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183-002
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, March 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1E-21 KUPARUK RIV UNIT 1E-21 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/17/2023 1E-21 50-029-20892-00-00 183-002-0 W SPT 5932 1830020 1500 2513 2508 2465 2444 350 390 390 390 OTHER P Guy Cook 1/30/2023 MITIA post Coil Tubing Drilling of 1E-21L1 per PTD 222-144. Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1E-21 Inspection Date: Tubing OA Packer Depth 1140 1900 1880 1870IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230130145706 BBL Pumped:0.7 BBL Returned:0.6 Friday, March 17, 2023 Page 1 of 1 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7420'feet None feet true vertical 6566'feet None feet Effective Depth measured 7143'feet 6697', 6999'feet true vertical 6313'feet 5923', 6187'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 7034' MD 6218' TVD Packers and SSSV (type, measured and true vertical depth) 6697' MD 6999' MD N/A 5923' TVD 6187' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 2207' 2207' Burst Collapse Production Liner 7337' Casing 6511'7368' 2173' 110'Conductor Surface Intermediate 16" 10-3/4" 76' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 183-002 50-029-20892-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL 25651 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1E-21 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 110' ~ ~~ INJECTOR ~~ ~ N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker FHL Packer Packer: Otis WD Perm Packer SSSV: None James Ohlinger james.j.ohlinger@conocophillips.com (907) 265-1102Staff CTD Engineer 6850-6948', 7100-7120', 7128-7158' 6057-6143', 6275-6292', 6299-6326' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Samantha Carlisle at 9:45 am, Jan 26, 2023 Digitally signed by James J. OhlingerDN: C=US, OU=ConocoPhillips, O=Wells - Coiled Tubing Drlling, CN=James J. Ohlinger, E=James.J.Ohlinger@ cop.comReason: I am the author of this document Location:Date: 2023.01.25 11:16:33-09'00' Foxit PDF Editor Version: 12.0.1 James J. Ohlinger DTTMSTART JOBTYP SUMMARYOPS 12/19/2022 DRILLING SIDETRACK Complete RD on 2G-09. Move rig from 2G pad toward 1E pad. 12/20/2022 DRILLING SIDETRACK Continue to move to 1E pad. Spot sub and servce modules oe 1E-21. RU CDR3- AC. Rig accepted @ 10:00am on 12/20/22, Test bop's AOGCC Witnessed by Brian Bixby 250/4000, test tiger tank and pdl's, pick up BHA# 1 HEW 12/21/2022 DRILLING SIDETRACK Finish deploying BHA# 1 HEW, RIH w/ HEW flushing well with seawater, tie in -12' correction, Set HEW on depth 7100' TOWS, displace well to millng fluid , pooh deploy BHA# 2 milling BHA, RIH tie in -13' correction, tag ws pinch point @ 7105' , start milling F/ 7104.8 to midnight depth of 7106.1' 12/22/2022 DRILLING SIDETRACK Complete 2.80" exit, ream window per plan and dry drift clean, TD rat hole @ 7122', POOH for Build assembly 2.4° AKO targeting 45° dls, Flush stack and deploy BHA# 3 RIH tie in -14 correction, pass through window clean, Drill build F/ 7122' T/ 7432' average DLS 47°, POOH for ER Lateral Assembly 12/23/2022 DRILLING SIDETRACK Un-deploy build BHA, Deploy BHA# 4 ER lateral assembly, RIH and drill ahead with .5° AKO w/ nov agitator and HYC A3 bit, drill to depth of 8697, start scheduled wiper trip 12/24/2022 DRILLING SIDETRACK Continue drilling ahead performing wipers when nesessary, 9300' out of zone pump sweeps pooh for OHAB 12/25/2022 DRILLING SIDETRACK Continued out of the hole for OHAB, un-deployed BHA# 4 Lateral assembly, Deployed BHA# 5 OHAB ran in hole tied in for -14, Set TOB 8025', pooh for ER Lateral Assembly, Deploy BHA# 6 ER Lateral Assembly .6° AKO w/ NOV agitator and HYC A3 bit, RIH tie in -13' correction, Dry tag billet @ 7826', mill off billet per best practice and drill ahead performing wipers as needed, new mud at bit 8077' 12/26/2022 DRILLING SIDETRACK Drill ahead from 8,349' to midnight depth of 9585 wiping the hole and tying in per recomended practice. 12/27/2022 DRILLING SIDETRACK Drill ahead 9585 to corrected TD 9802' Perform swab wiper trip. On bottom waiting for liner running pill downhole tool failure. Trip for replacement BHA. PUD BHA #6. Perform BOPE functiob test - Good. PD BHA #7 12/28/2022 DRILLING SIDETRACK Trip in BHA #7, Tie in for -14'. Clean trip to bottom 9802'. POOH pumping beaded liner running pill to window. 13.3PPg KWF to surface. Flow check well. Lay down BHA #7. M/U lower liner segment, Non ported nose, 40 Jts liner, NSQC receptical. Trip in. Correct -17' at pipe flag. Clean pass through window. Set down @ 8308'. Work pipe. Unable to move liner up or down. Release liner. TOL=7050'. POOH for fishing tool string. Make up BHA #9 fish liner with Jars. Trip in. Tie in for -14'. Latch fish @ 7048. Start Jarring up 12/29/2022 DRILLING SIDETRACK Continue jarring on stuck liner. Unable to get liner moving. Release from liner. Trip out for second liner run. Put Sealbore deployment sleeve @ 7010'. Get BHP 4237 PSI, @ sensor depth 6093.54 TVD. Check tree bolts. Trip out. Freeze protect tubing from 2500' with diesel 12/30/2022 DRILLING SIDETRACK Blow down reel with N2, rig up and un-stab coil secure for reel swap , change rams in doors and Nipple down Rig released 06:00 on 12/30/22 1E-21 CTD Summary of Operations Page 1/9 1E-21 Report Printed: 1/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/19/2022 17:00 12/19/2022 19:00 2.00 MIRU, MOVE RURD P Transport the truck shop and halfway house to 1E pad. 0.0 0.0 12/19/2022 19:00 12/19/2022 21:30 2.50 MIRU, MOVE DMOB P Pull service mod from well row, pull sub from 2G-09, jeep up and perform final walk around. 0.0 0.0 12/19/2022 21:30 12/20/2022 00:00 2.50 MIRU, MOVE MOB P Roll off 2G pa with rig. Held up by security at CPF2 pad for 10 minutes - ice road incident where a water buffalo had contacted the ALP sales line. Shelter swapping the sub in front of the pits while waiting. Continue to move rig to 1E pad 0.0 0.0 12/20/2022 00:00 12/20/2022 03:00 3.00 MIRU, MOVE MOB P Continue to 1E pad, Pull off the spine at 01:30 0.0 0.0 12/20/2022 03:00 12/20/2022 06:00 3.00 MIRU, MOVE MOB P On 1E pad, pull Jeeps. Hook up to sow.Rig up cellar containment, Set initial rig mats spot sub over well, spot service mod. 0.0 0.0 12/20/2022 06:00 12/20/2022 10:00 4.00 MIRU, MOVE RURD P Safe out rig. Set stairs. ensure emergency egress routes are clear. Complete cellar rig up. rig up PUTZ interconnect, comms. 0.0 0.0 12/20/2022 10:00 12/20/2022 11:30 1.50 MIRU, WHDBOP NUND P Nipple up BOP'S, continue to RU and prep for BOPE test, grease valves. ***Rig accept 10:00 0.0 0.0 12/20/2022 11:30 12/20/2022 16:30 5.00 MIRU, WHDBOP BOPE P Test BOPE, 250/4000 psi - 2500 psi for annular. AOGCC test witness by Brian Bixby Grease swab and master valves Start BOP test BOP test witness waived 250/4500 psi Test 1. Swab 2 - Pass - 12:01 Test 2. Blind/Shear, BOP TV2, Charlie 4, 5, 8, &12 -pass - 12:31 Test 3. BOP TV1, C3, C6, C7 & C11 - pass - 13:04 Test 4. super Choke C, Manual choke D - pass - 13:10 Test 5. Romeo3, Bleeder 3, Tango 2, C2 and C10 - pass - 13:30 Test 6. Charlie 1, 9, and Tango 1 Pass - ?? Install TIW test joint Test 12. Draw down accumulator. Koomy pressure 3100, close all record stable pressure 2400 psi, time to increase 200 psi 18, entire recovery time 41 - pass Test 7. Lower 2 pipe slip rams, TIW #1, Romeo 1, Bleeder 1-Pass Test 8. Annular BOP 250/2500- Pass 0.0 0.0 12/20/2022 16:30 12/20/2022 18:20 1.84 MIRU, WHDBOP BOPE T Test 9. Upper 2 pipe slip rams, Bravo 6, & 8-Bravo 6 F/P Greased re-tested ( 16:30 - 18:20 ) 0.0 0.0 12/20/2022 18:20 12/20/2022 20:00 1.66 MIRU, WHDBOP BOPE P Test 10. Bravo 7 & Bravo 5 Pass Test 11. 2-3/8 pipe slip rams, TIW#2 - Pass Test 13. Stab injector and line up to reverse circulated inner reel valve - Tested all gas detectors, pits, cellar, Verified flow alarms - 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 12/30/2022 Page 2/9 1E-21 Report Printed: 1/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/20/2022 20:00 12/20/2022 22:15 2.25 SLOT, WELLPR PRTS P Test PDL's TT line 0.0 0.0 12/20/2022 22:15 12/20/2022 22:45 0.50 SLOT, WELLPR CTOP P Valve alignments for Pressure Deploy 2100psi under master 0.0 0.0 12/20/2022 22:45 12/21/2022 00:00 1.25 SLOT, WELLPR PULD P PU BHA #1, Northern Solutions HEW 0.0 78.0 12/21/2022 00:00 12/21/2022 01:00 1.00 SLOT, WELLPR PULD P Pick up and deploy BHA# 1 HEW setting assembly , PDL frozen pump methanol to top and work free 78.0 78.0 12/21/2022 01:00 12/21/2022 03:15 2.25 SLOT, WELLPR TRIP P Tag up set depth 73.04' // RIH flushing well with seawater // Tie in K1 - 12' correction // RIH T/ 7108.8' Pick up to 40K // Pump min rate to shear @ 4000psi 2053 diff 3.55 DHWOB // Set down 3.06 good set // 78.0 7,108.8 12/21/2022 03:15 12/21/2022 03:36 0.35 SLOT, WELLPR CIRC P PU Wt 41 k lbs, PUH to 7,100'. Open EDC, pumping milling fluid to the bit. Flow out erratic, returns falling to nothing. Packed off on the back side. Swap back to seawater, pumping away to the reservoir. 7,108.8 7,100.0 12/21/2022 03:36 12/21/2022 04:36 1.00 SLOT, WELLPR CIRC P Pulling heavy in 7" while attempting to PUH, CT Wt to 70 k lbs. Work pipe and pumps, trying to clear pack off, attempt to pump down the back side, pressure up to 2,500 psi with no movement. Pull coil slowly out of hole 7,100.0 6,320.0 12/21/2022 04:36 12/21/2022 07:42 3.10 SLOT, WELLPR CIRC P Periodically attempt o RBIH, able to RIH at 6320' with 3 k CT Wt. Snubbing -5 k at 6,250'. Working way slowly up hole while waiting on LRS with MetOH, and heated water. Slowly pull into 75 k CT weight at 34449. Unable to RBIH. 6,320.0 3,449.0 12/21/2022 07:42 12/21/2022 11:42 4.00 SLOT, WELLPR CIRC P LRS on location, PJSM, RU and PT to 4500 psi. Bleed the backside from 2000 psi and leave coil in snubbed position. Pump 25 bbls of methanol to the coil @ 1 bpm followed by 25 bbls of diesel at 1 bpm and 20 bbls at 0.25 bpm. Chase diesel with Produced water ~ 146 °F getting 117 ° F across the micro motion. Continue to snub as well allows and bleed WH as it builds. 3,449.0 3,456.0 12/21/2022 11:42 12/21/2022 13:18 1.60 SLOT, WELLPR CIRC P Moving slowly in hole with positive coil weight ~ 9 k lbs. WH climbing to 2000 psi, attempt to flow, packs off quickly, Third try we established circulation to the tiger tank. Pumped 54 bbls around while RIH. Out micro motion up to 111 ° F 3,456.0 4,447.0 12/21/2022 13:18 12/21/2022 14:30 1.20 SLOT, WELLPR TRIP P RIH at 80 ft/min, cut pump from 1.6 bpm to 0.75 bpm.circulate bottoms up. - clean. 4,447.0 7,000.0 12/21/2022 14:30 12/21/2022 15:06 0.60 SLOT, WELLPR TRIP P Start milling fluid down the coil, RIH and time out milling fluid at 7,50', load the well with 7,000.0 7,050.0 12/21/2022 15:06 12/21/2022 16:30 1.40 SLOT, WELLPR TRIP P PU Wt 36 k lbs, POOH displacing well bore to milling fluid targeting 13.1 ppg EMW a the proposed window. 7,050.0 73.0 12/21/2022 16:30 12/21/2022 18:30 2.00 SLOT, WELLPR PULD P PUD BHA #1 78.0 0.0 12/21/2022 18:30 12/21/2022 19:45 1.25 SLOT, WELLPR PULD P PD BHA# 2 window mill assembly 1° FB Motor w/ 2.80 NS mill and string reamer 0.0 78.0 12/21/2022 19:45 12/21/2022 21:00 1.25 SLOT, WELLPR TRIP P RIH with window milling BHA 78.0 6,780.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 12/30/2022 Page 3/9 1E-21 Report Printed: 1/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/21/2022 21:00 12/21/2022 21:15 0.25 SLOT, WELLPR DLOG P Log K1 for depth control // Tie in for -13' correction // 6,780.0 6,814.0 12/21/2022 21:15 12/21/2022 21:30 0.25 SLOT, WELLPR TRIP P RIH dry tag WS @ 7105' 6,814.0 7,105.0 12/21/2022 21:30 12/22/2022 00:00 2.50 PROD1, WHPST WPST P Pick up start pumps establis perameters 1.83 5127 pp 730 diff 4188 ann Mill 2.80" exit F/ 7104.8 T/ 7106.1 7,105.0 7,106.1 12/22/2022 00:00 12/22/2022 02:00 2.00 PROD1, WHPST WPST P 1.83 5127 pp 730 diff 4188 ann Mill 2.80" exit F/ 7106.1 T/ 7107.9 Exit Continue time milling F/ 7107.9 T/ 7122.36 complete dressing of exit with string reamer 7,106.1 7,107.9 12/22/2022 02:00 12/22/2022 05:30 3.50 PROD1, WHPST WPST P Mill rat hole to TD of 7121.8' 7,107.9 7,121.8 12/22/2022 05:30 12/22/2022 06:30 1.00 PROD1, WHPST REAM P Perform reaming passes at HS, 30L, 30R, dry drift - clean, tag bottom, 7,121.8 7,121.8 12/22/2022 06:30 12/22/2022 08:36 2.10 PROD1, WHPST TRIP P POOH chasing sweeps to surface 7,121.8 78.0 12/22/2022 08:36 12/22/2022 10:18 1.70 PROD1, WHPST TRIP P Bump up, space out, PUD BHA # 2 window milling assembly. 78.0 0.0 12/22/2022 10:18 12/22/2022 11:18 1.00 PROD1, DRILL CIRC P Stab on, injector, jet stack, unstab 0.0 0.0 12/22/2022 11:18 12/22/2022 12:51 1.55 PROD1, DRILL PULD P PD BHA #3, build drilling assembly, 2.4 ° AKO over a RB HCC bit. 0.0 72.0 12/22/2022 12:51 12/22/2022 14:39 1.80 PROD1, DRILL TRIP P RIH w BHA #3, 72.0 6,780.0 12/22/2022 14:39 12/22/2022 14:51 0.20 PROD1, DRILL TRIP P Tie into the K1 for a -14' corection 6,780.0 7,033.0 12/22/2022 14:51 12/22/2022 15:03 0.20 PROD1, DRILL TRIP P Continue in hole, WOB spike to 2 k lbs as we ran past CMU @ 6969'. Continue in hole through window - clean. Some sort of pump issue, Pulled back into 7" to troubleshoot. 2" bleeder washed out. swap pumps, RBIH, window clean - 7,033.0 7,121.8 12/22/2022 15:03 12/22/2022 16:12 1.15 PROD1, DRILL DRLG P WH 900, IA 360, OA 448, CT 5100, At 1.82 bpm in and out. Free spin 608 psi BHP 4,322 psi targeting 13.2 ppg at the bit. CT Wt 14.9 k lbs, WOB 3 k lbs. Diff pressure falling off with WOB, PU Wt 40 k lbs, restart, 7,124.0 7,191.0 12/22/2022 16:12 12/22/2022 22:45 6.55 PROD1, DRILL DRLG P Diff pressure falling off with WOB, PU Wt 40 k lbs, restart, WH 851 psi, IA 572 psi, OA 564 psi, CT 5000 psi at 1.82 in and out, free spin 530 psi, BHP 13.16 ppg EMW, BHP 4302 psi, CT Wt 16 k lbs, WOB 3 k lbs. Stacking WOB with no motor work. Spud it, get back to drilling. Drill ahead. T/ 7432' Avrg. DLS 47° 7,191.0 7,432.0 12/22/2022 22:45 12/22/2022 22:54 0.15 PROD1, DRILL TRIP P POOH for ER Lateral Assembly 7,432.0 7,060.0 12/22/2022 22:54 12/22/2022 23:06 0.20 PROD1, DRILL CTOP P Pressure Check @ window 6203.12 TVD at pressure sensor 5257 Ann 13.21 Equiv resivoir pressure 7,060.0 7,060.0 12/22/2022 23:06 12/22/2022 23:30 0.40 PROD1, DRILL CIRC P Jet 7" tubing 7,060.0 7,019.0 12/22/2022 23:30 12/23/2022 00:00 0.50 PROD1, DRILL TRIP P POOH for ER Lateral Assembly 7,019.0 5,133.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 12/30/2022 Page 4/9 1E-21 Report Printed: 1/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/23/2022 00:00 12/23/2022 01:00 1.00 PROD1, DRILL TRIP P POOH for lateral assembly // Tag up space out 1.2' // 5,133.0 78.0 12/23/2022 01:00 12/23/2022 02:18 1.30 PROD1, DRILL PULD P PJSM // PUD BHA# 3 // Bit Out 2-4-CT- A-X-I-NO-BHA 78.0 0.0 12/23/2022 02:18 12/23/2022 03:30 1.20 PROD1, DRILL PULD P Pick up and PD BHA# 4 // .5° AKO w/ NOV Agitator and HYC A3 Cutter Bit 0.0 73.0 12/23/2022 03:30 12/23/2022 04:45 1.25 PROD1, DRILL TRIP P RIH w/ ER Lateral Assembly 73.0 6,760.0 12/23/2022 04:45 12/23/2022 05:03 0.30 PROD1, DRILL DLOG P Tie into the Ra tag for a -14' correction 6,760.0 6,806.3 12/23/2022 05:03 12/23/2022 05:15 0.20 PROD1, DRILL TRIP P Continue in hole,pass through window - clean 6,806.0 7,124.0 12/23/2022 05:15 12/23/2022 05:27 0.20 PROD1, DRILL DLOG P Log RA tag at 7,107' Top of WS at 7100' everything on depth. 7,124.0 7,186.0 12/23/2022 05:27 12/23/2022 05:39 0.20 PROD1, DRILL TRIP P Continue through build pumping 0.5 bpm, targeting 13.1 ppg EMW at the window. 7,124.0 7,432.0 12/23/2022 05:39 12/23/2022 08:45 3.10 PROD1, DRILL TRIP P WH 788 psi, IA 210 psi, OA 360 psi, CT 5,458 psi, AT 1.80 bpm in & out. Free spin 830 psi, BHP 4,347 psi targeting 13.1 ppg EMW @ the window. CT Wt 11 k lbs, WOB 1.6 k lbs ROP ~200 ft/ hr. 7,432.0 7,876.0 12/23/2022 08:45 12/23/2022 09:03 0.30 PROD1, DRILL WPRT P PU Wt 36 k lbs, PUH on scheduled wiper #1 of 2, chase 5x5 sweep up hole. **** ~7 k CT over pull @ 7,411' and WOB to -1 k with motor work at 7,345' as coil connector and motor pulled through higher gamma transition zone - looks like a fault. 7,876.0 7,149.0 12/23/2022 09:03 12/23/2022 09:27 0.40 PROD1, DRILL WPRT P RBIH 0.28 bbls cuttings returned on the trip 7,149.0 7,876.0 12/23/2022 09:27 12/23/2022 11:15 1.80 PROD1, DRILL DRLG P WH 726 psi, IA 617 psi, OA 654 psi, CT 5162 psi at 1.82 bpm in & out. Free spin 773 psi, BHP 4,377 psi targeting 13.15 ppg EMW at the window and getting 13.3 ppg EMW at the bit. CT 8 k lbs, WOB 1.9 k lbs, ROP 40 ft/hr. Swap mud, new mud at the bit 7,945'. 7,876.0 8,023.0 12/23/2022 11:15 12/23/2022 15:33 4.30 PROD1, DRILL DRLG P PU Wt 36 k lbs, Pick up to get new parameters with new mud around. WH 884 psi, IA 526 psi, OA 624 psi, CT 5,133 psi at 1.82 bpm in & out. Free spin 800 psi, BHP 4,383 psi targeting 13.15 ppg EMW at the window and getting 13.3 ppg EMW at the bit. RIH CT WT 11 k lbs. OBD, CT Wt 8,023.0 8,280.0 12/23/2022 15:33 12/23/2022 16:24 0.85 PROD1, DRILL WPRT P PU Wt 36 k lbs, PUH on scheduled wiper #2 of 2, chase 5x5 sweep up hole. 8,280.0 6,769.0 12/23/2022 16:24 12/23/2022 16:36 0.20 PROD1, DRILL TRIP P Tie in to the4 K1 for a +3. 6,769.0 6,813.6 12/23/2022 16:36 12/23/2022 17:06 0.50 PROD1, DRILL TRIP P RBIH, Jet 7" 6,813.6 7,019.0 12/23/2022 17:06 12/23/2022 17:30 0.40 PROD1, DRILL TRIP P RBIH 0.32 bbls cuttings returned on the trip 7,019.0 8,280.0 12/23/2022 17:30 12/23/2022 23:48 6.30 PROD1, DRILL DRLG P BOBD F/ 8280 T/ 8697' 8,280.0 8,697.0 12/23/2022 23:48 12/24/2022 00:00 0.20 PROD1, DRILL WPRT P Wiper T/ 7700 8,697.0 7,700.0 12/24/2022 00:00 12/24/2022 00:45 0.75 PROD1, DRILL WPRT P Wiper trip 7,700.0 8,697.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 12/30/2022 Page 5/9 1E-21 Report Printed: 1/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/24/2022 00:45 12/24/2022 12:45 12.00 PROD1, DRILL DRLG P BOBD F/ 8697 T/ 9090 1.81 bpm 872 diff 5300 pp ** note driller side PDL heat trace out at 11:00 am - notified driller and pusher 8,697.0 9,090.0 12/24/2022 12:45 12/24/2022 13:45 1.00 PROD1, DRILL WPRT P PU Wt 36 k lbs, PUH on scheduled wiper #2 of 2. WH 753 psi, IA 692 psi, OA 686 psi -WOB tugs at 8,775' belly of last big TF change 9,090.0 7,126.0 12/24/2022 13:45 12/24/2022 13:54 0.15 PROD1, DRILL DLOG P Tie into the RA tag for a +2' correction 7,126.0 7,144.0 12/24/2022 13:54 12/24/2022 14:12 0.30 PROD1, DRILL WPRT P Chase 5x5 sweep into 7", follow into cased hole, window clean - jet 7" 7,144.0 7,016.0 12/24/2022 14:12 12/24/2022 16:24 2.20 PROD1, DRILL TRIP P RBIH, set down in window, PU, try again 2 tmes, pass through the third. RIH, Stack WOB to 4 k lbs @ 8,080' (same as las trip in) and in the belly at 8,780'. 7,016.0 9,090.0 12/24/2022 16:24 12/24/2022 21:48 5.40 PROD1, DRILL DRLG P WH 743 psi, IA 514 psi, OA 594 psi, CT 5852 pis @ 1.81 bpm in and 1.63 bpm out. Free spin 838 psi, BHP 4,527 psi targeting 13.1 ppg EMW at the window getting 13.78 at the bit. CT Wt 1.42 k lbs, WOB 1.31 k lbs. ROP ~ 80 ft/ hr Drill out of zone ending @ 9300' , pump sweeps to pooh for OHAB 9,090.0 9,300.0 12/24/2022 21:48 12/25/2022 00:00 2.20 PROD1, DRILL TRIP T POOH for OHAB // PU WT 9,300.0 1,600.0 12/25/2022 00:00 12/25/2022 00:30 0.50 PROD1, DRILL TRIP T POOH // Tag up space out 1.2' // 1,600.0 75.0 12/25/2022 00:30 12/25/2022 02:00 1.50 PROD1, DRILL PULD T PJSM // Un-Deploy BHA# 4 2-2-CT-A-X -I-NO-BHA 75.0 0.0 12/25/2022 02:00 12/25/2022 03:00 1.00 PROD1, DRILL PULD T Pressure Deploy BHA# 5 OHAB 0.0 75.0 12/25/2022 03:00 12/25/2022 04:24 1.40 PROD1, DRILL TRIP T RIH w/ OHAB taking light retturns to tiger tank. 75.0 6,767.0 12/25/2022 04:24 12/25/2022 04:36 0.20 PROD1, DRILL DLOG T Tie into the K1 for a -14' correction Close EDC 6,767.0 6,813.0 12/25/2022 04:36 12/25/2022 05:33 0.95 PROD1, DRILL WPST T RIH w/ OHAB Window clean. Start building WOB @ 7,182' up to ~1 k lbs, fell off slowly by 7,428'. RIH to bit depth of 7,836.75' PU to neutral weight, Pump 0.5 bpm, tool sheared @ 6,500 bore pressure, WOB climbed to 3.8 k lbs, PU clean, Set down 2.3 k lbs WOB, good set. 6,813.0 7,836.0 12/25/2022 05:33 12/25/2022 07:33 2.00 PROD1, DRILL TRIP T PUH, into 7". Attempt to close EDC - failed. POOH w failed EDC. MW in out = 8.69 ppg. Bring mud back inside continue out of hole. 7,836.0 72.0 12/25/2022 07:33 12/25/2022 09:45 2.20 PROD1, DRILL PULD T tag up, PUD with failed checks checklist since EDC failed and would not open. DS PDL, freezing up. Tools stuck, utalizie MetOH to free. 72.0 0.0 12/25/2022 09:45 12/25/2022 11:15 1.50 PROD1, DRILL PULD T PD BHA #6 - L1 re drill erd assembly. 0.0 78.2 12/25/2022 11:15 12/25/2022 12:21 1.10 PROD1, DRILL TRIP T RIH w BHA #6 78.2 6,780.0 12/25/2022 12:21 12/25/2022 12:33 0.20 PROD1, DRILL DLOG T Tie into the K1 for a -13' correction. 6,780.0 6,806.8 Rig: NABORS CDR3-AC RIG RELEASE DATE 12/30/2022 Page 6/9 1E-21 Report Printed: 1/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/25/2022 12:33 12/25/2022 13:15 0.70 PROD1, DRILL TRIP T Close EDC, Continue to RIH *** Dry tag TOB 7827' PU Wt 36 k lbs 6,806.8 7,827.0 12/25/2022 13:15 12/25/2022 15:15 2.00 PROD1, DRILL KOST T PU, set rate, RIH to KO billet per 1,2,3 procedure. WH 729 psi, IA 108 psi, OA 128 psi, CT 5,707 psi @ 1.8 bpm in /out. Free spin 880 psi, BHP 4370 psi targeting 13.1 ppg @ the window, getting 13.26 ppg @ the bit. Start milling @ 7826.24' and 13:30, feed a few tenths per 6 minutes, engage auto drill at 1'/hr, 2ft/hr at 7,827.28', 7,827.0 7,828.6 12/25/2022 15:15 12/25/2022 17:15 2.00 PROD1, DRILL KOST T Off the billet, drilling ahead slowly, 7,828.6 7,830.0 12/25/2022 17:15 12/25/2022 22:51 5.60 PROD1, DRILL DRLG T Drill Ahead T/ 8300 7,830.0 8,300.0 12/25/2022 22:51 12/25/2022 23:30 0.65 PROD1, DRILL WPRT T Wiper to 7400' // Pick up wt 34K // Drift Billet Clean // 8,300.0 8,300.0 12/25/2022 23:30 12/26/2022 00:00 0.50 PROD1, DRILL DRLG T BOBD F/ 8300 T/ 8349' 1.81 bpm 836 diff 5285 pp 4374 ann 13.48 ECD MW in 8.59 MW out 8.65 Down wt 14k running in hole 8,300.0 8,349.0 12/26/2022 00:00 12/26/2022 03:45 3.75 PROD1, DRILL DRLG T BOBD F/ 8349' T/ 8700 1.81 bpm 836 diff 5285 pp 4374 ann 13.48 ECD MW in 8.59 MW out 8.65 Down wt 14k running in hole 8,349.0 8,700.0 12/26/2022 03:45 12/26/2022 04:33 0.80 PROD1, DRILL WPRT T Wiper to window for tie in and jet 7" 8,700.0 7,121.0 12/26/2022 04:33 12/26/2022 04:42 0.15 PROD1, DRILL DLOG T Tie into the RA tag for a +2' correction. 7,121.0 7,139.0 12/26/2022 04:42 12/26/2022 05:06 0.40 PROD1, DRILL CIRC T Jet 7" casing 7,139.0 7,145.0 12/26/2022 05:06 12/26/2022 05:42 0.60 PROD1, DRILL TRIP T RBIH 7,145.0 8,700.0 12/26/2022 05:42 12/26/2022 11:42 6.00 PROD1, DRILL DRLG T WH 850 psi, IA 446 psi, OA 497 psi, CT 5409 psi at 1.82 bpm in & out. Free spin 836 psi. BHP 4,413 psi while targeting 13.1 ppg EMW at the window and getting 13.4 ppg EMW at the bit. OBD, Ct Wt 4.8 k lbs, WOB 2 k lbs, ROP 41 ft/hr. 8793' PU Wt 42 k lbs 810 psi FS @ 1,81 bpm 9091 PU Wt 40 k lbs 8,700.0 9,100.0 12/26/2022 11:42 12/26/2022 12:03 0.35 PROD1, DRILL WPRT T PU Wt 38 k lbs, PUH on scheduled wiper #1 of 2 9,092.0 8,298.0 12/26/2022 12:03 12/26/2022 12:27 0.40 PROD1, DRILL WPRT T RBIH, CT Wt 15 k to 3 k @ 35 ft/min 8,298.0 9,092.0 12/26/2022 12:27 12/26/2022 15:03 2.60 PROD1, DRILL DRLG T WH 808 psi, IA 664 psi, OA 673 psi. CT 5,484 psi @ 1.80 in & out. Free spin 810 psi BHP is 4,467 psi targeting 13.1 ppg @ the window getting 13.5 ppg EMW at the bit. 9,092.0 9,300.0 12/26/2022 15:03 12/26/2022 18:15 3.20 PROD1, DRILL DRLG P Off trouble time. Drill ahead to 9,438 9,300.0 9,438.0 12/26/2022 18:15 12/26/2022 19:15 1.00 PROD1, DRILL WPRT P PU Wt 40 k lbs, PUH on long wiper to the window. Pull past RA tag while watching gamma. 0.45 bbls cuttings returned on the trip. 9,438.0 7,120.0 12/26/2022 19:15 12/26/2022 19:24 0.15 PROD1, DRILL DLOG P Tie into the RA tag for a +4' correction. 7,120.0 7,139.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 12/30/2022 Page 7/9 1E-21 Report Printed: 1/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/26/2022 19:24 12/26/2022 19:48 0.40 PROD1, DRILL CIRC P Jet 7" casing 7,139.0 7,108.0 12/26/2022 19:48 12/26/2022 21:00 1.20 PROD1, DRILL TRIP P RBIH, set down in the window, PU Spin the bit, re-try, clean.RIH. 7,108.0 9,438.0 12/26/2022 21:00 12/27/2022 00:00 3.00 PROD1, DRILL DRLG P WH 832 psi, IA 554 psi, OA 667 psi, CT 5858 psi, @ 1.85 in and out. free spin 857 psi, BHP 4539 psi targeting 13.1 ppg EMW at the window getting 13.86 ppg at the bit. CT 3.74 WOB 2 k lbs. 9,438.0 9,585.0 12/27/2022 00:00 12/27/2022 08:30 8.50 PROD1, DRILL DRLG P Drill Ahead T/9785 9,585.0 9,785.0 12/27/2022 08:30 12/27/2022 10:00 1.50 PROD1, DRILL WPRT P Wiper to 8700' // PU Wt. 37K 9,785.0 9,785.0 12/27/2022 10:00 12/27/2022 10:24 0.40 PROD1, DRILL DRLG P Drill to TD @ 9797 9,785.0 9,797.0 12/27/2022 10:24 12/27/2022 12:42 2.30 PROD1, DRILL WPRT P Pump 10 X 10 sweeps start swab wiper 9,797.0 7,070.0 12/27/2022 12:42 12/27/2022 13:00 0.30 PROD1, DRILL CTOP P Pressure Survey @ window 7070.68 MD 6206.99 TVD 4124 ann 7,070.0 7,070.0 12/27/2022 13:00 12/27/2022 14:18 1.30 PROD1, DRILL WPRT P Swab wiper // Tag up set depth 7,070.0 78.0 12/27/2022 14:18 12/27/2022 15:36 1.30 PROD1, DRILL TRIP P RIH to confirm TD 78.0 6,780.0 12/27/2022 15:36 12/27/2022 15:42 0.10 PROD1, DRILL DLOG P Log K1 tie in for -14' correction 6,780.0 6,803.0 12/27/2022 15:42 12/27/2022 17:36 1.90 PROD1, DRILL TRIP P Continue in to confirm TD, Set down @ 9802' confirmed TD, Recip waiting on liner running pill 6,803.0 9,802.0 12/27/2022 17:36 12/27/2022 19:00 1.40 PROD1, DRILL TRIP P Recip CT, waiting on liner ruuning pill / kill weight fluid 9,802.0 9,720.0 12/27/2022 19:00 12/27/2022 21:42 2.70 PROD1, DRILL TRIP T Trouble shoot dead tool. Able to power up. Unable to see tools or pressures. 9,720.0 62.9 12/27/2022 21:42 12/27/2022 23:00 1.30 PROD1, DRILL PULD T Tag up - Space out. PJSM. PUD BHA #6 62.9 12/27/2022 23:00 12/27/2022 23:30 0.50 PROD1, DRILL BOPE P Perform BOPE function test - Good 12/27/2022 23:30 12/28/2022 00:00 0.50 PROD1, DRILL PULD T PJSM, PD BHA #7. Lateral drilling BHA with RR HYC bit. No USR or agitator 12/28/2022 00:00 12/28/2022 00:18 0.30 PROD1, DRILL PULD T Continue presswure deploying BHA #7. Make up to coil and surface test, Tag up and set counters 62.6 62.6 12/28/2022 00:18 12/28/2022 01:36 1.30 PROD1, DRILL TRIP T RIH BHA #7 62.6 6,770.0 12/28/2022 01:36 12/28/2022 02:00 0.40 PROD1, DRILL DLOG T Log K1 for -12', PUW=33 6,770.0 6,802.0 12/28/2022 02:00 12/28/2022 03:15 1.25 PROD1, DRILL TRIP P Continue in well BHI off trouble time 6,802.0 9,803.0 12/28/2022 03:15 12/28/2022 05:30 2.25 PROD1, DRILL CIRC P Circulate for LRP and KWF 9,803.0 9,803.0 12/28/2022 05:30 12/28/2022 08:00 2.50 PROD1, DRILL TRIP P POOH lay in lrp and KWF // Paint EOP flags 9,803.0 100.0 12/28/2022 08:00 12/28/2022 08:15 0.25 PROD1, DRILL CTOP P Flow Check Will // No Flow // PJSM lay down dead well 100.0 100.0 12/28/2022 08:15 12/28/2022 09:00 0.75 PROD1, DRILL PULD P Lay down BAH# 7 Clean out well kill assemlby 100.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 12/30/2022 Page 8/9 1E-21 Report Printed: 1/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/28/2022 09:00 12/28/2022 09:15 0.25 COMPZ1, CASING RURD P Rig up to run liner 0.0 0.0 12/28/2022 09:15 12/28/2022 11:15 2.00 COMPZ1, CASING PUTB P Pick up 40 jts 2-3/8" Liner 0.0 1,252.0 12/28/2022 11:15 12/28/2022 11:39 0.40 COMPZ1, CASING PULD P Pick up Baker BHA // Put cart on well // 1,252.0 1,297.0 12/28/2022 11:39 12/28/2022 15:00 3.35 COMPZ1, CASING RUNL P Run liner in hole // Tie in window flag - 14' correction // Continue in hole to bottom // Started working pipe @ 8300' // Stuck pipe 1,297.0 8,300.0 12/28/2022 15:00 12/28/2022 17:18 2.30 COMPZ1, CASING TRIP T Pump off liner leaving TOL 7050' // . RBIH to confirm relatch - Good. POOH for fishing tools 8,300.0 70.0 12/28/2022 17:18 12/28/2022 17:54 0.60 COMPZ1, CASING PULD T At surface, flow check well, Lay down BHA #8, Liner running tools 70.0 0.0 12/28/2022 17:54 12/28/2022 20:54 3.00 COMPZ1, CASING RGRP T Weld cracked braces in CT storage reel 0.0 0.0 12/28/2022 20:54 12/28/2022 22:00 1.10 COMPZ1, CASING PULD T M/U BHA #9 to fish / retrieve liner, Make up to coil and surface test tools. Tag up and set counerds 0.0 56.8 12/28/2022 22:00 12/28/2022 23:30 1.50 COMPZ1, CASING TRIP T Trip in well, BHA #9 56.8 6,790.0 12/28/2022 23:30 12/28/2022 23:36 0.10 COMPZ1, CASING DLOG T Log K1 for -14-, Close EDC, PUW=33K 6,790.0 6,804.0 12/28/2022 23:36 12/28/2022 23:48 0.20 COMPZ1, CASING TRIP T Continue in well, Set down @ 7054'. PUH, we are latched up to liner 6,804.0 7,054.0 12/28/2022 23:48 12/29/2022 00:00 0.20 COMPZ1, CASING JAR T Start Jarring on liner 7,054.0 7,054.0 12/29/2022 00:00 12/29/2022 06:18 6.30 COMPZ1, CASING JAR T Continue Jarring on fish. 30K over // 55 jarring cycles no movement // pump off fish 7,054.0 7,054.0 12/29/2022 06:18 12/29/2022 06:48 0.50 COMPZ1, CASING CTOP T Flow check well 7,054.0 7,025.0 12/29/2022 06:48 12/29/2022 08:18 1.50 COMPZ1, CASING TRIP T POOH for second liner run 7,025.0 68.0 12/29/2022 08:18 12/29/2022 08:33 0.25 COMPZ1, CASING CTOP T Flow check well // PJSM laying down BHA 68.0 68.0 12/29/2022 08:33 12/29/2022 09:00 0.45 COMPZ1, CASING PULD T Lay down BHA dead well 68.0 0.0 12/29/2022 09:00 12/29/2022 10:00 1.00 COMPZ1, CASING PULD T Pick up liner and baker BHA# 10 0.0 75.0 12/29/2022 10:00 12/29/2022 12:00 2.00 COMPZ1, CASING TRIP T TIH with BHA# 10 // Tie in -13' // Tag liner @ 7050' // PU -.3.5K DHWOB // Pump off liner 75.0 7,050.0 12/29/2022 12:00 12/29/2022 12:15 0.25 DEMOB, WHDBOP CTOP P Check tree bolts with liner in hole 7,050.0 7,010.0 12/29/2022 12:15 12/29/2022 12:45 0.50 DEMOB, WHDBOP CIRC P Pump seawater to bit 7,010.0 7,010.0 12/29/2022 12:45 12/29/2022 14:15 1.50 DEMOB, WHDBOP TRIP P POOH swapping well to seawater 7,010.0 2,500.0 12/29/2022 14:15 12/29/2022 15:30 1.25 DEMOB, WHDBOP CIRC P Hook up little red pump 30bbls freeze protect into well 2,500.0 2,500.0 12/29/2022 15:30 12/29/2022 16:18 0.80 DEMOB, WHDBOP TRIP P Pull out of hole laying in freeze protect 2,500.0 75.0 12/29/2022 16:18 12/29/2022 17:54 1.60 DEMOB, WHDBOP PULD P PJSM // Undeploy BHA# 10 Lay down tools 75.0 0.0 12/29/2022 17:54 12/29/2022 19:12 1.30 DEMOB, WHDBOP CTOP P Install nozzle. Stab back on well. Flush BOPE and rig 0.0 0.0 12/29/2022 19:12 12/29/2022 20:06 0.90 DEMOB, WHDBOP CTOP P Unstab injector. Blow down surface lines 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 12/30/2022 Page 9/9 1E-21 Report Printed: 1/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/29/2022 20:06 12/29/2022 20:42 0.60 DEMOB, WHDBOP CTOP P Install Big hole nozzle, Remove floats in UQC. Stab back on well for N2 reel blowdown 0.0 0.0 12/29/2022 20:42 12/29/2022 22:12 1.50 DEMOB, WHDBOP CTOP P PJSM w/ SLB N2 crew. Rig up and cool down N2 unit 0.0 0.0 12/29/2022 22:12 12/29/2022 22:30 0.30 DEMOB, WHDBOP CTOP P N2 online down CT 1500 SCFM for 15 minutes 0.0 0.0 12/29/2022 22:30 12/29/2022 23:18 0.80 DEMOB, WHDBOP CTOP P Shut down N2, Rig down pumper. Bleed off N2 0.0 0.0 12/29/2022 23:18 12/29/2022 23:30 0.20 DEMOB, WHDBOP CTOP P Unstab injector, Pull UQC. 0.0 0.0 12/29/2022 23:30 12/30/2022 00:00 0.50 DEMOB, WHDBOP CTOP P Position reel. Lock out. Start removing inner reel iron, wash pipe, and high pressure bulkhead 0.0 12/30/2022 00:00 12/30/2022 01:30 1.50 DEMOB, WHDBOP CTOP P Continue removing inner reel iron, wash pipe, and high pressure bulkhead from reel 0.0 0.0 12/30/2022 01:30 12/30/2022 03:30 2.00 DEMOB, WHDBOP CTOP P PJSM, Rig up stabbing cable to coil. Pull CT out of injector back to reel and secure 0.0 0.0 12/30/2022 03:30 12/30/2022 06:00 2.50 DEMOB, WHDBOP NUND P Prep to change rams // Nipple down stack // Rig Released 06:00 on 12/30/22 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 12/30/2022 1E-21 CTD Schematic 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco MMG mandrel @ 6623' MD Baker 3-1/2" PBR @ 6684' MD (3" ID) Baker FHL packer @ 6697' MD (4.0" ID) 3-1/2" DS Nipple @ 6750' MD (2.813" ID) 3-1/2" Camco MMG mandrel @ 6804' MD CMU Sliding Sleeve @ 6983' MD (2.813' BX - 2.992") _________________ Otis packer @ 6999' MD (4.0" ID) 3-1/2" Camco D landing nipple @ 7022' MD (2.80" min ID) 3-1/2" SOS @ 7033' MD 10-3/4" 45.5# J-55 shoe @ 2207' MD 7" 26# K-55 shoe @ 7368' MD 16" 65# H-40 shoe @ 110' MD A-sand perfs 7100' - 7158' MD KOP @ 7100' MD C-sand perfs 6850' - 6948' MD 1E-21L1 TD 9803' MD Bottom of Liner 8300' MD Liner Top ~ 7010' MD 1E-21L1PB1 TD 9300' MD OHA Billet @ 7825' Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: SLM 7,143.0 1E-21 11/1/2022 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Milled nipple 1E-21 12/10/2022 famaj Notes: General & Safety Annotation End Date Last Mod By Note: Top of L1 CTD liner (SBR) at 7010' RKB 12/29/2022 spilch NOTE: Perform 100 bbl dynamic acid dispersion treatment with CT from 7,090' RKB - 7,150' RKB 5/10/2017 pproven Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 16 15.06 34.0 110.0 110.0 65.00 H-40 WELDED SURFACE 10 3/4 9.95 33.8 2,207.1 2,207.0 45.50 J-55 BTC PRODUCTION 7 6.28 31.3 7,368.4 6,510.5 26.00 K-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 30.2 Set Depth 6,691.9 Set Depth 5,919.2 String Ma 3 1/2 Tubing Description Tubing Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd Mod ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 30.2 30.2 0.00 HANGER 7.100 FMC TBG Hanger FMC 2.950 6,622.5 5,858.9 30.02 GAS LIFT 5.968 MANDREL,3 1/2X1- 1/2",MMG,EUE8RMOD,CAMCO SOV 2,000 psi csg to tbg Camco MMG 2.915 6,679.1 5,908.1 29.21 LOCATOR 4.500 Baker Locator Sub Baker 3.000 6,680.1 5,908.9 29.23 SEAL ASSY 3.760 Baker 80-40 Seal assembly Baker Seal Assym 3.000 Top (ftKB) 6,683.9 Set Depth 7,004.3 Set Depth 6,191.5 String Ma 3 1/2 Tubing Description Tubing Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,683.9 5,912.2 29.33 PBR 5.010 10-ft Baker 80-40 PBR Baker PBR 4.000 6,696.7 5,923.4 29.64 PACKER 7.000 Baker FHL Packer Baker FHL 3.000 6,750.3 5,970.1 29.53 NIPPLE 3.500 NIPPLE "NO GO" DS 2.812"Camco DS 2.813 6,803.5 6,016.5 28.93 GAS LIFT 5.968 Injection MANDREL,3 1/2X1- 1/2",MMG,EUE8RMOD,CAMCO Camco MMG 2.915 6,852.5 6,059.4 29.38 Blast Joint 3.500 Baker 20-ft 3-1/2" Blast Joints Baker 2.992 6,982.9 6,173.0 29.73 SLIDING SLV 4.480 2.813" BX CMU Sliding Sleeve Baker CMU 2.992 6,995.2 6,183.7 29.80 SEAL ASSY 4.000 Otis Seal Assembly Otis 2.980 Top (ftKB) 6,999.3 Set Depth 7,034.4 Set Depth 6,217.7 String Ma 6 5/32 Tubing Description Tubing Production Wt (lb/ft)Grade Top Connection ID (in) 4.00 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,999.3 6,187.2 29.83 PACKER 6.156 OTIS WD PERMANENT PACKER 4.000 7,021.9 6,206.9 29.35 NIPPLE 4.520 CAMCO D NIPPLE NO GO (MILLED TO 2.80" ON 12/10/22) 2.800 7,033.1 6,216.6 29.27 SOS 4.000 OTIS SHEAR OUT SUB 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,010.0 6,196.5 29.61 LINER TOP SBR (CTD liner top from Dec 2022) 12/29/2022 1.910 7,100.0 6,275.0 29.04 WHIPSTOCK Northern Solutions HEW Northern Solutions HEW 12/20/2022 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 6,622.5 5,858.9 30.02 1 GAS LIFT DMY RK 1 1/2 0.0 11/12/2016 0.000 6,803.5 6,016.5 28.93 2 INJ DMY RKP 1 1/2 0.0 11/12/2016 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,850.0 6,948.0 6,057.2 6,142.6 C-4, C-3, C-2, C- 1, 1E-21 1/20/1983 4.0 IPERF 7,100.0 7,120.0 6,275.0 6,292.5 A-4, 1E-21 1/24/2017 6.0 APERF 6 SPF 60* PHASE MILLENIUM II PERF GUN 7,101.0 7,115.0 6,275.9 6,288.1 A-5, 1E-21 1/20/1983 4.0 IPERF 7,128.0 7,138.0 6,299.5 6,308.2 A-4, 1E-21 1/24/2017 6.0 APERF 6 SPF 60* PHASE MILLENIUM II PERF GUN 7,130.0 7,145.0 6,301.2 6,314.4 A-4, 1E-21 1/20/1983 4.0 IPERF 7,138.0 7,158.0 6,308.2 6,325.7 A-4, 1E-21 1/23/2017 6.0 APERF 6 SPF 60* PHASE MILLENIUM II PERF GUN 1E-21, 1/25/2023 7:43:32 AM Vertical schematic (actual) Slotted Liner; 7,010.2-8,300.0 PRODUCTION; 31.3-7,368.4 APERF; 7,138.0-7,158.0 IPERF; 7,130.0-7,145.0 APERF; 7,128.0-7,138.0 APERF; 7,100.0-7,120.0 IPERF; 7,101.0-7,115.0 WHIPSTOCK; 7,100.0 LINER TOP; 7,010.0 LINER TOP; 7,010.0 PACKER; 6,999.3 SLIDING SLV; 6,982.9 IPERF; 6,850.0-6,948.0 GAS LIFT; 6,803.5 NIPPLE; 6,750.3 PACKER; 6,696.7 GAS LIFT; 6,622.5 SURFACE; 33.8-2,207.1 CONDUCTOR; 34.0-110.0 HANGER; 30.2 KUP INJ KB-Grd (ft) 39.00 RR Date 1/20/1983 Other Elev 1E-21 ... TD Act Btm (ftKB) 7,420.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292089200 Wellbore Status INJ Max Angle & MD Incl (°) 41.95 MD (ftKB) 3,925.00 WELLNAME WELLBORE Annotation Last WO: End Date 10/29/2016 H2S (ppm)DateComment SSSV: NONE Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread Slotted Liner 2 3/8 1.99 7,010.2 8,300.0 6,338.3 4.60 L-80 STL Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,010.0 6,196.5 29.61 LINER TOP SBR (CTD liner top from Dec 2022) 12/29/2022 1.910 7,825.0 6,327.8 90.82 OTHER Baker Oil Tools Open hole anchor billet set to plug back L1PB1 Baker OHAB 12/25/2022 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,047.1 6,228.8 29.25 Deployment Sleeve 2.375 NSAK 350-238 OH Permanent QCLL Northern Solutions 1.920 1E-21L1, 1/25/2023 7:43:35 AM Vertical schematic (actual) Slotted Liner; 7,010.2-8,300.0 OTHER; 7,825.0 PRODUCTION; 31.3-7,368.4 APERF; 7,138.0-7,158.0 IPERF; 7,130.0-7,145.0 APERF; 7,128.0-7,138.0 APERF; 7,100.0-7,120.0 IPERF; 7,101.0-7,115.0 WHIPSTOCK; 7,100.0 LINER TOP; 7,010.0 LINER TOP; 7,010.0 PACKER; 6,999.3 SLIDING SLV; 6,982.9 IPERF; 6,850.0-6,948.0 GAS LIFT; 6,803.5 NIPPLE; 6,750.3 PACKER; 6,696.7 GAS LIFT; 6,622.5 SURFACE; 33.8-2,207.1 CONDUCTOR; 34.0-110.0 HANGER; 30.2 KUP SVC KB-Grd (ft) 39.00 RR Date 1/20/1983 Other Elev 1E-21L1 ... TD Act Btm (ftKB) 9,802.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292089260 Wellbore Status SVC Max Angle & MD Incl (°) 99.00 MD (ftKB) 7,429.33 WELLNAME WELLBORE Annotation End DateH2S (ppm)DateComment C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\LCF4WGUY\2022-12-01_22064_KRU_1E-21_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 22064 KRU 1E-21 50-029-20892-00 Caliper Survey w/ Log Data 01-Dec-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET,SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM By Meredith Guhl at 1:50 pm, Dec 09, 2022 183-002 T37367 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.09 13:51:00 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1E-21 KUPARUK RIV UNIT 1E-21 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/20/2022 1E-21 50-029-20892-00-00 183-002-0 G SPT 5932 1830020 1500 3818 3817 3817 3816 140 150 150 150 4YRTST P Austin McLeod 6/5/2022 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1E-21 Inspection Date: Tubing OA Packer Depth 650 1810 1745 1735IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220605185841 BBL Pumped:0.9 BBL Returned:0.9 Monday, June 20, 2022 Page 1 of 1 9 9 9 9 99 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.20 15:39:31 -08'00' • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,June 12,2018 TO: Jim Regg P.I.Supervisor '\e1G1 (t 6116 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1E-21 FROM: Adam Earl KUPARUK RIV UNIT 1E-21 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1E-21 API Well Number 50-029-20892-00-00 Inspector Name: Adam Earl Permit Number: 183-002-0 Inspection Date: 6/9/2018 ✓ Insp Num: mitAGE180611083826 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IE-21 Type Inj W -TVD 5932 Tubing 2670 ' 2662 - 2659 - 2660 - PTD 1830020 - Type Test SPT Test psi 1500 ' IA 440 1800 - 1740 - 1735 BBL Pumped: 1.1 • BBL Returned: 1 - OA 275 - 375 • 375 - 375 • Interval 4YRTST P/F P >i Notes: MIT-IA SCANNED JUN 2 2 LII Zi S Tuesday,June 12,2018 Page I of 1 li STATE OF ALASKA JAN 2-9 • 2O�c� A OIL AND GAS CONSERVATION COMMI SION • REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate El Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: DAD ACID Stimulate El 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory ❑ 183-002 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service 0 6.API Number: 99510 50-029-20892-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1 E-21 ADL 25651 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7,420 feet Plugs measured None feet true vertical 6,556 feet Junk measured None feet Effective Depth measured 7,285 feet Packer measured 6697, 6999 feet true vertical 6,446 feet true vertical 5923, 6187 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 feet 16 " 110' MD 110 TVD SURFACE 2,173 feet 10 3/4" 2,207' MD 2207 TVD PRODUCTION 7,337 feet 7 " 7,368' MD 6510 TVD Tubing(size,grade,measured and true vertical depth) 3.5" J-55 7,033' MD 6,217'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-BAKER FHL PACKER 6,697' MD 5,923'TVD PACKER-OTIS WD PERMANENT PA( 6,999' MD 6,187'TVD SSSV -NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: SCANNED MAR 0 5 I017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 202 601 2370 Subsequent to operation: 0 0 591 967 2511 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service LI Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 0 GINJ❑ SUSP❑ SPLUG❑ 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: 317-482 Contact Name: Jason Burke Authorized Name: Jason Burke Contact Email: Jason.Burke@cop.com Authorized Title: Staff Wells Engineer Pei/ Contact Phone: (907)265-6097 Authorized Signature. Date: V`TZ- 3/i /lg RBDMS by In 2 9 2C18 Form 10-404 Revised 4/2017 Submit Original Only KUPIli1 E-21 � I I D a ig Well Attribu Max Angle W D TD Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(SOB) Alask1/43,111C° '0' 500292089200 KUPARUK RIVER UNIT INJ 41.95 3,925.00 7,420.0 COnOtOithiillos Comment H2S(ppm) Date Annotation End DateKB-Grd(ft) -Rig Release Date ... SSSV:NONE Last WO: 10/29/2016 I 39.00 1/20/1983 1E-21,1/2912018 9.27 31 AM Last Tag Vertical schema 0(acwat)....... Annotation Depth(ftKB) End Date Last Mod By Last Tag:SLM 7,163.0 11/13/2016 pproven HANGER,30.2 IaeiNf Last Rev Reason Annotation End Date Last Mod By Rev Reason:PERFORATE,PUMPED ACID IN PERFS see NOTES 5/11/2017 pproven Casing Strings �1 F Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I Grade Top Thread `` J. CONDUCTOR 16 15.060 34.0 0 0 0 0 65.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(ND)... Wt/Len(I.Grade Top Thread �� SURFACE 10 3/4 9.950 33.8 2,207.1 2,207.0 45.50 J-55 BTC Casi•ng Descri•ption OD(in) ID(in) Top(BOB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread I PRODUCTION 7 6.276 31.3 7,368.4 6,510.5 26.00 K-55 BTC III Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..)Set Depth(ND)I...Wt yb/SI Grade Top Connection ill I TUBING-UPPER 3 1/2 2.992 30.2 6,691.9 5,919.2 9.30 L-80 EUE 8rd Mod COMP 2016 RWO CONDUCTOR;340-110.0 I Completion Details lii t Top(ND) Top Incl Nominal Top(ftKB) (ttK8) (°) Item Des Com ID(in) 302 30.2 0.00 HANGER FMC TBG Hanger 2.950 6,679.1 5,908.1 29.21 LOCATOR Baker Locator Sub 3.000 SURFACE,33.8-2,207.1-. 6,680.1 5,908.9 29.23 SEAL ASSY Baker 80-40 Seal assembly 3.000 Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt pb/tt) Grade Top Connection ITUBING-C Sand 31/2 2.992 6,683.9 7,004.3 6,191.5 9.30 L-80 EUE Brd � Selective 2016 RWO GAS LIFT,66225 ,. Completion Details 4 Top(ND) Top Incl Nominal Top(BOB) (ftKB) (°) Item Des Com ID(in) 6,683.9 5,912.2 29.33'PBR 10-ft Baker 80-40 PBR 4.000 4 6,696.7 5,923.4 29.64'PACKER Baker FHL Packer 3.000 LOCATOR;6,679.1Ill 6,750.3 5,970.1 29.53 NIPPLE NIPPLE"NO GO"DS 2.812" 2.813 6,852.5 6,059.4 29.38 Blast Joint Baker 20-ft 3-1/2"Blast Joints 2.992 SEAL ASSY;e,880.1 i1 6,982.9 6,173.0 29.73 SLIDING SLV 2.813"BX CMU Sliding Sleeve 2.992 PBR;9683.9 LTJ 6,995.2 6,183.7 29.80'SEAL ASSY Otis Seal Assembly 2.980 OM Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection PACKER,6,696.7 a `- ' TUBING-Original 6.156 4.000 6,999.3 7,034.4 6,217.7 Completion Details Top(ND) Top Incl Nominal Top(ttK8) (ftKB) (") Item Des Com ID(in) 6,999.3 6,187.2 29.83 PACKER 'OTIS WD PERMANENT PACKER 4.000 NIPPLE,6,7503 �': 7,021.9 6,206.9 29.35 NIPPLE .CAMCO D NIPPLE NO GO 2.750 . 7,033.1 6,216.6 29.27 SOS _OTIS SHEAR OUT SUB 2.992 I. Perforations&Slots Shot I Dens Top(ND) Btm(ND) (shots/ft GAS LIFT;6,803.5 ,we' Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date I Type Corn 6,850.0 6,948.0 6,057.2 6,142.6 C-4,C-3,C-2,C 1/20/1983 40 IPERF -1,1E-21 .:: 7,100.0 7,120.0 6,275.0 6,292.5 A-4,1E-21 1/24/2017 6.0 APERF 6 SPF 60*PHASE MILLENIUM II PERF GUN • (PERF;e,e50.128,94e.0- 7,101.0 7,115.0 6,275.9 6,288.1 A-5,1E-21 1/20/1983 4.0 IPERF 7,128.0 7,138.0 6,299.5 6,308.2 A-4,1E-21 1/24/2017 6.0 APERF 6 SPF 60"PHASE MILLENIUM II PERF GUN 7,130.0' 7,145.0 6,301.2 6,314.4 A-4,1E-21 1/20/1983 4.0 IPERF • 7,138.0.. 7,158.0 6,3082 6,325.7 A-4,1E-21 1/23/2017 6.0 APERF 6 SPF 60'PHASE MILLENIUM II PERF GUN SLIDING SLV;8,982.9 II Mandrel Inserts 11 St _ ati SEAL ASSY;6,995.2 N Top(TVD) Valve Latch Pon Size TRO Run ea. Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Corn PACKER;6,999.3 1 6,622.5 5,858.9 Camco MMG 11/2'GAS LIFT DMY RK 0.000 0.0 11/12/2016 1- ],(3 2 6,803.5 6,016.5 Camco MMG 1 1/2 GAS LIFT DMY RKP ' 0.000' 0.0 11/12/2016 Notes:General&Safety NIPPLE;7,021.9 End Date Annotation 8/26/2010 NOTE:View Schematic w/Alaska Schematic9.0 10/24/2016 NOTE:WO SOS;7,033.1 _ 1/2/2017 NOTE:TAGGED APPARENT ICE PLUG @ 2264'SLM 5/10/2017 'NOTE:Perform 100 bbl dynamic acid dispersion treatment with CT from 7,090'RKB-7,150'RKB IPERF;7,101.0-7,115.0 APERF;7,100.0-7,120.0E-t APERF;7,128.0-7,138.0 . IPERF;7,130.0-7,145.0-. APERF;7,138.0-7,158.0. • PRODUCTION;31.3-7,388A-i • IE-21 DAD ACID STIMULATE DTTMSTAF JOBTYF SUMMARYOPS 12/22/17 ACID RIH TO TAG AT 7227' RKB. CIRCULATE DAD ACID TO END OF COIL. PUH TO 7,015', SQUEEZE 100 BBL DAD ACID TO FORMATION. TURN OVER WELL TO PRODUCTION AND RETURN WELL TO INJECTION. JOB COMPLETE. Vof T4 .,0,-„ 1//7„._-,,„ THE STATE • Alaska Oil and Gas ,to =2, of/� TAsKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ()i Q, Main: 907.279.1433 4LAs* Fax: 907.276.7542 www.aogcc.alaska.gov Jason Burke Senior Wells Engineer �1Q'J � � ConocoPhillips Alaska, Inc. scow P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1E-21 Permit to Drill Number: 183-002 Sundry Number: 317-482 Dear Mr. Burke: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French +L, Chair DATED this 1Zday of October, 2017. RBBE. S y t/ t ,1tA,1 1 3 2017 , . RECEIVED • STATE OF ALASKA OCT 0 6 201? ALASKA OIL AND GAS CONSERVATION COMMISSION PTS / j / 12 / (7 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon H Plug Perforations H Fracture Stimulate H Repair Well H Operations shutdown U Suspend ❑ Perforate ❑ Other Stimulate ❑I ' Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other:IDAD Acid StimE 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 183-002 3.Address: Stratigraphic ❑ Service 2, 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 50-029-20892-00 • 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 0✓ KRU 1E-21 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651 - Kuparuk River Field/Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 7,420' ' 6,556' ' 7285' ' 6446' . 1973 N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 76' 16" 110' 110' Surface 2,173' 10-3/4" 2207' 2207' Intermediate Production 7,337' 7" 7368' 6510' Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6850'-7158' . 6057'-6326' 3.5" L-80 7034' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER-BAKER FHL PACKER MD=6697 TVD=5923 PACKER-OTIS WD PERMANENT PACKER • MD=6999 TVD=6187 SSSV-NONE 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑I BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service Q 14.Estimated Date for 15.Well Status after proposed work: Operations: 11/1/2017 CommencingOIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑7 . GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jason Burke Contact Name: Jason Burke Authorized Title: Staff Wells Engineer Contact Email: Jason.Burke@cop.com Authorized Signature: pa-6: /o/ /7 Contact Phone: (907)265-6097 COMMIIIlll555lSION SE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 1,7 . 1.4i2„... Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDPost Initial Injection MIT Req'd? Yes ❑ No SCC- IJLi132017 Spacing Exception Required? Yes ❑ No 2, Subsequent Form Required: 1 U — 4 0 4' APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: I 't -4 u _ �� Submit Form and Form 10-403 Revised 4/2017 Approved application is vali - r 2 n f t e da e o approval. Attachments in Duplicate • • ConocoPhillips Alaska,Inc. Drilling&Wells ConocoPhillips Well Intervention Alaska 1E-21 Acid Treatment (10404366) Engineer: Jason Burke Wells Engineer 907-231-4568 DAD, dynamic acid dispersion, is an acid outside-phase emulsion prepared and stabilized with dispersing agent F103. The purpose of the dispersion is to simultaneously dissolve acid-soluble minerals and remove oil paraffinic deposits. Target areas can be tubulars, perforations or the critical matrix. Objectives: Spot Dynamic Acid Dispersion (DAD) treatment with CT into perforations to increase injectivity ( • Coiled Tubing: Spot 100 bbl of DAD into formation 1. MIRU 1.5"CT, MU 5 port wash nozzle BHA 2. Begin RIH down to 7160' MD. 3. When CT has reached depth begin pumping DAD treatment. When treatment is exiting the CT (depending on CT volume) shut in the choke and begin POOH to 7015'. Continue injecting DAD into formation and it out of the CT with produced water or diesel. a. Do not exceed 4500 psi surface pressure 4. After an additional 5 bbl of fluid has been injected behind the treatment POOH 5. RDMO CT. Return well to injection. Function SLB Code Concentration Quantity Acid corrosion inhibitor A264 4 gpt 15 gal HC1 H036 221.4 gpt 934 gal Emulsifier F103 15 gpt 63 gal Iron Control L058 20 ppt 76 lbs Non-emulsifier W054 2 gpt 19 gal Xylene A026 100 gpt 420 gal October 3, 2017 1E-21 Well Work Procedure Page 1 of 1 , ' KUP INJ 1E-21 Conor Phillips -''a „ Well Attributes Max Angle&MD TD Alaska,Inc. i WeliboreAPUUWI Field Mame Wellbore Statue nal(Cl MD(ftKB) Act Blm(ttKB) ,..c„�,,, ,,,,,,"at,. 500292089200 KUPAR UK RIVER UNIT INJ 41.95 3,925.00 7,420.0 ••• Comment H25(ppm) Date Annotation End Date KBGrd(it) Rig Release Date 1E-21.511162017 10 19'19 AM SSSV:NONE Last WO: 10/29/2016 39.00 1/20/1983 Vertical schematic(actual) Annotation Depth(1tK13) End Date Annotation Last Mod By End Date Last Tag:SLM 7,163.0 11/13/2016 Rev Reason:PERFORATE.PUMPED ACID IN pproven 5/11/2017 RANGER,30.2 114I PERFS see NOTES Casing Stnngs Geeing Deeenptlon OD(In) ID(In) Top(ttKB) Set Depth(1tKB) Set Depth(TVD)...WI/Len(I...Grade Top Thread i , i 1- CONDUCTOR 16 15.060 34.0 110.0 110.0 65.00 H-40 WELDED Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len p...Grade Top Thread SURFACE 103/4 9.950 33.8 2,207.1 2,207.0 45.50 J-55 BTC Casing Description OD(In) ID(In) Top(MB) Set Depth(ftKB) Set Depth(TVD)...WI/Len II...Gracie Top Thread PRODUCTION 7 6.276 31.3 7,368.4 6,510.5 26.00 K-55 BTC Tubing Strings Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(ft..J Set Depth(TVD)(...WI(Ib/ft) Grade Top Connection .a,TUBING-UPPER 31/2 2.992 30.2 6,691.9 5,919.2 9.30 L-60 EUE and Mod III III COMP Completion Completion Details Nominal ID .� Top(MEE) Top(TVD)(ftKB) Top Incl(6) Item Dae Com (in) CONDUCTOR,34.0-110.0 • 30.2 30.2 0.00 HANGER •FMC TUG Hanger 2.950 6,679.1 5,908.1 29.21 LOCATOR Baker Locator Sub 3.000 6,680.1- 5,908.9 29.23 SEALASSY Baker 80-40 Seal assembly 3.000 Tubing Description String Ma...IID(In) Top(NEB) Set Depth(ft..J Set Depth(TVD)(...Wt(IbIK) Grade Top Connectlen TUBING-C Sand 31/2 2.992 6,683.9 7.004.31 6,191.5 9.30 L-80 EUE Brd SURFACE,33.a-2,207.1- Selective 2016 RWO Completion Details Nominal ID Top(ORB) Top(TVD)(ttKB) Top Incl(°) Item Des Com (In) GAS LIFT;6.622.5 ' 6,683.9 5,912.2 29.33 PBR 10-ft Baker 80-40 PBR 4.000 6,696.7 5,923.4 29.64 PACKER Baker FHL Packer 3.000 6,750.3 5,970.1 29.53 NIPPLE NIPPLE"NO GO"DS 2.812" 2.813 6,852.5 6,059.4 29.38 Blast Joint Baker 20-ft 3-1/2"Blast Joints 2.992 6,982.9 6,173.0 29.73 SLIDING SLV 2.813"BX CMU Sliding Sleeve 2.992 LOCATOR,8.879.1 s. 6,995.2 6,183.7 29.80 SEAL ASSY Otis Seal Assembly 2.980 es Tubing Description 'String Ma...I ID(In) I To ftKB) -Set Deplh(ft..J Sal Depth)TVD((...I Wi)lb/fl) I Grade ITop Connection SEAL ASSY;6680.1 i i.I TUBING-Original 6.156 4.000 6,999.3 7,034.41 6,217.7 PBR',6,683.9 - Completion Details Nominal ID PACKER,6 696 7 "-" Top(ftKB) Top(TVD)(ftKB) Top Intl(") Item Dee Com (In) 6,999.3 6,187.2 29.83 PACKER OTISWD PERMANENT PACKER 4.000 7,021.9 6,206.9' 29.35 NIPPLE CAMCO D NIPPLE NO GO 2.750 I7,033.1 6,216.6 29.27 SOS 'ons SHEAR OUT SUB 2.992 I Perforations&Slots NIPPLE:6,750.3 d a Shot I Dene lop(TVD) Blm(TVD) (shcts/1 Top(ftKB) Btm(ttKB) (ftKB) (11KB) Zone Date 1) Type Com 6.850.0 6,948.0 6,057.2 6,142.6 C-4.C-3,C-2, 1/20/1983 4.0 IPERF C-1,1E-21 GAS LIFT 6,eo3s 7.100.0 7,120.0 6,275.0 6,292.5 A-4,1E-21 1/24/2017 6.0 APERF 6 SPF 60"PHASE MILLENIUM II PERF GUN 2.101.0 7,115.0 6,275.9 6,288.1 A-5,1E-21 1/20/1983 4.0 IPERF 2.128.0 7,138.0 6,299.5 6,308.2 A-4,1E-21 1/24/2017 6.0 APERF 6 SPF 60"PHASE MILLENIUM II PERF IPERF',8950.0.6.946.0- GUN 7.130.0 7,145.0 6,301.2 6,314.4 A-4,1E-21 1/20/1983 4.0 IPERF 7.138.0 7,158.0 6,308.2 6,325.7 A-4,1E-21 1/23/2017 6.0 APERF 6SPF 60"PHASE MILLENIUM II PERF GUN SLIDING SLV,9,982.9 Mandrel Inserts St all N Top(TVD) Valve Latch Pod Site TRO Run ms SEAL ASSN,0,9952 _ Top MB) MKS) Make Model 00(In) Sere Type Type lin) (pal) Run Date Com ®: 1 6,622.5 5,858.9 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/12/2016 PACKER:6,999 3 2 6,803.5 6,016.5 Camco MMG 1 12 GAS LIFT DMY RKP 0.000 0.0 11/12/2016 a;; Notes:General&Safety End Dale Annotation NIPPLE;7,0219 - 8/26/2010 NOTE:View Schematic w/Alaska Schematic9.0 - ill 10/24/2016 NOTE:WO SOS,7,033.1 1/2/2017 NOTE:TAGGED APPARENT ICE PLUG @ 2264'SLM 5/10/2017 NOTE:Perform 100 bbl dynamic acid dispersion treatment with CT from 7,090 RKB-7.150'RKB IPERF:7.101 0-7,115 0 APERF;7,100.0-7.120.0- APERF, ,100.0-7.120.0-APERF,7,126.0-7 138.0 IPERF',7,130.0-7,145.0 APERF;7,1380-7,118.0- - PRODUCTION.31.3-7.368.4- 115. 3- ao 2 RECEIVED • • ,27663,E SEP 2 9 2017 WELL LOG TRANSMITTAL#904150756 AOGCC To: Alaska Oil and Gas Conservation Comm. September 6, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 yo%'3/201 M.K.BENDER RE: Injection Profile : 1E-21COMEti Run Date: 7/11/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1E-21 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-20891-00 Injection Profile Log 1 Color Log 50-029-20891-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 0 FRS_ANC@halliburton.com Date: Signed:/ , 4/, 0o• WELL LOG TRANSMITTAL '726 zk 7S 0. PROACTIVE DIACINOSTIC SERVICES, INC. DATA LOGGED Nit/2017 ;.i. K BENDER RECEIVED To: AOGCC Makana Bender AUG 0 9 2017 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 AOGCC (907) 793-1225 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 attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 A 7 �.' 1) Injection Profile 10-Jul-17 1E-21 Color Log /CD 50-029-20892-00 2) ,}?, Signed : QL ��'�`"�v' !/ E;�k� Jy Date Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(CD.MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D.\Achives\MasterTemplateFiles\Templates\Di stribution\Transmittals heets\Conocophillips_Transmit.docx • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,June 12,2017 TO: Jim Regg ("" egg P.I.Supervisor elf 6/147 SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1E-21 FROM: Adam Earl KUPARUK RIV UNIT 1E-21 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1E-21 API Well Number 50-029-20892-00-00 Inspector Name: Adam Earl Permit Number: 183-002-0 Inspection Date: 5/27/2017 Insp Num: mitAGE170528121322 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IE-21 - IType Inj W- TVD 5932 - Tubing 2441 2443 • 2451 - 2438 PTD 1830020 - Type Test MITest psi 1500 • IA 855 1710 - 1700 - 1700 - BBL Pumped: 0.9 _ BBL Returned: 0.9 - OA 655 710 . 710 _ 710 Interval INITAL P/F P Notes: Initial MITIA post RWO per Sundry#316-307. SCANNED AUG 1 5 201 Monday,June 12,2017 Page 1 of 1 - STATE OF ALASKA ALOKA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Acid Stimulation LI 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory❑ 183-002 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service❑ 6.API Number: 99510 50-029-20892-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1E-21 ADL 25651 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7,420 feet Plugs measured None feet true vertical 6,556 feet Junk measured None feet Effective Depth measured 7,285 feet Packer measured 6697, 6999 feet true vertical 6,446 feet true vertical 5923, 6187 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 feet 16 " 110'MD 110 SURFACE 2,173 feet 10 3/4" 2,207' MD 2207 PRODUCTION 7,337 feet 7 7,368'MD 6510 RECEIVED Perforation depth Measured depth 6850-7158 feet J U N 0 2 2017 True Vertical depth 6057-6326 feet AOGCC Tubing(size,grade,measured and true vertical depth) 3.5" L-80 7034' MD 6,217'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-BAKER FHL PACKER 6,697'MD 5,923'TVD PACKER-OTIS WD PERMANENT PACKER 6,999'MD 6,187'TVD SSSV:NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A SCANNED JUN 2 2 2017. Treatment descriptions including volumes used and final pressure: Pumped 100 bbl of 10%HCL&XYLENE mixed 80/20 sx 170 @ 2700psi 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 630 2500 Subsequent to operation: o 0 1200 800 2500 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations LI Exploratory ❑ Development ❑ Service l] Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ El WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 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: 317-127 Contact Name: Jason Burke Authorized Name: Jason Burke Staff Wells EngineerContact Email:jason.burke@cop.com Authorized Title: Authorized Signa •-. 111P/ / Date: '-'2...-1/ Contact Phone: (907)265-6097 Form 10-404Revised 4/2017i,����� �5 .� / 7 RBDMS (/v JUN - 2 2017 Submit Original Only • • 1 E-2 1 DTTMS1 JOBTYP SUMMARYOPS 5/10/17 DRILLING Perform 100 bbl dynamic acid dispersion treatment with CT from 7,090' RKB-7,150' SUPPORT- RKB, RDMO, Turn well over to DSO. **Job Complete** EXP WO 5/11/17 PUMPING INJECTIVITY TEST TRACKING PUMPED 70 BARRELS OF DIESEL ONLY FINAL INJECTION PRESSURE WAS 2950 PSI AT 1 BARREL PER MINUTE JOB COMPLETE 5/27/17 ANNCOMM (ISW) : INITIAL STATE WITNESSED (ADAM EARL) MIT-IA(PASSED)TO 1710 PSI. KUP 1 E-21 • CanocPh44hhpS MT- Well Attribuilli Max Angl ID TD ARska.Inc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Garrottatidips 500292089200 KUPARUK RIVER UNIT INJ 41.95 3,925.00 7,420.0 ` Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-21,5/31/20176:42:33 AM SSSV:NONE Last WO: 10/29/2016 39.00 1/20/1983 Verbal srhematlp.(aPNd)............. Annotation Depth(ftKB) End Date Annotation Last Mal By End Date Last Tag:SLM 7,163.0 11/13/2016 Rev Reason:PERFORATE,PUMPED ACID IN pproven 5/11/2017 HANGER;30.2 ii'.1,:ii PERFS see NOTES Casing Strings I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.060 34.0 110.0 110.0 65.00 H-00 WELDED Casing DescriptionIF OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 1&qp SURFACE 10 3/4 9.950 33.8 2,207.1 2,207.0 45.50 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread IPRODUCTION 7 6.276 31.3 7,368.4 6,510.5 26.00 K-55 BTC 11.1. Tubing Strings ■ Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..{Set Depth(ND)(...Wt(lb/ft) Grade Top Connection ��,,,.r.�„1,,,,�r,.,�..,n���,,,,,,r.r, • 1!!. uw.TUBING-UPPER 3 1/2 2.992 30.2 6,691.9 5,919.2 9.30 L-80 EUE 8rd Mod COMP 2016 RWO I11. 1111 Completion Details .�, Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com Nominal ID CONDUCTOR;34.0-110.0 30.2 30.2 0.00 HANGER FMC TBG Hanger 2.950 6,679.1 5,908.1 29.21 LOCATOR Baker Locator Sub 3.000 6,680.1 5,908.9 29.23 SEAL ASSY Baker 80-40 Seal assembly 3.000 • • Tubing Description String Ma...ID(in) Top(0KB) Set Depth(ft..J Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING-C Sand 3 1/2 2.992 6,683.9 7,004 3 6,191.5 9.30 L-80 EUE 8rd SURFACE,330-2,207.1 • Selective 2016 RWO Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) GAS LIFT,6s22.5 it 6,683.9 5,912.2 29.33 PBR 10-ft Baker 80-40 PBR 4.000 6,696.7 5,923.4 29.64 PACKER Baker FHL Packer 3.000 6,750.3 5,970.1 29.53 NIPPLE NIPPLE"NO GO"DS 2.812" 2.813 6,852.5 6,059.4 29.38 Blast Joint Baker 20-ft 3-1/2"Blast Joints 2.992 LOCATOR;6,679.112 6,982.9 6,173.0 29.73 SLIDING SLV 2.813"BX CMU Sliding Sleeve 2.992 6,995.2 6,183.7 29.80 SEAL ASSY Otis Seal Assembly 2.980 ir itTubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...1W1(115/(t) Grade Top Connection PBR;6,60;4.9 - SEAL Asst;6,693.1 ':: TUBING-Original I 6.1561 4.0001 6,999.3 7,034.41 6,217.7 .. - Completion Details Nominal ID PACKER;6,696.7 --' Top(ftKB) Top(ND)(ftKB) Top Incl CI Item Des Corn lin) 6,999.3 6,187.2 29.83 PACKER OTIS WD PERMANENT PACKER 4.000 7,021.9 6,206.9 29.35 NIPPLE CAMCO D NIPPLE NO GO 2.750 I7,033.1 6,216.6 29.27 SOS OTIS SHEAR OUT SUB 2.992 NIPPLE;6,750.3 Perforations&Slots Shot Dens Top(ND) Btm(TVD) (shots/ Top(ftKB) Ben(ftKB) (ORB) (ftKB) Zone Date ft) Type Com 6,850.0 6,948.0 6,057.2 6,142.6 C-4,C-3,C-2, 1/20/1983 4.0 IPERF IC-1,1E-21 GAS LIFT;6,803.5w, � 7,100.0 7,120.0 6,275.0 6,292.5 A-4,1E-21 1/24/2017 6.0 APERF 6 SPF 60*PHASE MILLENIUM II PERF GUN 7,101.0 7,115.0 6,275.9 6,288.1 A-5,1E-21 1/20/1983 4.0 IPERF -1":. i I 7,128.0 7,138.0 6,299.5 6,308.2 A-4,1E-21 1/24/2017 6.0 APERF 6 SPF 60'PHASE IPERF,6,850 0-6,9413 0-.1" •11-. 1 MILLENIUM II PERF GUN 7,130.0 7,145.0 6,301.2 6,314.4 A-4,1E-21 1/20/1983 4.0 IPERF 7,138.0 7,158.0 6,308.2 6,325.7 A-4,1E-21 1/23/2017 6.0 APERF 6 SPF 60*PHASE • MILLENIUM II PERF GUN SLIDING SLV;6,962 9 TilEMandrel Inserts st ae on Top(ND) Valve Latch Port Size TRO Run SEAL ASSY,6,995.2r N Top(ftKB) (ftKB) Make Model OD(in) Sero Type Type (in) (psi) Run Date Corn 1 6,622.5' 5,858.9 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/12/2016 PACKER;6,999.3 r? IN - 2 6,803.5 6,016.5 Camco MMG 1 1/2 GAS LIFT DMY RKP 0.000 0.0 11/12/2016 Notes:General&Safety NIPPLE;7,021.9End Date Annotation 8/26/2010 NOTE.View Schematic w/Alaska Schematic9.0 _ 10/24/2016 NOTE:WO SOS;7,033.1iir 1/2/2017 NOTE:TAGGED APPARENT ICE PLUG @ 2264'SLM 5/10/2017 NOTE:Perform 100 bbl dynamic acid dispersion treatment with CT from 7,090'RKB-7,150'RKB IPERF;7,101,0-7,115.0 APERF;7,100.0.7,120.9 APERF;7,128.0-7,136.0 -. IPERF;7,130.0-7,145.0 APERF;7,136.00.7,158.0 PRODUCTION,31.3-7,366.4 • • of T4 ,s,', ��j,'", THE STATE Alaska Oil and Gas , s- �� of/k T /\ CKA Conservation Commission %o- _= 333 West Seventh Avenue 1 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 of ALASFax: 907.276.7542 www.aogcc.alaska.gov Jason Burke Wells Engineer V? ConocoPhillips Alaska, Inc. ,ky � P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field,Kuparuk River Oil Pool,KRU 1E-21 Permit to Drill Number: 183-002 Sundry Number: 317-127 Dear Mr. Burke: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy s. Foerster Chair DATED this 0-day of April, 2017. RBDMS - 4 2017 RECEIVED • • • STATE OF ALASKA MAR 2 8 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION f 14.117 APPLICATION FOR SUNDRY APPROVALS AOGOC 20 MC 25.280 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: a G id S741 wA 111---- 2. '2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development ❑ 183-002 3.Address: Stratigraphic ❑ Service 2, 6.API Numb PO Box 100360,Anchorage AK 99510 .Q�'O9t4 04 "�J 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? j'u144- KRU 1E-21 • Will planned perforations require a spacing exception? Yes ❑ No iz ?� 9.Property Designation(Lease Number): 10.Field/Pool(s): Kuparuk River Field/Kuparuk Oil Pool • ADL 25651 AKL 46 s►4?1 p p 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7420 6565 • 7285 • 6446 . 2000 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 76 16" 110 110 Surface 2173 10-3/4" 2207 2207 Intermediate Production 7337 7" 7368 6510 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6850'-7158' 1 6057'-6326' 3.5" L-80 7004' Packers and SSSV Type: Baker FHL Packer Packers and SSSV MD(ft)and TVD(ft):• 6697'MD&5923'TVD Otis WD Permanent Packer i 6999'MD&6187'TVD 12.Attachments: Proposal Summary U Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program 2 BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑✓ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/3/2017 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 2 • GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Jason Burke Email jason.burke@cop.com Printed Name Jason Burke Title Signature Phone 907-265-6097 Date // 3/27/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ 4--rD ~ 14 I lq Other: RBDMS L`` .`'R - 4 2017 Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No 12 Subsequent Form Required: jt — 4 t 4 APPROVED BY Approved by: lr� COMMISSIONER THE COMMISSION Date: _-L�- `7 / �4���/�, I 1 A Submit Form and Form 10-40 R v sed 11/20 5 �/( r I I alid for 12 months from the date of approval. Attachments in Duplicate t'��c1i 3/301 1/'447 • ConocoPhillips Alaska,Inc. ✓ Drilling&Wells ConocoPhillips Well Intervention Alaska 1E-21 DAD Treatment (10350288) Engineer: Jason Burke Wells Engineer 907-231-4568 DAD,dynamic acid dispersion, is an acid outside-phase emulsion prepared and stabilized with dispersing agent F103. The purpose of the dispersion is to simultaneously dissolve acid-soluble minerals and remove oil paraffinic deposits. Target areas can be tubulars, perforations or the 3-. critical matrix. Objectives: Spot Dynamic Acid Dispersion (DAD) treatment with CT into perforations to try to restore injectivity ✓ • Coiled Tubing: Spot DAD into formation 1. MIRU CT,MU 5 port wash nozzle BHA 2. Begin RIH, circulating at minimum rate until 7150' 3. Begin pumping DAD treatment. When treatment is 5 bbls from exiting the CT (depending on CT volume) shut in the backside choke and begin squeezing into formation. Chase the DAD treatment with produced water or diesel. a. Do not exceed 4200 psi surface pressure b. Note: Well has poor injectivity(.2 BPM @ 3000 psi) 4. As treatment is exiting begin POOH at 2 fm up to 7090'. 5. RIH at 2 fpm back down to 7150' MD, and then begin POOH at 2 fpm until all the treatment is pumped. 6. After an additional 5 bbl of fluid has been injected behind the treatment POOH 7. RDMO CT. Return well to injection. Function SLB Code Concentration Quantity Acid corrosion inhibitor A264 4 gpt 15 gal HC1 H036 221.4 gpt 934 gal Emulsifier F103 15 gpt 63 gal Iron Control L058 20 ppt 76 lbs Non-emulsifier W054 2 gpt 19 gal Xylene A026 100 gpt 420 gal February 5,2017 1E-21 Well Work Procedure Page 1 of 1 KUP INJ 1E-21 ConocoPhillips ..a Well Attributes Max Angle&MD TD Alaska,Inc, " Wellbore APIIUWI Field Name Wellbore Statue nal(6) MD(RKB) Act Blm(ttKB) t. P1y61r.„ 500292089200 KUPARUK RIVER UNIT INJ 41.95 3,925.00 7.420.0 ••• Comment HOS(Ppm) Date Annotation End Date KB-Grd(It) Rig Relent.Date 1E-21,2/7/2017 917.56 AM SSSV:NONE Last WO: 10/29/2016 39.00 1/20/1983 Vertical schematic(actual) Annotation Depth(ttKB) End Date Annotation Last Mod By End Date .. ..........._....._....... Last Tag:SLM 7,163.0 11/13/2016 Rev Reason:PERFORATE ['proven 2/7/2017 HANGER;30.2 CAI Casing Strings casing Deaerlptlan OD(In) ID(In) Top(ttKB) Set Depth(ttKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.060 34.0 110.0 110.0 65.001-40 WELDED Casing Description OD(In) ID(In) Top(ftK6) Set Depth(ttKB) Set Depth(TOO)...WULen(I...Grade Top Thread SURFACE 103/4 9.950 33.8 3207.1 2,207.0 45.50 J-55 BTC Casing Description 00(in) ID tint Top(ttKB) Set Depth(ttKB) Set Depth(100),.. WULsn II...Grade Top Thread PRODUCTION 7 6.276 31.3 7,368.4 6,510.5 26.00 K-55 BTC 1I ; Tubing Strings Tubing Deecriptlon Siring Ma.,.ID(In) Top(MB) Set Depth 11L..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection Iw., .0 vua,TUBING-UPPER 3 1/2 2.992 30.2 6,691.9 5,919.2 9.30 L-80 EUE 8rd Mod OMP 2016 RWO I II Completion Completion Details Nominal ID Top(ttKB) Top(TVD)(ttKB) Top Incl(•) Item De. Com (In) CONDUCTOR;34.9-110.0 • 30.2 30.2 0.00 HANGER FMC TBG Hanger 2.950 6,679.1 5,908.1 29.21 LOCATOR Baker Locator Sub 3.000 6,680.1 5,908.9 29.23 SEAL ASSY Baker 80-40 Seal assembly 3.000 Tubing Description String Ma...ID(In) Top(MB) Set Depth(ft...Set Depth(TVD)(...'Wt(Ib/t) Grade Top Connection TUBING-C Sand 31/2 2.992 6,683.9 7.004.3 6191.5 9.30 L-80 EUE 8rd Sl/R FACE;35.8-2,207.1- Selective 2016 RWO Completion Details Nominal ID Top(RKB) Top(TVD)(ttKB) Top Incl(') Item Des Corn (In) GAS LIFT:6.622.5 <..,� 6,683.9 5,912.2 29.33 PBR 10-tt Baker 80-40 PBR 4.000 6,696.7 5,923.4 29.64 PACKER Baker FHL Packer 3.000 6,750.3 5,970.1 2953 NIPPLE NIPPLE"NO GO"DS 2.812" 2.813 6,852.5 6,059.4 29.38 Blast Joint Baker 20-ft 3-1/2"Blast Joints 2.992 6,982.9 6,173.0 29.73 SLIDING SLV 2.813"BX CMU Sliding Sleeve 2.992 LOCATOR;6679.1 Ir 6,995.2 6183.7 29.80 SEAL ASSY ODs Seal Assembly 2980 M. Tubing Description String Ma...ID(in) Top(ttKB) Set Depth(ft...Set Depth(TOD)(...Wt(Ib/It) Grade Top Connection SEAL ASSY;66801 1 1 TUBING-Original 6.156 4.000 6,999.3 7,034.4 6,217.7 PBR;6.663,9 Completion Details Nominal ID PACKER:6.696.7 = ' _ Top(RKB) Top(TVD)(MIB) Top Ino!(") item Dee Com (In) 6,999.3• 6,187.2 29.83 PACKER OTIS WD PERMANENT PACKER 4.000 7,021.9' 6,206.9 i 29.35 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,033.) 6,216.6 i 29.27 SOS o-ns SHEAR OUT SUB 2.992 Perforations&Slots NIPPLE;6,750.3 I Shot Dene Top(TVD) Blm(TVD) (ahotall Top(ttKB) Btm MKS) (ttKB) (ttKB) Zone Date t) Type Com 6.850.0 6.948.0 6057.2 6,142.6 CA.C-3,C-2, 1/20/1983 4.0 IPERF C-1,1E-21 GAS LIFT:6.903.5 7.100.0 7,120.0 6,275.0 6,292.5 A-4,1E-21 1/24/2017 6.0 APERF 6 SPF 60"PHASE MILLENIUM II PERF GUN 7.101.0 7,115.0 6,275.9 6,288.1 A-5,1E-21 1/20/1983 4.0 (PERF 7.128.0 7,138.0 6.299-5 6,308.2 A-4,1E-21 1/24/2017 6.0 APERF 6 SPF 60"PHASE MILLENIUM II PERE IPERF;6,850.66.048.0--- GUN I7.130.0 7,145.0 6,301.2 6,314.4 8-4,1E-21 1/20/1983 4.0 IPERF _ 7.138.0 7,158.0 6,308.2 6,325.7 A-4,1E-21 1/23/2017 6.0 APERF 6 SPF 60"PHASE ■ MILLENIUM II PERF GUN SLIDING 6LV.6.962.9 +I Mandrel Inserts si all on Top(TVD) Valve Latch Pon Size TRO Run N Top(ttKB) (ORB) Make Model OD(In) Sery Type Type (In) (pal) Run Date Com SEAL ASSY;6,905.2 1 6,622.5 5,858.9 Camco MMG 11/2 GAS LIFT DMY RK 0.000 0.0 11/12/2016 PACKER',6,059.3 i 2 6,803.5 6,016.5 Camco MMG 11/2 GAS LIFT DMY RKP 0.000 0.0 11/12/2016 Notes:General&Safety End Date Annotation NIPPLE;7,021.9 8/26/2010 NOTE:View Schematic w/Alaska Schemabc9.0 A10/24/2016 NOTE:WO SOS;7,033.1 = 1/2/2017 NOTE:TAGGED APPARENT ICE PLUG X02264'SLM IPERF;7,101.0-7,115.0 APERF;7,100.0-7.120.t--.-----.. APERF;7,128.0-7,136.0 IPERF;7,130.67.145.0 APERF;7,138.67.158.0-. PRODUCTION;31.57,368.4 PTD1B3 -66Z Loepp, Victoria T (DOA) From: Beat,Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Wednesday, December 07,2016 10:57 AM To: Loepp,Victoria T(DOA) Subject: RE: KRU 1E-21(PTD 183-002) Follow Up Flag: Follow up Flag Status: Flagged Fantastic.Thank you for the help. SCANNED FEB 0 8 2017 Thanks, Andrew From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday, December 07,2016 10:56 AM To:Beat,Andrew T<Andrew.T.Beat@conocophillips.com> Subject: [EXTERNAL]KRU 1E-21(PTD 183-002) Andrew, The status of this well in our system is a WAG injector. We will modify the 10-403, 10-407(Sundry 316-307)to show it as a WAG injector. No need to submit any other paper work. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp analaska.gov 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.Loeou@alaska.gov 1 • STATE OF ALASKA ` AllIL OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Plug Perforations F Fracture Stimulate fl Pull Tubing 1 Operations Shutdown E Performed: Suspend Perforate I- Other Stimulate p r Alter Casing r Change Approved Program Plug for Redrill I— Perforate New Pool E Repair Well F Re-enter Susp Well E n 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory n 183-002 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic E Service 50-029-20892-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25651 KRU 1E-21 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: I,. Total Depth measured 7420 feet Plugs(measured) None true vertical 6556 feet Junk(measured) None Effective Depth measured 7285 feet Packer(measured) 6697,6999 true vertical 6446 feet (true vertical) 5923,6187 Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 16 110 110 SURFACE 2173 10 3/4 2207 2207 PRODUCTION 7337 7 7368 6510 R C._ , VEPerforation depth: Measured depth: 6850-6948,7101-7115,7130-7145 NOV 2 True Vertical Depth: 6057-6143,6276-6288,6301-6314 9 2016 9L Tubing(size,grade,MD,and TVD) 3.5,J-55,7034 MD,6218 TVD Packers&SSSV(type,MD,and TVD) PACKER(TUBING)-BAKER FHL PACKER 4762-T X 26# @ 6697 MD and 5923 TVD PACKER-OTIS WD PERMANENTPACKER @ 6999 MD and 6187 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): NONE Treatment descriptions including volumes used and final pressure: %MO 3 . 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-In - - - - Subsequent to operation Shut-In - - - - 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory fl Development E Service 17 Stratigraphic 1"-- Copies Copies of Logs and Surveys Run E 16.Well Status after work: Oil fl Gas [ WDSPL E Printed and Electronic Fracture Stimulation Data GSTOR I— WINJ F. WAG E GINJ E SUSP E SPLUG 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: 316-307 Contact Andrew Beat(a,265-6341 Email Andrew.T.Beat@conocophillips.com Printed Name Andrew Beat Title Sr. Wells Engineer Signature i\_ Phone:265-6341 Date Aitatf2010 Form 10-404 Revised 5/2015 V r-t_. 3/2 117 RBDMS [,V DEC - 6 2018Submit Original Only • • • 0 Operations Summary (with Timelog Depths) 1E-21 Ganoactehillips , Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr); Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/24/2016 10/25/2016 2.00 COMPZN MOVE RURD P Blow down steam and water, 22:00 00:00 disconnect interconnects and unplug rig.Move shop and satellite camp, pipe sheds and service modules,jack up and move sub off of well 2U-10. 10/25/2016 10/25/2016 5.00 MIRU MOVE MOB P Conduct Doyon Crew Change,Pull off 00:00 05:00 2U Pad and move 10 modules to 1E pad. 10/25/2016 10/25/2016 5.50 MIRU MOVE RURD P Shuffle equipment around on in order 05:00 10:30 to spot sub over well due to tight quarters on lower section of 1 E pad. begin spotting over well at 06:00 hrs and set down sub at 0800 hrs. lay out matting and set complex's. Lay Herculite and set Rock Washer etc. 10/25/2016 10/25/2016 4.00 MIRU MOVE MOB P PJSM.Continue to rig up and to plug 10:30 14:30 in rig. Work on rig acceptance check list. Bring on 8.8 ppg brine in mud pits, (rig accepted at 1400 hrs) 10/25/2016 10/25/2016 0.50 MIRU MOVE RURD P RU on IA and wing valve for killing 14:30 15:00 well to tiger tank 10/25/2016 10/25/2016 1.00 COMPZN WHDBOP RURD P PJSM,PU lubricator and PU to pull 15:00 16:00 BPV. Pressure test lubricator to 2500 psi for 5 minutes 10/25/2016 10/25/2016 1.50 COMPZN WHDBOP MPSP P Pull BPV as per FMC representative 16:00 17:30 10/25/2016 10/25/2016 0.25 COMPZN WELCTL MPSP P PJSM,pressure test lines to 2500 psi 17:30 17:45 10/25/2016 10/25/2016 2.50 COMPZN WELCTL KLWL P PJSM,kill well by pumping 200 bbls 17:45 20:15 down the IA.Shut down,swap over and bullhead 110 bbls down tubing at 4.5 BPM.ICP=1900 psi,FCP=1500 psi 10/25/2016 10/25/2016 0.25 COMPZN WELCTL KLWL P SI well with 1000 psi on tbg,pressure 20:15 20:30 bled off to 770 psi in 10 minutes. Bled the IA and tbg off to tiger tank to zero. 10/25/2016 10/25/2016 0.75 COMPZN WELCTL KLWL P Monitor well for 30 minutes.Well static 20:30 21:15 and on a vac. 10/25/2016 10/25/2016 0.50 COMPZN WHDBOP MPSP P Install BPV and test it to 1000 psi from 21:15 21:45 below for 10 minutes.Pressured up to 700 psi and established an injection rate @ 2 BPM.Pumped 5 bbls and shut down pump.Held 450 psi for 10 minutes with no leaks on BPV 10/25/2016 10/25/2016 0.25 COMPZN WHDBOP MPSP P PJSM,RD and BD lines 21:45 22:00 10/25/2016 10/26/2016 2.00 COMPZN WHDBOP MPSP P Nipple down tree and adapter. Install 22:00 00:00 blanking plug into hanger threads. Prep for BOP install. Measurements taken. 10/26/2016 10/26/2016 3.00 COMPZN WHDBOP NUND P Install adapter flange and rig up 00:00 03:00 BOP's. 10/26/2016 10/26/2016 0.50 COMPZN WHDBOP RURD P Fill BOP's/Choke manifold with 03:00 03:30 water.Blled all air out of the system and perform body test. Page 1/4 Report Printed: 11/4/2016 • • 0 Operations Summary (with Timelog Depths) 0 1E-21 C onoc cehithps Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time'.. End Time Our(hr)', Phase Op Code Activity Code Time.P-T-X Operation (ftKB) End Depth(ftKB) 10/26/2016 10/26/2016 5.50 COMPZN WHDBOP BOPE P PJSM-Test BOPE with 3-1/2"and 4" 03:30 09:00 test joint to 250/2,500 psi for 5 minutes each 2-7/8"x 5"UPR VBR's and 2-7/8"x 5"LPR VBR's. #1 Top Rams,valve 1, 12, 13, 14 and manual kill #2 Upper IBOP,HCR Kill,Valves 9, 11 #3 Lower IBOP,Valves 5,8,&10 #4 Dart Valve,valves 4,6&7 #5 4"Floor valve&valve 2 #6 HCR Choke,4"Kill Line,Demco Valve #7 Manual Choke Valve, HCR Kill #8 Annular Prevernter #9 Lower Pipe Rams #10 Blind Rams,valve 3 Accumulator test: System pressure=3000 psi.Pressure after closed= 1700 psi.200 psi attained=38 secs full pressure attained=182 secs.Nitrogen bottles avg=1850 psi. Test waived by Brian Bixby @ 12:00 10/26/2016 10/26/2016 0.50 COMPZN WHDBOP RURD P R/D Test equipment and B/D Choke 09:00 09:30 manifold,choke line and kill line 10/26/2016 10/26/2016 1.00 COMPZN WHDBOP MPSP P Suck out stack from above,remove 09:30 10:30 blanking plug.Unable to remove 3- 1/2"BTC 10/26/2016 10/26/2016 2.75 COMPZN WHDBOP NUND T PJSM-Decision made to break stack 10:30 13:15 @ 7-1/16"flange and nipple down riser to retrieve XO with landing joint. Sim-ops pick SLB spooling unit and basket and GBR casing equipment to rig floor. 10/26/2016 10/26/2016 1.75 COMPZN RPCOMP PULL P Nipple up stack R/U for body test/RD 13:15 15:00 same.MU landing joint PJSM BOLDS pull hanger to floor unseat at 115K dropped off to 90K.CBU @ BPM 450 PSI. 10/26/2016 10/26/2016 0.75 COMPZN RPCOMP PULL P Pick up Power tongs and hook up hyd. 15:00 15:45 10/26/2016 10/26/2016 0.50 COMPZN RPCOMP PULL P Pulled first joint to rig floor collars 15:45 16:15 hanging up in Well Head. Adjust BOP. 10/26/2016 10/26/2016 2.20 COMPZN RPCOMP PULL P POOH LD 3.5"production tubing 16:15 18:27 (recovered 32 SS bands). RD Schlumberger spooler. 10/26/2016 10/26/2016 3.75 COMPZN RPCOMP PULL P OOH with cut joint. Flare to 4 3/8" 18:27 22:12 Pics on S drive. Prep rig for fishing run. Lay'd down 209 joints and a cut joint. 15.79' 10/26/2016 10/26/2016 0.50 COMPZN RPCOMP RURD P Clear and clean rig floor,prep for BHA 22:12 22:42 make up. 10/26/2016 10/27/2016 1.30 COMPZN RPCOMP BHAH P Install wear ring,load DC in shed and 22:42 00:00 begin BHA make up to proper torque. 10/27/2016 10/27/2016 7.00 COMPZN FISH TRIP P Continue to RIH with Baker fishing 00:00 07:00 BHA#1 along with 201 jts of 4"DP for effect. Page 2/4 Report Printed: 11/4/2016 • • • `'0.2 Operations Summary (with Timelog Depths) 1E-21 ConocoPhillips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) - Phase Op Code Activity Code Time P-T-X Operation (ftK8) End Depth(ftK8) 10/27/2016 10/27/2016 0.30 COMPZN FISH TRIP P Make up top drive. Clear floor for 07:00 07:18 jarring action. Circulate BU prior to latching fish. 10/27/2016 10/27/2016 1.00 COMPZN FISH FISH P Take parameters prior to engage. 07:18 08:18 85K dwn, 174K up WT. 3 BPM @ 170 PSI. Tag top of fish 18'in on joint 201. TOF 6644'. Begin rotating with max torque at 11K. FS—7-8K. Worked down over TOF. Set grapple with 7' swallow with 250 PSI pump pressure increase-1 jar lick at 75K OP, Straight upull to 260k dragging fish OOH. RBIH to confirm fish set down 7'high. 10/27/2016 10/27/2016 0.70 COMPZN FISH CIRC P Circulate BU prior to POOH. At— 08:18 09:00 1000 strokes noticable bubbling below bushings. Total loss during circulation = 14.7 BBLS. 10/27/2016 10/27/2016 0.30 COMPZN FISH OWFF P Monitor well for flow. 09:00 09:18 10/27/2016 10/27/2016 4.70 COMPZN FISH PULL P POOH with fish. 15-20K over pull. 09:18 14:00 Pulling slow due to swab effect. 10/27/2016 10/27/2016 3.00 COMPZN FISH BHAH P Lay down fishing BHA and extended 14:00 17:00 fish. Recovered 342.68'of fish.. Botom of cut jount to Seal assym from Otis WD perm packer. Stag fish.Lay down blast joints. Mandrels appear to be washed out.Clean floor,Prepare for cleanout BHA#2 install. 10/27/2016 10/27/2016 1.00 COMPZN FISH BHAH P MU BHA for cleanout run. 17:00 18:00 10/27/2016 10/27/2016 2.30 COMPZN FISH TRIP P RIH to 6,700'MD take startup 18:00 20:18 parameters. 170 up/90 DWN,4 BPM at 300 PSI.5-410,6-480 PSI. 10/27/2016 10/27/2016 2.00 COMPZN FISH CIRC P Clean out through perf area with BHA 20:18 22:18 #2. Stab into SBR while pumping. Pump High Vis pill with over displacement to surface. returns 1-1. litttle to no solids witnessed. 10/27/2016 10/27/2016 0.70 COMPZN FISH PULD P Pull up hole above perfrs to prep for 22:18 23:00 slip&cut drill line. 10/27/2016 10/28/2016 1.00 COMPZN FISH SLPC P S/C drill line while monitoring hole 23:00 00:00 conditions. 10/28/2016 10/28/2016 6.00 COMPZN WELLPR TRIP P Continue to POOH post cleanout run 00:00 06:00 along with S/C drill line. 10/28/2016 10/28/2016 3.00 COMPZN WELLPR BHAH P Monitor hole for flow,lay down drill 06:00 09:00 collars/BHA. Break all connections. LD all Baker fishing equip. Sand and scale found in boot baskets.Clean rig floor. Prep for completion. Bring GBR equipment to rig floor for connections. Pull wear ring. 10/28/2016 10/28/2016 3.00 COMPZN RPCOMP PUTB P PJSM. Begin with Otis seal assy to 09:00 12:00 begin RIH with 3.5"L-80 combi upper/lower completion as per program.Hole conditions stable. 10/28/2016 10/28/2016 6.00 COMPZN RPCOMP PUTB P Continue to RIH with 3.5"L-80 combi 12:00 18:00 completion.rig up to circulate while locating in lower PKR. Up WT 95K DWN WT 75K. Page 3/4 Report Printed: 11/4/2016 • • 0r Operations Summary (with Timelog Depths) 1 E-21 ConocaPhiihps Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (MKS) End Depth(ftKS) 10/28/2016 10/28/2016 3.00 COMPZN RPCOMP HOSO P Locate Otis SBE w/circ pump on. PU 18:00 21:00 10K over string WT. Appears we are detained. Test SBE integrity PT good. Decide to Set upper PKR rather than potentially release upper PBR prematurely. Post PKR set perform PT to 2K. PT Failed. reattempt failed as well. Drop B&R for assurance. Failed as well. Pressure tubing up to 600 PSI/IA to 1000 PSI instant equalization. Appears SO valve partially then Completely sheared prematurely. Pressure test complete system to 1000PSI passed. Shear out PBR 25K overpull,Perform spaceout proceedure. Need 26.71'pups below joint 212. Install tubing hanger. 10/28/2016 10/28/2016 1.30 COMPZN RPCOMP CRIH P PJ safety meet. Pump CI around and 21:00 22:18 chase with 15 BBL seawater. 10/28/2016 10/29/2016 1.70 COMPZN RPCOMP THGR P Drain stack,land tubing hanger.PT 22:18 00:00 combi both IA and tubing to 3K for 30 min. Test passed. Install BPV. Prep for NUND. 10/29/2016 10/29/2016 1.00 COMPZN RPCOMP RURD P RD/BD pressure testing equipment. 00:00 01:00 10/29/2016 10/29/2016 0.75 COMPZN WHDBOP MPSP P Set BPV. Test to 1000 PSI for 10 min 01:00 01:45 in direction of flow. 10/29/2016 10/29/2016 1.25 COMPZN WHDBOP NUND P ND BOPE break door ram bolts for 01:45 03:00 clean pits, 10/29/2016 10/29/2016 0.75 COMPZN WHDBOP NUND P NU flange adapter and production 03:00 03:45 tree. Test flange 250/5000 PSI. . 10/29/2016 10/29/2016 1.50 COMPZN WHDBOP FRZP P rig up for freeze protect Utube system. 03:45 05:15 PT system. 10/29/2016 10/29/2016 1.50 COMPZN WHDBOP PRTS P PT production tree to 5000 PSI with Lil 05:15 06:45 Red Services 10/29/2016 10/29/2016 1.75 COMPZN WHDBOP FRZP P Freeze Protect well with 80 bbl's of 06:45 08:30 diesel. Pump at 2 bpm at 640 ICP FCP 825 psi Allow well to Utube,200 psi after 1 hour,Attempt to bleed off- continue to flow back-SWI. 10/29/2016 10/29/2016 1.50 COMPZN WHDBOP FRZP P RD Cellar equipment for freeze 08:30 10:00 protecting,dress tree. 10/29/2016 10/29/2016 2.00 COMPZN WHDBOP MPSP P RU lubricator and lubricate in BPV and 10:00 12:00 set. RD lubricator 10/29/2016 10/29/2016 2.00 DEMOB WHDBOP RURD P Continue to conduct WBM out of the 12:00 14:00 Critical path. RD equipment and prep for move. Release Doyen 141 @ 14:00 hrs Page 4/4 Report Printed: 11/4/2016 N., KUP 1E-21 •Conoco Phillips `wag Well Attribu Max Angl TD Alaska,Inc a Wellbore APIIUWI Field Name Wellbore Status ncl r) MD(ftKB) Act Btm(ftKB) CorwcoPfligipz 500292089200 KUPARUK RIVER UNIT INJ 41.95 3,925.00 7,420.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 1E-21,11/29/201610:41:28 AM SSSV:NONE Last WO: 10/29/2016 39.00 1/20/1983 Vertical.sclamahc(actual) Annotation Depth(ftKB) End Date Annotation last Mod By End Date Last Tag:SLM 7,163.0 11/13/2016 Rev Reason:WO,TAG,GLV C/O,PULL BALL 8 pproven 11/22/2016 HANGER;317.2 WA' ROD,RHC,CATCHER&PLUG Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth TVD)...Wt/Len(I...Grade Top Thread - CONDUCTOR 16 15.060 34.0 110.0 110.0 65.00 H-40 WELDED • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 1" F SURFACE 10 3/4 9.950 33.8 2,207.1 2,207.0 45.50 J-55 BTC [ I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 31.3 7,368.4 6,510.5 26.00 K-55 BTC 4 Tubing Strings +- Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING-Upper 3 1/2 2.992 30.2 6,691.9 5,919.2 9.30 L-80 EUE 8rd Mod wa,Completion 2016 RWO Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Corn (in) CONDUCTOR;34.0-110.0 ., 3 302 302 0.00 HANGER FMC TBG Hanger 2.950 6,679.1 5,908.1 2921 LOCATOR Baker Locator Sub 3.000 6,680.1 5,908.9 2923 SEAL ASSY Baker 80-40 Seal assembly 3.000 Tubing Description Shing Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Iblft) Grade Top Connection E TUBING-C Sand 31/2 2.992 6,683.9 7,004.3 6,1915 9.30 L-80 EUE 8rd IL Selective 2016 RWO SURFACE 33.6-2,207.1 Completion Details I I Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl CI Item Des Com (in) 6,683.9 5,912.2 29.33 PBR 10-ft Baker 80-40 PBR 4.000 GAS LIFT,6,622.5 6,696.7 5,923.4 29.64 PACKER Baker FHL Packer 3.000 6,750.3 5,970.1 29.53 NIPPLE NIPPLE"NO GO"DS 2.812" 2.813 6,852.5 6,059.4 29.38 Blast Joint Baker 20-ft 3-1/2"Blast Joints 2.992 6,982.9 6,173.0 29.73 SLIDING SLV 2.813"BX CMU Sliding Sleeve 2.992 6,995.2 6,183.7 29.80 SEAL ASSY Otis Seal Assembly 2.980 LOCATOR;6,679.1 • Tubing DescriptionString Ma...ID(in) D)Top(ftKB) Set Depth(ft..Set Depth(NI...Wt(lb/ft) Connection TUBING-Original 1 6.1561 4.000 6,999. 3 7,034.41 6,217.71 1Grade I SEAL ASSY;6,660.1 Completion Details PBR;6,683.9 - Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 6,999.3 6,187.2° 29.83 PACKER OTIS WD PERMANENT PACKER 4.000 PACKER;6,696.7 - - 7,021.9 6,206.9 29.35 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,033.1 6,216.6 29.27 SOS OTIS SHEAR OUT SUB 2.992 Perforations&Slots I Shot Dens NIPPLE;6,750.3 Top(ftKB) atm(ftKB) Top Katm(ND) (shoal (ftKB) (ftKB) Zone Date ft) Type Com 6,850.0 6,948.0 6,057.2 6,142.6 C-4,C-3,C-2, 1/20/1983 4.0 IPERF C-1,1E-21 7,101.0 7,115.0 6,275.9 6,288.1 A-5,1E-21 1/20/1983 4.0'IPERF 7,130.0 7,145.0 6301.2 6,314.4 A-4,1E-21 1/20/1983 4.0 IPERF GAS LIFT;6803.5 1• Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com r, 1 l 6,622.5 5,858.9 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/12/2016 IPERF,6,850.0-6,948,0- I.. I 2 6,803.5 6,016.5 Camco MMG 11/2 GAS LIFT DMY RKP 0.000 0.0 11/2/2016 Notes:General&Safety End Date Annotation 8/26/2010 NOTE:View Schematic w/Alaska Schematic9.0 10/24/2016 NOTE:WO SLIDING SLV;6,982.9 '. II SEAL ASSY;6,995.2 , 3if PACKER',6,999.3 NIPPLE;7,021.9 M SOS;7,033.1 P. IPERF;7,101.0.7,115.0 IPERF;7,130.0-7,145.0-. I PRODUCTION,31.3-7,368.4-. . oM • • a � y0 O L 7 W Lil e- e- e- " r- e- e- 1-- T el) ri (O (7 0 r e- r 0 • � , -? 0 N Z r x '10> 6 S 1IJ V �o p+r-n - o .L _ a�Y cu -0 ° Y r N O Q N ( O -O ID c6 N �S 0v 5 cu > O V 8: 0 a C OC O CO _ Q T y LC Y -° LU (0 ° -C C? m Q ° L U Q1 7 ❑ Q (WD (o co co (0 co co (0 co (O to L Q1 °U LO -J 0 , , , E +-' L O < 0 U U U U U U U U U U ti- �' I- 0 rr -' 900000 0000 v= c L Mu 0 Ne- e- V) t0 ti !� 00 O) O 0 {U-' L C to Z ,': 0 N U EMS -, U Z v > o Q) 2cc • O C i 1- ~ N 'D O 0000000000 C )- v W J J J J J J J J J J OA C — L) 0 } W W W W W W W W W W in U `�" F LL LL LL L LL LL LL LL LL LLY 01 _° CU 0 Q J J J J J J J J J J o _c > C CU tr, �- Q Q Q Q Q Q Q Q Q Q QJ In C ` •- G o) a Z Z Z Z Z Z Z Z Z Z N L N ° U O O ° LL LL LL LL LL LL LL LL LL LL CC --- L > CD 4... > C QJ Y O r O L v 0 O b) ro Z avv U w C o ..a ..1 — ETI.) .. us C" G a. F tzt .� uovi . °> L Q v a a [^O c. 0 p G J C Y J C to z J a GV 'i 0 G " m 0 1— a 1— E - 0 g E. 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'D O C Z E a, m Q W Q v E E u v a iC _ _ v f° m vi a 6) aj ei Q N N (D f` O f/) e- �+ N C i Y z t, �1„,, :Z O O N O N e- N N !C_' ro N Q) v somme o. a O N W J J W LL N N N N ,- E Z H O O vl i '.W N c Y '� .-.7^, .: f6 co C Cl EF C o G O CA a � 4 .. , , r Iaa4IJ s, ti OF T1� • • 1�j.- 4. THE STATE Alaska Oil and Gas ,,;-— a � of15 :1 Conservation Commission 333 West Seventh Avenue ^M. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS'" Fax: 907.276.7542 www.aogcc.alaska.gov Diana Guzman Sr. Wells Engineer SCANNED JUL 1 2 2016 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1E-21 Permit to Drill Number: 183-002 Sundry Number: 316-307 Dear Ms. Guzman: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, t_PV.81. Cathy P. Foerster ,,y,� Chair DATED this 7'"day of July, 2016. RBDMS J . 0 8 2016 RECEIVED • STATE OF ALASKA • JUN 0 3 2016 ' ALASKA OIL AND GAS CONSERVATION COMMISSION y)-rs 7d6// , APPLICATION FOR SUNDRY APPROVALS AOG 20 AAC 25.280 1.Type of Request: Abandon E', Plug Perforations r Fracture Stimulate) Repair Well F Operations Shutdown I....,. Suspend 1 Perforate 1- Other Stimulate FT Pull Tubing F Change Approved Program im Plug for Redrill 7 Perforate New Pool fl Re-enter Susp Well 7 Alter Casing Other: 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. 183-002 P Exploratory ) Development h 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-20892-00 7. If perforating: . 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a , KRU 1E-21 Will planned perforations require a spacing exception? Yes No F 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL 25651 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7,420' 6,556' 7285 6446 2. 152, 6980,7256 Casing Length Size MD TVD Burst Collapse Structural - Conductor 76' 16" 110' 110' Surface 2,173' 10 3/4" 2,207' 2,207' Intermediate Production 7,337' 7" 7,368' 6,510' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6850-6948,7101-7115,7130- 6057-6143,6276-6288,6301- 3.500" J-55 7,034' 7145 • 6314 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-OTIS RRH HYD RETRIEVABLE PACKER MD=6709 TVD=5934 PACKER-OTIS WD PERMANENT PACKER . MD=6999 TVD=6187 12.Attachments: Proposal Summary 2 Wellbore schematic 2 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory Stratigraphic I...... Development r Service 3 . 14. Estimated Date for 8/1/2016 15.Well Status after proposed work: Commencing Operations: OIL 5....... WINJ F WDSPL Is Suspended 1- 16.Verbal Approval: Date: GAS E WAG GSTOR fl SPLUG is GINJ 1. OpShutdown [_ Abandoned F....... Commission Representative: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Diana Guzman @ 265-6318 Email Diana.Guzman@conocophillips.com Printed Name Diana G man Title Sr.Wells Engineer / �v1e 2, 25:;)t4. Signature L.Phone 265-6318 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3lk _ 30 7 Plug Integrity ❑ BOP Test E Mechanical Integrity Test E Location Clearance ❑ Other: t30 P rc5 t 2 Sd P 5 I cJ Atiovlar- prrvoriTr) ,-ic to ,z 50 ps-+ Post Initial Injection MIT Req'd? Yes LTJ No ❑ �n Spacing Exception Required? Yes ❑ No R/ Subsequent Form Required: /b-- 4. A. RBDMS l,L- JUL 0 8 2016 APPROVED BY ,,../Approved by: C M ISSIONER THE COMMISSION Date: 7 7-� SQL a J Form 10-403 Revis 11/2015 (�aPb i for 12 months from the date of approval. Attachments in Duplicate • • „ ConocoPhillips JUN 0 3 2015 Alaska P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 June 1,2016 Commissioner Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 1E-21 (PTD#183-002). Well 1E-21 is a Kuparuk River Unit'A' & 'C' sand selective injector drilled and completed in 1983. Well 1E-21 has been shut in since 5/9/2012 due to a failed inner annulus (IA) draw down test. The well now has leaks identified by leak detection log in the vicinity of the upper injection mandrel and the seal bore receptacle (SBR). There is currently no evidence of any integrity issues with the production casing or surface casing and the current problems will be mitigated by replacing tubing. The well is currently SI and secured with a 2.75"CA-2 plug set in the D nipple profile. The purpose of this workover is to restore mechanical integrity to the well and re-establish injection into the A-sand interval. This will be accomplished by pulling the existing 3-1/2" tubing down to the Otis permanent packer at 6999'.A new selective completion above the existing Otis permanent packer will be installed as well. If you have any questions or require any further information,please contact me at 907-265-6318. Sincerely, ♦ i Diana Guz .n Wells Engineer CPAI Drilling and Wells • • 1E-21 Rig Workover P&R 3 '/2" Selective (PTD #: 183-002) Current Status: This well is currently shut-in and awaiting a rig workover. The well was secured with a 2.75"CA- 2 plug set September 2014 in the no-go nipple at 7022'. Scope of Work: • Pull the existing 3 11/2"completion to the pre-rig cut depth. • Pull Otis retrievable packer with upper selective. • Install a new 3 '/2" selective completion. General Well info: Well Type: Injector MPSP: 2152 psi using 0.1 psi/ft gradient(Most recent SBHP=2782 psi on 9/5/14) Reservoir Pressure/TVD: 2782 psi/6297' TVD(8.5 ppg)on 9/5/14 Wellhead type/pressure rating: FMC Gen I/5M psi BOP configuration: Annular/Pipe Rams/Blind Rams/Flow Cross/Pipe Rams TIFL/MIT results: MIT—OA passed December 20,2015 MIT-IA passed on May 9,2012 MIT-T passed December 27,2012 MIT-IA part of the pre-rig request to update results from 2012 Earliest Estimated Start Date: August 1,2016 Drillsite Petroleum Engineer: Amanda Bacala Workover Engineer: Diana Guzman Work:265-6318 E-mail: Diana.Guzman@conocophillips.com Pre-Rig Work 1. RU SL: a. Install dummy valve in Station#1 to isolate upper tubing for a MIT-IA b. Perform a MIT-IA to confirm 7"csg integrity down to Otis packer at 6709' c. Pull dummy valves from Station#1 .Leave open for circulation during the RWO. 2. RU E-line: a. Cut the 3 '/2"tubing at 6629'. 3. FT LDS's. 4. Set BPV. Proposed Procedure 1. MIRU 2. Pull BPV. Circulate workover fluid. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF,weight up,and repeat circulation as necessary. Verify well is dead.f 3. Set BPV&blanking plug,ND tree,NU BOPE and test to 2500 psig. . 4. Pull blanking plug&BPV. Screw in landing joint,BOLDS's, and pull tbg hgr to the rig floor. 5. POOH laying down 3 '/2"tubing from pre-rig tubing cut and spooling control line. 6. RIH with overshot and latch onto tubing stub.Jar packer free and POOH. • • 7. POOH with packer and upper selective. 8. Cleanout to top of packer. 9. MU new packer assembly w/new Otis Seal Locator on 3 '/z" injector string and RIH to top of Otis permanent packer(6998' RKB) 10. Pump pill of corrosion inhibited brine. ✓ 11. Sting into the seal bore until fully located, space out 1 ft. from fully located, set the packer. PT the IA. Shear the PBR. 12. Space out with pups,MU hanger, load the well with corrosion inhibited brine, land the hanger, and RILDS. 13. PT the tubing and IA Shear the SOV. 14. Install the BPV or two-way check. Pressure up on the IA to test the BPV or two-way check from below. Bleed IA to 0 psi. 15. ND BOPE. NU tree. If BPV is installed,pull BPV and install tree test plug. Test tree. 16. Pull test plug/two-way check. Freeze protect well with diesel. Set BPV. 17. RDMO. Post-Rig Work request: 1. Reset well house(s)and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: a. Pull SOV and set up for injection. b. Pull catcher c. Pull CA-2 4. RDMO. ` • . KUP INJ • 1E-21 • ConocoPhdhps u Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) Carlocaltewps 500292089200 KUPARUK RIVER UNIT INJ 41.95 3,925.00 7,420.0 °°° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-21,4/10/201411.43.28 AM SSSV.TRDP Last WO. 2/13/1985 39.00 1/20/1983 Vesical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag'SLM 7,158.0 5/21/2013 Rev Reason:GLV 0/0 hipshkf 4/10/2014 HANGER;30.2 1:--.1, c 11 HANGER; Casing Strings Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WI/Len(I...Grade Top Thread 1. 1 1. 1 / CONDUCTOR 16 15.060 34.0 110.0 110.0 65.00 H-40 WELDED Casing Description OD(In) ID(in) -Top)ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 703/4 9.950_ 33.7 2,207.7 2,207.0 45.50 J-55 BTC Casing Description OD)in) -ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Vat/Len(I...Grade Top Thread PRODUCTION 7 6.276 32.1 7,368.4 6,510.5 26.00 K-55 BTC pedTubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth)TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 3 1/2 2.992 30.2 7,034.4 6,217.8 9.30 J-55 EUEBrdABMOD -^-'s-,CONDUCTOR:3i.0-110.0•' I r ✓--Completion Details Nominal ID Top(ftKB) Top(TVD)(MB) Top Incl(°) Item Des Com (in) 302 30.2 0.00 HANGER FMC GEN III HANGER 3.500 SAFETY VLV;1926.8aril 4 1,926.8 1,926.7 0.69 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE 2.813 6,680.6 5,909.3 29.25 SBR OTIS SBR 2.813 6,708.7 5,933.8 29.54 PACKER OTIS RRH HYD RETRIEVABLE PACKER 2.970 6,861.3 6,067.1 29.20 BLAST JTS CAMCO STEEL BLAST JOINTS(OAL=106.6') 2.920 6,998.1 6,186.2 29.82 LOCATOR OTIS STRAIGHT SLOT LOCATOR 3.000 6,999.3 6,187.2 29.83 PACKER OTIS WD PERMANENT PACKER 4.000 I 7,022.0 6,206.9 29.35 NIPPLE CAMCO D NIPPLE NO GO 2.750 SURFACE;33.7-2.207.1----• . . 7,033.1 6,216.6 29.27 SOS OTIS SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Teel GAS LIFT;6,636.3 Top(ftKB) (ftKB) 1°) Des Corn Run Date ID(in) 6,980.0 6,170.4 29.71 FISH 2'WIRE 25"Wire Remain in Hole on 4/4/93;Cause 4/4/1993 0.000 of Friction Bites @ 6980'WLM 7,004.0 6,191.3 29.74 CATCHER 3 1/2"x 125:CATCHER SUB ON CA-2 PLUG 5/22/2013 - 0.000 7,013.0 6,199.1 29.54 PLUG 2.75 CA-2 PLUG 5/21/2013 0.000 7,256.0 6,411.8 28.57 FISH 1 1/2"CV w/RK Latch Suspect Dropped Valve 2/23/1998 - 0.000 SBR,0,680.6 -O. Downhole(2/23/98) Perforations&Slots Shot Dens PACKER;8,708.7 Top(TVD) Bim(TVD) (ahots/f Top)ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date I) Type Com ° 6,850.0 6,948.0 6,057.2 6,142.6 C-4,C-3,C-2, 1/20/1983 4.0 IPERF C-1,1E-21 INJECTION;8,746.1al 7,101.0 7,115.0 6,275.9 6,288.1 A-5,1E-21 1/20/1983 4.0 IPERF ' 7,130.0 7,145.0 6,301.2 6,314.4 A-4,1E-21 1/20/1983 - 4.0 IPERF INJECTION;6,817.4 Mandrel Inserts 7:145.0 atl I on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn I I 1 6,636.3 5,870.9 CAMCO KBUG 1 GAS LIFT OPEN 4/9/2014 2 6,746.1 5,966.4 CAMCO MMG-2 11/2 INJ DMY RK 0.000 0.0 5/22/2013 EXT IPERF:8.860.0-6.948.0 ' PKG 3 6,817.4 6,028.7 CAMCO MMG-2 11/2 INJ DMY RK 0.375 0.0 5/24/2013 ff 4 6,978.1 6,168.7 CAMCO MMG-2 11/2 INJ DMY RK 0.375 0.0 5/23/2013 Notes:General&Safety End Date Annotation _ 8/26/2010 NOTE View Schematic w/Alaska Schematic9.0 5/4/2012 NOTE:LEAKS FOUND AT GLM#2 @ 6749'ON WATER INJECTION SURVEY FISH;6,980.0 a\ 6/26/2012 NOTE.TAGGED OBSTRUCTION @ 61'WLM INJECTION;8,978.1 ill2 LOCATOR;6998.1 idyl PACKER.6,999.3 CATCHER;7.004.0 I,' 3 , u PLUG:7.013.0 1,. NIPPLE;7,022.0 $ SOS.7,033.1 _-,, IPERF;7,101.0.7,115.0-- -1 IPERF:7,130.0.7,146.0 FISH;7,256.6 PRODUCTION:32.1-7.368.4-4 - • - - • • • ConocoPh i l l i ps 1 E-21 Proposed Completion P&R Selective 16" 65.0#, H-40 to 110' MD — 11.- 10 3/4"45.0#,J-55 to 2207' MD t_ • 3 '/2"x 1 1/2" MMG-2 Mandrel r PBR Retrievable Packer @ 6670' mosK N 3'/z"x 1 1/2" MMG-2 Mandrel 4.7 ®f 3 1/2" x 1 1/2" MMG-2 Mandrel C-Sand Perfs @ 6850'-694:' -, Blast jts across the C-Sand a 3'/z" 9.3#L-80 8rd EUE Tbg w/ 5 If ? Otis WD Permanent Packer @ 6999' w/a straight locator 2.75" CA-2 Plug with catcher x 2.75" D Nipple Profile 1I -- Baker Shear Out Sub A-5 Perf @ 7101'-7145' —O.& A-4 Perf @ 7130'-7145' —P–Z,Z. Fish–7256' 7"26.0#, K-55 to 7368' MD —� G � Date: June 2,2016 Drawn By: Diana Guzman 3ge Project Well History File~ver Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J-&~- 00~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [3 Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: · .: [] Logs of various kinds NOTES: [] Other BY; BEVERLY BREN VINCENT SHERYL MARIA LowELL DATE: /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Scanning Preparation x 30 = + ~ BEVERLY BREN VINCENT SHERYL~LOWELL BY: Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: 'l ~'~)~' BY: Stage 2 {SCANNING IS COMPLETE AT THIB POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES ) = TOTAL PAGES PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES BEVERLY BREN VINCENT(~ MARIA LOWELL NO NO RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: General Notes or Comments about this file: ~si Quality Checked (do.et 3 x.:,. .* .e .. ":u'i.es".41re�.°7 .are,' . q:a �.. r'TOTIMI'''.. _'"' dl \V/7, THE STATE A e. (13- E' ��. 22.-121. J _ -- .__. _----- ---- 333 West Sevc nir, P vc, :e / ,�i. G t �' 1. > i /- "Ccrooe A!os.!Co 99501-3572 fit,;: ,l; r. �:A i, ✓� t .', Jai ,/.L / ,/2 Janelle Nesvold RWO Engineer SCANNED JUL ] �a14 — (�ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E-21 Sundry Number: 314-284 Dear Ms. Nesvold: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P.foerster Chair DATED this day of May, 2014. Encl. • STATE OF ALASKA RECEIVED • AL .A OIL AND GAS CONSERVATION COMN, ON SAY O 2014 s APPLICATION FOR SUNDRY APPROVALS CoS 5/ i/t- 20 AAC 25.280 ("� 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r' Change '•i• Se rlirfi r Suspend r Rug Perforations r I rforate r Pull Tubing • Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r" Alter casing r Other: I.--- 2. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 183-002 , 3.Address: 6.API Number: Stratigraphic r Service P.O. Box 100360,Anchorage,Alaska 99510 50-029-20892-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No (r7' 0(0,1/4. 1 E-21 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651 Kuparuk River Field/Kuparuk River Oil Pool i 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 7420 6556 7285' 6446' 7013' 6980',7256' Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 16 110' 110' SURFACE 2173 10.75 2207' 2207' PRODUCTION 7336 7 7368' 6511' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6850'-6948',7101'-7115',7130'-7145'1 6057'-6143',6276-6288',6301'-6314' 3.5 J-55 7034 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-OTIS RRH HYD RETRIEVABLE PACKER • MD=6709 TVD=5934 PACKER-OTIS WD PERMANENT PACKER , MD=6999 TVD=6187 SAFETY VLV-CAMCO TRDP-1A SAFETY VALVE %MD=1927 TVD=1927 12.Attachments: Description Summary of Proposal , I✓ 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service P 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/6/2014 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG 17 • Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Janelle Nesvold Email: Janelle.R.Nesvold(rD.conocophillips.com Printed Name Janelle Nesvold Title: RWO Engineer Signature I Phone:263-4641 Date 54/11/ Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3\4-4.-2.1' Plug Integrity r BOP Test V Mechanical Integrity Test /Location Clearance r Other: 1�D 1� tCS f 7`O .3J UD p5 , ` fi �J /_ f,��sS t�J .44 i T— /A i-,-1/Li v t d �f tt� 7La 'b'713761 i � z-c G, 51-6, tw c , Spacing Exception Required? Yes 0 No 0/ Subsequent Form Required: /D - 4 Q 4 (J �� APPROVED BY q / Approved by: p �T'�\ COMMISSIONER THE COMMISSION Dater Zp '( Approved application Is valid for 12 months tro the date of approval. Form 10-403(Revised 10/2012) oRIGINAL P« If Submit Form and Attachments in Duplicate VLF 3/27-/,1)- AO'Wr ✓ RECEIVED ConocoPhillips MAY 0 2 2014 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 30th,2014 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 1E-21 (PTD#183-002). Well 1E-21 is a Kuparuk River Unit'A' & 'C' sand selective injector drilled and completed in 1983. Well 1E-21 has been shut in since 5/9/2012 due to a failed inner annulus (IA) draw down test. The well now has leaks identified by leak detection log in the vicinity of the upper injection mandrel and the seal bore receptacle (SBR). There is currently no evidence of any integrity issues with the production casing or surface casing and the current problems will be mitigated by replacing tubing. The well is currently SI with a CA-2 plug set in the no-go nipple profile. The purpose of this workover is to restore mechanical integrity to the well and re-establish injection into the A-sand interval. This will be accomplished by pulling the existing 3-1/2" tubing down to the Otis permanent packer and running a new completion above the existing Otis permanent packer. If you have any questions or require any further information,please contact me at 263-4641. Sincerely, jE4ai A• r Janelle Nesvold RWO Engineer CPAI Drilling and Wells 1E-21 Kuparuk Injector Rig Workover (PTD #: 183-002) Current Status 1E-21 is currently shut-in with a CA-2 plug set in the no-go nipple profile. The MIT-IA passed but the IA DD test failed. Scope of Work The proposed workover will pull the 3-1/2"tubing and re-complete the well with a new 3-1/2"selective completion. • Pull 3-1/2"tbg from SBR • Pull OTIS retrievable packer w/upper selective • TIH with new 3-1/2"selective completion • Set FHL packer, shear PBR,and land tubing hanger General Well info MPSP: 2100 psi using max stabilized SBHP on 4/22/13 Reservoir pressure/TVD: 2730 psi at 7125' MD(6297' TVD)SBHP taken on 4/22/13 Wellhead type/pressure rating: FMC Gen I, 11"5K btm x 7-1/16"5K top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT Results: MIT-T: Passed December 27,2012(Follow-up IA DDT failed) MIT-IA: Passed on May 9,2012 MIT-OA: Passed on December 17,2013 Well Type: Injector Estimated Start Date: June 6,2014 Production Engineer: Dody Cahyadi(263-3720) Workover Engineer: Janelle Nesvold(263 -4641 /Janelle.R.Nesvold@ conocophillips.com) Pre-Rig Work Request 1. Pull DV from GLM#1 and leave open. 2. Set BPV. Proposed Procedure 1. MIRU. 2. Pull BPV. Load well with 9.6 ppg brine. Ensure well is dead. 3. Set BPV and blanking plug or two-way check. ND tree. 4. NU BOPE. Pressure test BOPE including annular. Pull blanking plug and BPV or two-way check. 5. Pull 3-1/2"tubing from SBR. a. If unable to pull tubing free,RU e-line,RIH w/RCT and cut tubing mid joint above SBR. 6. MU landing joint,BOLDS,POOH laying down tubing,and spooling control line. 7. RIH with overshot and latch onto SBR or tubing stub.Jar packer free and POOH. a. If unable to jar packer free,RU e-line and RIH w/RCT and cut tubing mid joint below the packer. 8. POOH with packer and upper selective. a. If a cut was made in the selective continue fishing until only the Otis permanent packer and tail pipe • are left in the well. 9. Cleanout to top of packer. —Proposed Procedure Continued-- 10. ontinued10. MU FH packer assembly w/new Otis Seal Locator on 3-1/2" injector string and RIH to top of Otis permanent packer(Top of packer set at 6998'RKB) 11. Spot corrosion inhibited brine around the selective above the PBR. 12. Sting into the seal bore until fully located,space out 1 ft. from fully located,drop ball&rod, set the FH packer. PT the IA. Shear the PBR. ✓ 13. Space out with pups,MU hanger,load the well with corrosion inhibited brine,land the hanger,and RILDS. 14. PT the tubing and IA. Shear the SOV. ✓ Cha 15. Install the BPV or two-way check. Pressure up on the IA to test the BPV or two-way check from below. Bleed IA to 0 psi. 16. ND BOPE. NU tree. If BPV is installed,pull BPV and install tree test plug. Test tree. 17. Pull test plug/two-way check. Freeze protect well with diesel. Set BPV. 18. RDMO. Post-Rig Work request: 1. Reset well house(s)and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: a. Pull ball&rod b. Pull RHC plug body c. Pull SOV and run DV.MIT-T to 3,500 psi d. Pull catcher e. Pull CA-2 f. RD slickline 4. RDMO. II • • KUP INJ 1E-21 ConocoPhiilips U Well Attributes An &MD Ta + Alaska Inc Wellbore API/UWI Field Name Wellbore Status )ncl(°) MD(RKB) Act Btm(ORB) 500292089200 KUPARUK RIVER UNIT INJ 41.95 3,925.00 7,420.0 °.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1E-21,4/10201411.43.28 AM SSSV:TRDP Last WO: 2/13/1985 39.00 1/20/1983 Vertical schematic(actual) Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,158.0 5/21/2013 Rev Reason:GLV C/O hipshkf 4/10/2014 HANGER;30.2 a , '� casing strings 11 1 S; Casingg Description OD(in) ID(in) Top(RKB) Set Depth(ORB) Set Depth(TVD)...WVLen(I...Grade Top Thread ■■ CONDUCTOR 16 15.060 34.0 110.0 110.0 65.00 H-40 WELDED Casing Desc pilon OD(in) ID(in) Top(RKB) 'Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread s SURFACE 103/4 9.950 33.7 2,207.1 2,207.0 45 50 J-55 BTC Casing De pilon OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(TVD)... WVLen(I...Grade Top Thread IN" II I PRODUCTION 7 6.276 32.1 7,368.4 6,510.5 26 00 K-55 BTC Tubing Strings Tubing Description String Ma...ID(In) Top(RKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/fp Grade Top Connection TUBING 312 2.992 30.2 7,034.4 6,2178 9.30 J-55 EUEBrdABMOD -A."CONDUCTOR;340110.0- Completion Details RKB TopNominal ID Top( ) (TVD)(fRCB) Top Ind(°) Item Des Com (in) 30.2 30.2 0.00 HANGER FMC GEN III HANGER 3.500 SAFETY VLV,1,926.8 1,926.8 1,926.7 0.69 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE 2.813 6,680.6 5,909.3 29.25 SBR OTIS SBR 2.813 6,708.7 5,933.8 29.54 PACKER OTIS RRH HYD RETRIEVABLE PACKER 2.970 6,861.3 6,067.1 2920 BLAST JTS CAMCO STEEL BLAST JOINTS(OAL=106.6') 2.920 6,998.1 6,186.2 29.82 LOCATOR OTIS STRAIGHT SLOT LOCATOR 3.000 6,999.3 6,187.2 29.83 PACKER OTIS WD PERMANENT PACKER 4.000 7,022.0 6,206.9 29.35 NIPPLE CAMCO D NIPPLE NO GO 2.750 SURFACE;33.7-2,207.1-' . 7,033.1 6,216.6 2927 SOS OTIS SHEAR OUT SUB 2.992 IOther In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl GAS LIFT;6,636.3 t". Top(RKB) (RKB) r) Des Com Run Date ID(in) 6,980.0 6,170.4 29.71 FISH 2'WIRE 25"Wire Remain in Hole on 4/4/93;Cause 4/4/1993 0.000 of Friction Bites @ 6980'WLM II7,004.0 6,191.3 29.74 CATCHER 3 1/2"x 125:CATCHER SUB ON CA-2 PLUG 5/22/2013 0.000 11 7,013.0 6,199.1 29.54 PLUG 2.75 CA-2 PLUG 5/21/2013 0.000 7,256.0 6,411.8 28.57 FISH 1 1/2•CV w/RK Latch Suspect Dropped Valve 2/23/1998 0.000 SBR;6.680.6 .s Downhole(2/23/98) I Perforations&Slots Shot Dens PACKER;6708.7 •-., Top(TVD) Btm(TVD) (shots/f • Top(RKB) Btm(RKB) (RKB) (RKB) Zone Date t) Type Com I 6,850.0 6,948.0 6,057.2 6,142.6 C-4,C-3,C-2, 1/20/1983 4.0 IPERF C-1,1E-21 INJECTION;6,746.1 ! 7,101.0 7,115.0 6,275.9 6,288.1 A-5,1E-21 1/20/1983 4.0 IPERF ll7,130.0 7,145.0 6,301.2 6,314.4 A-4,1E-21 1/20/1983 4.0 IPERF INJECTION;6.817.4 - Mandrel Inserts • - St f on Top(TVD) Valve Latch Port Size TRO Run N Top(RKB) (RKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 6,636.3 5,870.9 CAMCO KBUG 1 GAS LIFT OPEN 4/9/2014 2 6,746.1 5,966.4 CAMCO MMG-2 11/2 INJ DMY RK 0.000 0.0 5/22/2013 EXT IPERF,6.850.0-6948.0--= PKG 3 6,817.4 6,028.7 CAMCO MMG-2 11/2 INJ DMY RK 0.375 0.0 5/24/2013 4 6,978.1 6,168.7 CAMCO MMG-2 11/2 INJ DMY RK 0.375 0.0 5/23/2013 Notes:General&Safety End Date Annotation 8/26/2010 NOTE:View Schematic w/Alaska Schematic9.0 5/4/2012 NOTE:LEAKS FOUND AT GLM#2 @ 6749'ON WATER INJECTION SURVEY FISH;6980.0 6/26/2012 NOTE:TAGGED OBSTRUCTION @ 61'WLM INJECTION;6978.1 a LOCATOR;6,998.1le ]] I ,I 6 it ({ PACKER,6,999.3 + CATCHER,7,004.0 d\k11 a PLUG,7,013.0 NIPPLE;7,022.0 • I SOS,7,033.1 IPERF,7,101 0-7.115.0 IPERF;7,130.0-7,145 0 FISH;7,256.0 PRODUCTION,32.1-7,368.4-- • • aoZ 2t5 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 9, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 AMAIEDJUN 2 1 LUIZ RE: Injection Profile: 1E-21 Run Date: 5/3/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1E -21 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 - 20892 -00 Injection Profile Log 1 Color Log 50- 029 - 20892 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: `v(l 4E112. Signed: l PTD i 63 Regg, James B (DOA) From: NSK Problem Well Supv [n1617 ©conocophillips.com] Sent: Thursday, May 10, 2012 2:15 PM *4117,' To: Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 1 E -21 (PTD 183 -002) Report of failed IA DD test Attachments: 1E-21 schematic.pdf; MIT KRU 1E-21 Diagnostic MITIA 5- 9- 12.xls Jim, Guy Kuparuk injector 1E-21 (PTD 183 -002) was suspected to have TxIA communication due to pressure trends. Initial diagnostics included a passing MITIA but a failing IA DD test. The TIO prior to the testing was 1200/1660/20. The well has been shut in and will be added to the monthly injector report. Further diagnostics utilizing Slickline and possibly E -line will be scheduled. Pending the outcome, the appropriate paperwork will be submitted to repair or continue injection. Attached are a schematic, 90 day TIO plot, and test form for the diagnostic MITIA Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 �` -JUN 1 1 ZU7Z • 0 rs A Q k E a 3 w a > 0 s w t^4 w 4 M w 1.3 F 4 +�~ . 4 4 a H e 41 'al ® g F W Q ri w 1:5 H H N 0 0 a a 0RI >4 0 ILI ` � 0 3 w a 0 CnCO 04 ? - "' o w la 3 ° a x _ w ! li 1 Z T 1., a 4 H LI 3 4 CA Col z .1 C C n n M Is r a HI CC ! 1 Illit CC I C - --- - - - - 4 . i., 14 1-- W ! 3 U Cr w w w CL 1 X x F F ■ (0 i a a w 00 a J ' � z~' O W ;4 a. i:4 rn GI z • ova H rn a Fxxx 1 i t I Wrir•I RP N 1 f G0 ��'` www ).-, w o 4 H`° 0 H a N cn 0:1 14 41 ii H w o i o o x o+ ON v, o+ E/� ,� 0 0 0 0 0 0 0 0 0 0 I I I F+�I L,1 O t\ V .1 CO N N ON .O r Z "'� ' S ' , ' xi x '�'i N M N N N .1 .1 ./ N F F F F con O L i'..�g gg N O 3U yN 1 O N v, - W M —, G> , ,. oo O i" 2 J o000 0 o c: o PE _ 0 0 0 0 0 � �Q, _ 0 0 0 ry O ; m m m m x 7 -� • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reociAalaska.gov; doa .aoacc.prudhoe.bavnalaska.gov; phoebe.brooks(rDalaska.gov; tom v OPERATOR: ConocoPhllips Alaska Inc. Refl 57 4'' I v FIELD / UNIT / PAD: Kuparuk / KRU / 1 E DATE: 05/09/12 OPERATOR REP: Phiilips / Miller / Jensen AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1E -21 ` Type Inj. W ' TVD - 5,934' Tubing 1,200 '1,200 -1,200 1,200 Interval 0 P.T.D. 1830020 ' Type test P Test psi - 1500 Casing 1,660 '3,000 ' 2,925 '2,915 P/F P Notes: Diagnostic MITIA - OA 20 - 20 ' 20 ' 20 " Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 - 426 (Revised 06/2010) MIT KRU 1E -21 Diagnostic MITIA 5 -9 -12 ConacoPhillips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16th, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: ~~~~~~~ ~}~~ r~, (~ `ZdFi~~ <_ Ct~111~ISS10~ aka t~ & Gas C~ p~c~ra9a ~g ~ 002- 1 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRIl). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of foam 10-404, Report of Sundry Operations. The cement was pumped November 25th 2007 & March 21 2009, the corrosion inhibitor/sealant was pumped July 6th, 7~', 8th 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off I6 " Report of Sundry Operations (10-404) Kuparuk Field Date 7/16/10 1A.1C.1E PAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-11 50029206850000 1811730 10" n/a 10" Na 3.4 7/8!2010 1A-12 50029206880000 1811780 2" Na 2" Na 1.7 7/8/2010 1A-13 50029207000000 1811950 11" n/a 11" n/a 3.4 7/8/2010 1A-14 50029207060000 1820100 4" n/a 4" n/a 2.1 7/8/2010 1C-01 50029205260000 1801280 SF n/a 24" n/a 4.3 7/6/2010 1 C-02 50029205320000 1801350 24" n/a 24" n/a 8.5 7/6/2010 1 C-03A 50029205350100 2070630 SF n/a 16" Na 7.7 7/6/2010 1C-04 50029205470000 1801550 SF n/a 5" n/a 2.6 7/6/2010 1C-06 50029205640000 1810250 76 17.70 32" 3/21/2009 9.4 7/6/2010 1C-09 50029208590000 1821850 38' 8.00 6" 11/25/2007 6.8 7/6/2010 1C-10 50029208650000 1821930 37'6" 8.00 8" 11/25/2007 6.8 7/6/2010 1E-02 50029204720000 1800500 21" Na 21" Na 1.7 7/7/2010 1 E-03 50029204770000 1800560 4" Na 4" n/a 2.4 7/7/2010 1 E-06 50029204930000 1800780 12" n/a 12" n/a 13.6 7/7/2010 1 E-07 50029204950000 1800800 5" n/a 5" Na 2.6 7/7/2010 1E-08 50029204960000 1800810 5" n/a 5" n/a 2.6 7/7/2010 1 E-10 50029207250000 1820360 2" n/a 2" n/a 1.7 7/7/2010 1 E-13 50029207500000 1820780 5" n/a 5" Na 2.6 7/7/2010 1E-19 50029209050000 1830170 1" Na 1" Na 1.7 7R/2010 1 E-21 50029208920000 1830020 3" Na 3" Na 2.6 717@010 1 E-24A 50029208570100 1971870 2" Na 2" Na 1.7 7/7/2010 1E-25 50029208440000 1821700 3" Na 3" n/a 1.7 7/7/2010 1 E-28 50029208320000 1821580 4" n/a 4" n/a 2.5 7/8/2010 1 E-29 50029208280000 1821540 7" n/a 7" n/a 2.5 7/8/2010 Regg, James B (DOA) ~ ~~~-~° z From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Saturday, June 26, 2010 9:59 AM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Subject: KRU 4 Yr and Variance MIT's ~~'~°~' ~~Z~~ l~ Attachments: KRU 1 G-01 062510.x1s; KRU 2D-04 062510.x1s; KRU 1 E pad 062510.x1s KRU iG-01 KRU 2D-04 KRU lE pad 062510.x15 (21 KB) 062510.x15 (21 KB) 062510.x15 (21 KB) Attached please find the State witnessed Variance required MIT's for 2D-04 and 1G-O1 and State waived 4 year MIT's on DS1E. Let me know if you have any questions about the data. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 ~ ~ Y i~~l~. i.V 4.~~Si ~~~~~~ , 1 • FIELD /UNIT /PAD: Kuparuk /KRU / 1 E DATE: 06/25/10 OPERATOR REP: Ives/Mouser - ASRC AOGCC REP: Waived by Bob Noble Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov G'Z~I~~ OPERATOR: ConocoPhillips Alaska Inc. ~~$ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Packer Depth Pretest Initial 15 Min. 30 Min. Well 1E-21 Type Inj. W / TVD 5,943' Tubing 2,000 2,000 2,000 2,000 Interval 4 P.T.D. 1830020 Type test P Test psi 1500 Casing 1,620 ~ 3,000 2,960 2,960 P/F P / Notes: OA 80 80 80 80 Well 1E-22 Type Inj. N TVD 5,955' Tubing 2,250 2,250 2,250 2,250 Interval 4 P.T.D. 1822140 Type test P Test psi 1500 Casing 740 2,920 2,880 2,850 P!F P Notes: OA 490 520 520 520 Well 1E-104 Type Inj. W TVD 3,351' Tubing 900 900 900 900 Interval 4 P.T.D. 2042270 Type test P Test psi 1500 Casing 61 2,000 1,980 1,960 P/F P Notes: 45 Min T/I/O = 900/1960/200 OA 190 200 200 200 Well 1E-105 Type In'. N TVD 3,515' Tubing 200 200 200 200 Interval 4 P.T.D. 2050060 Type test P Test psi 1500 Casing 100 2,000 1,940 1,920 P/F P Notes: OA 100 140 140 140 TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 KRU 1E pad 062510.x1s 12/30/08 -1 `~,. ~~`~ -~ ~~~IllG~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # 2U-03 12080460 INJECTION PROFILE '~' - GZj 11/17/08 1 1 1Y-03 12096583 INJECTION PROFILE - 12/07/08 1 1 1 C-11 12114998 PRODUCTION PROFILE ~- ~ 12/14/08 1 1 i D-07 12114999 USIT ~ a 12/15/08 1 1 1 B-09 12115001 INJECTION PROFILE ~ L ~ 12/18!08 1 1 3G-26 12115002 WEATHERFORD WRP/SBHP 12/19/08 1 1 1C-18 12100472 INJECTION PROFILE (' 12/21/08 1 1 1 E-21 12115005 INJECTION PROFILE 12/22/08 1 1 2C-02 12100475 INJECTION PROFILE („) 3 12/24/08 1 1 I t, ~,.b tip, J~~r . Log Description N0.5024 Company: Alaska'Oif &'Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg Ke4ä' bIt:¡ loç, P.I. Supervisor ( I DATE: Wednesday, June 07, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHlLLIPS ALASKA mc lE-21 KUPARUK RIV UNIT 1E-2J ooô- \ Cô 1/' FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ..:lISP Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT lE-2I API Well Number 50-029-20892-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060605140823 Permit Number: 183-002-0 Inspection Date: 6/4/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 1E-21 , , I , I Well ¡Type Inj. I W I TVD 5943 IA 1175 2380 I 2320 2310 I I ~- I P.T. 1830020 ITypeTest . SPT ! Test psi 1500 OA I 200 240 ! 240 240 I I I ! Interval 4YRTST P/F P Tubing i 1700 1700 I 1700 i 1700 Notes Pretest pressures were observed and found stable~ Well demonstrated good mechanical integriy ~·t,"''''¡¡I~.rt..:r :~. .~li~-\r\~\ ~4~:'-~; i...' '., fOl ~ ( ",,' t,\ Wednesday, June 07, 2006 Page I of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 106 feet 3. Address Exploratory __ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__X Kuparuk Unit 4. LocaUon of well at surface 8. Well number 4926' FNL, 224' FEL, Sec. 16, T11N, R10E, UM (asp's 550301, 5959941) 1 E-21 At top of productive interval 9. Permit number / approval number 174' FSL, 2193' FWL, Sec. 15, T11N, R10E, UM 183-002/ At effective depth 10. APl number 50-029-20892 At total depth 11. Field / Pool 5150' FNL, 2813' FEL, Sec. 15, T11 N, R10E, UM (asp's 552992, 5959736) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 7420 feet Plugs (measured) true vertical 6565 feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 110' 16" 290 sxAS II 110' 110' SUR. CASING 2101' 10-3/4" ~2o0 sx AS ,~ & 25O sx AS ~ 2207' 2207' PROD. CASING 7262' 7" 625 sx C~ass G & 250 sxAS ~ 7368' 651 9' -:-:-:-:-:-:-:-:-:-:-:- :-:-:-:-:- :-:-:,:-:.:-:-:.:-:-:-:-: :-:: :-:-: ::::::::::::::::::::::::::::::::::::::::::::::: :.: :-:-.-: :-:.:.:..:.:.:..:..:.:.:.:.:.:.:.:_:.:.:.:.:.:.:: :< ::::::::::::::::::::::::::::::::::::::::::::: :.:<.:.:.:.:...:...:.:. ,:.:.:.. N0V 0 6 ~001 .:.:.:-:.:-:.:.:-:-:-:.:.:-:.:-: :.:-:->:.: ::::::::::::::::::::::::::::::::::::::::::::: :.:_:.:: :-:<-:-:-:-:-:-:-:-:-:-:-:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:..:.: :.:<: ::::::::::::::::::::::::::::::::::::::::::::::::::::::: :.:.:.:.:-:.:.:.....:.:...:,:... Tubing (size, grade, and measured depth) :~i:~:i!.~.i.~:~.~.i~;~.~.:.~.i.~:i~i~i~:!ii:!i!~!i!:i::!ii:ii:ii::iiiiii~!!i~;~i:~:~!:i~i~!:i~ii!~:!i!:i:~:i?i:~i!i~ii;i:i~:~::i~i::!.::.:!:.:i~.!:.~iii!. '1 Anchorage Packers & SSSV (type & measured depth) ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::;;;;,;;;,: :-: : :.::::;,;;;i: ..... '' ' ;4,;,' ' ' "' .... , " 13. Stimulation or cement squeeze summary Intervals treated (measured) . ..... -.-..-...-..-..- .-..., .... . ......... .- ....-..-..-. -..-..-. -.....- -.. .... .......-..- -..- . . .- - _ .. ::::::: :::::::::::::::::::::::: :::::::::::::: ::::::::: ::::; :.: .:::. :::: :...:.:..: : ............... :.,: ........... :........:. <......:.:..:.:..:.:..:.: Treatment description including volumes used and final pressure .......................................................................................... ' ' ' 14. Representative Daily Avera.qe Production or Injection Data OiFBbl ................................... Gas;M~. ..................... Wa~gr;Bb! ........... Ca~!ng Pressure ...... 7~ub. ing .Pressure ...... . ..... ::::::::::::::::::::::: ==================================== .... : .... :.:.: ............. :.::.:.:.: ........ :.::.. :....: ......... .......... : ..... .... ::.::..::.:. 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X :::i?iiii:.i?iiii~i;~iiiii!::!ii:::ii~i:ii~:~!iii:.iii::Gi~s::i?ii::ii:.i?ii!iiiiiii;~L¥s~n~d~:i: -- ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::-::::::-::: ::::::::::::::::::::::::::: :: ::-::-;-:-:;-;:-:;-:-;-:-;-;-;-;-'~;.;-;-;-:;-;-;-;-;-~.?:;-:-;-;-:-;-;----:-- :- . :---:;:.:;:-: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Gall Jeff Spencer 659-7226 Signed '~'-, 4 -- ~/~d-~--,~''*'~*~ Title Production Engineering Supervisor Date Jeff A. Spencer Prepared by Robert Christensen 659-7535 Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICATE 1 E-21 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary i :i:i: ~9/t4/0t commenced EOR:lnjectioni: ::: :: : ::::i:i~ : J MEMORANDUM- State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount~~ Commissioner THRU: Blair Wondzell P.I. Supervisor FROM: John Cds~' j~r~ Petroleum InspeCtOr DATE: september 11, 2000 SUBJECT: Mechanical Integrity Tests Phillips Alaska Inc. 1G Pad 04,05,06 Kuparuk River Unit Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. ' WellI 1G-04 I Type,nj.I s I T.V.D. I Tubing I 2575 I~ I~ I~ I,.te...,I 4 P.T.D.I 1821610 'lType testI P ITestpsil 1553 I CaSingl 450 117O0116751166O1 P/FI P~ Notes: ' WellI 1G-05 I Typelnj. I S I T.v.D. I 6122 I Tubingl :21'50 I 2150 I 2150 I 2150 lintel/alI 4 P.T.D.I 1830200 ITypetestl P ITestpsil 1531 I Casing'l 660 I 1575 I 1525 I i525 I PIE I P' Notes: WellI 1G,06 ITypelnj. I G I , oo'1 ~00 Ilntervall 4 P.-T.D.I 1822200 ITypetestl P .ITestp.sil 1477 I Casingl 600'I 1650 I 1620-1 1600I P/F I' P'' Notes: Well! P.T.D,I Notes: Notes: Type INJ. FlUid Codes F FRESHWATER INJ. G = GAS INJ. S = SALT WATER INJ. N -- NOT INJECTING Type Test 'M= Annulus M°nitodng P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details No failures witnessed. No problems encountered. Interval I= Initial Test 4= Four Year Cycle V= Required by Vadance W= Test dudng Workover O= Other (describe in notes) .I.T.'s Performed: 3_ Attachments: Number of Failures: 0 Total Time during tests: 1 hr. cc: MIT report form 5/12/00 L.G. MIT KRU 1G.___~9-11-00jc.xls 9/13/00 A,~o~ Oil Gas Conservation Commission 3uu I ~orcupine Drive Permit The following data is hereby acknowledged as being received: Dated: C~py sen((o sender: Yes ~ £C£11/,.. ARCO Alaska, inc. "-"' Post Office Bo~. ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 9, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in duplicate are multiple Reports of Sundry Well Operations on the following Kuparuk wells. Conversions 3N-11, 3N-10, 3N-05, 3N-04, 3F-12, 3F-03, 3F-08, 3N-03, 13, 1E-21, 1E-19, 1E-23, 1E-lA, 1E-04, 1E-16 and1E-27 Fractures and Stimulations '3K-14, 3C-16, 3K-17, 1E-14, 3N-17, 3F-16 and 2V-12 Perforations 3N-11, 3F-11 and 3N-SA Failed MIT 3N-12, 3N- I E-30 if you have any questions, please call me at 265-6840. Sincerely, G. B. Snl~llwood Senior Operations Engineer Attachments cc: J. Gruber M. L. Hago0d S. P. Twiggs KOE1.4-9 ATO 1478 ATO 1120 ATO 1130 RECEIVED NOV 1 6 1988 &la~ t~ii .& Gas C0~, ~ ..... ",~,,, ~cliQraget ':.~ .... ARCO AlasKa. Inc. is a Subsidiary ol At anticRichfieldComl3any 1. Type of Request: STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Pull tubing Alter casing Stimulate __ Plugging Repair well Pull tubing Perforate Other X 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 Location of well at surface 351' FSL, 225' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 174' FSL, 2193' FWL, Sec. 15, T11N, R10E, UM At effective depth 129' FSL, 2464' FWL, Sec. 15, T11N, R10E, UM At total depth 129' FSL, 2464' FWL, Sec. 15, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 7420' MD feet 6565' MD feet Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 2207' Intermediate Production 7 3 6 8' Liner Perforation depth: measured 7285' MD feet 6446' MD feet Conversion 6. Datum elevation (DF or KB) 106' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1E-21 9. Permit number/approval number 8-,.'.'.327 10. APl number 5o- 029-20892 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) NONE feet Size Cemented Junk (measured) NONE Measured depth .! True vertical depth 80' 80' 2207' 2207' 7368' 6519' I 6" 290 Sx ASII I 0-3/4" 1200 Sx ASIII & 250 SX ASI 7" 625 Sx Class G & 250 Bbls ASI 6850'-6948', 7101 '-7115', 7130'-7145' true vertical 6066'-6151', 6285'-6297', 6310'-6324' Tubing (size, grade, and measured depth) 3.5" , J-55 @ 7019' Packers and SSSV (type and measured depth) ?~'~'~ j~jj '& Camco TRDP-1A SSSV @ 1911', Otis RRH Packer @ 6693', Otis WD Packer @ Well 1E-21 was converted from gas injection to water injection on 6/24/88. No wireline work was required. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description includin~ volumes used and final pressure Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation S.I. 14. ...... 4513 1000 16. Status of well classification as: Oil __ Gas Suspended Subsequent to operation 15. Attachments NONE Copies of Logs and Surveys run Daily Report of Well Operations 2100 Service Water Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sr. Operations Engineer Date 1 1/01/88 SUBMIT IN DUPLICATE Form 06/15/88 ARCO Alaska, Inc. Date: May 3, 1988 Transmittal #: 7159 RETURN TO: ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1 E- 21 Kuparuk Fluid Level Report 4 - 2 1 - 8 8 Tubing AJasi(a, Uil ~ L~as Cons. If you have any questions concerning this or any other transmittals please call me at 265-6835. Receipt Acknowledged: DISTRIBUTION; D & M State of Alaska Date: Chevron Mobil SAPC Unocal STATE OF ALASKA '"". ALASK . OIL AND GAS CONSERVATION COMN,..,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator ARCO Alaska, ]:nc. 3. Address PO Box 100360, Anchorage, AK 4. Location of well at surface 99510 351' FSL, 225' FEL. Sec. 16 T11N RiOE UM At top of productive interval ' 174' FSL, 2193' FWL, Sec. 15, T11N, R10E, UN At effective depth 129' FSL, 2464' FWL, Sec.15, T11N, RIOE, UM At total depth 129' FSL, 2464' FWL, Sec. 15, T11N; RIOE? UM 11. Present well condition summary Total depth: measured 7420' [fid feet 5. Datum elevation (DF or KB) RKB 106 6. Unit or Property name Kuparuk River Unit 7. Well number 1E-21 ~A i ~'J ~ J ~,~ 8. Permit~umber Permit #83-2 true vertical 6565' TVD feet Effective depth: measured 7285' MD feet true vertical 6446' TVD feet Casing Length Size X X X If~I~gJ~I:I~LK~IX X X X X Conductor 80' Surface 2207' xxx~l~mx~l~(te Production 7368 ' xxx~Lr~Xxxxx Perforation depth: measured 9. APl number 50-- 029 -20892 10. Pool Ku~aruk River Oil Pnnl 6850' 16" i0-3/4" Plugs (measured) None Junk (measured) Cemented 290 SX ASII 1200 SX ASIII & 250 SX ASI 7" 625 SX Class G & 250 SX ASI -6948' 7101'-7115' true vertical6066,_6151, 6285'-6297' None Measured depth feet True Vertical depth 80' MD 80' TVD 2207' MD 2207' TVD 7368' MD , 7130'-7145', MD , 6310'-6324', TVD 6519' TVD -~, : Alaska., Tubing (size, grade and measured depth) 3½" ~-55 @ 7019' [fid Packers and SSSV (type and measured depth) Camco TRDP lA SSSV Fa lgll' Mn; n~i~ RRM Packer @ 6693' MD, 12.Attachments Description summary of proposal ~ Detailed operations program [] Convert well from qas injection service to water injectinn sc_rvic~. 13. Estimated date for commencing operation May, 1988 Otis WP Packer @ 698q' MD BOP sketch [] 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed j~ ~'~ .~,~ z,t,c,t,,~.,,,j,~,,~ Title Sr. Operations Engineer ~ ,~ Commission Use Only Notify commission so representative may witness Approva [] Plug integrity [] BOP Test [] Location clearanceI Approved Copy Returned Conditions of approval Commissioner ORIGINAL SIGNED 'BY LONNIE C. SMITH Approved by Date4/22/88 Form 10-403 Rev 12-1-85 INc. ~ '- 3~ 7 by order of the commission Date Submit in triplicate WELL 1E-2~ APPLICATION FOR SUNDRY APPROVAL APRIL 22,1988 1. Propose conversion from gas injection to water injection. 2. No workover or wireline work will be required so no BOP equipment or workover fluids are necessary. 3. The estimated static BHP is 3679 psi at-6200' SS based on data taken 4/20/88. Mr. C..V.' Chat*~rton . May 27, 1986 Page 2 -ATTACHMENT I.~ ,.,:.v'~ r- KUPARUK RIVER UNIT INJECTION LOGS ......... ,-, ~ ._ ~-. ~ ...... ~. ~ ..... ; .... ~INITIAL INdECTION PROFILES ...... Well Number Date of Initial Injection Date of Injection Profile 1A-7 3/21/83 3/25/83 1A-9 3/1/83 3/22/83 1A-11 3/7/83 3/21/83 1A-12 3/1/83 3/6/83 lA- 13 2/4/83 1 O/17/83 1A-!4 2/22/83 4/11/83 1A-15 3/1/83 3/18/83 1A-16 3/1/83 3/24/83 Well Number Date of Initial Injection Date of Injection Profile 1E-lA 1E-4 1E-9 1E-13 1E-14 1E-16 1E-19 1E-21 '1E-23 1E-27 . 1E-30 -_ 1 Number 1F-10 1F-11 1F-13 1F-15 Wel 5/8/83 5/17/83 4/17/83 5/19/83 2/16/83 10/4/83 2/8/83 3/7/83 2/10/83 8/2/83 2/11/83 3/15/83 4/29/83 5/1!/83 5/2/83 10/4/83 5/3/83 4/5/84 2/11/83 10/7/83 2/14/83 10/7/83 Date of Initial Injo +' _c~on Date of Injection Profile 8/13/84 10/30/84 8/12/84 9/24/84 8/16/84 9/25/84 8/16/84 9/26/84 - -Well Number Date of Initial Injection Date of Injection Profile ~ 1G-3 1G-6 1G-9 1G-i4 1G-16 10/25/85 12/20/85 7/28/84 9/23/84 9/15/84 9/23/84 8/24/84 9/22/84 8/24/84 9/22/84 ARCO Alaska, Inc. Post Office B' '00360 Anchorage, Ai~.=ka 99510-0360 Telephone 907 276 1215 December 9, 1985' Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices following wells at the Kuparuk River Field- Well Action Date Performed 1B1 Frac 11/6/85 1E8 Frac 1 2 / 6 / 85 1E-1 9 Conver s ion 1 0/1 7/85 1 E-21 Conve r s i on 8 / 1 / 85 1E-23 Convers i on 1 0/23 / 85 1G-2 Frac 1 2/6/85 1R1 Frac 11/5/85 1R2 Frac 11/5/85 1R4 Frac 11/6/85 1R6 Frac 11 / 6 / 85 1R1 3 Frac 11/1 /85 1R1 4 Frac 11 / 1 / 85 2D-5 Acidized 6/1 8/85 2D-6 Ac idi zed 6/18/85 2V5 Convers i on 7/6 / 85 on the If you have any questions, please call T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) me at 263-421 2. ARCO Alaska, Inc. is a Subsidiary' of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ulL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL i-I COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-2 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 5o- 029-20892 225' 4. Location of Well SURFACE LOCATION' 351' FSL, FEL, SEC. 16 T11N, R10E, UM BOTTOM HOLE LOCATION' 129' FSL, 2464' FWL SEC. 15, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 106' (RKB) 6. Lease Designation and Serial No. ADL 25651, ALK 469 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1E-21 11. Field and Pool KUPARUK RIVER FIELD KIJPARUK RIVER OIL POOL 12. 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). On August 1, 1985, Kuparuk well 1E-21 was converted from a water injection to a gas injection well. The "A" sand has been isolated and gas is being injected into the "C" sand only. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~.~/~.~..'~ ~C4--~_ Title KUPARIJK The space below for Commission use OPERAT IONS COORD I NATOR Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc~_~, Post Offic~ 3x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DAT~;: 09-05-85 TRANSMITTAL NO: 5332 FJ~TURN TO: TRANSMITTED tiECE I PT AND SEQUENCE OF 1H- 3 -" PBU 2A- I--- ' C ' 2B- 12:-' 'C' 2C-U 'A' 2V-2 - 'A' 2V-5 ~ 'A' ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B · P.O. BOX 100360 ANCHORAGE, AK 99510 HERL]dITH ARE THE FOLLOWING ITEMS. RETURi~ ONL SIGNED COPY EVENTS PRESSURE DATA PLEASE ACKNOWLEDGE OF THIS TRANSMITTAL. 03-07-85 SAND PBU 08-03-85 SAND PBU 08-01-85 SAND PBU 08-16-85 SAND PBU 07-27-85 SAND PBU 06-25-85 SEi'_,UENCE OF EVENTS FROM WELL lA-8"* bBHP & 1~1I$C. lA-5 PBU & MISC. lA-3-~''- PBU lA-3-'-- PSU lB-2-~ 'C' SaND PSU lB-2---- 'C' SAND PBU lB-5 ~ ~T~TIC TEMP.LOG 1E-21" RUN BHP & MISC. iF-5 "~ PBU 'A' & 'C' 1F-5 / PBU 1G-15/ 'C' SAND PBU 1G-15"- 'A' 5AND PBU 1G-15/ 'C' SAND PBU 1R-10~BHP & MISC. 1R-9./ BHP & HIbC. IR-12 ~, BHP & I~IISC. 2A-1/ 'C' SAND PBU 2A-1'/ 'A' SAND BHP 2A-l"' 'C' SAND PBU 2A-13,,- BHP & MISC. 2B-13--~ 'A' SAND 2B-13-~ 'C' SAND PBU 2B-13--' DATA FROM 2B-13--/ 'C' SAND PbU 2C-S ~ PBU 2G-16~ PBU 2G-16/ PBU RLCEIPT ACKNOWLEDGED: bAND & MISC. SURVEY BPAE B. CURRIER CHEVRON D & M DzxILLING L. JOHNi~TON NbK CLERK SERVICE 0 0 0 0 0 0 0 0 { ISLTD) O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 REPORTS/PRESSURE DATA 8-22-85 8-14-85 8-12-~5 8-11-85 8-05-85 8-06-85 ~-15-S5 ~-03-~5 ~-18-~5 8-17-85 8-10-85 8-06-85 8-09-85 8-15-~5 8-15-85 8-19-85 8-04-85 8-04-85 8-03-85 ~-25-85 8-02-85 8-02-85 8-03-85 8-01-85 8-17-85 8-17-85 8-1~-85 DI~T~iIBUTION: W. PAStiER EXXON *PLEASE NOTE--DISTRIB- UTION CONTINUED ON NEXT PAGE. ~., P~ILLIP~ OIL UNION J. ~T~,IELL K.TULIN/VAULT "::-'::.'-....~ '"- -:,~ ',:i.f,?,. :.. ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldcompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 17, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached are our notices of intention field well 2X-5 and to convert the injectors- to perforate Kuparuk following wells to 1E-lA; 1E-4; 1E-16; 1E-19', :1E-21~-~, 1E-23', 1E-27 If you have any questions, please call me at 263-4212. T. Mark Drumm Kuparuk Operations Coordinator TMD / kmc Attachment (In Triplicate) RECEIVED JUL ! 8 1985 . ~aska .0il & Gas Cons. Commission .... ---- ~. ~chorage STATE OF ALASKA ~'~'. ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ 2. Name of Operator ARCO ALASKA. I NC. 3. Address P. O. BOX 360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION: 35i' FSL, 225' FEL, SEC. 16, T11N, R10E, UM OTHER [] BOTTOM HOLE LOCATION. 129' FSL, 2464' FWL SEC. 15, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 1 06' {RKB) 12. I 6 . Lease Designation and Serial No. ADL 25651, ALK 7. Permit No. 83-2 8. APl Number s0- 029-20892 9. Unit or Lease Name KUPARUK RIVER UN I T 10. Well Number 1E-21 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL 469 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 ~ 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). it is proposed that Kuparuk well 1E-21 be converted from a water injector to a gas injection wel !. The wel I had water injection into both the "A" and "C" sands. Gas injection will be into the "C" sand only. ANT I C ! PATED START DATE- SEPTEMBER, 1985 RECEIVED ',1U L 1 $19 5 ,~ 0il & Gas 00~s. 6~,.r~ ~chorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KU PARU K /~/~"-~" ~~ Title OPERAT IONS COORD ! NATOR Signed The space below for Commission use Date 6/25/85 Conditions of Approval, if any: Approved by Approved Copy By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 °80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 'ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 17, 1985 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 1E-21 Dear Mr. Chatterton' Enclosed is a Well Completion Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU5/LI09 Enclosure If 4,?c.,2,.) ~°oe. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ..~ ALASKA - AND GAS CONSERVATION CC. MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well O~IL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ... 2. Name of Operator 71 Permit Number ARCO Alaska, Inc. ~' 83-2 3. Address 8. APi Number P. 0. Box 100:$60, Anchorage, AK 99510 50- 029-20892 4. Location of well at surface 9. Unit or Lease Name 351' FSL, 225' FEL, Sec.16, T11N, R10E, UM Kuparuk River' Unit At Top Producing Interval 10. Well Number 174' FSL, 2193' FWL, Sec.15, TllN, R10E, UM 1E-21 At Total Depth 11. Field and Pool 129' FSL, 2464' FWL, Sec.15, TllN, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk Ri ver 0i 1 Pool 106' RKB ADL 25651 ALK 469 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 01/11/83 01/17/83 01/20/83I N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey i 20. Depth where SSSV set I 21. Thickness of Permafrost 7420'MD,6565'TVD 7285'MD,6446'TVD YES I-~X NO [] 1927 feet MD 1450' (Approx) 22. Type Electric or Other Logs Run FDC/CNL/DIL/SP/GR/Cal ~ RFT, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 80' 24" 290 sx AS II 10-3/4" 45.5# J-55 Surf 2207' 13-1/2" 1200 sx AS III & 250 s: AS I 7" 26.0# J-55 Surf 7368' 8-3/4" 625 sx Class G & 250 s: AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7145' - 7130' 3-1/2" 7034' 6709' ~ 699~)' 7115' - 7101' w/4 spf, 90° phasing 6948' - 68607 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 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.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED APR l 9 1985 Alaska Oil & Gas Cons. Commission Anc,hor~pe Form 10-407 JMM/~NC48 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ . GEOUOGiCMARK'ERS -" . ' . "' ~" - :' ' ;: ...., - '~' FORM~,TION'-TESTS , '- ' ' . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 6849' 6065' N/A Base Upper Sand 6949' 6152' Top Lower Sand 7086' 6272' Base Lower Sand 7208' 6379' 31. LIST OF ATTACHMENTS Wnrl~nv~r W~I 1 Hi _~nry 32. I hereby ceEtify that the foregoing is true and correct to the best of my knowledge Signed & ~ ~ Title Associate F.§i.eer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in' other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10~107 ARCO Oil and Gas Company Well History - Initial Report- Daily Inetmctiona: Prepare and submit the "lnlllel Report" on the first Wednesday after a well is spudded or workover operations are stmled. Dally work prior to spudding should be summarized on the form giving inclusive dates only, District I County, parish or borough I State Alaska I North Slope Borough I Leaae or Unit I Title ADL 25651 I Completion Field Kuparuk River Auth. or W.O, no. AFE 304964 Alaska IWell no. 1E-g1 Nabors 1-ES API 50-029-20892 Operator -~ ARCO W.I. ARCO Alaska, Inc. Spudded or W.O. begun IDate I.our Pr or status Completion . I 2/2/85 I 1500 hrs. Complete record for each day reported Date and depth as of 8:00 a.m. 2/04/85 2/05/85 2/06/85 2/07/85 2/08/85 2/09/85 thru 2/11/85 56.24% if a W.O. 7" @ 7368' 7285' PBTD, Set BPV 10.8+ ppg NaC1/NaBr Accept rig @ 1500 hrs, 2/2/85. Pull BPV. Att to pull dummy @ lower GLM w/o success. Rn impression block. Prepare to kill well. Pmp 50 bbls 11.3 ppg BridgeSal pill, followed by 10.9 ppg brine. Circ ann to 10.8 ppg brine. 7" @ 7368' 7285' PBTD, Prep to LD hgr 10.9 ppg NaC1/NaBr NU BOPE. Fsh BPV pull'g tl, pull BPV. Shear SBR. Tst BOPE to 3500 psi. 7" @ 7368' 7285' PBTD, POH w/fsh 10.8+ ppg NaC1/NaBr Pull hgr to flr, pull 3½" tbg. RIH w/BHA, wsh over slick stick, rotate ratch latch out of pkr, CBU, POH w/fsh. 7" @ 7368' 7285' PBTD, TIH w/new mill shoe 10.8+ ppg NaCiTNaBr POH & LD fsh. -TIH w/pkr mill, spot BridgeSal pill across perfs, mill on pkr. 7" @ 7368' 7285' PBTD, Wsh to btm 10.9 ppg NaC1/NaBr Fin TIH, mill on pkr, POOH. PU Tri-State spear, TIH, spear , · pkr, POOH & LD pkr & fsh g tls. TIH w/blt/csg scrpr to 7066 found top of fill @ 7066', wsh'g to btm 7" @ 7368' ' Oska 0 7285' PBTD, Rn'g 3½" tbg 10.9 ppg NaCl/NaBr Circ hi vis pill, circ hole ~ln, POOH & LD csg scrpr/¢oot bskts. RIH w/BP, set @ 6793 ; would not tst. Lost plug on way out of hole. RIH w/RTTS & plug stinger, set @ 6745'±, POOH. ND BOP. Chg tbg spool to 5000 psi Gen III, NU BOP &tst. RIH & pull RTTS, push BP to btm, POH. RIH w/RTTS & BP. RU WL, RIH w/pkr & tailpipe assy, set @ 6984'. RIH w/3½" compl tbg. The above is _correct Signature For form preparation and ~llalributl-or~ - ' see Procedures Manual, Section 10. Drilling, Pages 86 and 87. Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District County or Parish Alaska North Slope Borough Field Lease or Unit Kuparuk River ADL 25651 Auth. or W.O. no. T t e AFE 304964 Completion Accounting cost center code State Alaska IWell no. 1E-21 Nabors 1-ES Operator JA.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Completion 2/2/85 Date and depth as of 8:00 a.m. 2/12/85 2/13/85 Complete record for each day reported Old TD New TD Released rig API 50-029-20892 I otal number of wells (active or inactive) on this, Dst center prior to plugging and I bandonment of this well our I Prior status if a W.O. 1500 hrs. J 7" @ 7368' No report available. 7" @ 7368' 7285' PBTD, RR Diesel/Crude Fin rn~g 214 jts, 3½", 9.3# 8RD EUE AB Mod CA w/SSSV @ 1927', SBR @ 6680', RRH Pkr @ 6709', 7" WD Perm Pkr @ 6999', "D" Nipple @ 7022', Shear Sub @ 7034'. ND BOPE, NU & tst tree to 5000 psi. Displ well w/30 bbls diesel, followed by 210 bbls crude oil. Set BPV. RR @ 1330 hrs, 2/12/85. Date PB Depth K nd of rg 7285' PBTD 1330 hrs. 2/12/85 Rotary Classifications(oil, gas, etc.)Oil Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production ' ~ ~_.~ Oil on test Ga~j?~[?C/~O~.CO.~.e?Wd~ Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature IDa~tt e.. J Title For form preparati~on anrd' di~t 'b ,ion-, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. Post Office Bo,, i00360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 27, 1984 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 PorcUpine Drive Anchorage, AK. 99501 SUBJECT: 1E-21 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to convert 1E-21 to a selective single completion. Since we expect to start this work on January 4, 1985, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, A ~//e~ Engineer JBK/PJA/tw SN/LO03 Enclosures 4aChora,qe C°a~i$$iort ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~' ALASKA O~L AND GAS CONSERVATION COIv, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LLx~ OTHER [] 2. Nameof Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 351' FSL, 225' FEL, Sec.16, TllN, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 106' 12. 7. Permit No. 83-2 8. APl Number 50-- 02g_?ORc~? 9. Unit or Lease Name wupa-uk R,.'ver Unit 10. Well Number 1E-21 11. Field and Pool Kuparuk River Field I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool ADL 25651 A. LK ~.69 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 Abandonmentsee 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1E-21 to a selective single completion. follows: The procedure will be as 1. Well will be killed with brine. Weight to be determined after running pressure bomb. 2. Current completion assembly will be pulled. 3. The well will be completed as a selective single and 5000# wellhead equipment will be installed. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost inte~val. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Esti mated Start: January 4, 1985 RECEIVED O EC 7 Alaska Oil & Gas Cons. O0,mmission Anchorage 14. I hereby ce, r,W~ that the foregoing is true and correct t° the best of my knowledge. Signed (///,/~,~_~¢~¢~ ~ Title Area Drillinq Engineer The space/ow ffr C~/o/~ssion se Conditions of Appro a~, if any: Approved by Form 10403 Ap~roved Copy Returned By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate Rev. 7-1-80 (PJA) SN/006 and "Subsequent Reports" in Duplicate ARCO Alaska, Inc.~.-~ Post Office x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 12/12/84 Transmittal No: 4909 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 . ~/~chorage, AK 99510 - ~ansmitted herewith are the following~ items Please acknowledge receipt and return one signed copy of this transmittal. PBU. SURVEYS - Torque Turn ~/2X-1 11/30- 12/02/84 J 1F-1 6/08 - 6/09/84 / 2Z-7 12/02 - 12/04/84 #64009 #63140 #63138 Otis %/2Z-5 11/29/84 2C-8 11/26/84 z./" 25:.-5 11/27/84' Calnco /1E-19 11/10/84 1E-21 11/10/84 /1E-23 11/11/84 /1E-27 11/11/84 /cat Receipt Acknowledged: Date: DISTRIBUTION B. Currier Drilling W. Pasher State of AK BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D & M NSK Ops. J. Ratbmeil Well Files ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 4, 1983 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached are subsequent reports of stimulations the following Kuparuk River Unit Well~s: 1E-20 1E-21 1E-22 1E-23 1E-24 1E-26 1F-7 1F-8 1G-4 1Y-14 If you h~ve any questions, please call me at Charles K. House Kuparuk Operations Coordinator CKH/kmc Attachment (In Duplicate) cc: W. Crandal 1/T. Best R. Ruedrich R. May performed on 263-4527. ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfietdCompany STATE OF ALASKA '. ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-2 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 50-029-20892 4. Location of Well SURFACE LOCATION' 351' T11N, R10E, UM FSL, 225' FEL, SEC. 16, BOTTOM HOLE LOCATION' 129' FSL, 2464' FWL SEC. 15, T11N, R10Ez UM 5. Elevation in feet (indicate KB, DF, etc.) ! 6. Lease Designation and Serial No. 106' (RKB) ~ ADL 25651, ALK 469 12. 9. Unit or Lease Name KUPARUK RIVER UNTT 10. Well Number 1E-21 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OTL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation ~1~ 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). On April 12, 1983, Kuparuk River Unit Well 1E-21 was stimulated with 12% HC1 through coiled tubing. All surface lines and BOP's were pressure tested to 4000 psig. The maximum coiled tubing pressure observed was 3100 psig and the maximum wellhead pressure was 1500 psig. Diesel was used to displace the acid. Nitrogen was injected via the coiled tubing and circulated intermittently with diesel to aid in cleanup. Following the cleanup period, the well was switched to the CPF. TOTAL AMOUNT 'USED' Acid 119 BBLS Nitrogen 2526 GALS Diesel 82 BBLS 14. I hereby cer_tify,~that the~oregoing js tru,e and correct to the best of my knowledge. Signed . ¢ · . - __ Title KUPARUK ' The spacet'6"~elow for Commission use OPERAT IONS COORD I NATOR Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate PRODUCTION (IN3ECTION) TEST DATA TEST SUMMARY ~ELL TYPE: Old New Producer Injector PERF TYPE: INTERVALS: PF' ! TEST SUI,¢HARY AVERAGE P~ (IN3ECTION) RATE DURING TEST: AVERAGE GOR: - AVERAGE ~OR: CUe~LATIVE PRODUCTION (IN3ECTION) DURIN~ TEST: BBL WHP /~o 0 PS! WHT '~ °F 'CHOKE /64" API GRAVITY 'AP! AT 60° FFBHP PSI SIBHP PSI HP AT ' PJ) : ' SS TOTAL P-~ (IN3ECTION) TIHE: HRS TOTAL SHUT IN TIHE: /~. HRS DATE HA3OR WELL EVENT HISTORY START END EVENT CUMULATIVE P~q~N (]N3ECT]DN): TOTAL P~(IN3ECTION) TIME: III+= SINCE LAST HABDR SHUT IN: · , // DAYS ?/ DAYS OPERATION: TTt, E EVENT KUPARUK RIVER UNIT SEQUENCE: OF EVENTS ~,~' 35' b ~ v..o._w,. L c !b'.3O -. KUP,'-NRI. JK El'.r-__, 1NEERI I".:G TRAN_SM i 3-FAL ~~ D. ~¥. Bose/Shelby J. FMtthews ' Transmitted herewith are the fol Ic~¢¢incj- PLEASE ~)11E: BL- BLUELINE, S- SEPIA, F- FILM, T- TAPE, f. F___ - -~ t .~;q'"AC,KND,'¢! Fq'U, ED: - d/~_F_..ASE R.EiUF'J'4 RECE ! PT TO: ARO3 ~l~, INC. ATIN: SHELBY J. IVA-FI}iE~;S - ATO/111 5-B P. O. BOX 100360 ANg~CGE, Al(. 9 9.510 ARCO Alaska, Inc. Post Office E,~.. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 11, 1983 Chat Chatterton State of Alaska Oil and Gas Conservation Commission 3'001 Porcupine Drive Anchorage, AK 99504 Dear Chat' Attached are notices of our intent to stimulate Kuparuk Unit Wells 1E-19, 1E-21, and 1E-23 with acid via coiled tubing. If you have any questions, please call me at 265-4527. Kuparuk Operations Coordinator CKH/kjc EnclosuFe xc' H. C. Vickers - AFA 326 R. A. Ruedrich - ANO 332 RECEIVED APR ~ i ,~,~,..~ Alaska Oit & Gas Cons, Commis~ior, Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany · STATE OF ALASKA P F £ ~. 'ALASK~!L AND GAS CONSERVATION C~--'~A MIS'S'I'ON I V ~ ~ 'SUNDRY NOTICES AND REPORT oN,WELLS ' "'~' ' !5'JO 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator ARCO ALASKA~ INC. 3. Address P. o. BOX 360t ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 351' FSL, 225' FEL, SEC. TllN, R-iOE, UN 16, BOTTOM HOLE LOCATION' 129' FSL, 2464' FWL, 7. Permit No. 83-2 8. APl Number so- 029-20892 9. Unit or Lease Name KUPARUK RIVER UN. TT 10. Well Number 1E-21 ' 11. Field and Pool KUPARUK RIVER FIELD SEC. 1~, Tl lN, R-10.E, UM 5. Elevation in feet (indicate KB, DF, etc.) / 6. Lease Designation and Serial No. KUPARUK R I VER 0 1 L · 106' (RKB) ADI. 256~! Al K 469 PC)OL 12. 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 I--] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~ Abandon [] Stimulation [] Abandonment [] Repair Well D Change Plans [] Repairs Made [] Other [] Pull Tubing ' [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with asubmitted Form 10-407 tor each comp:!etion.) 13. Describe Proposed or Completed Operations- (Clearly state ail 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 'acidize Kuparuk River Unit Well 1E-21 through coiled tubing to improve the well's productivity. The initial production test on this well indicated a high skin factor and a corresponding low flow efficiency. Other Kuparuk wells With similar characteristics have shown marked improvements following acid treatments. The treatment will consist of 5000 gals of 12% HC1 with mud and silt remover additives. The coiled tubing unit BOP's will be pressure tested to 4000 psig. The end of the coiled tubing will be positioned initially just below the lowermost perforations and then pulled up across the perforations as the acid is pumped. Pump pressure will be limited to 4000 psig and the tubing pressure will be limited to 1500 psig. Following the acid treatment, nitrogen will be injected through the coiled tubing and aid the cleanup. During cleanup the well will be p'roduced to tanks on location. Following the cleanup the well will be produced to CPF1. Expected start date' 4/12/83 Subsequent x..ym'k I~¢Porte':l 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KUPARUK Signed ~/~..~..~'--/~ ~__.~"./~.~ _Tit,e 0 P E R A T I 0 hi S The space below f,e'r Commission u~-~' cOORDINATOR Date ~//~///~'~ . Conditions of Approval, if any:' Approved by Form 10-403 Rev. 7~! .80 Approved Copy Returned By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ~-'~ Post Office Bc,...~60 Anchorage, Alaska 99510 Telephone. 907 277 5637 March 15, 1983 Mr. C. V. Chatterton Commissioner State of A16ska Alaska Oil & Gas 'Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton-- Enclosed are monthly reports for February on these drill sites' 1-25 1E-18 7-20 1E-19 7-21 1G-5 12-15 1G-6 12-16 1Y-12 12-17 1Y-13 13-2A 1Y-14 15-3 1Y-15 CIRI Wolf Lake Well #1 Ravik State #1 Also enClosed are well cOmpletion reports for: 1~24 1E-21 2-8. 1E-22 7-18 1F-1 7-19 1G-7 12-18 WSW-IO 13-9 .WSW-11 1E-20 Tract Well 24-11-14 We also are including subsequent Sundry Reports l~or 2-8, 7-18, 12-18, and 13-9. -- ARCO Alaska, Inc. is a subsidiary of AllanlicRi~hfieldCompany "~'~ .- STATE OF ALASKA ',~ '~-. ALASKA"..~:AND GAS CONSERVATION C6: :vllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-2 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20892 4. Location of well at surface 9. Unit or Lease Name 351' FSL, 225' FEL, Sec. 16, TllN, R10E, UM .LOCATIONS Kuparuk River Unit At Top Producing Interval~' VERiFiED ] 10. Well Number 174' FSL, 2193' FWL, Sec. 15, T11N, R10E, UM :Surf.~---- 1E-21 At Total Depth ~B. H. ~i 11. Field and Pool 129' FSL, 2464' FWL, Sec. 15, T11N, R10E, UM --"---'----- Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 106' RKB ADL 25651 ALK 469 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 01/11/83 01/17/83 01/20/83I N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I 21.Thickness of Permafrost 7420'MD,6565'TVD 7285'MD,6446'TVD YES FX1 NO [] 1881 feet MD 1450' (Approx) 22. Type Electric or Other Logs Run FDC/CNL/DIL/SP/GR/Cal , RFT, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 80' 24" 290 sx AS I I 10-3/4" 45.5# K-55 Surf 2207' 13-1/2" 1200 sx AS III & 250 sx ~5 I 7" 26.0# K-55 Surf 7368' 8-3/4" 62____~5 sx Class G & 250 sx ~,S I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number} SIZE DEPTH SET (MD) PACKER SET (MD) 7145 ' -7130' 3-1/2" 6775' 6740 ' 7115'-7101' 4 spf, 90° phasing 6948'-6860' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL - GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED ; OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. MAR .! 5 Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand 6849' 6949' 7086' 7208' 6065' 6152' 6272' 6379' N/A 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 Show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". 1E-21 Drilling History NU Hydril & diverter. Spudded well @ 0700 hrs, 01/11/83. Drld 13-1/2" hole to 2220'. Ran 53 jts 10-3/4", 45.5#/ft, K-55, BTC, csg w/shoe @ 2207'. Cmtd 10-3/4" csg w/1200 sx AS III & 250 sx AS I. Pumped 75 sx AS I top job. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW. Drld 8-3/4" hole to 7420' TD (01/17/83). Ran FDC/CNL/DIL/SP/GR/Cal. Ran RFT. Ran 186 jts 7", 26.0#/ft, K-55, BTC csg w/shoe @ 7368'. Cmtd 7" csg w/250 sx Class G and 375 sx Class G extended. Instld 7" packoff & tstd to 3000 psi - ok. Ran Gyro. Arctic packed 7" x 10-3/4" ann. Ran CBL f/7268'-2000'. Perf'd the following intervals w/4 spf, 90° phasing: 7145'-7130' 7115'-7101' 6948'-6918' 6918' -6888' 6880' '6860' Ran 3-1/2" completion assy w/tail @ 6775', pkr @ 6740', & SSSV @ 1881'. Tstd packoff to 3000 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Secured well & released rig @ 2315 hrs, 01/20/83. JG'sm 02/02/83 GRU2/DH1 0 RCO ALASKA~ INC YROSCOPIO, DIRECTIONAL SURVE'i' ADIUS OF CURVATURE HETHOD OF COHPUTATIOH URYEY ,RAN BY CHAPPELL OHPUTED FOR SD I BY OCEANTECH(Ft,1 L IN£,..E~ RECOR'D OF SURVEY 0 JOB HO !.3'48 KUPARUK E-2! KB ELEV 106,00 FT, SURVP_~ DATE OI / 19/e3 PROP'~ED D IR $85-36E T R U E EAS, ,DRIFT VERTICAL SUB DRIFT TOTAL COORDINRTE~i C L 0 S U R E $ EPTH ANGLE DEPTH "' SEA DIREC .~ D I STANCE AH(~LE D .H , . DEG, D H .S . 0 0 0 . ,00 -106.00 N .OOE .00 S ,80 W ,O0 S 90 0'. 0 W 100 0 11 100,00 -6.00 N79,45E .03 N ,16 E ,!6 N 79 27 O E 2.00 0 14 200,00 94,00 N ~,37W ,29 N ,37 E ,47 N 51 51 13 E 3.00 0 31 300,00 .194,00 S 6,~5W ,~ N ' ,.07 W ,31 N .~2 4 57 W 50.8 0.44 499,99 393,99 S74.52E , "'J,~~ 1,11 H 6e 11 47 E 708 ,0 12 699,97 593,97 N32.63E' ;2'~ J ' titic ' 800 .0 3.0 799 96 693 96 S60.O3E .. '~~.. ~ill,"'g 3,85 N. 86 6 3, E , , ~ , 4,40 N 84 52 50 E 9:0'0 0 1R 899,96 793'; 96 Sl 9,90E ,u~~,l~~.~'tjc)ilfil4,77 S 89 12 18 E lO00 0 18 9~9,96 893,96 S42,52E ,4~.'S ~4;99 E 5,01 S 84 59 48 E 11.08 0 4 1099,96 993,96 S82,68W .... 68 S 4 90 E 4 95 S 82. ~:, 19 E .12.00 0 25 1199,96' 1093.96 S48,4~E 1;00 $ 4,7~ E 4,8~ $ 7e ~ 2S E 130'0 0,47 1299,95 .1193,95' S 1,20E 1,96 S ', 5,14 E 5,50 S 69 .6 35 E 14.00 0 13 1399,95 1293,95 S33,52~ 2,79 $ 4,90 E 5,64 S 60 22 35 E 158:0 O 44 1499,95 ,1393,95 SI9,07W (3,53 S 4,54 E 5,75 S 52 7 1.3 'E 16 00 0 37 1599,94 1493,94 S41 , 13W 4,54 S 3,95 E 6,02 S 41 0 33 E 170.0 '028 1699,~3 1593,93 S ,93~ 5,~1 ~ . 3,62 E 6,51 S 33 47 7 E 180.0 0 19 1799,93 1693,'93 S68,32~. 5,94 S 3,25 E 6,77 S 2e 42 12 E 1900 0 q4 1~99,93 1'793,93 S53.93W 6,3~ S 2,45 E 6,83 S 21 .1 ~ E 200:0 I 3 , 1999,92 1'~93,92 S 6,95E 7,74 S I,~6 E 7,96 S 13 30 2S E 2100 8 41 2099,90 1993.90 S31,5~W 9,19 S 1,54 E. 9,32 S 9 31 45 E 2200 I 20 2199,69 2093,~9 S12,27W 10,~1 S. ,~9 E .10,~5 S 4 ~1 52 E 23:00 O ~t 2299,e7 2193,~7 S57.4C~E 12,34 S 1,52 E 12,43'S 7 2 27 E . 0 DOG L. EC SEVERITY DEG/10 OFT 000 183 05 0 2':,94 3F; 0 ...,67 550 083 300 300 100 c..-', .5 367 567' ,117 150 ,150 ,~17 .~17 .367 :.~Et;T I ON D ! S T ANCE .0 O .i5 ,34 -.09 ' ,33 t,oo 2,71 3,;91 4 .33 4 '7 ~ 5 01 4, ~ .} .:~ 431 4 05 '2 97 '-' 2 ;:29 :2 54 0 CO KUPARUK E-21 SURFACE LOCATION , GYROSCOPIC SURVEY JOB NO . 134.8 35i '14Sk'/225'WEL,SEC, 16,'T11. It',RI OE SURVEYED- 19 (JAN') 83. KB ELEV !06,00 FT, RS ,' DRIFT P TH i:I14GLE D H '.4'00 4 e :50.0 ? 42 ~600 !I 40 :?00 '14 19 !800 17 44 !900 2.0 23 ~OOO 24 4. IlO'O 2,7 15 120'O 30. 2.0 t300 33 8 tI40'O. 36 21' 150.'0 38 59 3600 40 47 ~7..00 41 4! ~800 41 24 ~goo 41 55 s, O00 41 1 6 ~,1.00 41 37 t2iO0' 41 26 430O 41:38 ~4'.00 41 '2 45.00 41. 15 4600 40:39 4700 40 38 4800 40 .7 49'00 40 2'0 5000 39 31' 51 O0 39 2 :TRUE' "~' VERTICAL ~UB DEPTH. ~'~ ' ~ "~,,.',,) · ':( . 2499,22 '~.393 .. 22'. RECORD'. OF SURVEY DRIFT "DIREC N66.0SE N62,20E 2597,77 ,: :249 I', 77 "' 14.7 O, I OE 2695,., 2 ! 25819,21 N82o 12E "":" ,! ..~.TE.S. ':..TOTAL COORP ~ - · s :, -'5,55 E :"" ' 8o 15 $ ::(......, ,,!4',82 [ ! ~35 $ .... ,",,;.,30',19 ',4..,O3 ", 9,7 E ,;,.., 2791', '3..I ',';', a685';31 2005., O 1 27?9, e 1 297,8,35 2~72.~'.35 3068,48 ~962 ,'48 3~56,!1 305'0;t~ 3241~15..~!35, 3323,31 32t7,31' · 3402,46 3296,46' 3479,.19 3373;1~ 3554,40 448,40 ' 3629,2q 3523.24 3703.95 3597'. 95 3778,74 3672.74 3853~7i 3747.7l 3928.57 3822.57 4003.43 3897'. 4~ 4078.52 3972.52 4i53.83 4:~47.e3 4229.. 35 4.123 ~ 35 4305,23 4199.23 4381.42 4275.42 4457.77 4351.77 4534,45 4428.45 461'1,87 4505.87' N86,78E NO5.48E. 1483,27E ". N86.52E 'N87,75E t.189,98E S89.42E N88 ,e2E S88 .'73E 887.83E 886,77E 887.03E 885.85E 806,25E S~5.57E SeD.28E SS4.73E S85. t 2E 885.02E S85.17E S84.40E 884,38E 884,37E 884.0SE 6.70 N' '.~:: . 79 ,' 43 E · 8,91 t4 '""i".1.',J2.;'04 E t,'49 ;70 E .... CL, OSURES DISTANCE ANGLE O H 17,93. N" 14;81 N '607,80 E 11,22 N 674,17 E 7.10 H 740.43 E 2,54 N :, 8'06,46 E--"" 2,19 'S 7.4e' s 13.23 8 19,05 S 24.69 S 30,26 s 36,15 S 42,46 8 48,75 S 13,01 S '23 41 13 E 16,9! S 6.1 11 41 E 30,22 S 87 25 52 E 52, !3 N 85 33, 46 E 79.72 N 85 10' 39 E 112,39 H 85 27 19 E -, t50,23 N 85 lO ,59 E :.'.:'.'.Y!"92,'81 E 193152 N 85 7 5 .E 241 6.5 H 8~ 31 10 E ~lI~;~ ~~L4'°'~l~rqF. 294 :16 N 86 7 3 E ' 412 05N 87 13 26 E o 14' e7 !2 E ;56 E 872,58- E '938.67 E '.1.004,47 E 1070;00 E 1!35.3.0 E 1200,19 E 12154,70 E 1328,'97 E 1392.84 E 541;86 N 88 6 11 E 607,98 14 88 36 14 E 674,27 H 89 2 48.E 740,46 H 89 27 3 E 806,46 H 89 49 11 E 872,58 S 89 51 21 E 938;70 S 89 32 35 E 1004,55 S 89 14 43 E 1070,17 S 08 58 48 E 1135,57 8 88 45 15 E 1200,57 8 88 33 20 E 1265,22 S 88 21 46 E 1329.65 S 88 I0 12 E 1393.69 S 87 59 43 E .'1456,87 S 87 49 5! E 55.14 8 1455,8.2 E DOG LEG SEVERITY DEG/IOOFT · ,: 3 567 3 980 2 750 3 44,1 3,66'3 3,00':,3 2,,878 3., 224 2,725 ,984 ,546 .530 ,829 S92 351 236 6~5 066 607 217 .817 ,~99 SECTION D I STANCE 6,57 15,44 30,20 51, ,46 78.61 110.92 148,15 190 80 238 53 290 85. 3~ 7 66 408 52 472 42 5,'38. 24 604 51 67 0 96 737 32 803 50 86,9 79 9..-:',6 1 0 1002 14 1 067.93 11.'33,47 1198,60 1263,38 1327,95 1392. t2 1455,4i , © RCO KUPARUK E-2'I _~URFAC- E LOCATION ~YP, OSCOPIC SURVEY' JOB NO '41348 ~t":" SEO'016,TI IN,R10E 351..j~L, ~25~WEL, · . 0 SURVEYED- 19 ,JRN 83 KB ELE¥ 106,00 FT, E¢~8, DRIFT EPIH ANGLE D ~l~l ,, 5200 '37 54 53.00 37 21 54,00 36 47 5500 36 47 560.0 36 29 5700.0 35 5i 59'8'0 33 47 6,00'0 33".' 4 61,,0,,032 43 62,00 32 49 63.00 3'1 57 64'00 3'1 22 65.0'0 30 2:0 6600 30 l'O 62..00 29 35 6800 28 50 69:00 29 14 700,0 29 22 72:0.'0 28 34 TRUEl ' VERTICAL DEPTH I~I~COI~P'" OF SURVEY DRIFT, ".'..D'IREC DEGo. ., .,476':J,36 ' 4663,36 se2.,esE'. 4849:01 4929,25. "4823,25.'-.Se2',g7E . 5090 ;22'~ "~984,22 ~'.:"S8'I ~ 65E., 5148,64 · 882 5232., 1 O 883 S83 S83 S82 $82 .,47E ,28E ,22E ,75E ,6'2E ,23E ,53E ,92E ,30E 881, ! 3E 8.82, O2E 881, t 2E ,' 880,87E 879,73E 5254:64 5338, I 0 5506,16 5590,,'61: I l~1484 ' 61 5675' 73 ' '556'9, 73 5761,58 5655,58 5~47,96 574t,96 5934,67'"'~'.,5828 i 67 6109~39 :.6003~39 6196.,60 *.~090,60 62~4,05 : 6~78, OS 6371,83 6265,83 T~TRL' COORD[NflTES · . , 83° 86 S._."..'.:'1'697,52 E · ' 9t,34 $ '?'!~56,.72-E DISTeNCE ANGL~. o H, 2302.00 S 86 I 6 E 2351,~7o s 85 56 e E 2400'~,37 8 85 50 59 E 2448077 8 85 45 55 E 2497,5? 8 85 40 59 E 2545~92 S 85 35 37 E . 259~ ,62 S 85 29 46 E 166,68 8 : 2345,78 E 173,7l S 2394, '07 E 180,82' 8 2442,08 E 188,00 S 2490,49 E 195,59 S 2538.40 E 2103,66 $ 2585,61 E DOG,LEG SEVERITY ,.DEG?IOOFT I .165 ,578 ,579 .130 ,322 .718 1 .314 ,804 ,75'7 .351 ,170 ,900 ,592 1 , 049 ,228 .591 ,798 ,452 ,254 .702 ,278 SECTION DISTANCE 1517,59 1578,.60 1638,83 1758,27 1817,20 i874,70 1930,90 1985,94. 2040,21 2094,29 2147,81 22~0,27 2251.50 2301,81 2351,54 2~00,24 2448,68 2497,51 2545,88 2593,60 HE FOLLOWIHG IS EXTRAPOLATED TO TO 7420 28 34 ' 6565,05 :OTTOH HOLE CLOSURE FEET ~iT $ 222041 $ 85 16 .18 E 2689, ~2 E 2698,3'0 8 85 16 18 E ,000 2698,30 RCO KUPARUK E-21 · · GYROSCOPIC SURVEY JOB NO SURFACE LOCATION.' 351'I,ISL,225fWEL,.SEC.16,TI'IH,RlOE ERSURED DEPTH A, ND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH.· SURVEYED- '19 JAH 83 KB ELEY 106.00 FT, ! i I , MEASURED DEPTH 0 '2:06 3.06 4'06 506 6.06 7.06 8O6 906' ! o06 1106 1206 1 306 1406 1500 16.06 1706 1806 1,906 20.06 2106 2206 2306 2406 2507 260'8 271 I 2815 2922 3030 3142 3258 3379 3505 3635 TRUE YERT,~GRg. SUB MD-TVO .PEP, TH SEA DIFFEREHCE O6 1'00' 200 '.,606,,"' :,!: 500 ' 706.. ,: 600 '806:; 700 :','. 906., 800 ',,I';006 ~, ' .... ,:'~,',,'9 00 ,! 1 06,/:;": ::,.,'.',', ! 0 O O · 't oo 1 406':',: '" ".~ } 300 '!506:' '"'1606,. 1706. 1806; 1906, 2:006,. 21 06, 2206, 2306, 24'06'. 2506.. 2606, 2.706, 2806. 2906, 3006, 3~06, 3206° 3306. 3406, 35060 1'500 1600 i7'oo 1800 !900 2000 21 O0 ,2200' 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 0 0 0- 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2 5 9 15 24 52 72 98 0 :0 :0 0 0 0 0 2 , ' 3 4 9 12 20 26 6,43 7,85 9,25 10o95 12,38 12.45 7.72 4,4:0 6 9.54 13,99 17,58 19o72 19.75 20,01 19,33 COORDINATES . , ,00 ,07 ,35 I.II 2,83 3,86 4~43 4,77 5,01 4'o89 4,81 5,14 4/89 '4,51 3,91 3,61 3°22 2,39 1 °87 1 ,50 °86 1 °60 5.97 15,65 31 ,81 54,74 84.18 119,69 162.'25 212.66 271.06 337.89 414.47 498,93 8 N N N S H '14 8 S 8 $ $ 8 S $ 8 S 8 $ 8 8 8 S S N H H N N H H H W E W' E' E E E E E E E E E E E E E E E E E E E E E E E E E E E E E E E ). ICO KUPgiRUK E-21 GYROSCOPIC SURVEY JOB NO 11348 SURFACE LOCATIOH 351 'HSL,225~WEL,SEC,IG~TIIN,RIOE ~ASURED DEPTH AND OTHER DATA FOR EVERY EVEN lO0 FEET OF SUB SEA D~PTH, TRUE HEASURED VERTICAL SUB HD-TV[) ,VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTIOfl TOTAL COORDINATES 3769 36'06, 3500 162 33 .390.3 .3706 ,, 3600 196 34 4'036 3006° 3700 230 34 4170 .3906, .3800 26.3 4.303 4006, ~900 297 34 4436 4106, 4000 3:30 4569 4206. 4100 363- 33 . 4701 4306. 4200 395 4832 4406. 4300 426 4963 4506, 4400 457 5092 4606 4500 ,186 ~,.:,5 o~ . 5220 4706. 4600 514 5471 4906 4800 564 5~41 5206. 51 O0 635 ' 5962 5306. 5200 655 20 6.081 5406, 5300 674 6200 . 5506, 5400 693 't9 6310 5606, 5500 712 19 6435 5706, 5600 729 17 6551 5806. 5700 '745 16 6667 5906, 5800 760 6782 6006. 5900 775 15 6896 6106. 6000 790 15 7011 6206. 61 O0 804 i4 7125 6306. 6200 819 15 7239 6406. 6300 832 7353 6506. 6400 846 7420 6565. 6459 854 15,91 I1,12 5,39 ,'69 7.67 1'5,40 22.94 30,31 38,17 46,43 ~4,64 F,:':7 2 , 7 4 ~1,74 "i~i'itit 1,011 , 118.8o 126,47 134.29 141,73 1,4:3 87 15'5 47 164 47 172 36 197 53 206 9~ 216 68 222 4 i :se?,2o E 676 .' 00 E 764° JO E $52,67 E 940,94 E 1 o28,35 E 1115,26 E ! 200.84 E %285,37 E 1:369.36 E 145t. 07 E 1529.83 E 1605,87 E 1680,27 E 1754,15 E 1826,41 E 1895,47 E 1961 .82 E 2 026. B3 E 2153, O0 E' 221~.64 E 2272.2,1 E o'~99 ~:'9 E 2440.21 E 2495,69 E 2550,23 E 2603,91 E 2657,49 E 2689,12 E ~URVE','EC- 19 JAN K8 EL'EV 106.00 FT. 83 © RCO KUPRRUK E-21 SURF~C,E LOC~T ION HTERPOL~TE[, ',/(ql. UEo FOR EVEN TRUE MEASURED VERTICAL. DEPTH DEPI'H ,0 0 1 0,00 1000 2'000 20'00 3000 2978 4000 3779 5,000 4534 6 O00 53:~8 7000 6197 1348 i OO~.~ F'EEI" OF: I'iEH,.-,bREI.~ DEPTH, ,:, UB . SEA :i'0 T~':~L [:OORD I NATES -1 O6, 18.94 2872 4 428' 52 ,~ 2 6091 6459 7 1.2 7 48. 121 i.88 222 00 S , O0 td 44 S 4,99 E 74 S I, 86 E 61 N 149,?'0 E 1 O N 740,43 E 75 '~' o i'392,84 E 31 S 1982,69 E O0 S 2490,49 E 4.1 S 268''9, 12 E , S U R',,-' E ',' E L - I 9 J i!i H ~,> I<B ELEV i06, O0 F'T, RCO KU'PARUK E-21 GYROSCOPIC SURVEY JOB NO 1348 '3URVEYED- 19 . N 83 SURFRC.E LO£:~TIOt,I ~,~-'I ~ i ' f'tSL ,225' kiEL, 'SEC ,16 , TIIN .... RIOE KB ELEV 106 O0 FT IIITERPOL~TED TRUE './ER'rlC~L DEPTHS, [:OORDIN~iE,~. ~ND~Lu,..URES FOR GIVEN.DEPI'HS TRUE ODE I'IEASURED VERTICAL TOT~IL Ct. uRDi 7~-;.',. t,l~:tl'Es 'C L 0 $ U R E !RHE DEPTH DEP TH D I .'3 TRNCE ' ~t,IGLE b t'l S SUB , UP SAND . UP S~IND ,LO 8AI4D , LO 8~t4D 'BTD 6849 6064,84 177,28 S 6949 6152,14 i84.24 S 7"086 6271.77 i94.53 S ;;'2 08 6378.86 20,4,35 S '"'285 6446,48 2! O, 9i S 7420 6565,05 222.4i S 2417,51 E 2424,.00 S 85 2531,76 E 2539,22 S 85 589,37 E 2597 42 8 85 2625.6.:0 E 2634.0~ S 85 2689.12 E ~698,30 $ 85 43 36 E' 29 I5 E ~4 26 E 5958,84 6'046,14 6,165,77 6272,86' 6340,48 6459,'05 , : i. : i Suggested form to be inserted in each "Active" well· folder to d~.eck for timely Compliance with our regulations. . Operator,- mi1 Nam~ and NUmbe~ -. Reports and Materials to be received by: ~ ~- t? Date Required Date Received .R.emarks -- Ccmpletion Report Yes :.; ' ._/ Wel 1 History' Yes · _ ...... ::," A,:-: :: .. Z.:'. 7"-~. _Samples did ./>'O--P. / - - ' · -- , ,, Core Ch±~s .: :..., .. ~, , . - , ? ~ ,, Core Desc~±~tio~ . yF?. / ~ : .... Registered ~ey Plat .: Inclina~on S~ey . - ........................ ~., · .: ._--3 ....... ~ :. ,. :>~,- .. D~e~ional ~ey Drill St~ Test Re~s x~'~.:: ~u~on T~t Re~s , ~ } · ? ~..-~ -- ~ · / ~-.~ .' ~s R~. Yes ~-~.? . , ,, Transmitted herewith are the follc~ing: PI.WASE NOTE:~~F - FII~I, T - TAPE, PC-PHOTOCOPY F~:c//C h{ L / / 19R3, c, ~a~ boris. Commission Anchorage AR00 ~, INC. ATi~: ~ - AFA/311 P. O. BOX 360 ~ORAGE, AK. 99510- Transmitted herewith are the follc~ing: PLF3~E NOTE: BL - BI/3ELINE, $ - SEPIA, F - FInal, T ~ TAPE, PC - PH~PY P. O. BOX. 360 ~/, Qo~o;~s~on ANCHORAGE, AK. 99510- ~'/~ Anchorago TO: William VanAlen FRCM: ~. o. ~ox.~6o ~/, ANC~DRAG~, AK. '99510 o. ,. Transmitted herewith are the following: TAPE, PC - PHOTOfX)PY ~ AR-~O Alaska, Inc./~''' Post Office E ,x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 10, 1983 Mr. C. V. Chatterton Commi ss i oner 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 January on these drill sites' 1-24 1E-20 7-18 1E-21 7-19 1E-22 7-20 1F-1 12-17 1G-6 12-18 1G-7 13-9 1Y-13 13-98 WSW-IO WSW-11 Tract Well 24-11-14 CIRI Wolf Lake Well #1 Ravik State #1 Also enclosed are-well completion reports for: 2-11 1E-23 7-17 1F-2 12-19 1F-3 13-1.1 1G-8 13-21 WSW-8 13-24 WSW-9 · The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including subsequent Sundry Reports for 1-24A, 2-11, 13-21 (3 reports), and 13-24. ARCO Alaska, Inc. is a subsidiary of AtlanticRichfietdCompany ~-~. STATE OF ALASKA 'ALASKA L. _ AND GAS CONSERVATION CO"~X/IlSSION MONTHLY REPORT OF DRILLING AND WORI OVER OPERATIONS 1. Drilling well j~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-2 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50- 029-20892 4. Location of Well atsurface 351~ FSL, 225' FEL, Sec. 16, T11N, R10E, UN 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' RKBI ADL 25651 ALK 469 For the Month of January ,19 83 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1E-21 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0700 hrs, 01/11/83. Drld 13-1/2" hole to 2220'; ran, cmtd & tstd 10-3/4" csg. Drld 8-3/4" hole to 7420'; ran logs. Ran, cmtd, & tstd 7" csg. Ran Gyro & CBL. Perforated the well. Ran 3-1/2" completion assy. Secured well & released rig @ 2315 hrs, 01/20/83. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests :. 10-3/4" 45 5#/ft, K-55, BTC csg w/shoe ~ 2207' Cmtd w/1200 sx AS 7" 26 0#/ft, K-55, BTC csg w/shoe ~ 7368' Cmtd w/625 sx Class G III & 250 sx AS I. SEE DRILLING HISTORY 14. Coring resume and brief description ., None 15. Logs run and depth where run FDC/CNL/DIL/SP/GR/Cal RFT CBL f/7268'-2000' 16. DST data, perforating data, shows of H2S, miscellaneous data 7145' -7130' 7115'-7101 ' 6948' -6918' 6918'-6888' 6880' -6860' 4 spf, 90° phasing Oil ~: Gas Cons. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED f/~.~/J. ~/~~ TITLE ............... DATE -~ with the A'laska Oil and G~ Conservat~n Commission by ~t)~t~e succeeding month, unless otherwise directed. Form 10~04 Submit in duplicate 1E-21 Drilling History NU Hydril & diverter. Spudded well @ 0700 hrs, 01/11/83. Drld 13-1/2" hole to 2220'. Ran 53 jts 10-3/4", 45.5#/ft, K-55, BTC, csg w/shoe @ 2207'. Cmtd 10-3/4" csg w/1200 sx AS III & 250 sx AS I. Pumped 75 sx AS I top job. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW. Drld 8-3/4" hole to 7420' TD (01/17/83). Ran FDC/CNL/DIL/SP/GR/Cal. Ran RFT. Ran 186 jts 7", 26.0#/ft, K-55, BTC csg w/shoe @ 7368'. Cmtd 7" csg w/250 sx Class G and 375 sx Class G extended. Instld 7" packoff & tstd to 3000 psi - ok. Ran Gyro. Arctic packed 7" x 10-3/4" ann. Ran CBL f/7268'-2000'. Perf'd the following intervals w/4 spf, 90° phasing: 7145'-7130' 7115'-7101' 6948'-6918' 6918'-6888' 6880'-6860' Ran 3-1/2" completion assy w/tail @ 6775', pkr @ 6740', & SSSV @ 1881'. Tstd packoff to 3000 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Secured well & released rig @ 2315 hrs, 01/20/83. JG:sm 02/02/83 GRU2/DH1 Al~sk3 0it,~:" Gas Cons. Cornrnissio,~,. Anci~orago MEMORANDUM of Alaska OIL AND GAS COMSERVATION COMMISSION DATE: ALA S~.A~; ~ Cha~ Thru: Lonnie C. Smith Commissioner /~ ~ ~ FmOM: Ben LeNorman Petroleum Inspector FILE NO: TELEPHONE NO: SUBJECT: January 19, 1983 108/R Witness BOPE Test on ARCO's Kuparuk 1E-21 Sec. 16, TllN, RIOE, UM Kuparuk River Unit ~Mo~d.a..y.,' .~a.nuary !O, _1983- I departed my home at 12:20 p.m. for a 12:50 porn. showup and 1:50 p.m. departure via Alaska Airlines flight #61 for Deadhorse arriving at 3:30 p°m. Weather: -22°F, clear, light wind. BOPE tests on $ohio's H-19 completed, the subject of a separate report. Tuesday, Janua_ry 11, 1983- Standing by on Sohio's R-IIo W_ednes.daY, January..!2~, 1983- BOPE tests on Sohio's R-11 completed, the subject of a separate report° BOPE tests on ARCO's Kuparuk 1E-21 began at 10:10 porn. and were completed at 11:10 p°m° BOPE inspection report is attached. Thursday, Janua_ry' 13, 1983 - Standing by on ARCO's Kuparuk IF-Io Friday, January 14, 1983- BOPE tests on ARCO's Kuparuk 1F-t completed, the subject of a Separate report. I departed Deadhorse via Alaska Airlines flight f~56 at 4:10 p.m. arriving in Anchorage at 5:50 pomo and at my home at 6:20 In summary, I witnessed successful BOPE tests on Sohio's R-II. Note: Company man advised inside B.O°Po and floor ball valve will be tested on all future tests. 4/8i STATE OF ALASKA ALASKA OIL & GAS CONSERVATION CCMMISSION B .0. P.E. Inspection Report Operator. /~ ~ Representative Well ./~'c' F'~,~;-..'~ o ,e~ /~'~/ Permit # ;F3- Location: Sec /~ T//~/R/~-M U~ /~ ~//4~asing Set Prillinq COntractor ~ ~,~J Rig ~ ~/ Representative Location, Genera] Well Sign Ceneral Housekeeping Reserve pit Rig BOPE Stack Test Pressure ACCUML~ATOR SYSTEM Full Charge Pressure ~ ~;~--o psig Pressure After Closure /~ psig Pump incr. clos. pres. 200 psig, 'min~.sec. Full Charge Pressure Attained: :k min~_sec. !Controls: Master ~ /~ Remote 0/~_ Blinds switch cover ~----_~ _' · Kelly and Floor Safety Valves - Annular Preventer Pipe Rams Blind Rams Choke Line Valves Upper Kelly Test Pressure Lower Kelly Test Pres sure Ball Type . Test Pressure Inside BOP 0//-~ Test Pressure H.C.R. Valve Kil 1 r,~ ne Valves Check Valve Choke Manifold Test Pressure No. valves.__ N©. flanges. Hydrauically operated choke Test Results: Failures. Test Time' ./ . hrs.. Repair or Replacement of failed equipment to-be made within. days and Inspector/q ~nm~ssion office notified. Remarks: ~_r~ ~-~ ~ -- Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector~ January 6,' 1983 Hr. Jeffrey B. F:ewin Senior Dritling Engineer A~CO Alaska, Inc. P. O. Box 36{) Anchorage, &laska 99516 Re: ~:uparuk River Unit !E-"I,~ ARQ Alaska, Inc. ' See. 16, TI1}t, R10E, UM. Sur. Loc. 35t'FSL, 225'F~L, . "644'FEL Sec. 15, TI1N, H10E, ~. Btm~ole Loc. 131'FSL, ~ . Dear Mr. gewin: Enclosed is the approved application for permit to drill the above referenced well. tf coring ia conducted, a one cubic inch chip frc~ rack, foot of recovered core is required. Sample~ of well cutting~s and a nmd log are not required. A continuous directional survey is required as per 2{) &AC 25.050(b)(5). If available, a taF~e containing the digitized log information shall be submitted on al! logs for ¢~pying except e}:peri~ental logs, velocity surveys and dipv~eter surveys. ~any rivers in Alaska and their drainage systems have been classified aa i~portant f~r the sPa~ming or migration of anadromous fish. ©perationa in lhe~e areas are ~u~jeet to A~= 16.0~.~7a and the regu!ation~ promulgated thereunder ~oae). Prior to co~nencing (Title 5, Alaska Administrative ~ ' ~perations you may be contac!ed by the Habitat Coordinator's ~,~=rtment of Fish and Came. · Pollution of any waters of the State is prohibited by AS e- there~mder Chanter 3, artieie ? and the regulations nre~ulgat~' (Title !~, Alaska Ad~ini~trative Code, Chapter 79) and by the Federal Water Pollution ~ontroI Act, a~ amended Prior to e~ncing operations you. may be eontacte~i by a representative of the Depart~:~ent of EnviroP~entaI Conservation. Te~ aid u~ in ~che~uiing field' wor}~-, please notify this office 24 hours prior to co~mencing installation of the }~.lowout ~r. Jeffrey B. Kewin ~uparuk RiVer Unit 1E-21 -2- January 6, 1983 prevention equipn~ent so that a representative of the Coraraission may be present to witness testing of the equipment before the surface casing shoe is drilled. V~ere a diverter system is reqUired, please also notify this office 24 hours prior to ¢~ncing equipment installation so that the Coramtssion may witness testing before drilling below the shoe of the conductor pipe. . In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Ve~ry~ tru!y yours, . Alaska Oil and Ga~ ~nservatlon Comtssion Eno 1 o sure cc: Department of Fish ~ Came, ~abitat Section w/o enel Depart~nt of Environmental -Conservation w/o encl. CVC:be ARCO Alaska, Inc. Post Office E. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 28, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1E-21 Dear Mr. Chatterton' Enclosed are' o An application for Permit to Drill Kuparuk 1E-21, along with a $100 application fee. o A diagram showing the proposed horizontal and vertical projections of 'the. wellbore. o A proximity map .... - o A well crossing analysis. o A diagram and description of th·e surface hole diverter system. o A diagram and description of the BOP equipment. Since we estimate spudding this well on January 10, 1983, your prompt approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, JBK/JG-sm Enclosures GRU1/L19 ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany /-"-' STATE OF ALASKA ~'"- ALASKA ,.~IL AND GAS CONSERVATION C~JMMISSION I ERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENTOILI~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 351' FSL, 225' FEL, Sec. 1G, T11N, RIOE, UN JANo At top of proposed producing interval 150' FSL, 2890' FEL, Sec. 15, T11N, RIOE, UN At total depth Anchorage Commissiot 131' FSL, 2644' FEL, Sec. 15, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF etc.) PAD 72', RKB 106' 6. Lease designation and serial no. ADL 25651 ALK 469 9. Unit or lease name Kuparuk River Unit 10. Well number 1E-21 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500~000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed ~ 30 Miles NW of Deadhorse miles 2644' FEL ~ TD feet 1E-2~Nell 60'± ~ 500 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date i 7496' MD, 6537' TVD feet 2560 01/10/83 ' 19. If deviated (see 20AAC25.050) 120. Anticipated pressures 2576 psig@ 80°F Surface ', KICK OFF POINT 2300 feet. MAXIMUM HOLE ANGLE 39 oI (see 20 AAC 25.035 (c) (2) 2924 psig@ 608! ft. TD (TVD) 21 I Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT . Hole ;~4" Casing Weight Grade 16" 65# H-40 ~13-1/2" 10-3/4" 45.5# K-55 7" i 8-3/4" 26# K-55 22. Describe proposed program: Couplingl Length Welded I 80' BTC ~' _ MD TOP TVD 35' I 35' 33' 33' I ) 31' I ~ 31' MD BOTTOM TVD 115'I 115' 2200'12200' 7496'16537' I I (include stage data) 250 cf ± 1100 sx AS III + 250 sx AS I 705 sx Class "G" ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approx. 7496' MD, (6537' 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", 5000 psi, 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 2576 psig. Pressure calculations are based on current reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. The well will be completed with 3-1/2", 9.2#, J-55 buttress tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon completion of the job. See attached well crossing analysis. 23. I hereby certi~.~at the foregoing is true and correct to the best of my knowledge SIGNED TITLE Senior Dri 11 ing Engineer The space belo~'fo~"~mr~ssion use / / DATE Samples required I Mud log required []YES [~NO I [~YES ~NO CONDITIONS OF APPROVAL Permit number ! Approval date APPF1ovED BY_~ Form 10-401 / / Directional Survey required APl number lXf] Y ES I-]NO SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE 1983 by order of the Commission GRU1/PD8 Submit in triplicate ANALYSIS OF 1E-21/1E-3 and 1E-21/1E-22 WELL CROSSINGS NOTE' Refer to the attached Proximity Maps. 1E-21/1E-3 The proposed Well 1E-21 will pass within a distance of 95' (at a measured depth of 1872' of well 1E-3. This distance was c-~6]culated using the gyro multishot data for 1E-3 and assuming that well 1E-21 will be drilled vertically to 1872' as planned. _ Well 1E-3 will have a radius of uncertainty of 54' in diameter at the depth at which the minimum distance occurs. Well 1E-21 will have a cone of uncertainty of 7~' across its major axis at the depth of inter- est. The areas of uncertainty for the two wells will, therefore, not intersect. If survey data indicates that the areas of uncertainty will overlap, the Contingency Procedures outlined below will be used. 1E-21/1E-22 The proposed well 1E-21 will pass within a distance of 60' (at a measured depth of 500') of well 1E-22. This distance was calculated assuming that both wells will be drilled vertically to 500' as planned. Both wells 1E-21 and 1E-22 will have cones of uncertainty of,2~/in diameter at the depth at which the minimum distance occurs. The ~reas of uncertainty for the two wells will, therefore, not intersect. Since the cones of uncertainty are so small, no well intersection problems are expected. Contingency Procedures If the survey data indicate that the areas of uncertainty will overlap, the following procedures will be used' 1. A deflection assembly will be run above the potential intersection to deflect the well in the appropriate direction. 2. All drilling parameters will be closely monitored until a safe crossing is made. GJL' sm 12/28/82 EDP/A RECEIVED J AN 0 19B3 Alas~ Oil & Gas Cons. Commission Anchorage 2.9 ARCO Alaska. Inc. Kuoaruk P~ro j ,e.c t date. drawn by scale: l,,_4c~, dwg. no.:N~K-~.toS.5,~, 8o0 ~ -~ ---~ ~"'"'--. ~----~-.... --.ooo~~---~--,. ~-~:oo- { ........ ~ .................. ........ {~oo-i' ............ .................... 1-3ooI'~ ........ ...... ~{' .......... 4oc -1 ...... PAD-E-; -{-WEL:L--~O-:'----21 .... ~R~'~S£1~--PROPDS~AL ......... { ...... ; ..... , ........... i .......... t ..... ~- - i ..... ~ ........... i .......... ~ .......... ! ........ ~ ............ i- .... ~ ........ ~ .... ~.__LLL_L~].LL~'~i'i'. ~.'.:~/,i ....... F ................ P ......... ~ ................. { ...... ' ........ i-. ~ ~ '- ............ ~ L : : ~ i : ' : I :~ ............~ ~.~'- --:'~ ........................... ; .... : : { ', ~ { : : ...... ~'~ ] Z--m~-T---~T~-~-T'~"-T .... ~-~-'~ ......... : ........... : ' , ................. : ~ ~ . - ; ~ / ~ ~ i ~ { : ~Om ............. ~'~ ~-: .... ~ ~"~ ....... ~ ' : I - : : I ~ ~ ~ : I Surface Diverter 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" L./ _ lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell j~ipple. 16" Conductor :RE£E VED JAN 0 0il & Gas Cons. Commis~ior; Anchorage that gas or fluid flow to surface is detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not shut in well under any. circumstances. Maintenance & Operation .~ 1. Upon initial installation close annular t preventer and verify that ball valves [ . have opened properly. I 2. Close annular preventer and blow air ~__ . through diverter lines every 12 hours. 3. Close annular preventer in the event ~t-5/8" 5000 PSI RSRRA BOP STACK" RNNULRR . PREVENTOR 9 ) BLIND 8 ) ) ~-~DRILLIN~ (. ) PIPE RRM$ ? - 4 ' · · TBG ' / I Alaska Oil & 8as Co~s, Com~issi '. 1. 16" Bradenhead 2. 16" 2000 PSI x lO" 3000 PSI casing head 3. 10" 3000 PSI tubing head 4. 10" 3000 PSI x 13-5/8" 5000 PSI adapter spool 5. 13-5/8" 5000 PSI 6. 13-5/8" 5000 PSI and kill. lines 7. 13-5/8" 5000 PSI pipe rams 8. 13-5/8" 5000 PSI blind rams 9. 13-5/8" 5000 PSI annular . pi pe rams drilling spool w/choke ACCb~,IULATOR CAPACITY TEST 1. -CHECK AND FILL ACCL~4ULATOR RESERVOIR TO PROPER LEVEL WIT~ HYDRAULIC FLUID. 2. ASSURE THAT ACCLI-[ULATOR PRESSURE IS 3000 PSI WITH 1500 PSI D~¢!'.';STREA/4 OF THE REGULATOR. 3. OBSERVE TIME I~H~( CLOSE ~J_L UNITS SIMULTA¢;E- OUSLY AND RECORD THE TIME AND PRESSURE REHAIN- ING AFTER ALL U~IITS ARE CLOSED Wiled CHARGI¢;G PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LO',;ER LIMIT IS 45 SECO:;DS CLOSI,NG TIME PJiD 1200 PSI REMAINING PRESSURE. - 13-5/8" BOP STACK TEST FILL BOP STACK ~(D M~,NIFOLD WITH ARCTIC DIESEL. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RE- TRACTED. PREDETE.~qINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCR~XS IN HEAD. CLOSE ANNULAR PREVENTER AIID CHOKES ~ID BYPASS VALVES ON MANIFOLD. TEST ALL COMPONEJ(TS TO 250 PSI AND HOLD FOR l0 MINUTES. INCREASE PRESSUP. E TO 1800 PSI AND HOLD FOR l0 MINUTES. BLEED TO ZERO PSI. OPEN ANNULAR PREV~(TER AND CLOSE TOP SET OF PIPE P~MS. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR l0 M I NUTES CLOSE VALVES. DIRECTLY UPSTREAM OF CHOKES. BLEED D(7RNSTRE~4 PRESSURE TO ZERO PSI TO TEST VALVES. TEST RDIAINING U~;TIESTED ~tANIFOLD VALVES, IF ANY,'WITH 3000 PSI UPSTREAH OF VALVE AND ZERO PSI D~XNSTP~F_AM. BLEED SYSTEM TO ZeRO~ PSI. - ' OPEN TOP SET OF PIPE RA~S ~,ND CLOSE BOTTOM SET OF PIPE R~tS. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR l0 MINUTES. BLEED TO ZERO PSI. OPEN BOTTOH SET OF PIPE RAMS. BACK OFF RUN- NING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RA~'LS AND TEST TO 3000 PSI FOR lO HINUTES. BLEED TO ZERO PSI. OPEN BLIiID RA~IS ~'(D RECOVER TEST PLUG. ,HAKE SURE MAIIIFOLD Ai(D LINES ~RE' FULL OF ARCTIC DIESEL ~-ND" ALL VALVES ARE SET IN DRILLI,';G POS I TI ON. TEST STANDPIPE VALVES TO 3000 PSI. TEST KELLY COCKS N,D" INSIDE BOP TO 3000 PSI WITH KOOi~Y" PL~.P. RECORD TEST INFO.~'~ATION G~ BLO'ROUT PREVE;(TER TEST F"oR,~i SIG,~" A~'~D SEND TO DRILLI~;G SUPER- VISOR. ' , PERFORI-1 COMPLETE BOPE TEST OhCE A WEEK A;~D FUNCTIO~ALLY OPERATE 8OPE DAILY. CHECK LIST FOR NEW WELL PERMITS' Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc thru 8) (3) Admin (9/thru 11) (4) Casg~,~..,~~ 7-~- g~ (12 thru 20) (21 thru 24) (6) Ad d: ~ -z. ~>,.>~/. le me 3. Is well located proper distance from property line ........ .......... 4. Is well located proper distance from other wells ., . .. 5. Is sufficient undedicated acreageS.available in th~ 6. Is well to be deviated and is well bore 7. Is operator the only affected party , .... .......... 8. Can permit be approved before ten-day wait ............... ' ........... 9~ 10. 11. 12. I3. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YE S NO Is the permit fee attached ...;~ ........................... ............ Is well to be located in a de. fined pool ............................. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... REMARKS Is conductor string provided .............. '. ............ , ............ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production Strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water 'zones ....... *.., ............ Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old:wellbore abandonment procedure included on 10-403 .......... ,. Is adequate well bore separation proposed .......... ' ................. Is a diverter system required ....................................... ~ Are 'necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to ~OOO psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) ...... ' ............ Additional requirements Engineering: Geology: ~ ~EW HWK ~ LC S WVA~ JKT~ HJH JAL .., ~ MTM-~__ rev: 12/06/82 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. .. iP 010 H()2 VE;RIF.[,LAt, IU.~ [.,ioiiNG PAGE ~B[.~E TYPE ;COaS PUN "" V ~U · 0 0 440 'O,OUO0 0,0000 0,0000 0,0000 0,0000 O,O000 0,0000 ATE :82/0~/0~ ;~XIMI.JM Lt!T~iGI'H :i024 * I h [;' 0 FQ ~:I A T J. [.) N tq ~; C ;) e i,,) S * * ,i~BLE IYPt!.; :'['00 0000 OUOU ,0000 O, O000 0 00 0 0 0 00:00 0 0000 0 O00O ('} 0000 0 0000 0 0000 0 O00O 0 0000 0 0000 0 0000 0 ' 0000 0,0000 0. 0000 ,O:U OU · 0 00 O: 0, OOOu o;oooo 0. () 00 0 "POl, O,i, i02 V'E:t,<I.F/,CATIC;4',,i ~,ISI"'ZI',*G PaGE 6 STATE DATA NTR~ P A G E .[ U, O R D Ei:R :05 7 3 .. ,';' 05 U : 1 h: b AP'.[ APl F'[hE t 2 / 1 3 1 5 :SI Zt., 1 1 2. I 1 4 1 1 :1 1, 4...9 :1. 49 1 i 49 I 49 1, 4 9 o O 1 191 o 0 . l ]. 1 , '13 1 o i:, ~ 29.0 0 o o 2081,4 792 · ,' ~ , . 3594,0000 ~'~,bFt:,: ::~,I',:9002 L:fl, b~ :' 1263,0000 ~:t3P -79720. 0000 ~P~., -7920,0000 PDI(.) O' 0654 PO20 152,250O 9,0000 000 0000 the i'~AME :RFT .102 ~RbiOi~, ~ : 22 ~liNOb'~ 6ff, N(;TH 1102,1 ~EVI, OOS FILE ~GT~; A I,L[J 60 ~ 7 21 ~ O~ '000 20' ~UO0 PR HORN 8,7500 1. OuO0 YE~:T -4~9. 0 12~4~ ~OhT ID bA q.'l 0 t.i t;' P D A 'I A PI [)6 3 T C 6 T~ 2 'I bi .3 'TN 5 Ta] 1 SE'CT N A 1'1 M F S ~ C~ CS 2 C83 fi T A T E ¢: O O N i' ~ 010 ~U2 VEF~,iFIL.,.,I..tt ....... !.~io.lir~t, PAGE 12 9~ t~Jb 21 O 102 w L~ 9 V () 0 1, 0 1 0 2 9~ ~I.~ O0 O !02 9 ~ i,~ 1 ~ U 0 t) 10 2 0 o 2a 255 311 12 1 '13 I~N[J t~FT ~ i) A T A · * O ,: 0 O 0 0 3292, gO00 O, 06 "19 ATE hXI~lji,~ [..,gt',{GT{"i : 102.4 REV I,{']US FlEE * I. NFuRi~'iAT£Oi'~ i;.biCOR[)5 .~,~. ICl : 'i[ {..,~ C.) L F ~ 8192 . 0000 )N A.C 2 ~ 0000 U N A b t~ ~ A b PSI (; P~S i G ~ 0,0000 u Ab ooOOA OOOl:l U t~ ~ ~ B S 0,0 O 0 0 U' N .AL S S 20 ' 0 O 00 U N ~ b P R M T U N ~ L, HO R N ut~Ab FEET LIN Ab -499 U r~ A i,, l ~ 8 4 8 I..i ~,~ A b M 0 N '1:' I 0 PAGE 10 COUNT~ · L H I F [ C A '1: .[ 0 ?'.! t, I $ T .J] ~ G P A G E 17 g'G I T O L C~I ~ ,,,., Cb h 1 C ~ D 2 C B ~, 2 B S D 3 Ct3D~ CBI, 3 ~ RT D F D t')~ V L) F P h DEl., 11.~t [" F D E: G F bb/G $ D L: G ~' D t~.; G F 440 0 0 ILl 00 0 0000 o 0'00 o 0000 O 000 0000 "ooOu u 0000 0 0000 OOOU 00 O0 ~ 0000 0000 u OUO0 0 0 0 0 0 0,0 O: 00 0. 0000 0,0000 0 * 00:0:0 0,0000 O, 0000 o, O00O 0; 0000 0, OOOO 0, O00O 0, OOO0 0, O00U O,OOO0 0,0000 0,0000 0 , ouO0 ~ r) A17A FURy, AT i 3 4 b 1 1 1 1, 4 C 0 D E 0 255 0 ,31 1 1 b , (i 6 % T Li M ATUi*! 5P~CIFICAii. b [:' 3,1. L, (; 0 2bb 0 311 1,2 IN ,lii~ 1 0 ., DATA 6 2., '/,.B 1 3 ? Pi)~() ' ,U679 WTtiO ~, ,L~ i~ !,, i"-; T ..'Y, P b: : T (J U O,O000 ~'1,92. 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