. The caliper recordings indicate a bend at 7,232'. A 3-D log plot of the caliper recordings across the 7" production casing logged is included in this report. Field Engineer: G. Etherton Analyst: M. Lawrence Witness: C. Kennedy ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281} 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Fieid Office Phone: (907} 659-2307 Fax: (907} 659-2314 r ~2 --p~o~ 1~0~6 • • PDS Multifinger Caliper 3D Log Plot ~,~. Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1 E-12 Date : November 27, 2009 Description : Detail of Caliper Recordings Across Proposed Sidetrack Location Comments Depth Max. Pen. (°~) Max. I.D. (ins.) 3-D LOG Image Map 1ft:120ft~0 100 6 7 53° 0° 90° 180° 270° 0° Min. I.D. (ins.) 6 7 Avg. I.D. (ins.) 6 7 Nominal I.D. 6 7 I I ', I 3.5" Tubing 7150 7160 Joint 1 7170 7180 ~, i i 7190 Joint 2 ~~ • ~_, °-~ a -m.. 6 l }:. j • • 7220 7230 Joint 3 Bend (7,232') 7240 7260 = ~I `..mac..-. ~.:~ .rs Perforations Nominal I.D. i ............................................... 6 7, Avg. I.D. (ins.) 6 7 Min. I.D. (ins.) 6 7 Comments Depth Max. Pen. (%) Max. I.D. (ins.) 3-D LOG Image Map 1 ft:120ft ~ _...__.~.,.., . .. 0 100 6 7 53° 0° 90° 180° 270° 0° PDS REPORT JOINT TABI.. Pipe: 7. in 26.0 ppf K-55 BTC Well: Body Wall: 0.425 in Field: Upset Wall: 0.425 in Company: Nominal I.D.: 6.151 in Country: Survey Date: ELATION SHEET 1 E-12 Kuparuk ConocoPhillips Alaska, Inc USA November 27, 2009 Joint No. Jt. Depth (Ft) I'r~n. Upset (lns.) Pen. Body (Ins.) Peen. % :Uc~t,~l loss `;4, Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 1 7156 l?. 32 0.61 100 ~S 6.26 Multi le holes! Erosion. 2 7168 l1._t5 0.93 l0U 5> 6.26 Perforations. Erosion. 3 7215 U. ~ ~ 0.60 1 tiO 54 6.22 Perforations. Erosion. Bend. 4 7263 i r_ 15 0.16 .9 _'~> 6.34 Corrosion. Erosion. - i i ~ _ Penetration Body Metal Loss Body Page 1 _.. I /~~~ KUP ,~ 1 E-12 ConoeOPhillips 1 ell Attributes x An le & MD TD .t l,i,_,_, i„ 1 Wellbore APWWI 500292073600 F1Hd Name KUPARUK RIVER UNIT WNI Status InU (°) ND (M(B) PROD 4627 4.500.00 Ad Bfm ) 7.512.0 Commert H2S Ippm) Date SSSW NIPPLE 15 9/26/2004 Arnotadon Fnd Date KB-Crd IBI Last WO: 10/14/2007 40 71 Rlg Release e 6!13/1982 wee coon -tE-t2 torzarzoo 2o] o]PM . Schematic-AIXU I Amotatlon DepDi (BIB) End Date Amotadan last Motl ... End Date Last Tag: SLM 7,302.0 4/6/2009 Rev Reason: Show Straddle Packer Assy. TAG Imosbor 10!28/2009 Casio Strin s fr w Casing Descriptlon CONDUCTOR Sung 0... 16 Sdng ID ... 15.082 Top (BKB) S 0.0 et DepN (L.. 80.0 Se[ Depth (ND) ... 80.0 Strng Ntt... 65.00 4dng ... H130 S[rirg lop Thrtl PE NANOER, s ', -, Casing Descriptlon SURFACE Sung 0... 103/4 SIrhNJ B) ... 9.765 lop ryB(e) S 0.0 et Depth p... 2,501.0 Set Depth (7VD) ... 2,499.7 Sung Wt... 45.50 Sung _. K-55 Slrtrg Top Thrtl BTC ~ Casing DesMpdon PRODUCTION Strng 0... 7 String ID ... 6.151 Top (IIYCB) S 0.0 et Depth (L.. 7.510.0 Set Depth IND) ... 6.573.5 Stang YYt... 26.00 Stdng ... K-55 Stdrg Top Thtd BTC coNDUCroR o I _°• ~° Casin9 Desaipdon SCAB LINER Stdng 0... 51/2 S[rtng ID ... 4.950 Top pD(B) S 31.7 et Depth (/... 6,765.3 SH Depth IND) ... 5,959.1 Slrhg VA... 15.50 Sldng ... L-80 Sldrtg Top Thrd 511 Hydril o-e - Liner Details NIPPLE. 682 Tap gdce) Top Depth IND) T I~BI op ind (°) tt em Descdptian Commert WIm) 6.712.7 5,916.5 36.16 X O Casing to tubing cross over 3.000 6,763.5 5,957.7 35.74 L OCATOR No Go locator W/space out 2.970 a~a Tubin Strin s cos uFr. Ci z~4s Tubing Description S[rtng 0... 5[rtrg ID ... Top pnce) Set Depth (/... Set Depm (ND) ... strtlg VA... Sung --. 5[nng Top Thrtl TUBING 31/2 2.992 -3.0 6.713.0 5,916.7 9.30 L-80 IBTM suRFACE. :~ Com letion Details o-2 sot Top Im(B) iop Depgi INDI T I~BI ap ind (°) ttem Descriptlan Comment ID (in) 4.8 4.8 -0.50 HANGER 3 1/2 x 11" ibg hanger 2.992 eAS LIFT. 387] 4822 482.2 0.08 NIPPLE 3 1/2 x 2.875" Cameo "DS" Nipple 2.875 6.692.7 5.900.4 36.33 LOCATOR 4.5" OD Locator w/ 2.5' of space out 3.000 6,696.0 5,903.1 36.30 SEAL 3.99" OD 80-40 Bonded Seal Assembly 3.000 Tubirg Descr(ption STRADDLE Strtry 31/2 ... String ID ... 2 990 Top B) S 6 713 3 et De g... 7 157 0 Set Depth (7VD) ... 6 280 4 S[rtrg W[... 9 30 Slrtrtg ... L-80 Sldng Top Thrd IBT cas IJF*, s oss PACKER . . . . . , . . Com le tion Details Top Depth (NDI T op Ind Top (111(6) pB(B) (°) tt em Descdptlon Commert ID Iln) SAS uFT. sits 6,765.3 5,959.1 35.72 P BR PBR 80-00 Baker 3.913 6,779.0 5,970.2 35.61 P ACKER Baker FHL retrievable packer 4762-7"26# 2.930 6,925.6 6,089.9 34.91 S LEEVE Baker Sliding Sleeve CMU 2.812 6,939.2 6,101.1 34.86 B LAST RING 3.5" 9.377 L-80 SC IBT W/Blast Rings from 7,005-7,095' 2.990 GAS UrT 7,136.8 6,263.8 34.49 P ACKER Baker F-1 Packer 4.000 r^`'n'' 7,140.1 6,266.5 34.49 S BE Seal Bore Extension 4.000 7,155.1 6.278.9 34.49 N IPPLE Cameo D Prorile N"ryple 2.75" 2 750 7,156.3 6,279.8 34 49 W LEG Baker Wireline Eniry Guide 3.000 Pertorations & Slots Top ptlCB) Btm IIBCB) Tap ITVD) RIK6) B[m I7VD) I~BI Zone Date sod Dann (sh._ Type Comment LOCATOR, 6.693 7.010 7.090 6,1592 6,2252 C-2, C-3, UNiT B. 1 E-12 8/14!1988 8.0 APERF Squeezed aff 3/17/97 SEAL, ssss 7,200 7,209 6,315.9 6.323.0 A-5, tE-12 6/13/1982 4.0 IPERF 7.200 7,208 6,315.9 6,322.1 A-5, tE-12 524/1997 4.0 RPERF 180 deg. Ph; 2 1/8" EJ BH 7.222 7,241 6,333.8 6,349.6 A-0; tE-12 5/24!1997 4.0 RPERF 180 deg. Ph; 21/8" EJ BH 7 225 7235 6,336.3 6.344.6 A-4.1E-12 10/4/2008 6.0 RPERF 2.5" HYPERJET. 60 deg phase 7,225 7,245 6,3363 6.3529 A-4, 1E-12 6/13/1982 4.0 IPERF 7,253 7,259 6.359.6 6.364.6 A-4, 1E-12 6/13/1982 4.0 IPERF s~aB LINER, 3z s 7 5 Stimulations & Treatments ~ , s PBR, 6,]65 Mn Top Max Btm T op Depth Bottom Depth PACKER, s,]]9 Depth IBKBI Oepih l~Bl (11/0) I~BI 1ND1 I~BI type Dale cammert sleeve.6s26 7,225.0 7,235.0 6.336.3 6,344.6 FRAC 10/7/2008 ASAND FRAC -PLACED 146,347H 1620 CARBOLITE BEHIND PIPE. SCREENED OUT w/3,391tt OF 9 ppa IN PERFS BLAST RING°, 6' 939 Cement uePSeS , 7.otc-7.oa-o Cament.7Ot0 Top (BKB) 7 Btm IBKB) o D (ND~ (BKB) film De (ND~ (M(B) Desalptlon Start Date Comment 7.010.0 7.090.0 6,159.2 6,225.2 Cement Squeeze 3/17/1997 Notes: General & Safe PACKER, ],t3] Entl Die Amata6an see, r.tau 9/18/2008 NOTE: VIEW SCHEMATIC w/9.0 NIPPLE 7.155 wLEe. ],,s6 Mandrel Details RPERF. T.200-7 20a IPERF, ht o B Top Dept (TVD) 1~B) h Top InG (°) ake odel OD Pn) erv Valve Type latdi Type Port Sze MI 7R0 Rio (psi) un Date om... 7.200-] 2os 1 2,490.0 2,488. 7 3.19 Camm KBG-2-9 1 Gas Lih GLV INT 0.125 1,301.0 10!102008 RPERF 2 3,817.4 3,752. 3 3125 Cameo KBG-2-9 1 Gas lift GLV INT 0.156 1,314.0 10/11/2008 , 7.zzs-7 z3s FRAC ] 225 3 5,087.9 4,690 2 44.32 Cameo KBG-2-9 1 Gas Lift OV INT 0.250 0.0 10/10/2008 , , RPERF. zzzz-] za t 4 6.114.9 5.444. 8 38.70 Camm KBG-2-9 1 Gas Lift DMY INT 0.000 0.0 10/3/2008 IPERF, zzzs-] zas 5 6,641.9 5,859. 7 36.75 Cameo KBG-2-9 1 Gas Lif[ DMV INT 0.000 0.0 10/3/2008 , IPERF, 7 253-] 259 PRODUCTION, 0.l 510 TD, 7 St2 ~. ortau F~xt,~da .. ~ ~.yti ..~ef% STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIO~~.S, ; 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate Q Other [] _, Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate Q Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhIIIIpS Alaska, InC. Development ^~ Exploratory ^ 182-060! ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20736-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 32' 1 E-12 ' 8. Property Designation: 10. Field/Pool(s): ADL 25651, ALK 469 Kuparuk River Field /Kuparuk Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 7512' feet true vertical 6575' feet Plugs (measured) Effective Depth measured 7114' feet Junk (measured) true vertical 6245' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SURFACE 2469' 10-3/4" 2501' 2500' PRODUCTION 7478' 7" 7510' 6573' SCAB LINER 5-1/2" 6763' 5957' Perforation depth: Measured depth: 7200'-7209', 7222'-7245' , 7253'-7259' true vertical depth: 6316'-6323', 6334'-6353', 6360'-6365' ~y c~ Tubing (size, grade, and measured depth) 3-1/2" , L-80, 5917' MD. Packers ~ SSSV (type & measured depth) Test pkr, Baker F-1 pkr @ 6745', 7137' Camco'DS' nipple @ 482' 12. Stimulation or cement squeeze summary: , Intervals treated (measured) 7225'-7235' 146347# of 16/20 carbolite behind pipe Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation 252 ~ 596 1520 -- 246 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ ~ Gas^ WAG^ GINJ^ WIND ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce @ 26 5-6471 Printed Name John PeirC@ _ /' Title Wells Engineer p ~~ '~~$ "O /,w, Signature Phone: 265-6471 Date ~ ~f~, Pre are b Shar n Allsu Drake 263-4612 f i Form 10-404 Revised 04/2006 ~ L ~~ ~ ,,;~1 i LOCt~ 11v~~ 7 /~ ~~ i3 ~ it Submit Ori~i ., Onl ~~~ ,, ~r~~``3/~ ` 1 E-12 Well Work Summary D94TE ~ SUMMARY 10/02/08 SET 2.75" CA-2 PLUG @ 71 KB.TESTED TBG GOOD. OPEN CMU ~26' RKB. MEASURE 30 MIN C SAND BHP @ 7000' RKB (3064 psi). CLOSED CMU VERIFIED WITH TBG TEST. PULLED STA 1 THROUGH 5. IN PROGRESS 10/03/08 SET 1" DV'S IN STA #1-4 DISPLACE TBG X IA WITH 165 BBL'S DIESEL. SET 1" DV IN STA #5 MITT 3500#, GOOD. MITIA TO 3500#, GOOD. DRIFT FOR TREE SAVER W/ BRUSH & 2.902" GAUGE RIND. PULLED 2.75" CA-2 PLUG FROM 7155' RKB. IN PROGRESS. 10/04/08 DRIFT W/ 11' X 2.55" OD SPENT GUN TO 7282' SLM. READY FOR E-LINE. 10/04/08 PERFORATED FROM 7225'-7235' WITH 10' 2.5" HYPERJET 6 SPF, 60 DEG. CHARGE DATA: PENE 13.1", ENTR. HOLE 0.43" TAGGED TD AT 7271' 10/07/08 COMPLETED A SAND HYDRAULIC FRACTURE STIMULATION. PUMPED A TOTAL OF 163,601# OF 16/20 CARBOLITE PLACING 146,347# BEHIND PIPE, 67% OF DESIGN. SCREENED OUT WITH 33,391# OF 9 PPA IN PERFS. LEFT 17,254# IN WELLBORE. PUMPED A TOTAL OF 1770 BBLS OF SW @ AN AVERAGE TREATING PRESSURE OF 3780 PSI. **"*NOTE: LOST ALL TREESAVER ELEMENTS IN WELLBORE.**** 10/09/08 PERFORM POST FRAC FCO DOWN TO HARD BOTTOM @ 7351' CTMD. SEEN HEAVY FRAC SAND AND BROKEN GEL THE ENTIRE CLEANING OPERATION. WASH GLM AND JEWERLY WHILE POOH.WELL SHUT AND FREEZE PROTECT TO 2800' MD WITH 60/40 AND READY FOR SLICKLINE TO INSTALL GAS LIFT DESIGN. 10/10/08 TAGGED TD @ 7298' SLM, EST. 27' RATHOLE. INSTALLED GLV DESIGN @ 2490', 3817', AND 5087' RKB. COMPLETE. - ~ KUP ConocoPhillips j : ~ wel) At aSSV. NIPPLE 12 'Annotation Depth (ftKB) End Date 7/1/2008 Annotation Last WO. I 10!14/2007 40.71 6/13/198 'i End Date Last Tag. 7271.0 10/4/2008 Rev Reason. FRAC 10/8/2008 Casing Strings Casing Descri ption String O... String lD ....TOp (ftK8) Set Depth(f... Set Depth(ND)... 'String Wt... String Gr.. . String Top Thrd CONDUCTOR 16 15.082 ~ 0.0 80.0 80.0 65.00 H-40 PE i Casing Description String 0... String ID .. . Top (kK6) ~I Set Depth (i... Sat Depth (TVD) ... iString W[... String Gr.. .'String Top Thrd I ,SURFACE ~ 103!4 9.765 0.0 2,5010 2,499.7 45.50 K-55 BTC jCasing Description String 0... String ID .. . Top (ftKB) Set Depth (t... Set Depth (ND) ... String Wt... String Gr.. . String Top Thrd !PRODUCTION 7 6.151 0.0 7,510.0 6,573.5 ~ 26.00 K-65 BTC Casing Description '.i String 0... Str rig ID ... Top (ftKB) Set Depth (i... Set Depih (TVD) .. St ~ng Wt... St rig Gr... String Top Thrd .SCAB LINER I 51/2 4.950 31J 6,765.3 5,959.1 I 15.50- L 80 571 Hydlil tails I Liner D Top Depth - ~. (TV DI Top Top (kK6)', (KKBI Inc! (°) Kam Descriptio n Comment ID (in) 6,712) 5,916.5 36.16 XO Caslnq to tubinq cross over 3.000' +~IrL~'r;.Y, i(h: Wellhore APUU WIIField Name (Well Status Prod/Inj Wall Type lncl (°) IMD (kK6) TD (max 500292073600 KUPARUK RIVER UNIT PROD 46.27 4,500-00 7,51: Comment R2S (ppm) Date I~gnnotation /End Date KBGrd (k) /Rig Release Dt HAVIuE R, S NIPPLE.482 GAS LIFT, 2,490 SURFACE, 0-2.501 GAS LIFT, 3,817 GAS uFT. S.OBB GAS LIFT. 6.115 GAS LIFT, -_ 6.fi42 LOCATOR, __ 6,fi93 BEAL, 6.696 Btin tE-12 /5/24/1997 4.ORPERF 180 deg-Ph; PBR, 6,765 - - - - SLEEVE, 6,926 - -- BLAST RING, - 6,939 APERF.~ 7,010-],090 - - Cemenl, 7,010 PACKER, 7.137 ---- - - ~ ~_ ~_ SBE. 7.140 - ~- -__ I J NIPPLE. 7,155- - - WLEG,7,1fi6 '~ RPERF. 7,200-],208 IPERf, 7,200-7.209 RPERF. 7,225-7.235 FRAC, ],225 RPERF. 7,222-7.241 IPERF, 7,225-7.245 1 E-12 SO FIANGER 3 1/2 z 11" tbg hanger 2.99: 08 NIPPLE 3 1/2 z 2.875" Camco "DS" Nipple 2.87: 33 LOCATOR 4.5" OD Locator w/ 2.5' of space out 3.001 _- 30 SEAL 3.99" OD 80-00 Bonded Seal Assembly 3.001 ing O .. String ID ... Top (ftKB) Sat Depth (i... Set Depth (ND) .. St tg Wt... String ... String Top Thrd 31/P ~ 2438 - 51 7,157.0 - 6,280.4 13.30 G 31/2"IF c -. - hiding Sleeve CMU # L-80 SC IB7 W/Blast Rings from 7,005-7,095' i Packer .re EMension D Profile Nipple 2.75" (RHC Installed)- (CS Lock) Stimulations 8 Treatments - ---~ _. it Bonom -` ------- -- ------- Min Top Max B1m Top Depth ~. Depth Depth i Depth (NDI (TVD) (ftKB) (ftKB) (ftK8) (kK8) Zona Data Comment 7,225.0 7,235.0 6,336.3 6,344.6 A-0, 1E-12 10/7/2008 A-SAND FRAC -PLACED 146,347# 16/20 CARBOLITE BEHIND PIPE. SCREENED OUT w/3,391# OF 9 ppa IN PERFS Cement Squeezes ' Top Depth Btm Depth (NDI (TVD) i i ! Top (kKBJ Btm (ftKB) (ftK8) (kK8) Description ~ Start Data ' Com_m_ent 7.010.0 7,090.0 6,159.2, 6,225.2.Cement Squeeze , 3/1711997 -_-,__ __ __-- Notes: General 8 Sa_fe_ty _ End Date Annotation 9;18/2005 NOTE: VIEW SCHEMATIC w/9.0 Mandrel Details Top Depth Top l; Port I (TVD) Inc! OD Valve latch Size TRO Run Stn Top (ftKB) (ftKB) (°) Maka Motlal (in) Sarv Type Type lint (psi) Can... Run Data 1 2,490.0 2,488.7 3.19 Camco KBG-2-9 1 Gas Lift DMY INT 0 0.0 10/3/2008 2 3,817.4 3,752.3 31.25 Camco KBG-2-9 1 Gas Lih !DMY INT 0 0.0 10/3/2008 3 5,087.9 4,690.2 44.32 Camco KBG-2-9 1 Gas Lift DMY INT 0 0.0 10/3/2008 4 6,114.9', 5,444.8 38.70~ Camco KBG-2-9 1 Gas Lift DMY INT 0 0.0 10/3!2008 5 6,641.9`, 5,859.7 36.76I Camco KBG-2-9 j 1 Gas Lift IIDMY INT 0 0.0 _ 10/3/2008- ~i~~~1116i-~i NO. 4759 Schlumberger -DCS 2525 Gambell Street, Suite 400 ATTN: Beth AK 99503-2838 ~,~~, f~ ~IUL L ~ ~~~~ Well Job # Log Description ,r ' ~ / ~` , ~, ., ~~ ~ ` z _ _ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite '100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 06/25/08 1G-14 11964620 INJECTION PROFILE ~ t~y- .°~ ~- ~~/ a ~ y ~~ ~/~/ 06/13/08 1 1 3A-16 11964621 LDL '" "-... ~ r r ;~ ~ 06/14/08 1 1 1 B-14 12061702 LDL ~'' [,~.-- ^~°? ~, / ~-- ~! •~ 06/15/08 1 1 2N-327 12061704 PRODUCTION PROFILE €=1~}° ~- -- , ~{~. ~--' ~P ' ,~°-F~ .~_- 06/17/08 1 1 1 B-04 12061705 INJECTION PROFILE j°°'- {~ ~ (--, ~' ~~ °~ <~(..°•--*.' ';'~ 06/18/08 1 1 2D-05 11964625 INJECTION PROFILE/LDLa ^-- °rs ~- ~^ . ~s'°-~ 06/18/08 1 1 1E-12 11964628 GLS ~ ~ I `'~-"`° P 06/20/08 1 1 3A-06 12061708 INJECTION PROFILE - ! rT ~~~-~:?~,t~ l ~~~.~~ 06/21/08 1 1 2A-08 11964629 INJECTION PROFILE ~kr.~'_ ='~ -'?'~~" /a~,~~~,%`~ 06/21/08 1 1 iL-11 11964630 PRODUCTION PROFILE g''= - ~~ '<""' I ~, 06/23/08 1 1 , , J , . Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • J ~t STATE OF ALASKA ~ ~~~ ~ ~ 2Qa~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERAT~I~~'~ ~` ~~~ ~°~~' Cnmmit;sion r._L ___ 1.Operations Pertormed: Abandon ^ Repair Well 0 Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing [~ P,snbrate New Pool ^ ` Waiver ^ Time Extension ^ Change Approved Program ^ /~`~l7-~ Perforate ^ Operat. Shutdown^ ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ Exploratory ^ 182-060! 3. Address: Stratigraphic ^ Service ^ 6. API Number: - P. O. Box 100360, Anchorage, Alaska 99510 50-029-20736-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 32' 1 E-12 8. Property Designation: 10. Field/Pool(s): ADL 25651, ALK 469 Kuparuk River Field f Kuparuk Oil Pool 11. Present Well Condition Summary: Totai Depth measured 7512' - feet true vertical 6575' - feet Plugs (measured) Effective Depth measured 7114' feet Junk (measured) true vertical 6245' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SUR. CASING 2469' 10-3/4" 2501' 2500' PROD. CASING 7478' 7" 7510' 6573' Scab Liner 5.5" 6763' 5957' Perforation depth: Measured depth: 7200'-7209', 7222'-7245', 7253'-7259' true vertical depth: 6316'-6323', 6334'-6353', 6360'-636~~~ r~~a P•~ t1 ~~1f ~ ~ 20U7 Tubing (size, grade, and measured depth) 3-1 /2" , L-80, 7157' MD. Packers & SSSV (type & measured depth} pkr- SAKER'FHL', BAKER'F-1' pkr= 6779', 7140' Camco DS nipple ~ 483' 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 Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation 231 486 585 -- 251 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: OilO Gas^ WAG^ GINJ^ WIND ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: 307-310 Contact Jim nls @ 265- • 1544 Printed Name C~ JS Title Welis Group Engineer ' .~ ~~ ~ `i Signature Phone Date Pr a b Sharon Al u -Dra a 26 -461 Form 10-404~eJised 0412006 ~~ IVi~lt ~ ~ ~~~% ~\~ ~~ Submit Original Only ~ • 1 E-12 Well Events Summary DATE Summary 9124!07 MIRU Nabors #3S 9/25/07 Kill well w/ 10.1 ppg brine. Install BPV. ND Tree. NUBOP. PT BOP 250/2500psi, OK. 9/26/07 Pull BPV. Cut tubing Ca). 2335'. POOH w/ cut tubing and spooled up control line on SLB spooler. Recovered all 34 bands. Made up Kelly and picked up Baker fishing tools. 9/27/07 RIH and tagged fish @ 2335'. Jarred on fish for 3 hours w/ no movement. POOH and ran washover BHA and washed over GLM to 2365'. POOH and prepared to make up cutter BHA. Total fluid losses for 24 hrs. = 136 bbls. 9128/07 First attempt with outside cutter failed and POOH. RIH to attempt to jar loose the fish also failed. RIH and had good cut, POOH with fish. Cut was made t~ 2419wapprox. 18" below collar. 9/29/07 Chemical cut tubing @ 6807' and had trouble getting out of hole. OOH wl chemical cutter and worked pipe up to 120K after conferring w/ town engineer. No gain on pipe after working and preparing for free point run. 9/30/07 RIH with SWS for freepoint logging. Had tool failure on first attempt and POOH, repaired tools and went back in hole for logging run. Found scale above the GLM that caused some anchor slippage. 10/1/07 Chemical cut tubing @ 4465' Able to pull fish free and POOH w/ fish. 1012107 RIH w/ fishing BHA. Engage fish @ 4465'. ,Jarred loose fish and POOH. Fish came out at the chemical cut at 6807'. The tubing was cut approx. 213 of the way by chemical cutter and we broke the rest. RIH to fish SBR. 10/3/07 POOH, inspected BHA and found no fish. Performed weekly BOP test 250/2500 psi, OK. Changed fishing BHA and RIH to retrieve SBR. '~' 1014107 Pulled SBR skirt and tubing stub. RIH to pull SBR polished rod and FHL packer. At time of report appears that we have the packer. Total 24 hr.fluid losses = 33 BBLS. 10/5/07 POOH w/ FHL Hacker, RIH w/ clean out BHA. 10/6/07 Lost circulation when opening C sands, regained returns, conditioned hole and continued clean out. Clean out thru A sands went well and able to make approx. 50' rat hole. New Q~TD ~ 7286' RKB, Total 24 hr. losses = 932 BBLS. 10/7107 RU SWS and set FB-1 packer at 7138' top of seal reciever, rig down SWS. PU lower completion equipment including a test packer, RIH. Total 24 hr. fluid losses = 339 BBL. 10/8/07 RIH w/ lower section of completion. Called out SWS to verify depth due to difference in pipe tally and E-line depth. Depth verified, set FHL packer, test casing. Casing test failed and began leak detection w/ Baker retrievamatic packer. . 10/9/07 Continue leak detection. Found good casing from surface to 2,705' along with 4,628' - 6,782' pressure tested to 2,500 PSI for 15 MIN. From 2,705' - 4,440' leak rate = 1 BPM~a 420 PSI. Leak rate from 4,440'- 4,628' = 1 BPM . 1,000 P .Discuss with Anchorage options. Decide to prepare well for 5-112" sleeve program. Set storm packer @ 120' & PT 2500 psi, OK. 10/10/07 ND BOPE and tbg Spool. Install new Gen 5 - 5 1/2 csg spool and BOP. Test BOP 250/2500 psi, OK. POOH w/ storm pkr. 10/11/07 Rih w/ 5 112" csg & sting into FHL pkr. 10/12/07 Land 5 1/2 csg and NU tbg spool. Set slickline tbg tail plug. PT 5.5" 2500 psi, OK. Start RIH w! 3.5" Production String. 10/13/07 Land tubing. PT tbg 2500 psi, OK. Install TWC. ND BOPE. NU tree. 10/14/07 PT tree 250/5000 psi, OK. Pull TWC. Install BPV. RDMO Nabors #3S. • C "~ ~~ KRU 1 E-12 Ct~~>a~t~Pt~i~li~s Alaska, !~~- i 1 E-12 _- ~ API: 500292073600 Well T e: PROD An le TS: 35 de 7010 TUBING SSSV Type: LOCKED OUT Orig 6/13/1982 Angle @ TD: 34 deg @ 7512 (0713, Com letion: OD:3.500, ID:2ss2) ~ Annular Fluid: Last W/O: 10/14/2007 Rev Reason: vShow PBR/SBE, 0..4...........1 ..... O..F 1 .... f1..~... 1 ..M I Inll..t..• XO7/7M7 PBRlSBE (6696-6713, OD:3.750) SCAB LINER (0-6763, OD:5.500, Wt:15.50) PBRlSBR (67636779, OD:5.880) TUBING (6713-7157, OD:3.500, ID:2.992) BLAST COLLARS (70o5-7os5, OD:4.560) pert (7200-7208) Perf (7200-7209) Perf (7222-7241) Perf (7225-7245) Last Ta : 7266' WLM TD: 7512 ftK6 Last Tag Date: 10/23/2007 _ Max Hale Angle: 46 deg (ril 450(1 _ _ ~ ~ Casing String -ALL STRINGS ~ Descri lion Size To Bottom TVD yVt Grade Thread CONDUCTOR 16.000 0 80 80 65.00 H-40 PE SUR. CASING 10.750 0 2501 2500 45.50 K-55 BTC ~' PROD. CASING 7.000 0 7510 6574 26.00 K-55 BTC SCAB LINER 5.500 0 6763 5957 15.50 L-80 511 Hydril Tubing String -TUBING Size To Bottom TVD VUt Grade Thread 3.500 0 6713 5917 9.30 L-80 IBTM 3.500 6713 7157 6280 9.30 L-80 Srr11E3TM Perfor,~Yiorts Summary ~ , Infanral ~ Tl{fl ~ 7nnn ~ Cfyf„c , G ~ CPF , Ilatn ~ l unn ~ C:nmmani ~ 7010-7090 6159-6225 -3,C-2,C-1, B C 80 0 3/17(1997 Sqz 7200 - 7208 6316 - 6323 A-5 8 8 5/2471997 RPERF i 80 deg. Ph; 2118" EJ BH 7208-7209 6323-6323 A-5 1 4 6/13/1982 IPERF -~ 7222- 7225 6334- 6337 A-4 3 4 5/24/1997 RPERF 180 de . Ph• 2 1/8" EJ BH "'~ 7225 - 7241 6337 - 6350 A-4 16 8 5/24/1997 RPERF 180 de . Ph; 2 1/8" EJ BH 7241- 7245 6350 - 6353 A-4 4 _4_ 6/13_/1982 IPERF f 7253 - 7259 I 6360 - 6365 I A-4 I 16 I _4 16/13/1962 I IPERF _ I I Stimulations & Treatments L Interval Date Type Comment I 7010 - 7090 3;1 I/1 ~J7 Cement Gas Lift MandrelsNalves I St I MD I TVD I Man Mfr I Man Type I V Mir ~ v Type i V OD Latch Port TRO Date Run Vfv I ~~ -~ 4 1 61151 5445 CAMCO I KBG-2-9 ~ I DMY I 1.0 I INT ~ 0.000 10 I10/14/200~ I lth ~( gs qu p ~ E3C' OMPLETION DMV 1~ INT o noo o inr14r2oo l 483 483 NIP CAMCO DS NIPPLE 2.875 6696 5903 PBR/SBE BAKER 80-40 H450-01-4081 PBR/SBE STABBED CROSSOVER 2.850 6713 5917 XO CASING TO TUBING CROSSOVER 3.000 6763 5957 PBR/SBR BAKER 80-40 PBR/SBR STABBED INTO FHL PACKER 2.970 6779 5970 PACKER BAKER FHL PACKER 2.930 4.010 4.000 Perf (72537259) ScblumblPgep NO. 4468 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 i\,.··I'I·"""m.~. 'rf\~'Mi"'"n OCT 9 1 '>007 ,{,,,rj,,,,_\J::<'<~:'¡''U\~IUI.JU¡;Þ) t} L Field: Kuparuk Well Job# Log Description Date BL Color CD 2N-327 11839673 PERF/SBHP .;)0'9 ~ ()~q 10/24/07 1 2T-201 (REPLACES 11839656 INJECTION PROFILE ù-.r:e...IC\~ - Lri rl 09/03/07 1 1A-23 11837520 PRODUCTION PROFILE lot I-oc:fì. 10/04/07 1 2M-09A 11846446 WFL t):t.Q.. lq(A -(-p.ò 10/04/07 1 31-08 11837517 LDL '~(ð - d/l) 10/02/07 1 2M-24 11839670 PRODUCTION PROFILE IC¡ <;;:) -()5() 10/03/07 1 1J-102 11846451 INJECTION PROFILE 0-r.c... ~ -/LÒ 10/10/07 1 1Y-02 11837516 INJECTION PROFILE í JTr' 14)(~ - ce:l 10/01/07 1 1E-112 11846450 INJECTION PROFILE UT('\ :::J^u_cP. { 10/10/07 1 2T-12A 11839669 LDL J~Ú -1{::)5(" 10/02/07 1 2B-07 11837522 INJECTION PROFILE l>T C'.. ''7rLf -~(.{ 10/05/07 1 1 E-12 11846447 DDL I~;} -bCðÒ 10/08/07 1 2N-327 11839671 SCMT ;}.o'+-- O~ c::¡ 10/23/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. '3 10/25/07 . . • 0 0 ~ ~ a SARAH PALIN, GOVERNOR ~r~p1 cwLa~7~7~ 0~ ~cVr~S 333 W. 7th AVENUE, SUITE 100 CO~Sa:IR•j~-~0~ COl-II-T15SIO1Q ANCHORAGE,AI,aSIU\ 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 J. Ennis Wells Group Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 ~._ ' ' ~~~+~ lv O V ~ 2007 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 E-12 Sundry Number: 307-310 - ~-~,~~® Dear Mr. Ennis: ~`~ 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~~ay of October, 2007 Encl. Sincerely, • ConocoPhillips October 10, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval 1 E-12 Dear Commissioner: • Jim Ennis Wells Group Engineer Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-1544 ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval following identification on 10/9/07 of 7" casing leaks between 2705' and 4628' during a tubing replacemenf workover. If you have any questions regarding this matter, please contact me at 265-1544. Since J. nnis W Its Group Engineer CPAI Drilling and Wells J E/skad ~~ • STATE OF ALASKA , , i ~ ~ r~ ALASKA OIL AND GAS CONSERVATION COMMISSION w APPLICATION FOR SUNDRY APPROVAL ~ . ~ ' "~`' `~ `' 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^/ Repair well Q Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^/ Exploratory ^ 182-060' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20736-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership o r landownership changes: Spacing Exception Requires? YeS NO Q 1E-12 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25651, ALK 469 RKB 32' Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7512' 6575' ~ 7114' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 80' 80' SUR. CASING 2469' 10-3/4" 2501' 2500' PROD. CASING 7478' 7" 7510' 6573' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7200'-7209', 7222'-7245', 7253'-7259' 6316'-6323', 6334'-6353', 6360'-6365' 3-1/2" J-55 6919' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER'FHL' pkr= 6848' Camco TRDP-1AE SSSV= 1904' 13. Attachments: Description Summary of Proposa{ Q 14. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat October 10, 2007 Oil ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoi is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265-1544 Printed Name ~ Title: Wells Group Engineer Signature Phone 265-1544 Date Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ ~. Other: ~ Subsequent Form Required: t Approved by: COM NER APPROVED BY THE CO MISSION Date: `Q' ~ 0 Form 10-403 Revised 06/2006 V r ~ ~'7 c3"`~~ Submit in Duplicate ERIC; ~a~ '~ • • 1 E-12 Casing Leak Isolation Supplemental Workover Procedure Note: Casing leaks have been identified between 2705' & 4628'. Rig Work 1. Complete weekly BOP test 250/2500 psi. 2. RIH w/ PBR seal assembly, one joint 3.5" tbg and 5" SBE on 5.5" Hydril 511 casing. Locate PBR and space for landing a foot off bottom. Circ annulus volume w/ 9.8 ppg brine containing 1 % by volume Baker Petrolite CRW-132. Sting into PBR and land 5.5" casing w/ slips. NDBOP & cut 5.5" casing. Install packoff & tubing head. PT 5.5" packoff. NUBOP. Install test plug. Close blind rams & PT below blinds 250/2500 psi. Pull test plug. Freeze protect 7" x 5.5" annulus w/diesel. 3. RIH w/ 3 %2", 9.3#, L-80, IBT Mod tbg w/special clearance collars as follows: a. Baker seal assembly w/ 4.5" locator b. 3-1/2" tubing and five KBG-2-9 1" GLMs per design w/ 1500 psi SOV in GLM #2 • GLM design MD's 2501', 3816', 5096', 6151', 6750' c. 2.875" Camco `DS' nipple @ 500' 4. Spot corrosion inhibited brine in IA below GLM #2 prior to stabbing into PBR. Space-out, land tbg hanger. RILDS. RU chart recorder to tbg & IA. With the annulus open, PT tubing to 2500 psi for 15 minutes. Bleed off tubing pressure to 1750 psi. Holding the tubing pressure at 1750 psi, PT IA to 2500 psi for 15 minutes. Bleed off tubing pressure to shear the dump kill valve. Install TWC. NDBOP. NUWH. Test tree and packoffs to 5000 psi. Pull TWC & install BPV. RDMO. Post-riq Work 1. RU slickline. 2. Replace shear valve w/ dummy. PT tbg 2500 psi. 3. Fish ball/rod & RHC plug. 4. Tag fill w/ 2" bailer. 5. Obtain `A' sand static BHP. 6. Install GL design for `A' sand production. • Original Como ~,- ~ 1 E-12 Proposed Completion w/ casing leaks tion Proposed 2007 Completion I ~ SCSSV 2.875" Camco D Nipple Collapsed GLM 5 KBG-2-9 GLMS 5.5" Hydril 511 Csg 3.5" IBT Tbg `FHL' Packer w/ SBR 2.75" Camco D-Nipple 3.5" IBT tbg w/ SCC 7" csg leaks 2705'-4628' 5" OD SBE (4" ID) 3.5" Tbg 3.5" x 7" 'FHL' Packer w! PBR ~ CMU w/ 2.81" DS 3.5" x 7" 'FB-1' Packer ~ I 2.75" Camco D-Nipple 7", 26# K-55 Casing Daily Operations Summary Rep~rt 1 E-12 Job: RECOMPLETION S~ert ^a~,e 19!24/2007 9/25/2007 9/26/2007 9!27!2007 9/28/2007 9/29; 2007 9/30/2007 10/1 /2007 10/2/2007 101?/2007 10!4/2007 10/5/2007 110/6/2007 Fred DatF 9/24;2007 9/26/2007 9'2 7 %2007 9/28!2007 9/29/2007 9/30/2007 10/ 1 /2007 10/2/2007 10/3/2007 16!4!2007 10/5 2007 10/6/2007 10/7/2007 Las 24hr Sim Travel plus MIRU Kiil wetl ~ ND Tree and NU BOPE Cut tubing @! 2335'. POOH w/ cut tubing and spooled up control line on SLB spoolar_ Recovered all 34 bands. Made up Kelly and picked up Baker fishing ±ools RIH and tagged fish @ 2335'. Jarred on'fish for 3 hours w/ no movement. POOH and ran washover BHA and washed over GLM to 2365'. POOH and prepared to make up cutter BHA. Total fluid losses for 24 hrs. = 136 bbls. First attempt with outside cutter failed and POOH. RIH to attempt to jar lose the fish also failed. RIH and had good cut, POOH with fish. Cut was made @ 2419' approx. 18" below collar. Chemical cut tubing and had trouble getting out of hole. OOH wl chemical cutter and worked pipe up to 120K after conferring w/ town engineer. No gain on pipe after working and preparing for free point run. Chemical cut appears good and cut was at 680T. RIH with SWS for freepoint logging. Had tool failure on first attempt and POOH, repaired tools and went back in hole for logging run. Found scale above the GLM that caused some anchor slippage. Chemical cut tubing @4465'. Able to pr~[I fish free and POOH wl fsh. Jarred loose fish and POOH. Fish came out at the chemical cut at 6807'. The tubing was cut approx 2/3 of the way by chemical cutter and we broke the rest. RIH to fish SBR. POOH,'inspected'`BHA and found no fish. Performed regulated BOPE test. Changed fishing BHA and RIH to retrieve.SBR' Pulled SBR skirt and tubing stub. RIH to pull SBR polished rod and FHL packer. At 'time of report appears that we have the packer. Total 24 hr.flnid losses = 33 BBLS. POOH FHL packer OOH and RIH w/ clean out BHA. Lost circulation when opening C sands, regained returns, conditioned hole and continued clean out. Clean out thru A sands went well and able to make approx. 50' rat hole. New TD @ 7286' RKB. Total 24 hr. losses = 932 BBLS. 10/7±2007 10/8/2007 10/9/2007 1 ors/zoo7 10/9!2007 10/10,2007 RU SWS and set FB-1 packer at 7 138' top of seal reciever. rig down SWS. PU lower completion equipment including a test packer. RIH. Total 24 hr fluid losses = 339 BBL. RIH w/ lower section of completion. Called out SWS to verify depth due to diffarence in pipe tally and E-line depth. Depth verified, set FHL packer, test casing. Casing test failed and began leak detection w/ Baker retrievamatic packer. Continue leak detection. ', Page 1/1 Report Printed: 10l10/2007~ + • • w ~ ' KRU 1 E-12 ~ Con4ct~Philtips ,~taska, lnc. .. --_- ~ E-~ 2 < _ _ - - - - - API: 50QZy"2U73600 Well T e: PROD An le m TS: 35 de ~ 70111 I SSSV Type: LOCKED OUT Orig 6/13/1982 Angle @ TD: 34 deg @ 7512 sssv Com letion: ( 00 ~ oo ~` ~ Annular Fluid: Last W/O: Rev Reason: Show CSG threads 3 s j I,, Reference Lo Ref Lo Date: Last U date: 6/16/2007 Last Ta : 7114 TD: 7512 ftKB (;asSnn2Str~inn"Ai 11STRIN(;S i. MaxrtnleAngle•i4haeg(rnn5tlrr I i I COLLAPSED TBG (2349-2350, OD:3.500, 1D:2.992) Gas Lift ndrellDummy Valve 2 (4511-4512, OD:5.313) Gas Lift ndrel/Dummy Valve 3 (6442443, OD:5.313) Gas Lift ndrel/Dummy Valve 4 (6785786, OD:5.313) SBR (6822823, OD:3.500) PKR (6848849, oD:s.15s> NIP (6886-6887, OD:3.500) TUBING (0-6919, OD:3.500, ID:2.992) SOS (6918-6919, OD:3.500) Cement (7010.7090) Pert (7010.7090) Perf (7200-7208) Perf (7200.7209) Perf (7222-7241) Perf (7225-7245) I ~, C_._~ Descri lion Size To Bottom TVD Wl Grade Thread CONDUCTOR 16.000 0 80 80 65.00 H-40 PE SUR. CASING 10.750 0 2501 2500 45.50 K-55 BTC PROD. CASING Tubing String - TU61NG Size To 7.000 0 Bottom TVD 7510 6574 26.00 Wt Grade K-55 BTC Thread 3.500 0 6919 6085 9.20 J-55 BTC 3.500 2349 erforations Summary Interval TVD 2350 Zone Status 2349 Ft SP F 9.20 Date J-55 T e BTC Comment 7010-7090 6159-6225 -3,C-2,C-1, B C 80 0 3/17/1997 Sqz 7200 - 7208 6316 - 6323 A-5 8 8 5/24/1997 RPERF 180 deg. Ph; 2 1!8" EJ BH 7208 - 7209 6323 - 6323 A-5 1 4 6/13/1982 IPERF 7222 - 7225 6334 - 6337 A-4 3 4 512411997 RPERF 180 de . Ph; 2 118" EJ BH 7225 - 7241 6337 - 6350 A-4 16 8 5/24/1997 RPERF 180 de . Ph; 2 1/8" EJ BH 7241- 7245 6350- 6353 A-4 4 4 6/13/1982 IPERF 725-7759 6~fin-fi'if,5 A-4 6 4 F/i'i/19R? IPERF .:Stimulations & Treatments -- _Interv_al Date Type Comment 7010-7050 13/17/1997 iGement i Gas Lift Mandrels/Valves ~ St ~ MD ~ TVD ~ Man Mfr ~ Man Type ~ V Mfr ~ V Type ~ V OD ~ Latch ~ Port ~ TRO ~ Date Run ~ Vlv ~ ~ 4 ~ 67851 59751 Gamco ~ KBUG ~ ~ DMY X 1 0 I BK 1 OA~O ~ 0 Othet'~plugs, equip., etc.) -COMPLETION De th TVD T e Descri lion X1 0/3 1 /1 9 9 71 I ID 1904 1904 SSSV Camco TRDP-1AE LOCKED OUT 7/19/84 2.813 6822 6005 SBR Baker'EBA-1 w/40M# SHEAR UNSHEARED 2.813 6848 6027 PKR Baker'FHL' 2.891 6886 6058 NIP Camco'D' Ni le NO GO 2.750 6918 6084 SOS Baker 2.992 6919 6085 TTL Geaerai Notes ---_ Date Note 2.992 _. 2/18/199 NOTE: Encoutered Collapsed Tubing an aDOrox. 2349': See WSR 12/18/97 Pert (7253-7259) • From: Ennis, J J [mailto:J.J.Ennts@conooophilltps.comJ Sent: Wednesday, October 10, 2007 8:58 AM To: Maunder, Thomas E (DOA) c~ Attsup-Drake, Sharon K Subject: RE: 1E-12 casing teaks Yes sir. You presume correctly. Thanks Tom. • ~~~ -~~ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, October 10, 2007 8:51 AM To: Ennis,) Cc: Attsup-Drake, Sharon K Subject: RE: 1E-12 casing Irks Jim, Thanks for the information. I presume that the installation of the 5-1/2" will require addition of another casing spool. That will allow monitoring of the 7-5l8" X 5-1/2" annulus for any pressure that might develop. I will look for the sundry today. Tom Maunder, PE AOGCC From: Ennis, J J [mailto:).).Ennis@eonocophifltps.com) Sent: Wednesday, October 10, 2007 7:23 AM ~~ t~~~~~~ ~~~~ Ta: Maunder, Thomas E (!~A) Cc: Allsup-Drake, Sharon K ~~'~ ,~~ ~-~, ~ , >~~~~~ Subject: 1E-12 casing teaks Good morning Tom, -~~ Nabors #3S has been on 1 E-12 since 9/24/07 to replace tbg w/ a collapsed Gt_M. All the tbg and the production packer have been fished successfully and a selective has been installed across the 'C' sand. As we discussed on the phone, casing teaks were identified yesterday and isolated between 2705' ~ 4628'. Our forward plan is to install a 5.5" flush joint string which wit[ be stung into the PBR on the top production packer and brought back to surface. Corrosion inhibited fluid will be circutated into the 5.5"x7" annulus. An SBE will be installed in the 5.5" for the 3.5" production tbg to be stung into. Sharon & t wilt get the 403 prepared today for submittal. A preliminary drawing of the completion is attached for reference. Jim Ennis j.j.ennis c~conocophiHips.com (907)265-1544 (1fU) (907)632-7281 (C} «'{ E-12 Preliminary completion sketch 10-10-07. PDF» ,~ -ia~ • ~J ~k'. ____ _. ~{ ,Q ~~ ~~~ ~, 3 •~ ~~~,~1s ~_ ter. ~~ ~~ ~~~~ `t ~°~~ i ~~k~ t`} ~ ~ 3 ' :~ F r . ., Maunder, Thomas E (DOA • From: NSK Problem Weil Supv [n161T@conocophillips.comj Sent: Friday, June 25, 200412:03 PM To: Tom Maunder AOGCC {E-mail); Jim Regg AC3GCC (E-mail) Subject: 2P-448A (PTD 202-005) 81 E-12 (182-060} added to CPAt weekly SCP report Tom & Jim, Two wells, 2P-448A {PTD 202-005) & 1E-12 (182-060) were added to the CPAI weekly producer SCP report today. 2P-44$A OA has sustained pressure due to charging from the open OA shoe. Current WHPs are: 260!141911002. Diagnostics verified tbg and production easing integrity and a waiver will be issued. 1E-12 Failed a TIFL an 6/24/04. Current ~iHPs are; 180/920/20. This well has collapsed tbg at 2347'. The well will be SI when diagnostic testing is completed as a rig is now required to repair the TxIA communication. Please let me know if you have any questions. Marie McConnell Problem Well Supervisor 659-7224 1 RE: FW: 1E-12 (182-060) Approval for temporary production ') ) Subject: RE: FW: 1E-12 (182-060) Approval for temporary production From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Wed, 20 Oct 200409:49:22 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> Tom, Below are 2 well tests for 1E-12 before it eventually hydrated off and stopped producing. oil rate (bpd) water rate (bpd) water cut (%) Lift rate (MSCFD) 9/28/04 10/04/04 30 12 214 181 88 94 0 700 Brad Gathman ConocoPhillips Alaska Inc. Problem Well Supervisor 907-659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, October 19, 20047:03 AM To: NSK Problem Well Supv Subject: Re: FW: 1E-12 (182-060) Approval for temporary production Brad or whoever is there this week, I was getting through my messages. What production rates/splits were seen during the flow test?? Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom, 1 E-12 has been shut-in as of 10/11/04 after the temporary flow test. Brad Gathman Problem Well Supervisor 907 -659-7224 SCANNED NOV 0 8 2004 -----Original Message----- From: NSK Problem Well Supv Sent: Friday, September 24, 2004 10:52 AM To: Tom Maunder AOGCC (E-mail) Subject: FW: 1E-12 (182-060) Approval for temporary production Tom, 1 E-12 was BOL on 9/23/04 for the 21 day flow test. The well will be SI by 10/14/04. 10f4 11/8/2004 1 :48 PM RE: FW: 1 E-12 (182-060) Approval for temp~. lry production ) Marie McConnell - Problem Well Supervisor 659-7224 -----Original Message----- From: NSK Problem Well Supv Sent: Friday, September 10, 2004 10:54 AM To: 'Thomas Maunder' Subject: RE: FW: 1E-12 (182-060) Approval for temporary production Thanks Tom--I will pass the message along. I will have them test the SVS system prior to flowing the well. By the way, do you have everything you need to approve the gaslift on 1 D-102? If not let me know. Thanks! Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 .. ," STATE OF ALASKA '~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate Plugging Perforate X Repair well Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address :P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service ,,, 6. Datum elevation (DF or KB) RKB 32 7. Unit or Property name Kuparuk River Unit 8. Well number feet 803' FSL, 812' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 2534' FSL, 2414' FEL, Sec. 16, T11N, R10E, UM At effective depth 2491' FNL, 2516' FEL, Sec. 16, T11N, R10E, UM At total depth 2488' FNL, 2517' FEL, Sec. 16, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 751 2 feet 6574 feet 1E-12 9. Permit number/approval number 82-60 10. APl number 50.-029-20736-00 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 7427 true vertical 6504 Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: feet Junk (measured) None feet Length Size Cemented Measured depth 80' 1 6" 217 Sx AS II 80' 2463' 10-3/4" 1125SxASIII& 2501' 250 Sx AS II 7475' 7" 1040 Sx Class G 751 0' measured 701 0'-7090',7200'-7209',7225'-7245',7253'-7259' true vertical 6159'-6225',631 5'-6322',6336'-6352',6359'-6364' True vertical depth 80' 2500' 6573' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 6919' Packers and SSSV (type and measured depth) Pkr: Baker FHL @ 6848'; SSSV: WRDP-1 @ 1904' (pulled in 3/97) 13. Stimulation or cement squeeze summary Perforate "A" sand on 5/24/97. ORIGINAL Intervals treated (measured) 7200'-7208',7222'-7241' Treatment description including volumes used and final pressure Perforated using 2 1/8" EJ Guns w/BH charges @ 2 SPF, fp was 2150 psi. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md RECEIVED DEC 2 2 1997 Alaska Oil & Gas Cons. Commissior A.n. ch_nr~e Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 1327 153 Subsequent to operation 5 6 31 804 1327 157 15. Attachments Copies of Logs and Surveys run m Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. (~ (".'UPARUK RIVER UNIT '~' WELL SERVICE REPORT ~' K1(1E-12(W4-6)) WELL JOB SCOPE JOB NUMBER 1 E-12 COILED TUBING CEMENT SQUEEZE 0303972121.7 DATE DAILY WORK UNIT NUMBER _ 05/24/97 ' REPERF AND ADPERF WITH 2 1/8" EJ BH 8337 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 12 (~) Yes- ('~ NoI ® Yes (~ No SWS-WALSH BLACK FIELD AFC,# CC# DAILY COST ACCUM COST Signe~l; / ESTIMATE 998688 230DS10EL $1 1,749 $211,430 ~~ Initial Tb.(:l Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer'Anr~- I' F~nal Outer Ann 2100 PSI 2150 PSI 0 PSI 0 PSII 0 PSI I 0 PSI DALLY SUMMARY I EJ BH @ 2 SPF 180 DEG PHASED (4 SPF TOTAL) PERFORATED 7200-08' & 7222-41' ELM, COULD NOT GET DEEP ENOUGH TO SHOOT LOWER INTERVAL. PERFORATED W/2-1/8" TIME 07:30 09:00 11:00 11:30 14:00 16:30 18:30 LOG ENTRY MIRU SWS (WALSH & CREW). MU GA#1 (WT/MAG/CCL/19' - 2-1/8" EJ BH @ 2 SPF ORIENTED 90 DEG CW F/HIGH SIDE). PT BOPE TO 2500 PSI. TGSM. RIH WITH WT/MAG/CCL/19' EJ BH GUN. 2.125" OD, 31' ON BOTTOM TIED IN W/6/11/82 SWS CBL NOT DEEP ENOUGH TO SHOOT LOWER MOST (BOTTOM A4) REQUESTED INTERVAL. CONCURRED W/DSE TOGO AHEAD & PERFORATE UPPER A4 SECTION. PERFORATE F/7222.5-7241.5' ELM W/2-1/8" EJ BH @ 2 SPF ORIENTED 90 DEC CW F/HIGH SIDE (PERFORATED AS SOON AS RECEIVED LINE TENSION OFF BOTTOM). SUCCESSFUL FIRE. POOH. ALL SHOTS FIRED. MU GA#2 (SAME AS BEFORE BUT 90 DEC CCW F/HIGH SIDE). RIH. TIE-IN AND SHOOT 7222-7241' ELM (AS DEEP AS WE COULD GET) WITH 19' EJ BH ORIENTED 90 DEG CCW FROM HIGH SIDE OF HOLE. POOH. ALL SHOTS FIRED. MU GA#3 (SAME AS BEFORE BUT 8' AND ORIENTED 90 DEC CW F/HIGH SIDE OF HOLE. RIH. TIE-IN AND SHOOT 7200-08' WITH EJ BH, 2 SPF, ORIENTED 90 DEG CW FROM HIGH SIDE. POOH. ALL SHOTS FIRED. MU GA#4 (SAME AS BEFORE BUT 90 DEG CCW F/HIGH SIDE). RIH. TIED-IN, BECAME STUCK AT 7201', WORKED FREE, SHOT 7200-08' WITH EJ BH, 2 SPF, ORIENTED 90 DEG CCW FROM HIGH SIDE. POOH. ALL SHOTS FIRED. 19:30 RDMO. WELL TURNED OVER TO PRODUCTION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $659.00 i, APC $250.00 $63,600.00 ARCO $0.00 $5,900.00 BAKER OIL TOOLS $0.00 $23,603.00 BIOZAN $0.00 $1,000.00 BP $0.00 $900.00 DIESEL $0.00 $2,593.00 DIESEL GEL $0.00 $100.00 DOWELL $0.00 $73,943.00 DRILLEX $0.00 $5,210.00 HALLIBURTON $0.00 $6,597.00 LITTLE RED $0.00 $7,425.00 MI FLUIDS $0.00 $8,400.00 SCHLUMBERGER $11,500.00 $11,500.00 TOTAL FIELD ESTIMATE $11,750.00 $211,430.00 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Perforate _ Repair well Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development ,,,.X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 803' FSL, 812' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 2534' FSL, 2414' FEL, Sec. 16, T11N, R10E, UM At effective depth 2491' FNL, 2516' FEL, Sec. 16, T11N, R10E, UM At total depth 2488' FNL, 2517' FEL, Sec. 16, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 32 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1E-12 9. Permit number/approval number 82-60 10. APl number 50-029-20736-01;3 11. Field/Pool Kuparuk River Field/Oil Pool 751 2 feet Plugs (measured) None 6574 feet Effective depth: measured 7427 feet Junk (measured) None true vertical 6504 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 1 6" 217 Sx AS II 80' 80' Surface 2463' 1 0-3/4" 1125 Sx AS III & 2501' 2500' Intermediate 250 Sx AS II Production 7475' 7" 1040 Sx Class G 751 0' 6 57 3' Liner Perforation depth: measured 701 0'-7090',7200'-7209',7225'-7245',7253'-7259' true vertical 61 59'-6225',631 5'-6322',6336'-6352',6359'-6364' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Pkr: Baker FHL @ 6848'; SSSV: WRDP-1 @ 1904' (pulled in 3/97) 13. Stimulation or cement squeeze summary Fracture stimulate "A" sands on 11/5/97. _,,-r,~.~,, [..... Intervals treated (measured) ORIGINAL 7200'-7208',7222'-7241' Treatment description including volumes used and final pressure ~1~ Pumped 226 Mlbs of 16/20, 12/18, and 10/14 ceramic proppant into the formation, fp was 7300 psi. 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 1342 139 Subsequent to operation 2 9 5 139 3108 1350 188 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ./~,~ Form/1~)-404 Rev 0~/88 '~(~ (' 'q~. {t~¢ ¢,~ Title Wells Superintendent Date I SUBMIT IN DUPLICATE ARCO Alaska, Inc. (~'~ {r KUPARUK RIVER UNIT '~ WELL SERVICE REPORT ~ K1 (1E-12(W4-6)) WELL JOB SCOPE JOB NUMBER 1 E-12 FRAC, FRAC SUPPORT 1021970805.1 DATE DAILY WORK UNIT NUMBER 11/05/97 "A" SAND REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 (~ Yes O NoI ® Yes O No DS-YOAKUM CHANEY FIELD AFC#f CC.#f DAILY COST ACCUM COST Signe,d /,~'/~'" ESTIMATE KD1291 230DS10EL $135,702 $155,259 ~' ~(., ~. - Initial Tb.cl Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 2000 PSI 2200 PSI 25 PSI 75 PSII 750 PSII .500 PSI DALLY SUMMARY "A" SAND REFRAC COMPLETED. INJECTED 226000 LBS OF PROP IN THE FORM W/12.4# PPA OF #10/14 @ THE PERF'S. MAX PRESSURE 7300 PSI AND F.G. @ (.96). FREEZE PROTECTED TBG DOWN TO 2800' W/25 BBLS OF DIESEL. TIME 06:30 08:00 08:20 09:30 10:30 13:00 14:00 15:00 LOG ENTRY MIRU DOWELL FRAC EQUIP, LRS HOT OIL UNIT, AND APC VAC TRUCK. HELD SAFETY MEETING (17 ON LOCATION). PT'D BACKSIDE LINES AND EQUIPMENT TO 4000 PSI. SET TREESAVER AND PT'D HIGH PRESSURE LINES 8500 PSI. - 1' ~ .,~r__mm~.,,.~,,~,,'.,,~.,~, ~ ~.~ ,ir, '-,.,,, r PUMP BREAKDOWN W/50# DELAYED XL Gw @ 15 BPM. VOLUME PUMPED ~ BBLS.. USED 5614 LBS OF #16/20 PROP. MAXIMUM PRESSURE 6400 PSI AND ENDING PRESSURE 3300 PSI. STEPPED DOWN RATE THEN S/D. OBTAINED ISIP OF 2961 PSI W/F.G. @ (.91). MONITORED WHTP AND PULSED TO CLOSURE. DETERMINED CLOSURE TIME +-30 MINS @ 2620 PSI. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. VOLUME PUMPED 183 BBLS. MAXIMUM PRESSURE 6500 PSi AND ENDING PRESSURE 4480 PSI. S/D AND OBTAINED ISIP OF 3318 PSI W/F.G. @ (.96). MONITORED WHTP FOR CLOSURE. DETERMINED CLOSUREIME +-14 MINS @ 2980 PSI. PUMP FRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. VOLUME PUMPED 1701 BBLS. MAXIMUM AND ENDING PRESSURE 7300 PSI. S/D. PUMPED 228984 LBS OF PROP (21310 LBS OF #16/20, 198690 LBS OF #12/18, AND 8984 LBS OF #10/14). INJECTED 226000 LBS OF PROP IN THE FORMATION W/12.4# PPA OF #10/14 @ THE PERF'S. LEFT 2984 LBS OF PROP IN THE WELLBORE, EST TOP OF FILL @ 7000'. FREEZE PROTECTED TBG DOWN TO 2800' W/25 BBLS OF DIESEL. STARTED R/D. DEPRESSURED THE INNER CSG BACK TO 500 PSI AND R/D LRS HOT OIL UNIT. REMOVED TREESAVER (50% OF CUPS LOST). CONTINUED R/D. R/D COMPETE AND DOWELL LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $680.00 , APC $5,700.00 $11,700,00 DIESEL $400.00 $650.00 DOWELL $127,842.00 $134,342.00 GELLED DIESEL $0.00 $450.00 HALLIBURTON $0.00 $5,677.00 LITTLE RED $1,760.00 $1,760.00 TOTAL FIELD ESTIMATE $1 35,702.00 $155,259.00 1. Type of Request: STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown __ Stimulate __ Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska. Ins. i3. Address P. O. Box 100360, Anchorage, AK 99510 ,5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 803' FSL, 812' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 2534' FSL, 2414' FEL, Sec. 16, T11N, R10E, UM At effective depth 2488' FNL, 2527' FEL, Sec. 16, T11N, R10E, UM At total depth 2488' FNL, 2527' FEL, Sec. 16, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 7 51 2 feet 6575 feet Plugs (measured) 6. Datum elevation (DF or KB) 106' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1E-12 /~/~*' t/~c-q' t~ O. Permit number/approval numbor 82-60 / 8-507 10. APl number 5o-029-20736 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7 4 2 7 true vertical6504 feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size 78' 16" 2501' 10 Cemented Measured depth True vertical depth 7510' 7" Perforation depth: measured 3/4" 217 Sx AS II 78' 78' 1050 Sx AS III & 2501' 2500' 250 Sx AS I 963 Sx Class "G" 7 51 0' 6 5 7 3' 7225'-7245', 7253'-7259' MD 701 0'-7090', 7200'-7209', true vertical 6159'-6225', 6316'-6323', 6336'-6353', 6360'-6365' TVD Tubing (size, grade, and measured depth) 3 1/2" 9.3 Ib/ft, J-55, 6919' MD RKB Packers and SSSV (type and measured depth) Camco TRDP-1AE SSSV @ 1904'; Baker FHL Packer @ 6848' 13. Stimulation or cement squeeze summary Well 1E-12 was perforated in the C Sands from 6484'-5444' MD on 8-14-88 (see attached). Intervals treated (measured) Treatment description including volumes used and final pressure 14. Re_Dresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1 28 96 439 1 283 170 Subsequent to operation 343 272 369 1207 207 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form i0-404 {~ev' 06/15/88 ~' Service Date SUBMIT IN DUPLICATE WELL SERVICE REPOR .ARCO Alaska, Inc. ' Sf~b$1dlary of Atlantic Richfield Compe~' WELL · CONTRACTOR .EMARKS i [-% I""1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather JTemp' J Chill Fact°r Visibility IWlndVel'Report 'F 'F mile. ARCO Alaska, In~. O 'Subsidiary of Atlantic Richfield Coml~ REMARKS C?F-I 0 IOPERATION AT RE~:~ORT TIME WELL SERVICE REPOF RI CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Report IChill Factor l Visibility °FI Wind Vel. 1. Type of Request: STATE OF ALASKA ALASKA OIL AND GAS ~SERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown __ Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska. In(~, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development * Exploratory _ Stratigraphic _ Service 4. Location of well at surface 803' FSL, 812' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 2534' FSL, 2414' FEL, Sec. 16, T11N, R10E, UM At effective depth 2488' FNL, 2527' FEL, Sec. 16, T11N, R10E, UM At total depth 2488' FNL~ 2527' FEL~ Sec. 16~ T11N~ R10E, UM 12. Present well condition summary Total Depth: measured 7512' MD feet true vertical 6575' MD feet 6. Datum elevation (DF or KB) 105.7 RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1E-12 ~,o~ 9. Permit num~3er/approval number 10. APl number 5o- 029-2073§ 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) NONE Effective depth: measured 7427' MD feet true vertical 6504' MD feet Junk(measured) NONE 13. Casing Length Size Cemented Measured depth Structural Conductor 78' 1 6" 217 Sx ASII 78' Surface 2501' 1 0-3/4" 1050 Sx ASIII & 2501' Intermediate 250 SX ASI Production 751 0' 7" 963 Sx Class G & 7510' Liner Perforation depth: measured 7200'-7209', 7225'-7245',; 7253'-7259' true vertical 6316'-6323', 6336'-6353', Tubing (size, grade, and measured deptl~, 3.5" J-55 @ 6919'~ MD ~,~ Packers and SSSV (type and measured d_.epth) True vertical depth 78' 2500' 6573' E'i' D 6360'-6365' JA,...; ~., ,.:;..~,9~i~::~ 41a,~ka 0il ~ Co/~& Camco TRDP-1AE SSSV @ 1904' MD, Baker FHL Packer @ 6848' MD Stimulation or cement squeeze summary Intervals treated (measured) 7200'-7209', 7225-7245', 7253'-7259' 14. Treatment description including volumes used and final pressure The A Sand in Well 1E-12 was fracture stimulated on 3/18/86. The treatment is described on the attached well service report. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 332 158 120 932 137 Subsequent to operation 15. Attachments Copies of Logs and Surveys run X Daily Report of Well Operations X 435 92 30 108 142 16. Status of well classification as: Oil X Gas Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~]/~,., /~ -.~ ~{~,,~/Y~ Title Sr. Operations Engineer Form 1~--~'04 ~ev - 06/1~5/88 Date 1 1/01/88 SUBMIT IN DUPLICATE '~ARCO Alaska, Inc( ~, Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT ' ;NTRACTOR IO~ER/~ION AT REPORT TIME REMARKS CC..,~3Ro$5~ WL. it Oil& ~Chorag I~ I-"l CHECK THIS.LB,IrtOCK If sUMMARY..CONTINUED, i ON BACK Weather [ TelflP:' l Chill'Fact°r" [ VislbilltYReport OF OF / miles IWInd vel' ARCO Alaska, Inc. Date: September 7, 1988 Transmittal #: 7285 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. Please acknowledge receipt and return 3 F- 1 3 Kuparuk Fluid Level Report 8 - 2 7- 8 8 Casing 3 K - 1 8 Kuparuk Fluid Level Report 8 - 2 7 - 8 8 Tubing 3 B - 1 3 Kuparuk Fluid Level Report 8 - 2 6 - 8 8 Casing ' 3 Q- 15 Kuparuk Fluid Level Report 8 - 2 7 - 8 8 Casing · '3 N-08A Kuparuk Fluid Level Report 8 - 2 6- 8 8 Casing ~, 3 H - 1 4 Kuparuk Fluid Level Report 8 - 2 6 - 8 8 Casing 1 E- 1 2 Kuparuk Fluid Level Report 8 - 2 6 - 8 8 Casing '~ 3 K - 1 4 Kuparuk Fluid Level Report 8 - 2 6 - 8 8 Casing ' 31 - 0 3 Kuparuk Fluid Level Report 8 - 2 6 - 8 8 Casing 1 Y- 06 Kuparuk Well Pressure Report 8 - 2 6 - 8 8 Both Sands · 1 Y-0 7 Kuparuk Well Pressure Report 8 - 2 6 - 8 8 Sand 'A' Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska ........... Date;., Chevron Unocal Mobil SAPC STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ,$SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend . ' Operation Shutdown ~ ~ Re-enter suspended well -- Alter cas,ng El TIme extension Change approved program Plugging "']. Stimulate .~' Pull tubing Amend order .r Perforate ~ Other 2 Name of Operator ARCO Alaska, ;[nc. Address PO Box 100360, Anchoraqe, Al< 99510 . Kup D~i~' ~levation (DF or KB) Unit or Property name aruk River Unit Location of well at surface 7. Well number 803' FSL, 812' FEL, Sec.16 T11N RIOE UM 1E-12 At top of proDuctive ~nterval ' ' ~ 8. Permit number 2534' FSL, 2414' FEL, Sec.16, T11N, RIOE, UN Permit #82-60 At effective depth 2488' FNL, 2527' FEL, Sec.16, T11N, RiOE, UN At total depth 2488' FNL? 2527' FEL, Sec.16, T11N, RiOE, UM 9. APl number 5O-- 029-20736 10. Pool Kuparuk River 0ii Pool 11. Present well condition summary Total depth: measured 7512' MD feet true vertical 6575' TVD feet Plugs (measured) None Effective depth: measured 7427' MD feet Junk (measured) None true vertical6504, TVD feet Casing Length Size Cemented Measured depth xxx~X~k~(~kxxxx Conductor 78' 16" 217 SX ASII 78' Surface 2501' 10-3/4" 1050 SX ASIII & 2501' xxx~nX~te 250 SX ASI I Production 7510' 7" 963 SX Class G 7510' xxx krk xxxx Perforation depth: measured 7200'-7209' 7225'-7245' 7253'-7259' MD true vertical6316,_6323, 6336'-6353' 6360'-6365' TVD feet Tubing (size, grade and measured depth) 3½" J-55 @ 6919' MD Packers and SSSV (type and measured depth) Ca.m.c.o TRDP-!AE SSSV @ !904' MD~ Baker F~L P~c~' o 6RaR' Mn 12.Attachments Description summary of proposal ~ Detailed operations program [l_] Acidize tubing and perforate C Sands' 7010'-7090' MD-RKB. 13. Estimated date for commencing operation 6-17-88 14. If proposal was verbally approved · ~ubsecluent ~Vo~: P. eportect on Name of approver /-', '~// ¢' /~ Form No. Dated~/~/__ Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed h Ct~~ ~ /6~...t~lj~~,~itle Sr. Operations Engineer Commission Use Only Conditions of approval Approved by N,otify commission so representative may witness I Approval No. ~ Plug integrity ~ BOP Test ~ Location clearanceI Approved Copy Returned URiGINAL SIGNED ...... ~ BY LONNIE C. SMITH Commissioner Form 10-403 Rev 12-1-85 True Vertical depth 78' 2500' 6573' RECEIVED by order of the commission Date (~_..~,~ ~ Submit in triplicate Date ~//,,,~/~, Al~=,,a Oil & G~s Anch0ra~a BOP sketch M. Ander, son/G. Wylie '6/17/88 Page 2 WELL 1E-12 ACID PROCEDURE 1) Titrate 15% HCI: 12% < HCI < 16% is acceptable. Test for FE < 300 PPM. * 2) Pump 25 BBis acid (1050 gals) at a maximum injection rate of I BPM. Displace acid with 35 BBIs diesel. Total displacement to packer is 60 BBIs. 3) Flow well back through surface facility. 4) Operations Engineering representative to take three pint or quart samples of fluid returned at 30 minute intervals starting 2 hours into flowback (to obtain a sample of spent acid). 5) After flowing well for 5 hours or until 100 BBIs of fluid have been produced, repeat steps 2 through 4. 6) Test well at normal gas lift setting (400 mcf/d). 7) Make gauge ring run to tag fill. Acid Composition (D~)w~tl Trade names.~ 15% HCI MSR-100; should include an iron chelating agent, 0.5% A250 corrosion inhibitor. 0.2% w35 anti-sludge additive. Fluid requirements 15% HCI Diesel 50 BBLs (2100 gals) 70 BBIs' * NOTE: A pretreatment emulsion test on an oil sample from the A Sand should be performed with both live and spent acid. 100% breakout should occur within 1 hour. Use the attached form for the emulsion test, ARCO Alaska Inc. is a subsldi,~y o~ Atlantic Richfield Company WELL 1 E-12 PERFORATING P~EDURE 1) MIRU Wireline for gauge ring run. PT lubricator to 3000 psi. 2) RIH. Tag fill (last tag at 7304' MD RKB 5/28/86). 3) POOH. RDMO Wireline unit. 4) Perform a 12 hour A Sand well test prior to perforating C Sands. 5) MIRU E-line perforating unit. PT lubricator to 3000 psi. 6) With well shut-in, RIH with CCL/perf guns/magnetic decentralizer. 7) Tie in depth using Schlumberger CBL dated 6/11/82 (short joints at _+ 7030'-7080' MD-RKB) 8) Open well to production to establish drawdown. 9) After verifying that well is flowing, perforate the following interval: Depth (MD-RKB) Log_ Shot Density_ Phasing 7010'-7090' CBL 6/11/82 8 SPF* 60° 'V' or D IL 6/9/82 ' 8 SPF requires two gun runs per interval oriented 30° to opposite sides of the hole, 10) Flow the well at least 15 minutes after each gun run. SI well and POOH for next gun run. 11) After last run, POOH, RDMO E-line unit. 12) Allow well to stabilize and perform well test. 3 1. 5000 PS, I?" WELLHEAD CONNECTOR FLANGE :2. 5000 PSI WIR£LINE RAMS (VARIABLE SIZE:) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PS1 4 1/6" FLOW TUBE PACK-Orr HI,RELINE BOP EO,UIPHENT ARCO Alaska, Inc. ( .... Post Office B6x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 March 11, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate are intent Kuparuk River Field: Well Action notices on the following wells Anticipated Start Date 1E-12 Stimulate 1E-14 Stimulate March 17, 1986 March 17, 1986 If you have any questions, please call me at 265-6840. Sincerely, g. B .~ Smal 1 wood Senior Operations Engineer GBS'pg-O015 Attachments cc' File KOE1.4-9 RECEIVrr) MAR ! 2 ]986 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of Well SURFACE LOCATION: 803' FSL, 812' FEL, SEC. 16, TllN, RIOE, tN 5. Elevation in feet (indicate KB, DF, etc.) _ 105.7' (RI<B) 12. 7. Permit No. 82-60 8. APl Number 50- 029-20736 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1E-12 11. Field and Pool KUPARUK RIVER FIELD 6. Lease Designation and Serial No. KUPARUK RIVER 0IL POOL ADL 25651, ALK 469 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" Sand in Kuparuk Well 1E-12 be fractured to improve production. The treatment wil consist of 150 bbls of gelled diesel with 6760~ 20/40 sand. ANTICIPATED START DATE: March 17, 1986 MAR 1 2 1986 ~rage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ ~ ~~1~..~.~~'? Title Ku~ruk The space below ~ Commission use Sr, Operations Engr. Conditions of APproval, if any: Approved by ~9roved Copy -" 'Roturned COMMISSIONER By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Attac~ent Page Drill Site 1H Wel 1 No. 1H-3 ~1H-4 ~.4. %1H-6 ~1H-7 ~1H-8 Log Date 8/16/82 8/13/82 6/21/82 7/20/82 7/22/82 Drill Site Well No. Log Date 1E Drill Site 1G Well No. "~IG-1 ""~1G-2 '"~1G-3 ',,IiG.4 %1G-8 Log D,ate. 9/7/82 ' 9/25/8~ 9/28/82 12/8/84/ 10/13/82 11/12/82 3/12/83 1/22/83 Dri 11 Si te Wel 1 No. L,O,,g Date 1F IF-1 2/19/83 1F-2 2/3/83 ""'IF-3 1/31/83 "1F-4 5/29/83 %1F-5 10/25/82 '~1F-6 10/28/82' '~ 1F-7 11/19/82x~ ~ 5/7/83 "/~% RECEiVi "/ FEB 2 1 1986 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc.[ [' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 R I.E'[' U R i;-! T 0 ' I I", A~ *! ,.,. Ii I T 'T' 17 I';:IECEIPT AH, D F"' !:? IE/.:.? t.! R E R E F:' 0 F;."FS' ' T 0 R Iii U E T U R N 2 W .... t S ~ P ['.{ U I:;: E I:: (:! F;,'"i' i Y "" t t ~ F:' Ii',' LJ R I:i: I::' 01:;,' "1" 2A .... t ,/ S;'¥AT:I:C (:.;.RA ( F:' L.. Ii!: A 5' Iii: N 0 2 B .... t ::.Y ''/ F:' B IJ R Iii: F:' 0 F;,"I" '2 B ..... i 6/ F:' B U I:;:. {!:' I::' 0 R'I" 2 !) "' t '1 ~"'"/i::' B U I::..' Iii: F:' C1F:.: T 2 i) .... i 5 '"'- F:' I:::lii: S ."i: U R Ii:..' F:' 2 I::'"" 8 ''/' F:' B U R Iii: F:' !:)R'I" 2 F:"- I t .b'ff F:' B UR Iii: F:' (:)I:;,"T 2 (..7. '"'7 ~ F:'B U R Iii: F:' 0 I::,:'r (') :5 .... i 3'"' Iii~5 I:7: U N:'J: i 0 4 "" 0 t .... 8 !5 I:': U N:I;: t ):) :1: '" l ' ", ... I::. r, T R F:' 'T' (') 4 .... ,::. 3 '"' ~:~ '5 F;..' LJ N ':J: t "[' I!i'. "l' H I S I::' A 1.;1'i I C t.J I... A R R liil P O R T 212 S V (3 4 -,:'.')9 .... Iii 15 I:;: LJ N :;l: t ,7' 4 .... t (').-.. 8'.5 1:;,' U N :',:: t (.) ::T, .... i t .... 8'.!~; R U N :il: i A I.. I... 0 F:' I':' 0 4 "- (:> 7.... 8 '.:.i.': F,,' U N:I:' t (-) 4 .... 'i 9'"' 8'.:J F:,' U i"i :ii: t (i:' 4 .... t 8'"' 8'.5 I:;: U i"J. :I',: t (')4 .... ti .... Iii !5 RUN :l::t I::' I';,' Y T I..i I N ,. ) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office"( 100360 Anchorage, ~,aska 99510-0360 Telephone 907 276 1215 DATE: APRIL 22, i985 TRANSMITTAL NO' 5i48 RETURN TO- ARCO ''^~" ~-'lL,--l~ ATTN.' RECORD£ CLERK AT.O-i t t 5B F:',O, BOX i ANCF!ORA6E, 'Al'--'. 'FF,'AH;~.HI'¥TED HEREWITH* ARE THE F'OL. LOWIU. G ITEMS, F'LEASE ACKNOWLEI)GE P'"-c-rz!F"r,; ..... ,- , AND RF~TU.RN ONE SIGNED L. CF~]-"r' OF THIS TRAN~MII'TAL ~OE/I NI'I"-,r'~M I TTEN T LIFT '"'OE;:./F'ROD I..f~(]~ & ' A' SAND SO,:r/c.r.,I, ....... , ,- .c....., ( .T. NITIAL ,?OE/F'BU SOE/F'BU $OE/F'BU $C~I..'-./' C' 'SAND F'BU SOE/SBI..IF'. - ' A ' & STATIC BHF' DATA STATIC BHF' DATA STATIC Bi'.IPDATA STATIC BI--IF' DATA STATIC Bf..IF' DATA STATIC BI-IF'DATA ,.~TATIC BHP DATA STATIC BHP DATA $'FATIC BHP DATA STATIC BhF D~..~,~-., STATIC BI'tP DATA STATIC BHF' DATA STATIC BHF' DATA STATIC BHF' DATA STATIC P"~' nATA !%, FI Y' STATIC n,..;p ......... ,.-~TA STATIC BHP DATA STATIC BHF' DATA STATIC BHP DATA STATIC BHP DATA ~-rA~IC BI-IF' YTATtC BHF' DATA F, R c. (, 9 H r.', r_- ,-~,,.. ~,,'.~. SURVEY F'BLI PRESSURE ) 'C' SANDS o. ",,zE, EIF'T. AC'/NO',,~LEDGED '_...,. DISTRIBUTION: q:F'AE DRILLING W F A~I-IER 3. CUr.,.:RIER L. .JOFIN£TON EXXON ::HEVRON hiOBIL F'HILLIF'5' OIL "? ,-'% M NSK r- -.,/ _.I..ERI, J. RATHHELL ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany 4/6-7/85 3/i t/85 ,. ~/~) Z. /C)r~.. 512/85 J/J/85 J/4/85 J/~ 8/85 ~/24/85 ~/24/8~ . S/3/85 3/2/8~ 3/2/85 S/2/85 S/~ 9/85 ~/2~/85 ~/2~/8~ ~;/26/8~ ~/25/85 ~/26/q t/2~ ~-/8~ t/~t/~ I/~/8~ f/f f/o,~ RECEIVED APR 2 5 lS85 Alas~a Oil & Gas.___Cons. Commission D A T E: _ SO~- - UN I ON i<,TWLIN/VAULT ARCO Alaska, Inc. Post Office I~ 100360 Anchorage, A,-.,ka 99510-0360 Telephone 907 276 1215 RETURN TO' ARCO ALA.~I<A, INC~ ATTN' RECORD~ CLERI< ATO-i i f 5B P.O. BOX ~00360 ANCHORAGE, AK 995t8 TRAN.~HITTED HEREWITH ARE THE FOLLOWING RECEIF'T AND RETURN ONE ,~IGNED COF'Y OF DATE- APRIL ~9 t98~' TRAN,~MITTAL NO- 5~47. F:' A G E OF' ':-2' · ~ ~,1 i I 1 Eft.':, F L,::.A,.?E ACI< NOWL..EDGE TH I &' 'FRANSM I TTAL. RECEIPT EVENT£.': 'A' EAND FRAC-GELLED WATEF~ ,.'?. TAT ! C BHP F'BU . F'BtJ F'BU F'RU PBLI ~ELI..ED HATER FRAC I.iYDRAULTC FR.~C POST FRAC TEHF' LOr;5' PDL.I F'DU .ETRTI'C DI-iP . F'DU PBU GELLED WATER BATCH FF:AC F'O,DT FRAC TEHF' LOG STATIC BI--IF' STATIC BHF' INJECTIV!TY TE~T I$IP STATIC [41'-I P Bi-iP F'BU PO,ST FRAC TEMP LOG' BI--IF' POY. T I---RAC TEHF' LOG .I. iYD, FRACTURE PBU PBU · 4/3/85 4/S/85 4/2/85 4/t -2/85 515f/85 ~I~t 185 4/~/85 4/~/85. 4/2/85 4/9- ~ 0/85 4/7-8/85 4/8/85 4/~-~3/85 4/~ ~-~ 2/85 4/~ 2/85 4/~ 2/85 4/~ ~/85 4/~ ~/85 4/~3/85 4/~ ~/85 4/~ 2/85 4/~ 2/85 4/~ 2/85 ' 4/~ 4-~ 5/85 4/~ 4/85 4/~ 5/85 4/~ 5/85 4/~ S-~ 4/85 4/~ 4-~/85 BF'AE B., CtJRRIER CHEVRON DISTRIBUTION: DRII_L!NG W, F'ASHER I .....IOHNSTON EXXON HOBIL PHILLIPS OIL N3K CLERK J. RAI'HMELL ARCO Alaska, Inc. ii a Subsidiary of AtlanticRichfieldCompany RECEIVED Alaska Oil & ~as Cons _C.~ DATE: ~ATE OF AL~~ 20H I 0 UNION i< ~ULIN/VAUI_T M EMORAN:'..)UM Stat of Alaska ALASKA OIL A~,ID GAS CONSERVATION CO1,R~ISSION TO: THRU: FROM: C. V~~.~erton DATE: February 5, 1985 .,..!~// F,LE NO: D. BILL. 10 Core, his s ioner TELEPHONE NO: Ben LeNorman SUSJECT: Witness Retests of Petroleum Inspector ARCO's Kuparuk 1C-6, Low Pilot and ARCO's Kuparuk 1E-12 SSSV, Kuparuk River Unit. Saturday, February_ 2, 1985: I departed my Dome at 6:00 am for a ~..30 am. Sho~t~"and 7~']-0-~.~ departure via Alaska Airlines, Flt. #55 for Deadhorse, arriving at 9:10 am. Weather: +2°F, clear. BOPE tests on ARCO's Kuparuk 2U-1 were completed, the subject of a separate report. Sunday~ February_3, ~98~: BOPE tests on ARCO's Kuparuk 2W-1 were completed, th~ subject of a separate report. Low pilot on ARCO's Kuparuk 1C-6 and SSSV on ARCO's Kuparuk 1E-12 were retested successfully. Safety valve test report is attached. Mond_a~, 1985: Twenty-one co~ponents retested on hig-[~een ARCO Prudh0e. B~'y wells, the subject of a separate report. I departed Deadhorse via Alaska Airlines, Flt. ~56 at 5:40 pm arriving in Anchorage at 7:20 pm and at my home at 7:50 pm. In sunmnary, I witnessed successful retests of ARCO's Kuparuk 1C-6 low pilot and 1E-!2 SSSV. Attachment 02.00IA(Rev. 10,79) 0 .',';C-, #5 4/8o STATE OF ALASKA OIL & GAS CONSERVATION COMMIS~-~N Safety Valve Test Report Date Co.~c. P~SS~S - PSIG Operator Well' Pilot' FLG SI ~N SSV SSSV Plt/Loc No. ' High ~w TBG TBG CSG IP FP Test IP FP Test ~-~'PT~ ~ ~o ~ " . . ,,, .... ~,, i ....... I i " . ,,. I ,, ...... .... ., ..................... ..... .,, ,,, .................. ........ , , ....... ,, ~ .... .......... .................... ......... .......... ..... ........... ~ ...... _ .......... , ...... .......... Remarks:/~7 ;:,~ ,, .... .... ..... .Inspectors ARCO Alaska, Inc, F:,:, Ofi:c{ .x 360 Ancho;age. Alaska 99510 ~ele~hone 907 277 5637 Date: 9/04/84 Transmittal No: 4712 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 ~ransmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. PRESSURE ANALYSIS/PBU SURVEYS & SEQUENCE .QF EVENTS 1E-12w/~ 8/17/84 1E-15~ STATIC BHP 8/05/84 1F-2~"/ SIBHP 6/04/84 1F-3~ ~ 4/30/84 1F-4 '~ SlBHP 6/04/84 1F-5-~.(~~ 5/08/84 1F-6 - SIBHP 6/05/84 1F-?" SIBHP 12/19/83 1F-7" SIBHP 6/05/84 1F-7/ SIBHP 4/30/84 1F-9-'~ GAS LIFT. SURVEY 4/29/84 1 -9 / W0 12/26/83 12/20/83 1F-10/ ~OWN - · 12/21/83 1F-11-- CPB[~I./ , 12/23/83 1F-11-~-"P~ZDRAWDOWN-_-_~3/15/84 1F-1lj PB-UTTTRAWTR)%~ 12/24/83 1F-12~ ~U!DPAnmn~!.-A 3/09/84 1F-12~ ~U'"A" S~ 7/03/84 1F-12~ PBU/PDD 3/10/84 1F-12~ PBU/Pg~ "A" 3/09/84 '~ '"A" 1F-13~.~ , _S.~D~ 5/03/84 1F-13~/ SlBHP-NEW-"C" 1/26/84 /04/84 Receipt Acknowledged: 1F-16~/ 1F-16 - /cat DISTRIBUTION B. Adams F.G. Baker P. Baxter BPAE D & M Drilling Geology Mobil pL~S&&L~~ "A" S ~ANS~~ V~ Date: ~ ~,tas~'a 0il 6 (~as Cons. Commiss Anchorage C. R. Smith state of Alaska Sohio W.V. Pasher G. Phillips Phillips Oil J.J. Rathmell Union ~hevron NSK Operations R&D Well Files ARCO Alaska, inc. ':,: -;':e:,,. cL':'- 277 5~37 Date: 8/16/84 Transmittal No: 4686 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 /~ansmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. PBU SURVEYS/Pressure Analysis lC-1 Static BHP 4/12/84 Camco lC-5 " " 4/13/84 " 1C-6 Gas Disp. 5/16/84 Otis lC-7 PBU 4/20~21 Camco 1C-9C~alloff Test 4/29/84 " lC-10~" " 5/06/84 " 1D-1 Static BHP 4/19/84 " 1D-5 Falloff Test 4/29/84 Otis 1E-12 Flow BHP/GLV 7/01/8484 Camco 1E-17 Static BHP 1/8-11/84 Otis 1E-18 " " 1/03/84 " 1E-24 Injectivity 6/21-22/84 " 2F-8 T Log PBU 5/06/84 Otis 2F-11 Initial PBU 5/22/84 Camco 2F-12 Initial Well 5/15/84 '" 2F-13 " " 5/14/84 Ot±s 2F-14 PBU 5/03/84 " 2F-15 PBU State 4/26/84 /cat Receipt Acknowledged: B. Adams Camco DISTRIBUTION F.G. Baker P. Baxter BPAE Drilling Geology Mobil G. Phillips Phillips Oil J.J. Rathmell State of Alaska · Sohio Union Chevron NSK Operations R&D Well Files KUPARUK ENGINEERING TRANSMITTAL # ~ ~.~ TO: William Van Allen FROM: D.W. Bose/Shelby J. Matthews Transmitted herewith are the following: PLEASE NOTE' BL - BLUELINE, S - SEPIA, F - FILM, T - TAP~PY RECEIPT ACKNOWLEDGED: -R E V DATE' APR 2 v,1983 ' PLEASE RETURN RECEIPT TO: ARCO ALASKA, INC. ATTN: SHELBY J. MATTHEWS - AFA/311 P.O. BOX 360 ANCHORAGE, AK. 99510 Alaska Oil & Gas Cons, Commission Anchorage February 16, 19 83 ARCO Alaska~ Inc. P.O. Box 360 Anchorage, Alas -ka..9 9510 Re~ Subsequent Reports, Sundry Notices and Reports on Wells (Form' 10-403 ) Attn~ Pete Van Dusen _.. District Drilling Engineer For the following lists of "Notice of Intention To:" Sundry Notices and Reports' on Wells (form 10-403) this office does not have on record the "Subsequent-Report of~" defining the action taken on the approved intention. Please advise this office by $~bsequent Report of the disposition of the intention. We 11 ARCO Dar e ~. · DS 14-18 2/11/81 : W. Sak River State B5 6/9/81 . DS .12-8A 10/23/81 DS 12-?~ -11/23/81 DS 13-3 11/2/81 DS 12-4 12/15/81 BP 24-10-14 DS 13-2 West Bay St ate 1 BP 31-10-16 DS 15-3 Oliktok Pt. 1 DS 15-3 .._ DS 5-11 ~ ..~. DS 16-13 N.-Prudhoe Bay St. 2 Rup aruk 1E-12 12/15/81 12/23/81 2/2/82 2/23./82 : /17 / 82 3/23/82 '3/23/82 4/2/82 4/5/82 6/2/82 6/2/82 Brief Description_ of__ Int_en_tion Change course of this well. Workover Abandon lower borehole prior to sidetrack Abandon l°wer borehole prior .to sidetrack Pull and replace tubing Abandon lower borehole prior to sidetrack Plug and abandon Pull and replace tubing Test Lisburne formation Plug and abandon· Change setting depth 9 5/$" casing Deepen 8% hole to basement Change set%lng depth 9 5/8" casing Pull tubing and repair casing Sider rack Abandonment 'proc edure C~ange grade L-SO portion of 7" casing ARCO Exploration ~. any Exploration utions - Alaska Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 SAMPLE TRANSMITTAL SHIPPED TO:STATE OF ALASKA Alaska 0il & Gas Conservation Comm. 3001 Porcupine Dr. Anch.,AK. 99501 ]]AND CARRIED by R.Pittman DATE: Feb. 3,1983 OPERATOR: SAMPLE TY~E: ARCO Core ch~ps NAME: Kuparuk 1E-30,1H-6,1G-4, 1E-12,1E-13,and 1E- 14. SAMPLES SENT: ~uparuk 1E-30 b750 - 7084 , Kuparuk 1H-6 6364 - 6421 6424 - 6539 6630 - 6689 Kuparuk 1G-4 6444 - 6467 6469 - 6503 6520 - 661.6 6624 - 6637 6761 - 6885 ALL SAMPLES ARE AT ONE FOOT INTERVALS. Kuparuk lE-12 7016 - 7018 7026 - 7038 7040 - 7097 7238 - 7266 7270 - 7310 Kuparuk I'E- 13 7086 - 7173 7176 - 7228 7294 - 7322 7324 - 7352 7354 - 7439 ,Kuparuk 1E- 14 6603 - 6628 6635 - 6645 Box Count Kup. 1E-30 = 13 Kup. 1H-6 = 9 Kup. 1G-4 = 10 'Kup. 1E-12 -- 6 Kup. 1E-13 = 12 Kup. 1E-14 = 14 Total boxes =64 6649- 6766 6769 - .6934 , 'NT BY: . . - _ Paleo Lab Tech. RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: RECEIVED BY: ARCO EXPLORATION CO. P. O. BOX 360 ANCHORAGE, AK. 99510 ATTN: R. L. BROOKS DATE- · RFCFI\./ P KUPARUK ENGINEERING TRANSMITTAL FROM: WELL 'NAME: D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PLEASE NOTE: ~~ F - FILM, T' - TAPE RECEIVED ~/) ~.~~/..~ AUG-6 ~982 RECEIPT ACKNOWLEDGED: ~. DATE: · ~S AlaskaOil&G'asCons. CommissJo~ PLEASE RETURN RECEIPT TO:../ ARCO. A KA, INC. Anchorage ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE., AK 99510 KUPARUK ENGINEERING TO: Transmitted herewith are the following: PLEASE NOTE: ~/~~~SE~ F- FILM, T - TAPE RECEiYE ) PLEASE ~TU~ ~CEIPT TO: '' ARCO ALAS~, INC. ~ ~ ,~ ~ , ~'~ · ,:~ ~. O~ ~G~Cons Cornish' ' " P. O. BOX 360 .. 'ANCHO~GE, ~ 9951'0 :ka, Inc. [ Post Office Box~ Anchora.qe, Alaska 99510 Telephone 907 277 5637 July 12, 1982 Mr. C. V. Chatt'erton State of Alaska Alaska Oil & Gas.ConserVation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for June on these drill sites- 2-24 14~22 2,25 15-6 6-17 18-1 13-22 18-2 13-25 1E-13 13'26 1H-8 14-15 Also enclosed is a well completion report for Kuparuk IE,l.~,;~,and subsequent sundry reports for- 3-14 14-6 4-9 15-3 4-15 Eileen No. 1 11-4 NGI-7 (Since the information on the Eileen well is of a confidential nature, we would appreciate it if you could store it in a secure a rea. ) Surveys for 2-22 and 13-21 are being reran; completion reports for these wells will be submitted when approved surveys are received. Sincerely, P. A. VanDusen Regional Drilling Engineer PAV/JG:llm Enclosures GRU1/L48 ARCO Alaska. Inc. is a subsidiary of AtlanlicRichfieldCompany WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL~Xx GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-60 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20736 4. Location of well at surface 9. Unit or Lease Name 803' FSL, 812' FEL, Sec. 16, TllN, R10E, UM '~ Kuparuk River Unit At Top Producing Interval VERIFIED I 10. Well Number 2534' FSL, 2/+14' FEL, Sec. 16, T11N, R10E, UN Surf.~F 1E-12 At Total Depth lB. H.~ 11. Field and Pool 2488' FNL, 2527' FEL, Sec. 16, T11N, R10E, UM -- Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool 105.7' RKBI ADL 25651 ALK 469 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 05/28/82 06/09/82 06/13/82I N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set 121. Thickness of Permafrost 7512'MD,6575'TVD 7427'MD, 6504'TVD YES IX1 NO [] 1900' feet MD 1900' (approx) 22. Type Electric or Other Logs Run D I L/SP/GR/SFL/FDC/CNL/Cal, Gyro/CBL, CBL/VDL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED lb' 62.5# t-40 Surf 78' 24" 217sx AS II 10-3/4" 45.5# (-55 Surf 2501' 13-1/2" 1050sx AS III & 250 sx AS II 7" 26.0# (-55/ Surf 7510' 8-3/4" 963sx Class G L-80 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) 7253 ' -7259' 3-1/2" 6935' 6860' 7235' -7245' 7225'-7235' 4spf,90° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7200'-7209' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST · Date First Production I Method of Operation (FloWing, gas lift, etc.) 1 Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD e 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 li~hology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See attached core description JUL 1 21982 Alaska Oil &a~ ,,Gas Cons. Commission GRU 1/WC4 · ,nc.orate Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. " 30. ] . GEOLOGIC MARKERS FORMATION TESTS i NAME Include interval tested, pressure data, alt fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. J Top Upper Sand 7009' 6158' N/A Base Upper Sand 7086' 6221' Top Lower Sand 7173' 6293' Base Lower Sand 7333' 6426' -- 31. LIST OF ATTACHMENTS Dril]in9 History, Core Description, Gyroscopic Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Lz~TJ,~.~./~)"~- ~z~_''~l~''z Title Sr. D rilli n g E ngr ~.//~ ~ 1i . /.,__._ /,,_ · 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 (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic PumP, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none" Form 10-407 Kuparuk 1E-12 Drilling Hi story NU Hydril & diverter. Spudded well @ 0030 hrs, 05/28/82. Drld 13-1/2" hole to 2541'. Ran 60 jts 10-3/4", 45.5#, K-55, BTC csg w/shoe @ 2501'. Cmtd w/1050 sx Arctic Set III & 250 sx Arctic Set II. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to' 1500 psi. Drld 8-3/4" hole to 6764'. Attempted to pull wear bushing. Pulled on tst jt - stripped out of J-slot @ 100,000 #. Set RTTS w/SSSV on top @ 198'. Ran 7 stands HWDP below RTTS; tstd RTTS to 1000 psi. ND stack. Cut out wear bushing; dropped 2 pieces downhole (5" x 6" x 5/16" & 1-1/2" x 6" x 5/16") NU stack & tstd to 3000 psi - ok. Recovered 5" x 6" x 5/16" fish. Unable to recover other piece. POH w/SSSV & pkr. Set wear bushing. Ream 90' to bottom & cont drlg to 7016'. Cored #1 f/7016'-7026' (recovered 2-1/2' - sand). Cut core #2 f/7026'-7040' (recovered 12-1/2'). Cut core #3 f/7040'-7100' (recovered 60'). Reamed 8-1/2" hole to 8-3/4" hole (7016'-7100'). Drld to 7225'. Cut core #4 f/7238'-7269' (recovered 31') Cut core #5 f/7269'-7312' (recovered 41'). Tstd BOPE to 3000 psi - ok. Ream 8-1/2" rathole f/7238'-7312'. Drld 8-3/4" hole to 7512' TD (06/09/82). Ran DIL/SP/GR/SFL/FDC/CNL/Cal f/7512'-2501'. Ran 143 jts 7", K-55, 26#/ft, BTC csg & 20 jts 7", 26#/ft, L-80 BTC csg w/shoe @ 7510'. Cmtd 7" csg w/963 sx Class G. Instd 7" packoff & tstd to 3000 psi - ok. Ran gyro/CBL. Arctic packed 7" x 10-3/4". annulus w/300 bbl water, 250 sx AS II cmt, & 97 bbl Arctic pack. Ran CBL/VDL/CCL/GR f/7342'-2000'. Reran CBL f/7364'-6500'. Perf'd 7253'-7259', 7235'-7245' (4 spf, 90° phasing). Perf'd 7225'-7235' & 7200'-7209'. Ran 3-1/2" perf completion assembly w/tail @ 6935' & pkr @ 6860'. Tstd tbg hanger to 5000 psi - ok. Tstd packoff to 3000 psi - ok. SSSV nipple @ 1900'. ND BOPE. NU tree & tstd to 3500 psi - ok. Disp well with diesel. Dropped ball. Closed SSSV. Secured well & released reig @ 1830 hrs, 06/13/82. JG:llm 07/07/82 GRU1/DH23 JUL 1 2 i982 Aiaska 0il & ~as Cons. Commission Anchorage ARCO Alaska, Inc. Date: Subject: Internal Correspor~ ,ce July 6, 1982 Kuparuk 1E-12 Core Descriptions From/Location: To/Location: M. P. Matthieu - ANO-908 J. A. Gruber - AN0-354 7016' - 7026' Cut 10' Recovered 2.5'. Sandstone, brown, fine to medium grained, good show. 7026' - 7040' Cut 14' Recovered 11.3'. Sandstone, greenish-gray, medium grained, glauconitic, good shows. 7040' -7099' Cut 59' Recovered 58.5'. Sandstone, brown, fine grained, numerous cemented zones, fair to excellent shows. Last five feet interbedded sandstone and shale. 7238' - 7270' Cut 32' Recovered 30'. Interbedded sandstone and shale, with proportion of sandstone increasing downward from 20% to 90%, oil stained, fair shows. 7270' - 7312' Cut 42' Recovered 41'. Interbedded sandstone and shale, with shale increasing downward to 90%, oil stained. · M. P. Matthieu GeolQgist Extension Exploration MPM: kdm RE£EIVED JUL 1 2 I982 ~!aska Oil & Gas Cons. Cornmissi~n Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany COMPLETION REPORT ARCO OIL + GAS GYROSCOPIC SURVEY RADIUS OF'CURVATURE METHOD OF COMPUTATION COMPUTED FOR SDI BY OCEANTECH(FM L!NDSEY RECORD OE ASSOC.) SURVEY '0 24 JUNE 82 KUPARUK E-12 KB ELEV 105.7 FT. TRUE MER. S. DRIFT VERTICAL SUB DRIFT DEPTH ANGLE DEPTH SEA DIREC D M DEG. 0 0 0 100 0 10 200 0 52 3300 0 400 0 1 50 0 0 6 600 0 12 700 0 19 800 0 900 0 16 1000 0 7 I I .0.0 0 16 120.0 0 7 130.0 0 24 140'0 0 16 1500 0 22 1600 1 7 1700 1 13 1800 0 58 1900 '1 45 2000 2 49 21 O0 3 18 2200 :3 55 230.0 4 38 2400 4 19 .00 100 O0 2O0 O0 299 99 399 99 499 99 599 99 699 99 799 99 899.99 999,99 1099.99 1199.99 1299 99 133399 98 1499 98 1599 97 1699 95 1799 93 1899 91 1999 82 2099 68 2199 48 2299 20 2398 90 -los. --5. 94, 194. 294, 394, 494. 594, 694. 794. 894, 994. 1 094, 1194. 1294. 1.394, 1 494, 1594, 1694, 1794., 1894, 1993,, 20933. 2193. 2293, 7O S .OOE 70 S53,7.2E' 30 $89,23E 29' 824.52E 29 29 29 29 29 29 29 29 29 29 .28 28 27 25 233 21 t2 98 78 50 20 872.83W 866,1 7E 84 7, OSE N67, .40W N 9,40E N72.70W N 1 7,63E 82.0.70E S 5,330E - N80. 0SE 853 25E N 8 80W N19 ??E S88 83E S47 28E S 8 55E 812 033W - S 4,98W · S 3.30W S 6,60W S 5.48W TOTAL COORDIHATES C L..O S U R E S DISTANCE ANGLE D M, S -, 0 0 41 .57 .91 1,16 1 1 . 07 ,21 1,29 .59 ~,46 5.42 10,70 16,97 24,41 32.20 S ,00 W S .06 E S ,90 E 8 1,54 E tS.(¢ ific !': n tiona' S I, I"3 E S 1,48 E S 1.50 E S 1.83 E S 2,38 E S 2.75 E N 2,8? E 4,44 E 6,17 E 7.26 E 7.14 E 6.35 E 5.90 E 5,25 E 4.43 E ,00 S 90 0 0 W ,!4 S 26 51 30 E ,99 S 65 46 45 E 1,74 S 61 55 24 E · . 1.75 :3 60 14 33 E 1.79 S 57 58 58 E 2,05 S 57 48 28 E 2,07 S 48 39 51 E I,.78 S 52 1 27 E I :55 S 55 17 45 E 1,28 8 61 52 46 E 1 .51 S 67 39 54 E 1.75 S 58 51 59 E 2.17 S 57 40 28 E 2.71 S 61 33 44 E 2,95 .S 68 49 I E 2.88 N 85 50 4 E 4,63 N 73 48 36 E 6.20 N 84 30 18 E 7,41 S 78 37 21 E 8.97 S 52 47 29 E 12,44 S 30 42 25 E 17,97 S 19 9 42 E 24,97 S 12 8 39 E 32.',50 S 7 49 54 E DOG LEG SEVERITY DEG../IOOFT .000 .167 ,700 .817 .033 .083 ,loo .133 ,2833 .217 ,133 ,'133 .133 ,267 .133 ,100 ,750 ,105 ,250 ,784 1 . 068 ,484 ,617 .734 ,317 SE~ON DIS1 ,CE ,00 -.14 -.90 -1 ,63 -1 ,65 -1 .71 -I ,96 -2,05 -1 ,75 -1 ,50 -1 ,19 -1 ,35 -2 ,53 -2 60 - 1 '? £ -1 9.3 -3 58 -5 85 -8 77 -1'2 25 -16 70 -21 92 -27 28 0 ARCO KUPARUK E-12 HERS, DRIFT DEPTH ANGLE D H 25-00 3 9 2600 2 46 2700 2 46 2800 6 0 2900 8 34 3000 1 0 6 31 O0 12 58 3200 17 4 3300 18 40 34.00 21 30 3500 24 7 36 00 26 4 3700 28 25 3800 30 50 390:0 33 22 4000 35 56 410.0 38 43 4200 41 16 4300 44 5 44'00 46 3 45O0 46 16 46-00 45 39 4700 45 1 0 4800 44 52 4900 '44 34 5000 44 33 510-0 44 19 520'0 44 18 530.0 43 52 TRUE VERTICAL DEPTH 2498.68 2598,55 2698,43 2798. 12 2897,3 2995,98 3093.95 3190.51 3285,67 3379.58 3471,75 3562.31 3651 .21 3738,13 3822,82 39 OS. 06 3984 4061,14 4134.64 4205,25 4274.52 4344,03 4414,23 4484,90 4555,94 4627, 18 4698,59 477 O, 15 4841 ~-~UB SEA 2392,98 2492,85 2592,73 .2692,42 279! 289 O, 28 2988,25 3084,81 3179,97 3273.88 3366,05 3456,6 3545.51 3632.43 37'17,12 3799.36 3878.85 3955.44 4 028,94 4 099,55 4168,82 4238,33 4308.53 4379,20 4450,24 4521 . 48 4592,89 4664.45 4736.28 GYROSCOPIC SURVEY RECORD OF SURVEY JOB NO 1357 24 JUNE 82 DRIFT DIREC DEG, S 4,82E 8, !, 22E H88.23W N66,13W N64.4 OW N57,87W N53.47W N59,35W. H61 , 15W N56.82W N49. OOW N46.. 52W N47.55W N47 .SOW N47.47W N47.82.W N47.67W N47.7 OW N47.83W N4 7,62.W H47.75W N47.55W N46.95W N46.30W N45.47W N44,45W H43,70W N43,1 N42.32W TOTAL COORDINATES 38,72 s 43;'88 s" · , 46.93 8 45,24 $ 39,93 S 32,10 $ 4.39 E 4.66 E 1,59 E 5.82 !J !7,34 W 31,55 W ' C L.O S U R E S D I STANCE ANGLE D M · 20l~83 $ 48,05 U . 52',37 S 66 ~50 '$ 69,64 W 69,94 $ 84 · 96, . o4 49~~~~111C !64,34 N 72 78 ~~:.e~lti~ 2 o3, ~e H 67 142~5 N'~251,99 ~ 294,90 N 61 . '38.,96 S 6 28 14 E 44,13 S 6 3 57 E 46,96 S 1 56 20 E 45,62 S 7 19 32 W 43,54 S 23 28 27 W 45.01 8 44 30 8 W 33 52 W 40 12 W 48 49 W 21 46 W 23. 24 W 41. 43 W ! 33W 58 31 Gl 23 5 W 7 35W 5 56 W 15 49 tJ 178.75 H 297,2'0 W 346,82 N 58 217,07 N 339,23 W 402,74 N 57 257,86 N 384.12 W 462.64 N 56 301.14 N 431.65 W 526,32 N 55 346,71 N 481,,85 W 593.',62 t,I 54 _'394,3.3 N 534.24 W 664,01 N 53 34 5 W' 442.89 .H 587.57 W 735,79 N 52 59 32 W 491,3.1 N 640,70 W 807,39 N 52 31 2 W 539,66 N 693.00 W 878.34 N 52 5 26 W 588,25 N 744,42 W 948.79 N 51 41 1 W 637,24 N 794,95 W 1018.84 H 51 17 1 W 686.90 N 844.53 W 1088.61 N 50 52 36 W 737,20 N 893.23 Gl 1158,15 N 50 28 0 W 787.94 N 941.23 W 1227,51 N 50 3 57 Gl 839,05 N 988.43 W 1296,53 N 49 40 22 W DOG LEG SEVERITY DEG/IOOFT 1.184 ,367 ,217 3,242 2.584 1,530 2.875 4.148 1,611 2,876 2,924 2,008 2.362 2,433 2.534 2.570 2,784 2,550 -2,817 1,953 .228 .625 556 441 509 50t 434 285 579 SECTION DISTANCE ,~19 -36,57 -30,46 -18,91 -3,70 !5,61 40,56 69,51 102,13 140.00 182.09 227,59 276,68 329,47 385 ~ 94 44~4 50'. 36' 577.26 647,54 719,14 790,51 861 .28 '331 ,66 1 001 , 76 1 071,75 1141 .64 1211 .42 1280.95 0 ARCO KUPARUK E-12 GYROSCOPIC SURVEY JOB NO 1357 24 © JUNE 8'2 RECORD' OF SU ¥'EY TRUE HERS, DRIFT VERTICAL SUB DEPTH ANGLE DEPTH SEA D M DRIFT DIREC DEG. TOTAL COORDINATES CLOSURES DISTANCE ANGLE D M 540.0 43 41 4914.17 4808.47 55'80 4:3 22 4986.67 4880.97 560.0 43 10 5059.48 4953.78 5700 42 46 5132,64 5026.94 58'00 42 ? 52 06.44 5100.74 59'0'0 41. 16 5281.11 5175.41 6000 40 43 5356.59 5250.89 6100 39 16 5433.20 5:327.58 62(10 38 52 55!0,82 5405.12 630.0 39 4 5588,56 5482,86 6400 38 7 5666.72 556.!,02 65'00 37 34 5745.69 5639,99 6600 36 40 5825.42 5719.72 6?00 36 I-6 5905.83 58'00.!3 6800 35 26 5986.88 5881,18 6900 35 1 6068.55 5962.85 7000 34 37 6150.6:3 6044.93 7100 34 28 6232.99 6127.29 72'00 34 31 6:315.40 6209.70 .7300 33 39 6398.22 6292.52 THE FOLLOWING '_-. H41.37.W N4O.58W N39.30W N38.72W H3?~I.7W N36,90W N36.32W NJS.S2W N34.77W H34,00W N32.48W N31.35W N29.60W N28.13W N26.92W N26.02W N24.95W N23.97W H24.OTW N23.20W 890.60 H 1034,58 W 942.69 N 1079.75 W 995',!6 N 1123.76 W 1048,'13 N t166,66 W !'!0-!.35 N !208.16 W I154.4.4 N .1248.21 W 1.207, 1,0 H 1287.33 W 1764.74 N 46 50 1.25'~5 N 1325,04 W !82.7.89 N 46 27 ,31 8~7~,.j_36 ~! _,~ 1889.75 , 46 5 1'36Z~~.~~, 1951.38 N 45 42 1414~~~~~~~w w_,~¢~ific 2012,33 N 45 1466;~~6~~ 2072.05 N 44 56 1570,9; 87.85 N 44 6 1622.88 N -1549.85 W 2244.05 N 43 1674.53 H 1575.56 W 2299.23 N 43 15 1726, 89 H 1600,14 ~ 2353.69 N 42 1777,72 H 1623,62 1~29.46 H 1646,,6~ ~ I~SO.80 N 1669.14 IS EXTRAPOLATED TO TD 1365.!1 N 49 16 37 W 1433,30 N 48 52 46 W 150.1';06 N 48 28 22 W 1568.34 H 48 3 48 W 1634.81 N 47 38 52 W 1700,.2:3 N 47 14 6 W 32 W 38 W 38 W 42 W 29 W 21W 5:3 W 2407.58 N 42 24. 21 W 2461 .40 N 41 59 24 ~ 2514.65 N 41 35 ~6 ~ 751'2 33 39 6574.70 6469,00 N23.20~ 1988,77 N 1715.42 W 2626.38 N 40 46 46 W BOTTOM HOLE CLOSURE 2626.38 FEET AT N 40 46 46 W DOG LEG SEVERITY DEG/IOOFT .483 .498 ,628 .496 953 858 603 '469 497 355 112 ,693 082 ,661 ,914 ,511 ,.528 · .349 ,0,$6 ,907 .000 SECTION DISTANCE 135~13 141 lOO 1487,55 1555 68 1623 08 1689 45 1754 87 1818 91 1881 65 1944,16 2006, O0 2066.61 2125.99 2184.15 2241.17 2297.08 2352,-48 240~ ~1 2460.85 25~4.40 °'26 38 0 ARCO KUPARUK E-12. GY, ROSCOP~IC SURVEY JOB HO ! ~57 IHTERPOLATED TRUE VERTICAL DEPTHS, -COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE CODE MEASURED VERTICAL TOTAL NAME DEPTH DEPTH COORDINATES C L 0 $ U DISTANCE R E RNGLE D M S 24 SUB SEA 0 JIJNE 82 TP. UP/SI,ID 7009 6.158,04 t 730,~'3 H E~$. UP,."SHD 7086 622! . 45 .t TP. LI.J.,'SND 71 73 62.93.15 ! 8.15,49 N BS. LId/SND 7333 6425.69 1908.23 N PBTD 7427 (5503.9.4 1 '3Se;., 36,N TD 751;2 6574,70 1988,77 H 1602,2<) 14 1620,40 W 1640,44 Id 1678,29 W 1704.33 t4 1715.42 Id 2400,06 2446,85 2541,26 2617o32 2626,38 H 42 47 35. W N 42 27 56. W N 42 6 '1 W N 41 19 53 W N 40 37 48 W N 4O 46 '46 W 6052,34 6115,75 6187,45. 6319.99 6398.24 6469.00 Scientific Drilling International © RRCO KUPARUK E-12 GYROSCOPIC SURVEY' JOB NO 1357 MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN !00 FEET OF SUB SEA DEPTH'. MEASURED DEPTH TRUE VERTICRL SUB MD-TVD DEPTH SEA DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 206 306 406 506 606 706 806 906 ! 006 1106 1206 1306 1406 1506 1606 1706 1806 1906 2006 2! 06 2206 2307 2407 2507 ';'607 2707 280:9 2909 3010 3112 3216 3428 3537 J649 206, 1 O0 306. 200 406. 300 506, 400 606, 500 706. 600 806. 700 906. 800 1 006. 900 ! I 06. 1 000 1206. 1 I O0 1306. 1200 1406. 1300 1506. 1400 !606. 1500 1706, 1600 1806. 1700 1906, 1800 2006, 1900 21 06, 2000 2206. 21 O0 2306. 2200 2406, 2300 2506. 2400 2606, 2500 2706. 2600 2806. 2700 2906. 2800 3006. 2900 31 06. 3000 3206, 31 O0 3306. 3200 3406, 3300 35O6, 3400 3606. 3500 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 '0 0 0 0 0 I I ! 2 4 6 10 t-5 22 31 42 0 0 0 0 0 0 0 0 0 0 Scientific Dril'ling i? Internati°n a! 0 , ' O 0 0 0 , 1 O 0 0 2 2 4 5 7 .4! ,83 1.1!. 1 I, 09 .60 o-92' I .15 31 31 29 52 1 .64 5.71 11 .04 17.40 24.94 32.71 39.10 44.23 46.91 ,14.92 39 31. 16 19..20 4.11 !2.11 32.34 60.03 93,21 SS 8 S $ 8. S S S S S S S S H N N S S 8 S 8 S S S S S $ 8 S S N N N I 5 7 lO 13 16 20 .99 E 1,54 E 1,52 E 1.52 E 1,75 E !,52 E 1,40 E ! 25E 1 13 E 1 4! E I 50 E 1 87 E 2 40 E 2 75 E 2,91 E 4.57 E 6,24 E 7,29 E 7.08 E 6,32 E 5.87 E 5,19 E 4.38 ';E 4,42 E 4.65 E 1,22 E 6.56 W 8,49 W 3,04 W 0,28 W 3,69 W 2,30 W 4,39 W 8.20 W 3.87 W 24 JUNE © 0 ARCO KUPRRUK E-12 GYROSCOPIC SURVEY' HEASURED DEPTH AND OTHER DATA FOR EVERY EVEN !00 FEET OF ,JOB NO 1357 SUB SEA DEPTH. 24 0 JUNE 82 MEASURED DEPTH 3762 3880 400! 4127 4260 4401 4545 4688 4829 4970 5110 5250 5388 5526 5663 5799 5933 6064 6193 6322 6449 6575 6700 6823 6945 7067 7188 7309 7429 TRUE VERTICAL SUB MD-TVD DEPTH SEA DIFFERENCE 3706. 3600 3806, 3700 3906, 3800 4006, 3900 41 06, 4000 4206. 4J00 4306, 4200 4406. 4300 4506, 4400 4606. 4500 4706, 4600 4806. 4700 4906. 4800 5006. 4330.0 51 06. 5000 5206, 51 O0 5306, 5200 5406, -5300 5506. 5400 5606, 5500 5706, 5600 5806, 5700 5906, 5800 6006, 5900 61 06. 6000 6206, 61 O0 6306, 6200 6406, 6300 6506, 6400 56 95 121 154 1 94 239 282 323 364 404 443 482 520 557 593 626 658 687 716 743 769. 794 839 861 882 903 923 9ERT.ICRL CORRECTI'ON TOTAL COORDINATES. 13 0,03 22 2 J 7,39 26 269,42, 33 328.24 4 O 394.65 45 464,72 43 533.78: 41 602,55 32 29 29 27 26 :? 25 2.3 22 22 21 21 20 '1240.71 1307.31 1374.13 1440.53 1506.07 1570.84 1634.79 1697.87 1 76 O. 59 1823,37- 1888,27 1988, 11 243.96 288.97 339.58 396'. 82 461.49 534.58 611.56 686.69 759.32 829.68 898.03 964.77 1 029.22 1 091,38 1151.00 1207.75 1358.96 1404.56 1447.26 ~ 486.75 1522.73 1555.87 1586.84 16~5.95 1643.96 167 i, 63 1704.91 © ~RCO KUPARUK E-12 GYROSCOPIC SURVEY JOB NO 1357 2,4 0 JUHE '82 INTERPOLATED VALUES FOR EVEN !000 FEET .OF HEASURED TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA 1000 1000. 894. 2000 2000. '1894. 3000 2996. 2890, 4000 3905, 3799. .5.0-00 4627, 452!. 6000 5357, 5251. 7000 6151. 6045. DEPTH, TO. TRL' COORDINATES · · ~.60 S 3.42 S 32, {.0 $ 2!-7,07 N 686.90 N -.~2o?,11o N 726. D9 N 1,13 E 7,14 E 31.55 W 339,23 W 844.53 W 1287,.33 W 1600,14 W ,.SCientific i~!Jt ~~ :-i'Drillin'g International I : . ! Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. O~rator~ Wel ]/Name and ~umber Reports and Materials to be received by: .. Required Date Received Remarks · _ , .. Completion Report Yes 7 Well .History Yes 7 :Samples "//~-- PI ' 0 i< Mud Log Registered S~ey Plat Je"CS Inclination .Su~ey ~d .. , . ::': ,.~ ......... ,k,,.:..,,,~ ....... > .... Dr~ll St~ Test Re~~~ Pr~u~on T~t Repros ~ ~" 5 ~ /2- ~ X~:': ~ >' " / , , ~S R~ "r X,, -l:::~ Yes' ' KUPARUK ENGINEERING TO: TRANSMITTAL # .~~_ 0~-~.~ FROM: D.W. Bose/Lorie L. Johnson DATE: Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM,(T - TAPE 3 RECEIVED EIPT ACKNOWLEDG ~/ PLEASE RETURN RECEIPT TO: ' ARCO ALASKA, INC. ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK 99510 JUN 2 21982 DATE: Alaska Oil & Gas Cons. Commissi, ....... orage ARCO. A!aska, Inc. , Post Office B~. Anchorage, AlasKa 99510 Telephone 907 277 5637 June 8, 1982 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 monthly reports for May on these drill sites' 1-9 13-26 2-21 14-17 2-22 14-22 2-24 15-5 13-21 15-6 13-22 1H-6 13 - 24 Also enclosed is a well completion report for Kuparuk 1E-11. Sincerely, P. A. Van Dusen Regional Dril'ling Engineer PAV/JG'llm Enclosures GRU1/LI$ JUN - 9 lS82 ARCO Alaska. Inc. is a subsidiary of AtlanticRichfieldCompany ~ .... STATE OF ALASKA J 'ALASKA(. _AND GAS CONSERVATION C~ ,vIISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well~(~ Workover operation [] 2. N~][nReCO6 ooerator 7. Permit No. ~ Alaska, Inc. 82-60 3. A~d.res~) BOX 360 Anchorage AK 99510 8'AP'~u~-er20736 · ' ' 50- 9. Unit or Lease Name FEL, 803' FSL, Sec. 16, T11N, R10E, UN Kuparuk River Field 4. Location of Wel~,~ I at surface 5. Elevation in feet (indicate KB, DF, etc.) 105.7' RKB 6.ADLLease D2e~i~n~°n and serialALK 469N°' 10. Well No. 1E-12 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of May ,19 82 ..... 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0030 hrs, 05/28/82. Drld 13-1/2" hole to 2541'; ran, cmtd & tstd 10-3/4" csg. Drld 8-3/4" hole to 3718' as of 05/31/82· See Drilling History 13. Casing or liner run and quantities of cement, results of pressure tests 16" 62 5#/ft, H-40, Conductor set @ 78' Cmtd w/217 sx AS II ~ · · · 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2501'. Cmtdw/1050 sx AS III & 250 sx AS II See Drilling History 14. Coring resume and brief description None 15. Logs run and depth where run None' to Date · 16. DST data, perforating data, shows of H2S, miscellaneous data N/A JUN - 9 ]982 A~,aska Oil & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 'SIGNED-"~~ ~M.~ TITLE Sr. Drilling Engineer DATE ~-~--~'~--- NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with ~heAlaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Rev. 7-1-80 GRU1/MR10 Submit in duplicate Kuparuk 1E-12 Drilling Hi story NU Hydril & diverter. Spudded well @ 0030 hrs, 05/28/82. Drld 13-1/2" hole to 2541'. Ran 60 jts 10-3/4", 45.5#, K-55, BTC csg w/shoe @ 2501'. Cmtd w/1050 sx Arctic Set III & 250 sx Arctic Set II. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi. Drld 8-3/4" hole to 3718' as of 05/31/82. JG:llm 06/07/82 RECEIVED JUN - 9 1982 ~Jaska Oil & Gas Cons. Commission Anchorage GRU1/DH14 ARCO Alaska, Inc. ~ Post Office B'~,~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 1, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1E-12 Dear Mr. Chatterton: Attached is a Sundry Notice which proposes a change in our 7" casing design on Kuparuk 1E-12. Since we expect to be running 7" casing on June 9, 1982, your prompt review of this application would be appreciated. If you have any questions, please call me at 263-4970. Sincerely, illing Engineer JBK/JG:llm Attachment KEW1/L1 RECEIVED JUN - 21982 AJaska 0/1 & Gas Cons. Commission Anchorag~ ARCO Alaska, inc. is a subsidiary of AtlanticRichfieldCompany SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator ARCO Alaska, ]:nc, 3. Address P. 0. Box 360, Anchorage, AK 99510 4. Location of Well At Surface: 812' FEL, 803' FSL, Sec. 16, T11N, R10E, UM :At Total Depth: 2410' FEL, 2570' FSL, Sec.. 16, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 66.7'GL, 71.1'Pad,lOS.7'RKB 12. I 6 . Lease Designation and Serial No. ADL 25651, ALK 469 7. Permit No. 82-60 8. APl Number 50-029-20736 9. Unit or Lease Name Kuparuk River Field 10. Well Number 1E-12 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans. [] Repairs Made Pull Tubing [] Other C~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to set the Grade L-80 portion of the 7" casing 'string from O-2000'MD (0-2000' TVD), in lieu of O-4000'MD (0-3500' TVD) as indicated in the Permit to Drill dated May 26, 1982. The balance of the string will remain as grade K-55. The purpose of the L-80 is to provide additional overpull when reciprocating the 7" casing during cementing operations. On Well 1E-12, only 2000' of L-80 casing is required to provide sufficient tensile strength (including safety factors of 1.5 on the body and 1.8 on the connection) to reciprocate casing. We expect to be running 7" casing on 3une 9, 1982. JUN - 2 .i982 A~aska 0il & Gas Cons. C0mmissi0~ 14. I hereby cer~,v~hat the foregoing is true and correct to the best of my knowledge. Signed Title Senior Drilling Engineer The space b~w for ComMission use Conditions 6f Approval, if any: Date Approved by ORIGinAl SIGNED BY LOHNIE C. SMITIi Approved ::opy Returned COMMISSIONER the Commission Date Form 10-403 ' Rev. 7-1-80 KEW1/A27 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate : MEMOR N'DUM Sta e of Alaska .AKASKA OIL.AND GAS CONSERVATION COMMISSION TO:Chat~~n DATE:' Chai~fi ~ FILE NO: ~.-?/ THRU: Lotmie C. Smith 4 ('~ TELEPHONE NO: Commissioner FROM: SUBJECT: Rarold Ro Hawkins Petroleum Inspector June 1, 1982 To witness BOPE Test ARCO. Kuparuk 1 E-12 Sec 16. TllN. RIOE UMo Permit No. 82-60 _Saturday. May, ,29.,. ~982: I left. Anchorage at 2:30 p.m. by Alaska Air- lines to Prudhoe arr~ving at 4~00 p.m., and at Kuparuk 1 E-12 at 6:30 p.m. When I arrived at the location nippling up the BOPE ~as in process. ~pnday,.. 3~..!982: I witnessed the BOPE test on Kuparuk 1 E-12. It was found that the hydraulic lines from the H.C.R. valve and the blind rams were crossed and this vas corrected. Also the accumulator supply valve to the accumulator manifold ~s shut off, this was also corrected, and the BOPE test resumed. I filled out an AOGCC report which is attached. In summary, I witnessed the BOPE test on 1 E-12. When the corrections mentioned above ~ere completed, the BOPE test was performed satisfactorily, 02-00 IA(Rev.10/79) ,. O&G #4 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Well Operator Well Location: Sec /~ ~/~/ R/~ Drilling Contractor. Representative /~:~ ~ ~jr~<?~ Permit # ~,~ -'~.., ~ /~3/ Casing Set @ .2~-~ /. ft. Rig ~ 3~ 'Rep~esentativ~.~;~/~ ~-~~ Location, General Well Sign General Housekeeping Reserve pit Rig BOPE 'Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pres sure Yod Test Results: Failures ACCUMULATOR SYSTEM Full Charge Pressure ~~ psig Pressure After Closure f/~,~'d~ psig 200 psig Above Precharge Attained: min~J sec. · Full Charge Pressure Attained: ~ min~.~ sec Controls: Master Remote ~.~/.~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly Test Pressure ~d~ ~9 Lower Kelly Test Pressure Ball Type Test Pressure Test Pressure ~, Test Pressure S~L~ Inside BOP Choke Manifold No. Valves/~ No. flanges ;~ ~ Adjustable Chokes / Hydrauically operated choke. Test Time ~ hrs. _'.~ ~ ,",~ /,,¢./ RePair or Replacement of failed equipment to be made within '---~' days and Inspector/Commission office notified. · Remarks: ~.~/~/ ~[ ~,~ ~T'~./'~ ~f , . . ~sErlDu~ion / ' ' orig. - AO&~C cc - Operator Su~euu&so= air. Idark A. ~lajor Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 ~.Alehorasr~- Al~m~t ~9510 P~mit Ho. 82-60 Su~. ~c. 81~*F~, 863'F~, See 16, TII~, RIOE, ~. Steele Loc. 2410'~L, Z570*FSL, Sec 16, TIIN, RIOE, ~. Demi, ~r. Major: Enclosed is the approved application for pemit to drill the above referenced well. gall samples and a md log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)($). If available, a tape containtntr the digitized log information shall be submitted on all logs for copying except mxpertn~ntal logs, velocity surveys and ditxm~ter' surveys. htany ~ivers in Alaska and their drainage systems have been classified as important for the spawntn~ or migration of anadromous fish. Operations in these areas are subject to AS 15.05o870 and the regulations protnulgated thereunder (Title 5, Alaska Administrative Code). P~tor to c~ncing operations you may be oontacted by the Habitat Coordinato~*s Office, Department of Fish and Game. Pollution of an~ waters of the State is prohibited by AS 46, Chapter 3, Article 7'and the regulations promulgated thereunder (Title 18, Alaska Ad~inistrative Code, Chapter ?0) and by the Federal ~at.er Pollution Control Act, as amended. Prior to c~noing operations you nmy be contacted by a representative of the l~partraent of Enviromnental Conservation. T° aid us in scheduling ~teld work, ~e would appreciate your notifyi~ this office within 48 hours a~ter the ~vell is spudded,. We would also like to be noti.fied so that a representative of the Commission ~ay be present to witness Mark A. Major Prudhoe Bay Unit DS 1E-12 -2- May 26, 1982 testini~ of blowout preventer equitxnent before surface casing shoe is drilled, In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very t ru I y your s, C. V. Chatterton Chairman of BY O~D~a OF THE Alaska Oil and Gas Conservation Commission ]~ne 1 o sure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. CVC ~ be STATE OF ALASKA "O(i ALASKA ILAND GAS CONSERVATION C ,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL [] SINGLE ZONE DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. D ~ P ~' i i, ,- ,, 3. Address '% /,, ~ E I Y ~ U P.O. Box 360, Anchorage, Alaska 99510 4. Location of well at surface ~Y 1 8 ]98~) 9. Unit or lease name 812'FEL, 803'FSL, Sec. 16, T11N, R10E, UN Kuparuk River Field 10.. Well number At top of proposed producing interval ~,J~;~ 0il & Ga8 Cons. ~,~), rJr~L~0~ 2410'FEL, 2570'FSL, Sec. 16, T11N, RIOE, UM /Wcl~0rage At total depth 11. Field and pool 2410'FEL, 2570'FSL, Sec. 16, T11N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. Kuparuk River 0il Pad 66.7'GL, 71.7' Pad, 105.7'RKBIADL 25651, ALK 469 12. Bond information (see ~0 AAC 25.025) ~° Type Statewide Surety and/or number Federal Ins~trance Co. 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 Deadhorse miles At surface, 803 feet 'tEll Weu 0-750'TVD,120' feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 7310'MD 6641 'TVD feet 2560 06/01/82 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures 2773 psig@80~F Surface KICK OFF POINT 750 feet. MAXIMUM HOLE ANGLE38 ° I (see 20 AAC 25.035 (c) (2) 3155 psig@~l~L~ ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 24" 16" 65# H-bO Welded 80' 34.7' 134.7' 115' I 115' 150 cf .+ 13-1/2"10-3/4 '45 . 5# K-55 BTC 2707' 32.9' 132 9' 2740' I I ' I2500' 1125 sx AS III plus I ] 250 SX AS I8--3/4" 7" 26# 1-80 BTC 3969' 31.0' 1131.0' 4000' 1350O' 1040 sx 7" 26# K-55 BTC 3310' 4000' ,13500' 7310' 116641' 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field~Kuparuk River Oil Pool develop- ment Well to approximately 7310' MD, 6641' TVD. Selected intervals will be logged. A 20" 2000 psi annular diverter will be installed on the 16" conductor while drilling the surfac~e hole. A 13-5/8" RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure will be 2773 psig based on cooling of a gas bubble rising at constant volume. The well will be completed with 3-1/2", 9.2#, 0-55 buttress tubing. Non-freezing fluids will be left 'in uncemented annuli through the perma- frost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon conclusion of the job. 23. I hereby certifyjhat the foregoing is true and correct to the best of my knowledge SIGNED ~~ ~./~ TITLE Sr. Drlg. 'Engineer DATE ~"/~/~_ The space be~ f¢C~mfssio~q~se" CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required I APl number i--lYES ~O [-]YES ~,10 I~-Y-E.~ UNO1 5o- Permit number Approval date ,,-'"~]~/,'~;6/8~' // I SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY ~,.....,.~~ ,COMMISSIONER DATE l~__y ~6~ 1.qR~. ~ /,/ // by order of the Commission Form 10-401 ONI1/B3 Submit in triplicate Rev. 7-1-80 ANTI£IPATED PRESSURES Expected reservoir pressure in the Kuparuk interval has been determined to be 3155 psig from RFT and pressure build-up data. This pressure ~ 6040' SS = 6146' TVD will be balanced by 9.87 ppg mud weight. Normal dr±lling practice calls for 10.4 ppg weight prior to penetration and during drilling of the Upper Kuparuk and remaining intervals. This will result in a 169 psi overbalance. It is antic±patedAthe surface BOPE equipment could be subjected to a maximum of 2773 psi during drilling operations. Derivation assumes a gas kick at reser- voir temperature and pressure (154°F, 3155 psi), gas migration to the surface without expansion, and cooling to 80°F cellar temperature. This is well below the 5000 psig BOPE working pressure and less than the 3000 psi weekly test pressure. Pi : pressure initial (reservoir) Ti : temperature initial (reservoir) Vi : volume initial (reservoir) Pf : pressure final (surface) Tf : temperature final (surface) Vf = volume final (surface) PiVi : PfVf Ti Tf Since Vi : Vf, i.e.~ no expansion. Pi : Pf PiTf Ti T--'~ Then Pf : Ti _ (3170 psia)(80°r + 460) (154°F + 460) Pf = 2788 psia = 2773 psig RECEIVED 1 8 ]982 AJaska Oil & Gas Cons. Commission /~chorage 30: llm 05/17/82 ONI1/A21 MAY 1 8 1982 Alaska Oil a Gas Cons. Commission Anchorage 8o'/ ..__ }glo~ WE ~ , EgL-=- ? ~, ~,11 "-- WE · · .!'~i. "0 ' ' L . g/'/" " WE ~ ~' /~ < ~1 ~1 '- G~' WE ' ~ >816 ~ ,, el.?~ < .. . .~. · ' .. . . . .~ . ? ~.' :.'~:.:" .. : .'-~.:..~ ...."'" .. . . ~. ~: · ~. · ~ : :. '~ . ' ... .. ~. ~'::'. '.' · ' ' A ~. . ..~. . .. :~:: i .-~ . . ..... ..... ..., ..... (TSC N,~lO~,u.~.)2! 2Z EBY CERTIFY THAT i AM :-.:7... .? . . . . ,-': , !. ~ I I WELL #8 Y 5,960,60Oo2~O i ~ X = -. 549,889.825 i 80'/~ '--- LAT .-- 70°18~11 283" -.i..., , LONG = 149°35~'45o185'' [![ WELL #7 ' Y : 5,960.,480.368 ~, >~'1o' X = 549,889.~6 'x: ~,2.'a' < LAT = 70918~ 10o104" :, x= ' ET - LAT = .70 18 08 ~ .. ~~ ~1~.' < .~. x~ '~ .... . .~, ~', _ .-:~:.:~. ' "'::. ' h~ · ' ~ i ..~ · ~- .: . - " X =' 549':,889.O39 ' -~]: - ~ ~--~ '{.... ~ LAT = 70°18:~07.7~q'' .':. , . '~:"~.:~L ... r ..~' ~53' LONG = 1~9°35~5,278''' --.....L~. .~ ~ . . · .- "' =i . gl~' "" ~ ~ UELL ~q Y = 5,960:,120,155 ~ , ' a~4' x ' '5q~,889.818 :' . ........... ~ ~' ~' ~ : LAT ' 70°18'06.561'' :.- '...~-~L~";'.:-:.. E4~ · ' " LONG = 1~°35"~5,279'' .',._~,' ~/¢ -< ~ .... . '....~ ~ ~,. . . __X~ /~.~ '' ~5~' WELL ~3 · Y = 5~960,000.596' '~ X .= 549,889, 506 ~ '~ ~ '~ >N/~' ~ LAT =. 70°18~05.386''. ~ ~R LONG 149o35'45.311" ~ '~%~'_,:~ .. ~ ~ ~"- ~ e~e' ~ =. . Z~ ~ ~ "~' ~' ~ ''~1~/'~ < ....__~ Y = 549, 889 '996' 5O4 '-... ~.-7" ~ ~ ~ ~,_ ~{~' ~ LAT = 70o18'04.204'' · ] ' ' EI~ LONG = 149,35'45.320" .... . '..,'.....'.: , .. . .~. ~, , . . . . -.' :-.... ~ .'. ~':.: .." ::.-',~,~.. . .~ . :~';:- ..~..:,::.:-' .. WELL fl . X =. 5,959,760.244 :.'.':':' '~ ' ..'~'~.' ..... m-_ ..... ':.::'. 'Y .... 549,889,514 ."o.~;.~ '"-'.:'I .m '. - "-" '. .'. ,.'::.:...~ -'-,.~:.~/.~ ..- : ' ..... LAT = 70°~8'~03.022'' ' '"'":': '" '~' ':':~" '-'~'""' "' ~ LONG'= 149°35~45.358'' '" ' 7"'.'.' '.~. ' ~ "{' : . . ". :'. " · ', -'- i ~ · ' , ' ' : . ' .' .' ...: .~:.: ..:.:v..~:..~.~....... -t..... ~ ~ ~ · . ~: . .. :..~.. ..'' ."'-" · ... (T~[N,~OS~UU ' ~ F ~ , ~'"'"' :..~:...~.."~.-HE~EBY CERTIFY THaT ~ ~ . . , ~%.. .... :.~?.~ .' '.':':" "".:--'PROPERLY-REGISTERED AND LICENSED ' , ~=~"' ~ ~/$~:"-:~::~ ' . : v .. . .- . - '.-. -TO PRACTICE LAND-SURVEYING IN ....- -. :. ,~ ~ c~.j~ ~ ,~/ t., .~ ~ ~ . ...-... 'THE. STATE THaT R E E I" ' ........ ' .... '"-/.~-t.-~-' :BUILT-SURVEY MADE BY' ME, AND ""' - . ~'~/~'~']"~'2,,~,:f' :;"":~ .:-"..: . · ' -, '~,q2i:. ~ ,,L,:;~4**.~,* · ~ ~" ' .... · ..':. THaT ~LL DI~E~S~O~S ~D OTHE~ ~AY ...~;.. -.". - . . . ":" DETAILS'ARE CORRECT, AS OF: ' .' ': .'" '~'u~'-. .~",~ - -:' .- ~ · ~/ ~ '/~ ' - "- AA~M,',o,, ~% ~ES~l~% ~ . .- . ;., : .' .'..'-.,- ..... . .. ... ... . ~%,~.:~.,~ . . II I ' W LLS 1- 7,,Loq T o e Ac- 5U UT I I , 'AtlanticRichfieldCompany ~ DATE. DRAWING No: NORTH A~ERlCAN PRODUCING DIVISION ~/17/~O ALASKA DISTRICT .... KUPARUK Illll I II II I II I II I / Surface Dive~ ' System 1. 16" Bradenhead. 2. 16" x '20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer, 5. 20" 2000 psi annular preventer. 6. -20" bell gipple. · detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor RECEIVED MAY 1 8 1982 Maintenance & Operation ~ 1. Upon initial installation close annular ! preventer and verify that ball valves ! have opened properly. . ! 2. Close annular preventer and blow air ~_ . through diverter lines every 12 hours. t_ 3'. Close annular preventer in the event that gas or fluid flow to surface is .< P!PE R~MS TBG HD 3 CSG HD Z 13-5/8" 5000 PSI RSRRA BOP STACK 2. 3. 4. 5. 16" Bradenhead 16" 2000 PSI x 10" 3000 PSI casing head lO" 3000 PSI tubing head lO" 3000 PSI x 13-5/8" 5000 PSI adapter spool 13-5/8" 5000 PSI pipe rams 13-5/8" 5000 PSI drilling spool w/choke and kil 1. 1 ines 13-5/8" 5000 PSI pipe rams 13-5/8" 5000 PSI blind rams 13-5/8" 5000 PSI annular . . . . ACCLI.IULAii3R CAPACII~' TEST CHECK AND FILL ACCUHULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACC1,HULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWILSTREN. t OF THE REGULATOR. OBSERVE TIME THBt CLOSE ALL UNITS SII-iULT~iE- OUSLY AND RECORD THE TII4E AND PRESSURE R~4AIN- ING AFTER ALL U,'.IITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECO:;DS CLOSII'~G TIME ,MiD 1200 PSI REMAINING PRESSURE. - 13-5/8" BOP STACK TEST RECEIVED 8. MAY.' 1 8-i982 s Cons. Commission or.a§o 11. 12. . FILL BOP STACK A~iD MANIFOLD WITH AJ~CTIC DIESEL. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY TEACTED. PREDETE~"IINE DEPllJ THAT. TEST PLUG WILL SEAT AND SEAT IN WEtlJ4EAD. RUt( IN LOCK DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER ~ CHOKES ~ID BYPASS VALVES ON ~qIFOLD. TEST ALL COHPONEJ(TS TO 250 PSI AND HOLD FOE lO MINUTES. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR l0 MINUTES. BLEED TO 7.~qO ~SI. O,PEN ANNULAR PREVEJiTER ANI) CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 3000 .PSI AND HOLD FOR l0 HI NUTES. CLOSE VALVES. DIRECll. Y urpSII~EAJ, I OF CHOKES. B LEEDDOWNSTREA~4 ~.,,/~~TED PSI, TEST PRESS~P~O ZERO TO VALVES. TEST Rr~tAINI I~IANIFOLD VALVES, IF ANY, WITH/ UPSI~RE~q OF VALVE A~ND ZERO PSI D~(ST~ . BLEED SYSTEM TO ZERO PSI. OPEN TOP SET OF PIPqP~ AND CLOSE SET OF PIPE RA~S. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR lO. MINUTES. BLEED TO ZERO PSI. OPEN BOTTOM SET OF PIPE RA~tS. BACK OFF RUN- NING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RA~LS AND TEST TO 3000 PSI FOR 10 [-IINUTES. BLEED TO ZERO PSI. OPEN BLIIID RAMS AND RECOI~ TEST PLUG.' MAKE SURE HA~IIFOLD AIiD LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLI)~G POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. lEST KELLY COCY, S NtD Ii, SIDE BOP TO 3000 PSI' WITH KOOiIEY PUMP. 15. RECORD TEST INFO.~4ATION ON BLIT~OUI~ PREVETiTER -.:i'~.::. TEST F'OI~i SIGN AJiD SE)iD ~0 DRILLIi4G SUPER- ---:--'-~,- 16. VISOR. -" ' ?,' ". ~ PERFORI-S CC~tPLETE BOPE IT. ST O~tCE A WEEK A~ID ~' '-:" FUNCTIOriALLY OPERATE BOPE DAII.Y. .., - . .¥-~,.ii~:!i-:~.. .. ALASKA OIL AND GAS CONSERVATION COMMISSION IA)' S. HA¥¥OND, 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501'-3192 TELEPHONE (907) 279..-1433 Mr. Jim 0nesko ARCO Alaska, Inc. Anchorage, Alaska Attached is the second check for DS 1E.-12. As I stated in our phone conversation, this check was not needed as the original permit to drill had not been approved. Bettyjane Ehrlich ~ Secretary to the Commissioners ARCO Alaska, Inc. ( Post Office B~.. ,~60 Anchorage, Alaska 99510 Telephone 907 277 5637 May 17, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUB3ECT: Kuparuk 1E-12 Dear Mr. Chatterton: Enclosed are: · A revised application for Permit to Drill Kuparuk 1E-12, along with a $100 application fee. · A diagram showing the proposed horizontal and vertical projection of the wellbore. · An as-built drawing of "E" pad indicating the proposed surface location. · A proximity map indicating the relative location of Kuparuk wells 1E-5, 1E-6, 1E-7, and 1E-11. · A determination of the maximum pressure to which BOP equipment could be subjected. · A dlagram and description of the surface hole diverter system. · A dlagram and description of the BOP equipment. Since we anticipate spudding ~hls well on 3une 1, 1982, your prompt review of this Qpplication w111 be appreciated. If you have any questions, please call me at 263-4970. Sincerely, Sr. Drilling Engineer OBK:OO/llm Attachments 0NIl/B4 ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany Gas Cons. CommissioTt ~chor~e ARCO Alaska, Inc. ( Post Office B~. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 7, 1982 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1E-12 Dear Mr. Chatterton- Attached are- · An application for Permit to Drill Kuparuk 1E-12, along with a $100 application fee. · A diagram showing the proposed horizontal and vertical projection of the wellbore. · An as-built drawing of "E" pad indicating the proposed surface location. · A proximity map indicating the relative location of Kuparuk wells 1E-6 and 1E-11. · A determination of the maximum pressure to which BOP equipment could be subjected. · A diagram and description of the surface hole diverter system. · A diagram and description of the BOP equipment. If you have any questions, please call me at 263-4970. Sincerely, Sr. Drilling Engineer JBK'JO/hrl RECEIVED, APR 1 6 ]982 Alaska Oil & Gas Cons. ComrnJssion Anchorage Attachments cc' Mr. Ron Podboy ONI1/A22 ARCO Alaska, Inc. is a S~bs[diary of AtlanticRichfieldCompany STATE OF ALASKA O~M ALASKA ,L AND GAS CONSERVATION C MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL [] SINGLE ZONE []( DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO A1 aska, Inc. 3. Address P. 0. Box 360, Anchorage, AK 99510 4. Location of well at surface - ~ ~ f ~ Lf 9. unit or lease name 812' FEL, 803' FSL, Sec. 16, T11N, RiOE, UM APR Kuparuk River Field At tOp of proposed producing interval ] 6]982 10. Well number 2549' FEL, 2549' FSL, Sec. 16, T11N, RiOE, I~skaOil&Gasj~m~_.~_ 1E-12 At total depth , TllN, R10E, UM j,~.j~;_~.,ll~.~.Fieldandpoo, 3007' FEL, 3010' FSL, Sec 16 "1{(~m.qk River Field 5. Elevation in feet (indicate KB, DF etc.) l 6. Lease designation and serial no. ~-- Kuparuk,,~iver 0i 1 Pool 66.7' GL, 71.7 Pad, 105.7 RES FDL '25651, ALE 469 ~ ',,,,,,., 12. Bond information (see ~0 AAC 25.025) Federal Insurance Co. Type St atewi de Surety and/or number A~ount $ 500,0~,0 13. Distance and direction from nearest town 14 Distance to nearest property or lease line : 15~qE)istance to nearest drilling or completed 30 Mi. NW geadhorse miles At surface, 803' feet ~-~wel, O-260~'TVD, 66.' ~feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spu¢l date 7997' MD, 6894' TVD feet 2560' "'"~ 06~]~,~-82 / 19. If deviated (see 20 AAC 25.050) 120. Anticipated pr~sures ~,~sig@,qr~° I~' surface KICK OFF POINT 2600 feet. MAXIMUM HOLE ANGLE 41 °l(~AC25.03qc)(2) '?,155 ~Jpsig@~---ft. TD(TV~D)' 2~ ~,, Pro~osed Casing, Li~er and (~ementing Pro~am /,//~"~ . SIZE CASIN~AND LINEI~ / / SETTING DEPTH t,?' QUANTITY OF CEMENT Hole Casing Weight Grade ~'q Coupiin~ Length IMD T~P TVD MD BOTTOM"'TVD (include stagedata) ' ' 24 16 65# H-40 ~lded~ 80' ~2.7',/!32.7' ]1'3' ~I ~.3' 1.~n nf + 13-1/2 10-3/4 45.5# K-55 BT~,.~\~2469' 3~779" ' ' . ~30.9 2500' i 2500' 1050sx AS III .plus 250sx AS ,II 8-3/4 7 26# K-55 BTC ~,~968' 29.2' !29.2' 7997' 116894' 1320sx Class G 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill~a Kuparuk River Field, KUparuk River Oil Pool develop- ment well to approximately 7997' MD, 6894' TVD. Selected intervals will be logged. A 20" 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8" RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure will be 2755 psig based on cooling of a gas bubble rising at constant volume. The well will be completed with 3-1/2", 9.2#, J-55 buttress tubing. Non-freezing fluids will be left in uncemented annuli through the perma- frost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon conclusion of the job. 23. I hereby certify t_hat the foregoing is true and correct to the best of my knowledge SIGNED TITLE Sr. Drlo. Fnoinem_r DATE The space bel~ fojl~'mr~siorl/uSe ~' - - " " '' - / CONDITIONS OF APPROVAL I ' Samples required Mud log required Directional Survey required APl number []YES ~O []]YES J~NO J~YES r-lNG 50_O.~ ~-.-1.,~ 7~' Permit number Approval date ,~'?,-~ O ' I SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY ,COMMISSIONER DATE by order of the Commission Form 10~,01 ReV. 7-1-80 Submit in triplicate SECTtbNi_.;: .......... j ...... .-- : i i1~ iii L Y X= LAT .--- LONG I ! WELL #8 WELL #7' Y X LAT LONG Y LAT LONG Y LAT LONG WELL #6 WELL #5 . WELL #4 WELL #3. Y 'X LAT LONG WELL #1 WELL #2 Y X LAT LONG X Y LAT LONG V · ~ WE _ r~ 0 j_ } ¢31' WE . E 'Wi ~ ~ 653' .ES~ < Wi -' . .~ . : - .,.~ . '.. .~ , .~ · , _ '. ~..~2~ ~ . : :~ :- :';'. .. · . . . ~ , "" ..... ':." 16 15 , .... ., . ( r m, 2i EBY CERTIFY THAT i AH X -y LAT LONG = 1 5,960,600.Z~0 -- 549,889.825 70°18t I 1.283" 49°35'45. 185'' = 5,960, 480. 368 = 549,889 ..&W36 = 70918' 10. I:04" = 149°35'45.z19'' .. ' 5,~60~36(~.207 = ' - 549,889,.255'. = .70°18~08.~23,,' = 149o35.~45.:~49" = 5,960,240o410 =' · · 549?, 889-039 = 70°18'~ 07.744" = 149°35' 45oZ78" . = '~5,960~, 120.155 = 549,889:o, 818 ' 70°18'06.561'' = 149°35~45o2:79'' = 5~960,000,.59'6 : 549,889.5O6 :. 70°18'05.386" = 149°35'45.311" = 5,959,880..504 = 549,889i.996 : 70°18'04o204I' = 149,35'45.320" o. = 5,959,760~.244 ' 549,88~'.514 = 70of8,03.~022,, -. 149o35'~45.358,, . . -- ' ' _ .~'~" OF AL '~.= '. '-' ' i HEREBY ,:,-~ -q,~,.. ..... .. <~. ~ ~'., -. · .. ~ , ~,~ ' A --'PROPERL~ REGISTERED AND LICENSED . TO PRACTICE LAND-SURVEYING IN ' ~-, ' ,~ .., _, .. THAT ----:-- 'BUILT-SURVEY MADE BY ME, A D ~P~ ~/ ....... '[N/'-'~.'2~[~.~',' ~,.,,,?,T'-""'~' '- - THAT ALL.DIMENSIONS AND u~m~.~. ' ~ 'Y'~"' Z"~ ~7" ~ '"~ '" DETAILS'ARE CORRECT, AS OF-~28~.Ojj& ' ~_' _ t/~ ~,-..,,u: ~ ~-~..-.~ -- ' · ' "Aachom.] ~".mssion 'h] ~"~ ...... ~ ~$~,~_~' ·. ~ · . ... . . . . ~,~q~_~ --"~'m . · ._ ...... . . -. . ' ~,~. ~'~-' - . i i Ill I I I I I II I I I I _ II I I :_ ' "' "' ' ' "' . ' ' '" -- -- 'AtlanticRichfieldCompany NORTH AMERICAN PRODUCING DIVISION io/~/~l' ALASKA DISTRICT .... KUPARUK I ~'~'- i i i i ~. ii i ~L ii iJi i _ . 355~ 3376 .......... t .................... -~ ................................... ~ ' ........ T .............. ~ .......................... L'.-;~ ~ ................... i ........ :":r-O ....... :- ~ '--, ..... ti .......... ~ ......... ~ .... I ! ...... : ..................... ~~.. L-.T-7'~i ....... _... i ........ ANTICIPATED PRESSURES Expected reservoir pressure in the Kuparuk interval has been determined to be 3155 psig from RFT and pressure build-up data. This pressure @ 6040' SS : 6146' TVD will be balanced by 9.87 ppg mud weight. Normal drilling practice calls for 10.4 ppg weight prior to penetration and during drilling of the Upper Kuparuk and remaining intervals. This will result in a 169 psi overbalance. It is anticipated the surface BOPE equipment could be subjected to a maximum of 2755 psi during drilling operations. Derivation assumes a gas kick at reser- voir temperature and pressure (158°F, 3155 psi), gas migration to the surface without expansion, and cooling to 80°F cellar temperature. This is well below the 5000 psig BOPE working pressure and less than the 3000 psi weekly test pressure. Pi = pressure initial (reservoir) Ti = temperature initial (reservoir) Vi : volume initial (reservoir) Pf = pressure final (surface) Tf = temperature final (surface) Vf : volume final (surface) PiVi PfVf Ti Tf Since Vi = Vf, i.e., no expansion. Pi = Pf PiTf Ti T-~ Then Pf - Ti = (3170 psia)(80°F + 460) (158°F + 460) Pf = 2770 psia = 2755 psig JO-hrl 03/31/82 ONI1/A21 APR 1 6 1982 Aiaska Oil & Gas Cons. Commissior~ Anchorag~ 13-5/8" 5000 PSI RSRRA BOP STAC~ _ PREV~NTOR .,q. 9 /,. BL!~ RRHS 8 PZPE RRMS 7 DRILLING s OOL. 6 ) PIPE RRHS ) s ( C ) · 2. 3. 4. ® ® . 16" Bradenhead 16" 2000 PSI x 10" 3000 PSI casing head 10" 3000 PSI tubing head l 0" 3000 PSI x 13-5/8" 5000 PS I adapter spool 13-5/8'i 5000 PSI pipe rams 13-5/8" 5000 PSI drilling spool w/choke and kill. lines 13-5/8" 5000 PSI pipe rams 13-5/8" 5000 PSI blind rams 13-5/8" 5000 PSI annular- . ACCL~.IULAI'OR CAPAC[I~ TEST le . ' TBG HD 3 CSG HD 2 IRE£EIVEI) 10, 11. 12. 13. CHECK AND FILL ACC~-IULATOiJ RESER~rBIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCCTIULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DO~LSTREAI4 OF THE REI~ULATOR. OBSERVE TIME TH-Cfi CLOSE AIL UNITS SIHULTA~IE- 0USLY ~(D RECORD THE TINE AND PRESSURE REMAIN- ING AFTER ALL ~(ITS ARE (CLOSED WITit CHARGING PLR~P OFF. RECORD ON IADC REPORT. 11~ ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSIIiG TIME' AND 1200 PSI REIqAINING PRESSURE. 13-5/8" BOP STACK TEST FILL BOP STACK A~iD MA~NIFOLI) WITH A~CTIC DIESEL. CHECK THAT ALL HOLD D(7~lt SCREWS ARE FULLY RE- TRACTED. PREDETEEqINE DEPTH THAT TEST PLUG WI LL SEAT AND SEAT IN WELLt4EAD. RUli IN LOCK DOWN SCRE~S IN HEAD. CLOSE ANNULAR P~EVEHTER ~ CHOKES Arid BYPASS VALVES ON M/iugIFOLD. TEST ALL C0¢,iPONFJJTS TO ZSO PSI AND HOLD FOR l0 MINUTES. INCREASE PRESSURE TO 1800 PSI AND 14OLD FOR l0 MINUTES. BLEED TO ~ PSI. OPEN ANNULAR PREVE~tTF~ A~ CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 3000 I~SI AND [(OLD FOR MI NUTES. CLOSE VALVES. DIRECTLY U~AI,! OF CHOKES. BLEED DO'~NSTRF_A,M PRESSURE TO ZERO PSI TO TEST VALVES. TEST P~IAINIflG LIJiTESTED ihIANIFOLD VALVES, IF ANY, WITH 3000 I~SI UPSll~4 OF VALVE AND ZERO PSI EK72~JSl~T:AM. BLEED SYSTEH TO ZERO PSI. - OPEN TOP SET OF PIPE RA~ A~D CLOSE BOTTOM SET OF PIPE RAHS. INCREASE PRESSURE TO 3000 t~SI AND HOLD FOR lO HINUTES. BLEED TO ZERO PSI. OPEN BOTTOH SET OF PIPE RA'4S. BACK OFF RUN- NING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAHS AND TEST TO 3000 PSI FOR 10 ~-tlNUTES. BLEED TO ZERO PSI. OPEN BLIND RAHS AND RECOYEA TEST PLUG. MAKE SURE HANIFOLD AIJD LINES AI~ FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POS I TI ON. TEST STANDPIPE VALVES TO ~K)00 ': :-:APR 1 6 19.82 14.WITHTEST ~OC~EyKELLY COCKSpij14p.A~ID IIISII)E BOP TO_..3000 PSI '- 15. RECORD TEST INFO,~4ATION ~ BLET~K)LFr PREVENTER Al~sk~Oil & G~s Cons. Oommiss~T F'0~t SIGN ~(D S~O TO DRILLI~ SUPER- . -,,,,,-~.~~'h~ra"~ . VISOR. 16. PERF'O~-t C~IPL~E BOPE ~ ONCE A ~E~ AND FUNCTIOnaLLY OPE~TE BOP~ ~ILY. . . _ Surface Dive ~er System 1. 16" Bradenhead. " 2. 16" x '20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. lO" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. ~20" bell gipple. Maintenance & Operation 1. Upon initial installation close annular preventer and verify that ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually over- ri de and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor APR t. 6. i98-2 _. ~a~Ka,Oil & Gas, Cons.' CHECK LIST FOR NEW WELL PERMITS ITeM APPROVE DATE (2 thru 8) " (9 thru 11) 10 (4) Casg~z'~~u 20) ~Jl-thru 214) (6) .Add:_ ~(~~' ~.,,/~-t~'~/'~ ® 4. 5. 6. 8, , 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Company Lease & Well No. YES NO Is the permit fee attached ......................................... Is well to be located in a defined pool ............. Is well located proper distance from property line ...... Is well located proper distance from other wells .......... Is sufficient undedicated acreage available in this pool · . · pi Is well to be deviated and is well bore at included ............... only affected party ................................. Is operator the ·roved 'before ten-day wait .................. ........ Can permit be app Does operator have a bond in force .. . · 'Is a conservation order needed .... :::::::::::::::::::::::::::::::::::. ''' ' '' '' ' ' ' ' ''''' Is administrative approval needed ........... Is conductor string providedcircu~;g. ....... ~'c~ggl~ ~d ~g~f~gg Is enough cement used to ::1:1::1 Will cement tie in surface and intermediate or production strings Will cement cover .all known productive horizons ..... · ::::::::l 11 111 Will surface caszng protect fresh water zon s ...... Will all casing give adequate safety in collapse, tension and burst.~ Is this well to be kicked off from an existing wellbore ............. Is old Wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed .......................... Is a diverter system required ....................... ''" Are necessary diagrams of diverter and BOP equipment' ~~ ''' :'[ Does BOPE have sufficient pressure rating -Test to Does the choke manifold comply w/API RP-53 (Feb.78) .......... REMARKS Additional requirements Additional Remarks: ~ 0 ~Z Geology; Engin~e_r ~ng: K ,cs WVA _ J KT'~Y RAD ~ re~: 01/13/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE CHECK LIST FOR NEW WELL PERMITS IT~4 APPROVE DATE e 6. 7. 8. (3) Admin (~--- ~'/6 ~fn~ 9. · (9 thru 11) 10. 11. (4) Casg ~ .~-/g~-~ 12. ~2 thru 20) 13. 14. 15. 16. 17. 18. 19. 20. %21 thru 24) 22. 23. 24. (6) Add: ~~.-" ~/--/~'"~"~"'~25. Company .. Lease & Well No. Is the permit fee attached .......................................... Is well to be located in a defined pool ............ Is well located proper'distance from property i~'n~iiiii!iiiiii ii · · · · · Is well located proper distance from other wells .... Is sufficient undedicated acreage available in this pool ........ Is well to be deviated and is well bore plat included .. ii..[ Is operator the only affected party ......... ~ ....... {' · Can permit be approved before ten-day wait ........ Does operator have a bond in force ..... ' ............................. Is a conservation order needed ...................................... 1 d Is administrative approva neede ................................... Is conductor string provided . .. ..~~, Is enough cement used to circu{~;~'~'~nd~'~' Will cement tie in surface and intermediate or production strings , Will cement cover all knOwn productive horizons .................... Will surface casing protect fresh water zones ... ................... Will all casing give adequate safety in collapse, tension and burst· Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ......................... Is a diverter system required ...................................... Are necessary diagrams of d±verter and BOP equipment attached .... Does BOPE have sufficient pressure rating- rest to Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements REMARKS '~] ~z Additional Remarks: Geology: Engine~ ,ryng: HWK _~ LCS ~-Q~BEW ~ WVA'\ JKT rev: 01/13/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry 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. h~ PAGF 2 · I I DVP OIO.HOI Vti{~l,~ [CA~,~IOi:~ LiSTI~G PAGE 3 ' ~T ?T 0 0 0: O 0 4 0 S F L U ~'~ i L 9 q ~4 :~ 7 0 0 0 0 ~ 0 ! L ~4 D t D 0 ~ ~ ~ 7 0 0 · o 0 ~ 0 · ~ . . . ~ .... IL :..~!~-I 7 3!. 1~2 0 · ' 0 -~: ~a ""~ G/C3 42 35 ! O ~ 0 4 0 G :~ F :} {: . 31 3 2 O~:HO p"oN 'GIC3 42 ,~.4 0 1 1 1 t ! 1 t t 1 REPR CODE 68 68 68 6R 68 68 2.1641 8418 2,1641 12.8418 0,1211 2.3535 15,~738 0,0527 1~ 4355 '4023 0,0771 12.7578 2§.2148 .0542 6,1367 15.8203 0.0508 2.0293 1~,i406 .t055 3.2754 1g.7246 .1626 2.2793 -999,2500 -999.25u0 2.7539 999.2500 999,2500 D~.-iPT 6500,OOu',) ~Li.ji 3.3.398 I~ : _ ~..7754 tb~.~ 3. 574~ R.,0~ -~9<.25u0 :G~ : _IO~.~::D~~ ~.A~I .~!,AS~:~ .... -.~ 9 .25o0 OEPT 6400.0000 SFLU ' 2.'g'309 ' IL~a 2.412! ILD Z.2969 R'H{}P "999;2500 GR 104,06~5- CALI ' !0,]828 DR~U -v~.z~uO D~PT 6300,0000: 8FLU 3.8652-t&!:4 2,8945 IDD 2.5859 Sm 'j. n9;3i25 GR i14;i250 NPHI '999'2500 DPHI '999.2500 R~Ub -~:99,2500 G~ -_ $.~, i-gS~_, C::~.~ l !9.. ~.~-~ ~: 999,25 ~q~:AT '9-99. 2500 ~CNL ~o99,2500 FCN[ -999,2500 D¢JP¢ 6200,0000. ;SFI:,¢ -:'- :3.076~ I:LM" ,_;3'2~8- ILD 3.1680 SP -113,3125 GR : &26,6250 .k4P~t -. :.- ~99~,2500- DPRi -999,2500 ........ . - _ . ~. : -: ; ¢ - ;. D~iPT &lOO,O000 SFI..,U 2-5.:5~7~ :- : _2.,3809 tbD 2 3730 8,,0~, -999,2:~OU ~.~ ..179,7~ ~¢0 C:Ab! ~ i-u. 4.63 PR~O -999.2500 ~'~q a ?b -99~,2500 f'~CNL ~9q9-~ 2500 ~*C'N L ~999.2500 SP -g8,5000 GR 168.2:500 ~P.~ t -:999.2500 DP~I 4..a., ~ 99.2.. ~ . - ,., ,~, - .....+, 2.-, .................. -999. 2500 . ' . D~iPT 59uO,UOUO ~¢l..,U !.5e~4 lG,~ : t,6:514 _.t~O ~'~4P" -~99 ~DuO GR 1,~7.:~7-0 CAbi . - 10,27~ DRHO ~ ¢- -~ ~ > ,, ,~' ~ ~.?' '~ ¥ ~ - % .: 2;. k¢ * .~d- ~ ' ': ' : ;- ~4 PA.T ~999. 2500 N Cf',~ [, - ~999' 2~OS ~'CmL -999,25 0'{} ' 2. ! Ag~ I DEPT 580~,0000- SFf,[J : : 2;8'!64 I':L~ * '*' RN(JB -999,2-500 GR C'ALI 1o/0~9! DRPfO .. . R,~u~ -:¢9-9.2~00 GR 1.:26, u.v :,, 0 CAbI 11.4~75 iDAHO . . SP -I08.9375- G~ 101.3::~5 ~P~4Li ~ -_999,2-50C~ DPHI ~;~C'~c~ -'999.2500 GR 101,3t25 CALi' - t_i,1:0'~ DRHO NRAI: · - ,999. 2500 ~605 t0.3..~ ORHO 'qr}~ -999.2~00 GB 85.37:}u C~LI ~:,;.. ~>: ~ , .... { - ,"~ · '" -~' ' "A - .- ' :- _ ,- 1.7422 -999,2500 -~99.2500 i.5781 -999,2500 -999.2500 2.0742 -999.2500 -999.25o0 -999.2500 -999.2500 2. t 406 -999 2500 -999: 2500 2.0293 -999.2500 -999.2500 PAGE 6 S'P ~07;0000 GR a2'OOOO 'WPHI '999.25'00 DPHI ~ AT 'q99;2%00 ¢~ C~:(., ' ~9~9; 2500 FC~/ -999.2500 - ~ -. , . ~. ~ ? ~% ~- . ~- ~ ~'. ~ . ' ' L ~ - - - : - · : : .- . . : - _ _ ~P -I22,5625 GR R8,9:375 ~;'PP~ ~ 3~,3~6~ DP~I R~L)~ 2.29~9 GR . . - 88.937:5 CA~I - 10,72~6 2.2520 . G-e -82.5000 CA~t : . 1.0,6563 OaaO ~''- ': :: -~, ~:- ,:., ', ' : ';":'::;:' n 4400.0000 SP'Lu 3.2012 IL?! 3.6563 tbu -1.0~,875u GN 110,5o00 t~-Ht. - 3o,z305 OPHI : · : :,- ' : -: < - : :' :~ i l~ 2.8262 :999 2500 999~250o 2,4707 -999.2500 -999,2500 2.49O2 99 2500 -999:2500 -999,2500 -999.2500 2.7324 2~,6309 .2187 2~ .81o5 .4844 0.0210 000'0 ' 727 3.4063 24.5605 0.0044 4.21~7 0049 4.5000 24.1211 0.0t51 3.7070 19.8242 I bVP 0tO,P. O1 V~RI?ICATION t, ISTING, , S~ '1,12~7500 ~ 95'. 4375 ,~'PHI 40.0879 ,~' - 4 n~ 0o~' ~ v-u 3 238- I ~ 3-50~9 I-bO S~ -12~. 8'750 GR 94'0000 ~: PI.{ ~ 8,. -t '"'~'" :-"-"" a ~ ' ~Hn~.~ 2,1953 G8 77;'3750 C'~L~ - D~PT 3900.0000 8Fbii _ 2,4980 -l.b~-i · 3,4902 ~ 2i 2'~ ~ ~5~' ~k'~ ~I ;'9'37~ ~0;0:3-91-DPfiI R~OR 2.1836 G.R · 8i.9.~7,5 ~CALI - 13.56~5 DRHO R~O~ ' 2; 1953 eR 79,-I250 CaLl'-- - -t3'9297 DRHO ,. . ~ ~ '~ -- ~ -..~ ~ ~- OgP~ ~700.uO00 5FI, U : - 6,.7~0-5-:~hM.. - 6,..0t56 $° 'i'I3'9'375 GR: "54~2~.-87' ::~"Pfii :: 42/;I97~ SPIll ~'~.'0~ 2~1'309: GR 5~,2t87 CALl ~, I1.~:2969- -.D~O a~Pr - ~600.0000' SF. LU-'~: ::12'7"578 ': t:::i,'~ -" : :. :' :'I1~'2:~78 iLO R:h 0 ~7: 7;2246' G~ '~Sg:'; 25 O0 CaLl tv~ ~j~. :,~ ~ ~< :.. ~ ~. ~ ' :- :,,~.., ,.~ m- .~ ~~ '.¢'~ . -~.::~.~ -~.,,~ - ' F~"* ~'00 O00t: '~F .,~j 7 ~5 ~ 4922 ihD SP -~:6,6875 GP ' ~9.'0000' ~PHI ~:i~'~7 t;~'e, 2'l.' ~::C~J'[; 26i6200t~0 :~CNL '"717-;5000 ILD N~AT ], 4~80 ~C,N]~ i9:55. 0000 FC~L - 57:~,0000 . . . D~ .... :~ '~160 0000 $~LU 6,2~9t Iba 7.9609 1SD :: . : :: - :' _ PAGE 0.0322 3.5605 21.2402 0.0313 3.7793 23 2910 0:0024 2~.707o .1211 0.0039 5.2813 .0098 3.6465 28,2227 0.0049 4.2617 2~.5391 .0225 3~.8242 14453 -0.0063 10.6016 ~5.7813 0.0103 8.5391 23~6328 0.0000 13.0391. 8027 2 ~0845 9.0391 DgP% o~©u,0OOu SFLU .10,4922 IL~4 · 9, 6406 t&D 9.4297 SP -57'2197 ~ 7~.O000 ~P~I 44,9707 uPHI 23.8770 R.~O~ ~ 2559 G~ 78 o-o00 cAg. I li.7i~ DRHO 0.0571 o i.~21u GR ...5.1~75 ~ALI . .8516' D~HO ,0107 D~PT 2900,0000 SPLU 7,.:7617 tG~ :. 8. t0t.~ IUD _~.3594 S~ .52 ~-7~g ~P 7g~-3~ ~-5 ~3"P gI 43,4570 DP~I 27.3926 ~ ~ !:) ~ 2.1973 G~ · ~ 7~,3i~5 -'CALl -lO. 6563 DRMO 0.0352 S~ -7~.5~5 G~ ~4.:~375 ~.~I .52.~855 D-~'HI 31.2988 abO~. 2'1328 GR '64~4375 CALl ~ 12"8594 [)RHO 010146 SP '46,0000: CI~ :!9;156:2' aPHI ' 43.:408t DPHI 33.4473 a~06 2,0977 Ga 39,:t5~2 Ca~I 1-2,0859- bRiO -0,0034 DEpT 2600'0000 $ F i":U -12.2'3~4 i'L'~ '; i2.710:9-ILD 13.0079 R'~O[~ z;0176 GR ' - 56.Ia75 CALI I2;1562 DRHO ;0020 . _ - . . O& P' ~' z~oO. uO!)O 5~gu ~.~4~4 lS~:i 5.7031 !~u 2000 OeO0 S~ zu:~. t250 G~ 37.~7 r~.,~h I 5o, 6 ~00 u~t Oa/i5 ~!3¢ ~ 119717 G~ ']7'~95~7-CALI -!'0.2g9'l D~HO ~,o~4209 : . _ _ - ~AGE 9
