Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
185-152
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 18, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1R-15 KUPARUK RIV UNIT 1R-15 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/18/2025 1R-15 50-029-21387-00-00 185-152-0 W SPT 6318 1851520 1800 2450 2450 2450 2450 730 2030 1960 1930 REQVAR P Guy Cook 5/1/2025 MITOA to 1800 psi as per AIO 2B.088. 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 1R-15 Inspection Date: Tubing OA Packer Depth 630 700 700 700IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250430101943 BBL Pumped:0.5 BBL Returned:0.5 Friday, July 18, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 99 9 9 9 9 MITOA to 1800 psi as per AIO 2B.088 James B. Regg Digitally signed by James B. Regg Date: 2025.07.18 12:16:15 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 18, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1R-15 KUPARUK RIV UNIT 1R-15 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/18/2025 1R-15 50-029-21387-00-00 185-152-0 W SPT 6318 1851520 3000 2450 2450 2450 2450 580 870 880 880 REQVAR P Guy Cook 5/1/2025 MITIA every 2 years to maximum anticipated injection pressure as per AIO 2B.088. 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 1R-15 Inspection Date: Tubing OA Packer Depth 600 3310 3180 3120IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250502163751 BBL Pumped:1.9 BBL Returned:1.9 Friday, July 18, 2025 Page 1 of 1 99 9 9 9 9 9 9 999 9 9 9 9 9 9 9 MITIA every 2 years AIO 2B.088 James B. Regg Digitally signed by James B. Regg Date: 2025.07.18 12:13:47 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 12, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1R-15 KUPARUK RIV UNIT 1R-15 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/12/2024 1R-15 50-029-21387-00-00 185-152-0 W SPT 6318 1851520 3000 1880 1880 1880 1880 350 620 630 630 INITAL P Josh Hunt 11/3/2023 MITIA to max anticipated injection pressure per AIO 2B.088. This is a waivered well, originally from IAxOA communication. In May of 2023 the well failed a MIT IA. The tubing was recently replaced to restore the well integrity. This is the initial IA MIT. Sundry #323-402. 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 1R-15 Inspection Date: Tubing OA Packer Depth 900 3320 3210 3200IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH231103155229 BBL Pumped:1.7 BBL Returned:1.5 Friday, January 12, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 MITIA AIO 2B.088. initial IA MIT. Sundry #323-402. James B. Regg Digitally signed by James B. Regg Date: 2024.01.12 10:32:07 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 12, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1R-15 KUPARUK RIV UNIT 1R-15 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/12/2024 1R-15 50-029-21387-00-00 185-152-0 W SPT 6318 1851520 1800 1880 1880 1880 1880 280 2020 1940 1910 REQVAR P Josh Hunt 11/3/2023 This is the MITOA to 1800 psi per AIO 2B.088. The well was shut in during the normal required test date. 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 1R-15 Inspection Date: Tubing OA Packer Depth 820 910 900 900IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH231103160917 BBL Pumped:0.7 BBL Returned:0.5 Friday, January 12, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 AIO 2B.088. James B. Regg Digitally signed by James B. Regg Date: 2024.01.12 10:33:51 -09'00' 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: Diagnose Casing/Packer Leak 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 feet None feet true vertical feet 7182'feet Effective Depth measured feet 6644', 6758', 6925'feet true vertical feet 6226', 6313', 6442'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" 4-1/2" L-80 J-55 6753' 6953' 6310' 6464' Packers and SSSV (type, measured and true vertical depth)6644' 6758' 6925' 6226' 6313' 6442' 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: Kuparuk Oil Pool 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: Contact Name: Contact Email: Contact Phone: 3804' 3804' Burst Collapse Production Casing 7361' 7" 7397' 6811' 3767' 115'Conductor Surface 16" 9-5/8" 77' measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 185-152 50-029-21387-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025635 Kuparuk River Field/ Kuparuk Oil Pool KRU 1R-15 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) 0 Gas-Mcf MD 150 Size 115' 2000 15500 0 2500 1775 323-402 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A SLB Blue Max RH Baker FHL Baker DB SSSV: None Jonathan Coberly jonathan.coberly@conocophillips.com (907) 265-1013 6861-6885', 7046-7053', 7058-7098', 7164-7173' 6393-6411', 6536-6541', 6545-6576', 6628-6635' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 7420' 6833' 7075' 6558' Authorized Name and Digital Signature with Date: Authorized Title: RWO/CTD Engineer Supervisor By Grace Christianson at 4:00 pm, Nov 01, 2023 Page 1/6 1R-15 Report Printed: 10/27/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/30/2023 17:00 10/1/2023 00:00 7.0 0 MIRU, MOVE MIRU MOB P Cont. to lay mats for staging area. Stage 1R-15 wellhead equipment behind well. Back rig off 1R-19. Stage rig on mats. Hang tree in cellar and MU test spool to BOP stack. Move double mats from 1R- 19 to 1R-15. 10/1/2023 00:00 10/1/2023 04:00 4.0 0 MIRU, MOVE MOB P Continue to move rig mats from 1A-19 to 1A-15. Pull 2 1/16" gate valve w/ integral from IA on 1A-19. Pull T-Mats and Cellar pit liner from 1A-19. Clean up around well and level gravel. 10/1/2023 04:00 10/1/2023 06:00 2.0 0 MIRU, MOVE MIRU MOB P Move rig onto double mats. Level up rig. Call Pad Ops to witness backing rig over the well. Spot rig over 1R-15. Lay cribbing. Berm in rig. 10/1/2023 06:00 10/1/2023 09:30 3.5 0 MIRU, MOVE MIRU RURD P Begin rig acceptance checklist. Measure rig RKB to Tubing Spool ULDS. Spot cuttings box and align chute. Spot Tiger Tank. RU choke and kill lines to tree. RU Hardline to Tiger Tank. Gather Initial Pressures: T/I/O = 350, 550, 50 psi. . Accept rig @ 09:30 Hrs 10/1/2023 09:30 10/1/2023 11:30 2.0 0 MIRU, WELCTL MIRU COND P Load 9.6# NaCl KWF brine into pits. Build deep clean pill. 10/1/2023 11:30 10/1/2023 12:00 0.5 0 MIRU, WELCTL MIRU PRTS P PT squeeze manifold and tiger tank lines T/ 2500 PSI. 10/1/2023 12:00 10/1/2023 12:30 0.5 0 MIRU, WELCTL MIRU PRTS P PJSM for well kill. 10/1/2023 12:30 10/1/2023 15:15 2.7 5 MIRU, WELCTL MIRU KLWL P Bleed free gas off of TBG F/ 130 PSI T/ 0 PSI. Bleed free gas off of IA F/ 100 PSI T/ 50 PSI. Pump 31 bbl Deep Clean pill. Chase with 343 bbls 9.6# NaCl KWF down Tubing taking IA returns to Tiger Tank. @ 3 BPM, At 325 bbls 9.6# pumped, measured good 9.6# brine returns. SI Choke. Bleed trapped pressure. NU 7 1 1/6" x 13 5/8" DSA. NU BOPE. Begin loading 217 joints of 3 1/2" DP on ODS. 10/1/2023 15:15 10/1/2023 15:45 0.5 0 MIRU, WELCTL MIRU OWFF P OWFF for 30-min at Tubing and IA whitey valves at tree. No Flow. 10/1/2023 15:45 10/1/2023 16:30 0.7 5 MIRU, WELCTL MIRU MPSP P RU T-Bar. Install IS-A BPV. 10/1/2023 16:30 10/1/2023 16:45 0.2 5 MIRU, WELCTL MIRU PRTS P PT BPV from below T/ 1,000 psi for 10 Min. 10/1/2023 16:45 10/1/2023 17:45 1.0 0 MIRU, WHDBOP MIRU RURD P B/D, R/D circ manifold & tiger tank line. 10/1/2023 17:45 10/1/2023 22:00 4.2 5 MIRU, WHDBOP MIRU NUND P Clean up cellar area. Hang hoses. N/D tree. Inspect hanger neck threads. Good. Function LDS. Install slip-on blanking plug. Bleed 20 psi from IA. Gas. Bled to 0 psi. Will monitor during BOP test. 10/1/2023 22:00 10/2/2023 00:00 2.0 0 MIRU, WHDBOP MIRU NUND P NU 7 1 1/6" x 13 5/8" DSA. NU BOPE. 10/2/2023 00:00 10/2/2023 04:30 4.5 0 MIRU, WHDBOP NUND P Finish NU BOPE. Straighten WH/Stack. R/U Choke and Kill line. Install bell nipple. Rig Name: NORDIC 3 Rig Accept : 10/1/2023 Rig Release : 10/7/2023 Well Name: 1R-15 Page 2/6 1R-15 Report Printed: 10/27/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 10/2/2023 04:30 10/2/2023 09:00 4.5 0 MIRU, WHDBOP MIRU BOPE P Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested annular, UVBR's, w/ 3 1/2" test joints. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 ½ EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3050 PSI, after closure=1750 PSI, 200 PSI attained =17 sec, full recovery attained =119 sec. UVBR's= 5 sec, Simulated LVBRs= 5 sec. Annular= 19 sec. Simulated blinds= 5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =1887 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Austin McLeod. 10/2/2023 09:00 10/2/2023 10:00 1.0 0 MIRU, WHDBOP MIRU RURD P L/D Test Joint and slip-on blanking plug. B/D, R/D testing equipment. 10/2/2023 10:00 10/2/2023 10:30 0.5 0 MIRU, WHDBOP MIRU MPSP P Pull ISA BPV. 10/2/2023 10:30 10/2/2023 11:30 1.0 0 6,722.0 6,692.0 COMPZN, RPCOMP MIRU PULL P M/U Landing Joint. Set 10K down. BOLDS. Pull hanger off seat 65K. Pipe free @ 125K. Pull hanger T/ 6692', PUW=95. 10/2/2023 11:30 10/2/2023 12:45 1.2 5 6,692.0 6,692.0 COMPZN, RPCOMP MIRU CIRC P Circ STS+ @ 5 BPM and 500 psi. Overboarding contaminated fluid. 10/2/2023 12:45 10/2/2023 13:15 0.5 0 6,692.0 6,692.0 COMPZN, RPCOMP MIRU OWFF P Perform 30-min NFT. L/D hanger and landing joint. Blow Down lines. R/U control line spooler. 10/2/2023 13:15 10/2/2023 13:30 0.2 5 6,692.0 6,692.0 COMPZN, RPCOMP MIRU SFTY P PJSM w/ SLB & rig crew on L/D completion. 10/2/2023 13:30 10/2/2023 15:00 1.5 0 6,692.0 6,147.0 COMPZN, RPCOMP MIRU PULL P L/D 3 1/2" completion F/ 6692' T/ 6147', PUW=95K. 10/2/2023 15:00 10/2/2023 15:30 0.5 0 6,147.0 6,147.0 COMPZN, RPCOMP MIRU SVRG P Service rig. Secure top drive service loop. 10/2/2023 15:30 10/2/2023 19:00 3.5 0 6,147.0 4,942.0 COMPZN, RPCOMP MIRU PULL P Cont L/D 3 1/2: completion F/ 6147' T/ 4942', PUW=88K. Recover 31 of 31 SS bands from control line. L/D SSSV. R/D SLB spooler. 10/2/2023 19:00 10/2/2023 23:30 4.5 0 4,942.0 0.0 COMPZN, RPCOMP MIRU PULL P Cont. TOOH w/ 3 1/2" Completions F/ 4,942' to surface. L/D Cut Joint. Slight flare on 20-30 deg of cut. Length of cut joint = 14.48'. Pulled total of 210 joints of 3 1/2" Tubing + cut joint. 10/2/2023 23:30 10/3/2023 00:00 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU BHAH P Clean and clear rig floor and pipe shed. 10/3/2023 00:00 10/3/2023 04:00 4.0 0 0.0 227.0 COMPZN, RPCOMP MIRU BHAH P Cont. clean and clear rig floor and pipe shed. Fire Drill @ 12:30AM. PU/MU BHA #1 (3 1/2" Tubing Overshot w/ pack-off and mill guide). 10/3/2023 04:00 10/3/2023 12:00 8.0 0 227.0 6,710.0 COMPZN, RPCOMP MIRU TRIP P TIH w/ BHA #1 to tubing cut depth @ 6,722' ORKB. PUW = 133K. SOW = 120K. Lightly tag top of tubing stub @ 6,710' RKB. Rig Name: NORDIC 3 Rig Accept : 10/1/2023 Rig Release : 10/7/2023 Well Name: 1R-15 Page 3/6 1R-15 Report Printed: 10/27/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 10/3/2023 12:00 10/3/2023 16:30 4.5 0 6,710.0 6,710.0 COMPZN, RPCOMP MIRU FISH P PUH. Obtain parameters. PUW = 133K, SOW = 120K, RPM = 50. Torque = 4600 KFt-lbs. Pump Rate = 3 BPM @ 450 psi. TIH slowly and dress off tubing stub per Yellow Jacket. Swallow and latch tubing stub with Overshot. Set 20K down to attempt to push seals down to free up in sealbore. Pickup 25K over to confirm good latch. Attempt to straight pull free before jarring. Start jarring 25K over 158K with 30K straight pull after jars fire. Bring pump online in tension for some hydraulic assist with 2,000 - 2,500 PSI. At 17 cycles bring jars up to 30K.Straight pull every fifth time to 32K over, work up T/47K over for jar licks and straight pull to 52K over, no progress with straight pull, stop with straight pull and continue with jar licks at 47K over with 2,500 PSI 10/3/2023 16:30 10/3/2023 17:00 0.5 0 6,710.0 6,702.0 COMPZN, RPCOMP MIRU FISH P At 75 hits, Pull into tension. Circulate for hydraulic effect. S/D pump @ 2700 PSI bleed off pump. P/U to 47K over 180K. Back online down tubing, 2500 PSI. Jars fires came free. PUH 10' lost tubing pressure, 10/3/2023 17:00 10/3/2023 17:30 0.5 0 6,702.0 6,625.0 COMPZN, RPCOMP MIRU CIRC P Taking gain in trip tank. CBU @ 5 BPM 1141PSI Dump 45 BBLS on bottoms up Circulate until well clean Stand one stand back T/6,625' 10/3/2023 17:30 10/3/2023 19:15 1.7 5 6,625.0 6,625.0 COMPZN, RPCOMP MIRU OWFF P Flow check while on TT Perform post jarring derrick inspection 10/3/2023 19:15 10/3/2023 22:45 3.5 0 6,625.0 226.0 COMPZN, RPCOMP MIRU TRIP P POOH F/6,625' T/226' 10/3/2023 22:45 10/3/2023 23:15 0.5 0 226.0 226.0 COMPZN, RPCOMP MIRU OWFF P Flow check 10/3/2023 23:15 10/4/2023 00:00 0.7 5 226.0 80.0 COMPZN, RPCOMP MIRU BHAH P Lay down BHA #2 and 3 1/2" tubing fish 10/4/2023 00:00 10/4/2023 00:30 0.5 0 80.0 0.0 COMPZN, RPCOMP MIRU BHAH P Lay down BHA #2 and 3 1/2" tubing fish Cut JT = 17.02' Total fish layed down = 35.70' 10/4/2023 00:30 10/4/2023 01:00 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU RURD P Set wear ring 10/4/2023 01:00 10/4/2023 02:45 1.7 5 0.0 242.0 COMPZN, RPCOMP MIRU BHAH P Prep BHA #2 components in pipe shed Pick up BHA #2 T/242' 10/4/2023 02:45 10/4/2023 06:00 3.2 5 242.0 6,547.0 COMPZN, RPCOMP MIRU TRIP P RIH F/242' T/6,547' 10/4/2023 06:00 10/4/2023 07:30 1.5 0 6,547.0 6,744.0 COMPZN, RPCOMP MIRU WASH P Circulate at 5 BPM 1090 PSI Wash down F/6,547' T/6,744' 130K UP 120K DN Set down 5-7K at 6,744' M/S depth puts PBR top at 6,732', see pump pressure from 460 PSI to 650 PSI at 3 BPM when tagged up on PBR Had to work 6 1/8" mills from 6,728' to 6,733' - Lower mill at 6,714' - 6719', top mill at 6,710' - 6,715', see 5-8K drag up and down and never really get clean Rig Name: NORDIC 3 Rig Accept : 10/1/2023 Rig Release : 10/7/2023 Well Name: 1R-15 Page 4/6 1R-15 Report Printed: 10/27/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 10/4/2023 07:30 10/4/2023 10:30 3.0 0 6,744.0 6,729.0 COMPZN, RPCOMP MIRU CIRC P Tag up at 6,744' with 5-7K DN Pump 20 BBL hi vis sweep to clean up PBR When sweep coming out mule shoe turn pumps up to 8.5 BPM 3060 PSI, pick up above PBR when sweep clear of mule shoe to 6,729' Get a good amount of sand back after sweep out of hole, pump another 20 BBL hi vis sweep Cirulate hole clean 10/4/2023 10:30 10/4/2023 11:00 0.5 0 6,729.0 6,729.0 COMPZN, RPCOMP MIRU OWFF P Lay down single - flow check 10/4/2023 11:00 10/4/2023 14:45 3.7 5 6,729.0 242.0 COMPZN, RPCOMP MIRU TRIP P POOH F/6,729' T/242' 10/4/2023 14:45 10/4/2023 16:30 1.7 5 242.0 0.0 COMPZN, RPCOMP MIRU BHAH P L/D collars, L/D BHA #2 10/4/2023 16:30 10/4/2023 17:30 1.0 0 0.0 0.0 COMPZN, RPCOMP MIRU BHAH P Clean clear rig floor of BHA equipment 10/4/2023 17:30 10/4/2023 18:00 0.5 0 0.0 14.3 COMPZN, RPCOMP MIRU BHAH P M/U BHA #3 Test packer, No drill collars14.3' 10/4/2023 18:00 10/4/2023 23:15 5.2 5 14.3 6,660.0 COMPZN, RPCOMP MIRU TRIP P Trip in hole BHA #3 T/6,660' 126K UP 117K DN 10/4/2023 23:15 10/5/2023 00:00 0.7 5 6,660.0 6,672.0 COMPZN, RPCOMP MIRU PRTS P Break circuation make sure lines are full Set test packer @ 6,672', C.O.E. = 6,668' R/U test equipment and hoses, purge air out of lines Pressure up down drill pipe T/3,000 PSI, Pressure up to 3,000 PSI , bleed off to 1,800 PSI in 2 min, leaking by packer, pump a total of 2.2 BBLS Bleed off pressure 10/5/2023 00:00 10/5/2023 00:30 0.5 0 6,672.0 6,672.0 COMPZN, RPCOMP MIRU PRTS P Pull packer into tension with 25K overT/150K on hook, pressure up down drill pipe to 3,100 PSI, bleed down to 2,520 PSI in 2 min, nothing coming up past packer, pump a total of 1.1 BBLS OA at start = 50 PSI, OA at 3,000 PSI = 50 PSI C.O.E. = 6,668' 10/5/2023 00:30 10/5/2023 01:30 1.0 0 6,672.0 6,672.0 COMPZN, RPCOMP MIRU PRTS P Rig up test IA Pressure up to 3,120 PSI F/30 Min Pump a total of 1.9 BBLS OA at 50 PSI at start OA at 100 PSI when pressure up to 3,120 PSI OA @ 100 PSI at 15 Min/ IA @ 3,090 PSI OA @ 100 PSI at 30 Min/ IA @ 3,080 PSI 40 PSI loss in 30 min Bleed off pressure - open rams Unset packer 10/5/2023 01:30 10/5/2023 02:00 0.5 0 6,672.0 6,672.0 COMPZN, RPCOMP MIRU OWFF P Flow check while packer elements relax 10/5/2023 02:00 10/5/2023 09:48 7.8 0 6,672.0 14.0 COMPZN, RPCOMP MIRU PULD P POOH Kitty Wells style F/6,672' T/14' 10/5/2023 09:48 10/5/2023 12:00 2.2 0 14.0 0.0 COMPZN, RPCOMP MIRU BHAH P On surface with test packer. Continue to process 3 1/2 completion. Load out remaining drill pipe 10/5/2023 12:00 10/5/2023 17:00 5.0 0 0.0 0.0 COMPZN, RPCOMP MIRU RURD P Pull wear ring, load 3 1/2 completion. Rig down rig floor. P/U GBR tongs and tools. Rig Name: NORDIC 3 Rig Accept : 10/1/2023 Rig Release : 10/7/2023 Well Name: 1R-15 Page 5/6 1R-15 Report Printed: 10/27/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 10/5/2023 17:00 10/5/2023 22:15 5.2 5 0.0 0.0 COMPZN, RPCOMP MIRU OTHR P Finish loading and processing 3 1/2" tubing for completion run Load and process 3 1/2" completion components 10/5/2023 22:15 10/6/2023 00:00 1.7 5 0.0 457.0 COMPZN, RPCOMP MIRU PUTB P PJSM, run 3 1/2" completion as per detail T/457' 42K DN Make up TQ = 2,900#, make up with TQ turn tongs 10/6/2023 00:00 10/6/2023 10:00 10. 00 457.0 6,729.0 COMPZN, RPCOMP MIRU PUTB P Run 3 1/2" completion as per detail F/457' T/6729 Make up TQ = 2,900#, make up with TQ turn tongs 10/6/2023 10:00 10/6/2023 10:45 0.7 5 6,729.0 6,744.0 COMPZN, RPCOMP MIRU PUTB P 6729 P/U 213 to pump M/U, PUW=87K, SOW=83K. Come online down tubing .RIH see pressure increase @ 6733 to 250 PSI. S/D pump. Bleed off. Continue in to setdown @ 6744 10K Down wt..PUH to neutral weigh @ 6744' 10/6/2023 10:45 10/6/2023 12:00 1.2 5 6,744.0 6,708.0 COMPZN, RPCOMP MIRU PUTB P Pull up out of seals and repeat to confirm marks / space out. Lay down JT 212 and 211. Make up space out pups 19.67'. P/U JT #211. hanger, and landing joint 10/6/2023 12:00 10/6/2023 13:15 1.2 5 6,708.0 6,708.0 COMPZN, RPCOMP MIRU CRIH P Line up 9.6 PPG inhibited brine down IA returns up tubing 200 BBls 10/6/2023 13:15 10/6/2023 13:45 0.5 0 6,708.0 6,739.0 COMPZN, RPCOMP MIRU THGR P Drain stack, RIH land tubing hanger, Verify landing mark through IA. 10/6/2023 13:45 10/6/2023 14:00 0.2 5 6,739.0 6,739.0 COMPZN, RPCOMP MIRU THGR P Run in LDS 10/6/2023 14:00 10/6/2023 15:15 1.2 5 6,739.0 6,739.0 COMPZN, RPCOMP MIRU RURD P Drop ball and rod to RHC plug, Rig up for packer set, tubing test, IA test, and Shear out SOV 10/6/2023 15:15 10/6/2023 16:00 0.7 5 6,739.0 6,739.0 COMPZN, RPCOMP MIRU PRTS P Pressure up tubing against ball in RHC to 3700 PSI, 18 Strokes to reach pressure. Hold for 30 min 10/6/2023 16:00 10/6/2023 16:15 0.2 5 6,739.0 6,739.0 COMPZN, RPCOMP MIRU PRTS P Bleed tubing down to 2500 PSI, Pressure up IA to 3000 PSI 10/6/2023 16:15 10/6/2023 16:45 0.5 0 6,739.0 6,739.0 COMPZN, RPCOMP MIRU PRTS P Surface leak in cellar, Bleed off IA to repair 10/6/2023 16:45 10/6/2023 17:15 0.5 0 6,739.0 6,739.0 COMPZN, RPCOMP MIRU PRTS P Bring anulas back up to 3000 PSI for 30 min. Good test 10/6/2023 17:15 10/6/2023 17:45 0.5 0 6,739.0 6,739.0 COMPZN, RPCOMP MIRU PRTS P Bleed off IA. Pressure up tubing to 3500 PSI / 30 Min Good test 10/6/2023 17:45 10/6/2023 18:15 0.5 0 6,739.0 6,739.0 COMPZN, RPCOMP MIRU SFTY P Saftey meeting with new crew coming on, double check lines and valve line ups 10/6/2023 18:15 10/6/2023 19:00 0.7 5 6,739.0 6,739.0 COMPZN, RPCOMP MIRU OTHR P Shear out SOV, circulate at 2 BPM 1000 PSI thru GLM B/D and R/D lines Flow check 10/6/2023 19:00 10/6/2023 20:30 1.5 0 6,739.0 0.0 COMPZN, WHDBOP MIRU MPSP P Install BPV, test from below to 1000 PSI F/10 Min 10/6/2023 20:30 10/7/2023 00:00 3.5 0 0.0 0.0 COMPZN, WHDBOP MIRU NUND P N/D BOP's and all lines 10/7/2023 00:00 10/7/2023 01:00 1.0 0 0.0 0.0 COMPZN, WHDBOP MIRU NUND P N/D BOP's and all lines Rack back BOP and secure 10/7/2023 01:00 10/7/2023 02:30 1.5 0 0.0 0.0 COMPZN, WHDBOP MIRU NUND P N/U Tubing head adaptor, install test dart and test tubing adaptor T/5,000 PSI 10/7/2023 02:30 10/7/2023 04:30 2.0 0 0.0 0.0 COMPZN, WHDBOP MIRU NUND P N/U tree 10/7/2023 04:30 10/7/2023 05:00 0.5 0 0.0 0.0 COMPZN, WHDBOP MIRU FRZP P R/U LRS and freeze protect lines, test lines to 5,000 PSI Rig Name: NORDIC 3 Rig Accept : 10/1/2023 Rig Release : 10/7/2023 Well Name: 1R-15 Page 6/6 1R-15 Report Printed: 10/27/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 10/7/2023 05:00 10/7/2023 05:30 0.5 0 0.0 0.0 COMPZN, WHDBOP MIRU PRTS P Fluid pack tree, test to 5,000 PSI F/10 min 10/7/2023 05:30 10/7/2023 05:45 0.2 5 0.0 0.0 COMPZN, WHDBOP MIRU MPSP P Pull test dart and BPV 10/7/2023 05:45 10/7/2023 06:30 0.7 5 0.0 0.0 COMPZN, WHDBOP MIRU FRZP P Pump 70 BBLS diesel down IA taking returns up TBG Pump @ 2 BPM 2100 PSI Let diesel U-tube B/D and R/D lines 10/7/2023 06:30 10/7/2023 10:00 3.5 0 0.0 0.0 COMPZN, WHDBOP MIRU RURD P Secure well obtain final pressures Clean up in cellar, Rig off TT line.Rig off cuttings chute. 10/7/2023 10:00 10/7/2023 12:00 2.0 0 0.0 0.0 DEMOB, MOVE MIRU MOB P Warm up moving system Jack up rig RIG RELEASE 12:00 Rig Name: NORDIC 3 Rig Accept : 10/1/2023 Rig Release : 10/7/2023 Well Name: 1R-15 Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: RKB 7,075.0 1R-15 10/19/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Post rig - Pulled B&R, RHC, RBP, pulled & set BPI, updated tag depth 1R-15 10/20/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: SLOW IA X OA COMMUNICATION 2/2/2015 lehallf NOTE: View Schematic w/ Alaska Schematic9.0 10/18/2010 ninam 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 38.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 37.0 3,804.2 3,803.7 36.00 J-55 BTC PRODUCTION 7 6.28 35.5 7,396.8 6,811.2 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 27.2 Set Depth 6,753.2 String Max No 3 1/2 Set Depth 6,309.5 Tubing Description Tubing Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection HYD563 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) 27.2 27.2 0.00 Hanger 6.980 3.5" x 7 1/16" Gen 4 FMC TUBING HANGER ('H' BPV Profile) 3 1/2" EUE lift threads FMC Gen 4 2.920 6,586.6 6,181.4 39.94 Mandrel 4.730 3.5" x 1" KBG-2-9, L-80, TSH 563 BxP SLB KBG-2-9 2.818 6,644.0 6,225.5 39.76 Packer 5.990 Packer, 3 1/2" x 7" SLB BluePack RH Max VAMTOP SLB BluePac k 2.885 6,730.2 6,291.7 39.49 Nipple - X 4.500 2.813" X-Nipple, 9CR, TSH563 HES 2.813" X -Nipple 2.813 6,743.0 6,301.6 39.56 Locator 4.550 Baker Locator, 4.55"OD, .91' long and 1.66' from fully located 2.960 6,744.0 6,302.3 39.56 Seal Assembly 3.780 Seal Assembly, Baker 80-40 GBH22 (10.32' of seals below locator) Baker Seal Assembl y 80-40 2.960 Top (ftKB) 6,744.6 Set Depth 6,953.4 String Max No 4 1/2 Set Depth 6,463.9 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8RD 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) 6,744.6 6,302.8 39.56 PBR 5.125 BAKER PBR 3.000 6,758.3 6,313.4 39.58 PACKER 6.078 BAKER FHL PACKER 3.000 6,796.9 6,343.1 39.55 INJECTION 5.625 MERLA TMPD 2.875 6,835.0 6,372.6 39.53 BLAST RINGS 4.500 BLAST RINGS (2)2.992 6,913.8 6,433.3 39.45 NIPPLE 4.484 AVA BPL LANDING NIPPLE 2.750 6,916.7 6,435.6 39.44 XO Reducing 3.500 CROSSOVER 3.5 x 2.875 2.875 6,924.4 6,441.5 39.42 LOCATOR 3.500 LOCATOR 3.000 6,925.4 6,442.3 39.42 PACKER 6.150 BAKER DB PACKER 3.250 6,945.2 6,457.6 39.38 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 6,952.7 6,463.4 39.36 SOS 3.750 CAMCO SHEAR OUT SUB 2.441 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) 6,913.0 6,432.7 39.45 SLEEVE - CLOSED AVA 2.75" BPI Sleeve (OAL = 29") 10/17/2023 2.310 7,182.0 6,641.7 38.42 FISH 1" DMY Retrieved Latch Only; Body is in 7" CSG 11/28/1985 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) 6,586.6 6,181.4 39.94 1 INJ DMY BTM 4.72 0.0 10/17/2023 Schlumb erger KBG-2-9 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,861.0 6,885.0 6,392.6 6,411.1 C-1, 1R-15 10/9/1985 12.0 IPERF 5" HJ II Csg Gun; 120 deg. ph 7,046.0 7,053.0 6,535.7 6,541.1 A-4, 1R-15 10/9/1985 4.0 IPERF 4" HJ II Csg Gun; 90 deg. ph 7,058.0 7,098.0 6,545.0 6,576.1 A-4, A-3, 1R-15 10/9/1985 4.0 IPERF 4" HJ II Csg Gun; 90 deg. ph 7,164.0 7,173.0 6,627.6 6,634.7 A-2, 1R-15 10/9/1985 4.0 IPERF 4" HJ II Csg Gun; 90 deg. ph 1R-15, 10/27/2023 9:55:37 AM Vertical schematic (actual) PRODUCTION; 35.5-7,396.8 FISH; 7,182.0 IPERF; 7,164.0-7,173.0 IPERF; 7,058.0-7,098.0 IPERF; 7,046.0-7,053.0 PACKER; 6,925.4 SLEEVE - CLOSED; 6,913.0 IPERF; 6,861.0-6,885.0 INJECTION; 6,796.9 PACKER; 6,758.3 Seal Assembly; 6,743.9 Nipple - X; 6,730.2 Packer; 6,644.0 Mandrel ; 6,586.5 SURFACE; 37.0-3,804.2 CONDUCTOR; 38.0-115.0 Hanger; 27.2 KUP INJ KB-Grd (ft) 36.59 RR Date 8/13/1985 Other Elev 1R-15 ... TD Act Btm (ftKB) 7,422.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292138700 Wellbore Status INJ Max Angle & MD Incl (°) 41.96 MD (ftKB) 5,550.00 WELLNAME WELLBORE Annotation Last WO: End Date 10/7/2023 H2S (ppm)DateComment SSSV: TRDP Certificate Of Completion Envelope Id: 11AED01703B34102A5316D9D0BC5F915 Status: Completed Subject: Here is your signed document: KRU 1R-15 10-404.pdf Source Envelope: Document Pages: 8 Signatures: 1 Envelope Originator: Certificate Pages: 5 Initials: 0 Jonathan Coberly AutoNav: Disabled EnvelopeId Stamping: Disabled Time Zone: (UTC-06:00) Central Time (US & Canada) 600 N Dairy Ashford Rd Houston, TX 77079-1100 Jonathan.Coberly@conocophillips.com IP Address: 138.32.8.5 Record Tracking Status: Original 11/1/2023 4:53:44 PM Holder: Jonathan Coberly Jonathan.Coberly@conocophillips.com Location: DocuSign Signer Events Signature Timestamp Jonathan Coberly Jonathan.Coberly@conocophillips.com Security Level: Email, Account Authentication (None) Signature Adoption: Pre-selected Style Using IP Address: 138.32.8.5 Sent: 11/1/2023 4:53:55 PM Viewed: 11/1/2023 4:54:01 PM Signed: 11/1/2023 4:54:44 PM Freeform Signing Electronic Record and Signature Disclosure: Accepted: 10/21/2021 1:38:44 PM ID: 816074ce-6cf9-4a8e-a803-d7ca1a5695a7 In Person Signer Events Signature Timestamp Editor Delivery Events Status Timestamp Agent Delivery Events Status Timestamp Intermediary Delivery Events Status Timestamp Certified Delivery Events Status Timestamp Carbon Copy Events Status Timestamp Jenna Taylor Jenna.L.Taylor@conocophillips.com ConocoPhillips Security Level: Email, Account Authentication (None) Sent: 11/1/2023 4:54:45 PM Viewed: 11/1/2023 5:33:35 PM Electronic Record and Signature Disclosure: Accepted: 10/16/2023 5:54:47 PM ID: 67551fd2-158e-440c-8245-f971ef8ee62c Witness Events Signature Timestamp Notary Events Signature Timestamp Envelope Summary Events Status Timestamps Envelope Sent Hashed/Encrypted 11/1/2023 4:53:55 PM Certified Delivered Security Checked 11/1/2023 4:54:01 PM Signing Complete Security Checked 11/1/2023 4:54:44 PM Completed Security Checked 11/1/2023 4:54:45 PM Payment Events Status Timestamps Electronic Record and Signature Disclosure ELECTRONIC RECORD AND SIGNATURE DISCLOSURE From time to time, ConocoPhillips (we, us or Company) may be required by law to provide to you certain written notices or disclosures. Described below are the terms and conditions for providing to you such notices and disclosures electronically through the DocuSign system. Please read the information below carefully and thoroughly, and if you can access this information electronically to your satisfaction and agree to this Electronic Record and Signature Disclosure (ERSD), please confirm your agreement by selecting the check-box next to I agree to use electronic records and signatures before clicking CONTINUE within the DocuSign system. Getting paper copies At any time, you may request from us a paper copy of any record provided or made available electronically to you by us. You will have the ability to download and print documents we send to you through the DocuSign system during and immediately after the signing session and, if you elect to create a DocuSign account, you may access the documents for a limited period of time (usually 30 days) after such documents are first sent to you. After such time, if you wish for us to send you paper copies of any such documents from our office to you, you will be charged a $0.00 per-page fee. You may request delivery of such paper copies from us by following the procedure described below. Withdrawing your consent If you decide to receive notices and disclosures from us electronically, you may at any time change your mind and tell us that thereafter you want to receive required notices and disclosures only in paper format. How you must inform us of your decision to receive future notices and disclosure in paper format and withdraw your consent to receive notices and disclosures electronically is described below. Consequences of changing your mind If you elect to receive required notices and disclosures only in paper format, it will slow the speed at which we can complete certain steps in transactions with you and delivering services to you because we will need first to send the required notices or disclosures to you in paper format, and then wait until we receive back from you your acknowledgment of your receipt of such paper notices or disclosures. Further, you will no longer be able to use the DocuSign system to receive required notices and consents electronically from us or to sign electronically documents from us. All notices and disclosures will be sent to you electronically Unless you tell us otherwise in accordance with the procedures described herein, we will provide electronically to you through the DocuSign system all required notices, disclosures, authorizations, acknowledgements, and other documents that are required to be provided or made available to you during the course of our relationship with you. To reduce the chance of you inadvertently not receiving any notice or disclosure, we prefer to provide all of the required notices and disclosures to you by the same method and to the same address that you have given us. Thus, you can receive all the disclosures and notices electronically or in paper format through the paper mail delivery system. If you do not agree with this process, please let us know as described below. Please also see the paragraph immediately above that describes the consequences of your electing not to receive delivery of the notices and disclosures electronically from us. How to contact ConocoPhillips: You may contact us to let us know of your changes as to how we may contact you electronically, to request paper copies of certain information from us, and to withdraw your prior consent to receive notices and disclosures electronically as follows: To contact us by email send messages to: DocuSign.Admin@conocophillips.com To advise ConocoPhillips of your new email address To let us know of a change in your email address where we should send notices and disclosures electronically to you, you must send an email message to us at DocuSign.Admin@conocophillips.com and in the body of such request you must state: your previous email address, your new email address. We do not require any other information from you to change your email address. If you created a DocuSign account, you may update it with your new email address through your account preferences. To request paper copies from ConocoPhillips To request delivery from us of paper copies of the notices and disclosures previously provided by us to you electronically, you must send us an email to DocuSign.Admin@conocophillips.com and in the body of such request you must state your email address, full name, mailing address, and telephone number. We will bill you for any fees at that time, if any. To withdraw your consent with ConocoPhillips To inform us that you no longer wish to receive future notices and disclosures in electronic format you may: i. decline to sign a document from within your signing session, and on the subsequent page, select the check-box indicating you wish to withdraw your consent, or you may; ii. send us an email to DocuSign.Admin@conocophillips.com and in the body of such request you must state your email, full name, mailing address, and telephone number. We do not need any other information from you to withdraw consent.. The consequences of your withdrawing consent for online documents will be that transactions may take a longer time to process.. Required hardware and software The minimum system requirements for using the DocuSign system may change over time. The current system requirements are found here: https://support.docusign.com/guides/signer-guide- signing-system-requirements. Acknowledging your access and consent to receive and sign documents electronically To confirm to us that you can access this information electronically, which will be similar to other electronic notices and disclosures that we will provide to you, please confirm that you have read this ERSD, and (i) that you are able to print on paper or electronically save this ERSD for your future reference and access; or (ii) that you are able to email this ERSD to an email address where you will be able to print on paper or save it for your future reference and access. Further, if you consent to receiving notices and disclosures exclusively in electronic format as described herein, then select the check-box next to I agree to use electronic records and signatures before clicking CONTINUE within the DocuSign system. By selecting the check-box next to I agree to use electronic records and signatures, you confirm that: You can access and read this Electronic Record and Signature Disclosure; and You can print on paper this Electronic Record and Signature Disclosure, or save or send this Electronic Record and Disclosure to a location where you can print it, for future reference and access; and Until or unless you notify ConocoPhillips as described above, you consent to receive exclusively through electronic means all notices, disclosures, authorizations, acknowledgements, and other documents that are required to be provided or made available to you by ConocoPhillips during the course of your relationship with ConocoPhillips. 323-402 By Grace Christianson at 9:15 am, Jul 18, 2023 X VTL 8/03/2023 XX BOPtestto2500psig Annular preventer test to 2500 psig MDG 7/24/2023 10-404 DSR-7/19/23GCW 08/04/2023JLC 8/4/2023 08/04/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.08.04 16:54:45 -08'00' RBDMS JSB 080823 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-05-26_22095_KRU_1R-15_ArcherVividAcoustidLDL_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22095 KRU 1R-15 50-029-21387-00 Archer Vivid Acoustic LDL 26-May-23 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 PTD: 185-152 T37838 Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.12 10:18:32 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1R-15 (PTD 185-152) Report of failed MITIA Date:Tuesday, May 9, 2023 8:36:59 AM Attachments:AnnComm Surveillance TIO for 1R-15.pdf From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Friday, May 5, 2023 2:40 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1R-15 (PTD 185-152) Report of failed MITIA Chris, KRU 1R-15 (PTD 185-152) Failed it’s SW MITIA today. The well will be shut in and freeze protected as soon as possible. Diagnostics will follow and once a plan forward has been developed any required paperwork for corrective action or continued injection will be submitted. A 90 day TIO trend and wellbore schematic are attached. The 10-426 will be submitted once the information from the field has made it in. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 265-6471 Cell phone: (808) 345-6886 1R-15 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 1R-15 2023-04-24 735 305 -430 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 6,954.0 1R-15 1/1/2023 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled RBP & Tagged 1R-15 1/1/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: SLOW IA X OA COMMUNICATION 2/2/2015 lehallf NOTE: View Schematic w/ Alaska Schematic9.0 10/18/2010 ninam 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 38.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 37.0 3,804.2 3,803.7 36.00 J-55 BTC PRODUCTION 7 6.28 35.5 7,396.8 6,811.2 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 27.5 Set Depth … 6,953.4 Set Depth … 6,463.9 String Ma… 3 1/2 Tubing Description TUBING 3.5x2.875 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8RD 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) 27.5 27.5 0.00 HANGER 8.000 FMC GEN III TUBING HANGER 3.500 1,766.7 1,766.6 0.40 SAFETY VLV 5.938 BAKER FVL SAFETY VALVE 2.813 1,811.5 1,811.4 0.48 GAS LIFT 5.625 MERLA TMPD 2.875 3,067.2 3,066.9 1.57 GAS LIFT 5.625 MERLA TMPD 2.875 3,800.4 3,800.0 1.69 GAS LIFT 5.625 MERLA TMPD 2.875 4,218.3 4,217.6 5.17 GAS LIFT 5.625 MERLA TMPD 2.875 4,540.9 4,532.5 18.32 GAS LIFT 5.625 MERLA TMPD 2.875 4,895.1 4,855.5 26.62 GAS LIFT 5.625 MERLA TMPD 2.875 5,311.6 5,212.5 35.34 GAS LIFT 5.625 MERLA TMPD 2.875 5,726.7 5,530.3 41.82 GAS LIFT 5.625 MERLA TMPD 2.875 6,166.4 5,863.0 41.38 GAS LIFT 5.625 MERLA TMPD 2.875 6,744.6 6,302.8 39.56 PBR 5.125 BAKER PBR 3.000 6,758.3 6,313.4 39.58 PACKER 6.078 BAKER FHL PACKER 3.000 6,835.0 6,372.6 39.53 BLAST RINGS 4.500 BLAST RINGS (2) 2.992 6,913.8 6,433.3 39.45 NIPPLE 4.484 AVA BPL LANDING NIPPLE 2.750 6,916.7 6,435.6 39.44 XO Reducing 3.500 CROSSOVER 3.5 x 2.875 2.875 6,924.4 6,441.5 39.42 LOCATOR 3.500 LOCATOR 3.000 6,925.4 6,442.3 39.42 PACKER 6.150 BAKER DB PACKER 3.250 6,945.2 6,457.6 39.38 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 6,952.7 6,463.4 39.36 SOS 3.750 CAMCO SHEAR OUT SUB 2.441 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) 6,913.8 6,433.3 39.45 SLEEVE - OPEN AVA 2.75" BPI SLEEVE SET WITH 2: 5/32" PORTS 3/8/2009 7,182.0 6,641.7 38.42 FISH 1" DMY Retrieved Latch Only; Body is in 7" CSG 11/28/1985 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,861.0 6,885.0 6,392.6 6,411.1 C-1, 1R-15 10/9/1985 12.0 IPERF 5" HJ II Csg Gun; 120 deg. ph 7,046.0 7,053.0 6,535.7 6,541.1 A-4, 1R-15 10/9/1985 4.0 IPERF 4" HJ II Csg Gun; 90 deg. ph 7,058.0 7,098.0 6,545.0 6,576.1 A-4, A-3, 1R-15 10/9/1985 4.0 IPERF 4" HJ II Csg Gun; 90 deg. ph 7,164.0 7,173.0 6,627.6 6,634.7 A-2, 1R-15 10/9/1985 4.0 IPERF 4" HJ II Csg Gun; 90 deg. ph 1R-15, 1/2/2023 8:20:39 AM Vertical schematic (actual) PRODUCTION; 35.5-7,396.8 FLOAT SHOE; 7,395.1-7,396.8 FLOAT COLLAR; 7,310.5- 7,312.1 FISH; 7,182.0 IPERF; 7,164.0-7,173.0 IPERF; 7,058.0-7,098.0 IPERF; 7,046.0-7,053.0 SOS; 6,952.7 NIPPLE; 6,945.2 PACKER; 6,925.4 LOCATOR; 6,924.4 NIPPLE; 6,913.8 IPERF; 6,861.0-6,885.0 INJECTION; 6,796.9 PACKER; 6,758.3 PBR; 6,744.6 INJECTION; 6,697.6 GAS LIFT; 6,166.4 GAS LIFT; 5,726.7 GAS LIFT; 5,311.6 GAS LIFT; 4,895.1 GAS LIFT; 4,540.9 GAS LIFT; 4,218.3 SURFACE; 37.0-3,804.2 GAS LIFT; 3,800.4 FLOAT SHOE; 3,802.5-3,804.2 FLOAT COLLAR; 3,714.2- 3,716.0 GAS LIFT; 3,067.2 GAS LIFT; 1,811.5 SAFETY VLV; 1,766.7 CONDUCTOR; 38.0-115.0 HANGER; 37.0-41.4 HANGER; 27.5 KUP INJ KB-Grd (ft) 36.59 RR Date 8/13/1985 Other Elev… 1R-15 ... TD Act Btm (ftKB) 7,422.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292138700 Wellbore Status INJ Max Angle & MD Incl (°) 41.96 MD (ftKB) 5,550.00 WELLNAME WELLBORE1R-15 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, June 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1R-15 KUPARUK RIV UNIT 1R-15 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/01/2023 1R-15 50-029-21387-00-00 185-152-0 W SPT 6318 1851520 3000 1450 1450 1450 653 977 957 REQVAR F Austin McLeod 5/5/2023 MIT-IA. Two year to MAIP. AIO 2B.088. S/I. 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 1R-15 Inspection Date: Tubing OA Packer Depth 400 3300 2910IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230506182633 BBL Pumped:4.8 BBL Returned:3.7 Thursday, June 1, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 99 9 9 9 AIO 2B.088.S/I. F James B. Regg Digitally signed by James B. Regg Date: 2023.06.02 11:01:20 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, June 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1R-15 KUPARUK RIV UNIT 1R-15 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/01/2023 1R-15 50-029-21387-00-00 185-152-0 W SPT 6318 1851520 1800 1450 1450 1450 1450 610 2010 1945 1925 REQVAR P Austin McLeod 5/5/2023 MIT-OA. Two year to 1800psi. AIO 2B.088. 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 1R-15 Inspection Date: Tubing OA Packer Depth 420 450 450 450IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230506182853 BBL Pumped:0.8 BBL Returned:0.5 Thursday, June 1, 2023 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 9 9 MIT-OA.AIO 2B.088. James B. Regg Digitally signed by James B. Regg Date: 2023.06.02 11:03:41 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1R-15 (PTD 185-152) Update and plan forward Date:Thursday, March 2, 2023 1:51:11 PM Attachments:AnnComm Surveillance TIO for 1R-15.pdf From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Thursday, March 2, 2023 12:30 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1R-15 (PTD 185-132) Update and plan forward Chris, KRU 1R-15 (PTD 185-152) (AIO 2B.088) is reaching the end of its extended monitor period. The well was BOI on January 05, 2023 for a monitor period and exhibited no signs of annular communication throughout this time period. All diagnostic testing passed including the SW-MITIA performed January 18, 2023 (10-426 submitted in the last email). At this time CPAI intends to returns the well to ‘normal’ status. If any future indications of AnnComm are observed the well will be reported and appropriate actions taken at that time. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 1R-15 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 1R-15 2022-12-19 518 110 -408 IA 1R-15 2023-01-15 160 200 40 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 6,954.0 1R-15 1/1/2023 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled RBP & Tagged 1R-15 1/1/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: SLOW IA X OA COMMUNICATION 2/2/2015 lehallf NOTE: View Schematic w/ Alaska Schematic9.0 10/18/2010 ninam 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 38.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 37.0 3,804.2 3,803.7 36.00 J-55 BTC PRODUCTION 7 6.28 35.5 7,396.8 6,811.2 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 27.5 Set Depth … 6,953.4 Set Depth … 6,463.9 String Ma… 3 1/2 Tubing Description TUBING 3.5x2.875 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8RD 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) 27.5 27.5 0.00 HANGER 8.000 FMC GEN III TUBING HANGER 3.500 1,766.7 1,766.6 0.40 SAFETY VLV 5.938 BAKER FVL SAFETY VALVE 2.813 1,811.5 1,811.4 0.48 GAS LIFT 5.625 MERLA TMPD 2.875 3,067.2 3,066.9 1.57 GAS LIFT 5.625 MERLA TMPD 2.875 3,800.4 3,800.0 1.69 GAS LIFT 5.625 MERLA TMPD 2.875 4,218.3 4,217.6 5.17 GAS LIFT 5.625 MERLA TMPD 2.875 4,540.9 4,532.5 18.32 GAS LIFT 5.625 MERLA TMPD 2.875 4,895.1 4,855.5 26.62 GAS LIFT 5.625 MERLA TMPD 2.875 5,311.6 5,212.5 35.34 GAS LIFT 5.625 MERLA TMPD 2.875 5,726.7 5,530.3 41.82 GAS LIFT 5.625 MERLA TMPD 2.875 6,166.4 5,863.0 41.38 GAS LIFT 5.625 MERLA TMPD 2.875 6,744.6 6,302.8 39.56 PBR 5.125 BAKER PBR 3.000 6,758.3 6,313.4 39.58 PACKER 6.078 BAKER FHL PACKER 3.000 6,835.0 6,372.6 39.53 BLAST RINGS 4.500 BLAST RINGS (2) 2.992 6,913.8 6,433.3 39.45 NIPPLE 4.484 AVA BPL LANDING NIPPLE 2.750 6,916.7 6,435.6 39.44 XO Reducing 3.500 CROSSOVER 3.5 x 2.875 2.875 6,924.4 6,441.5 39.42 LOCATOR 3.500 LOCATOR 3.000 6,925.4 6,442.3 39.42 PACKER 6.150 BAKER DB PACKER 3.250 6,945.2 6,457.6 39.38 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 6,952.7 6,463.4 39.36 SOS 3.750 CAMCO SHEAR OUT SUB 2.441 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) 6,913.8 6,433.3 39.45 SLEEVE - OPEN AVA 2.75" BPI SLEEVE SET WITH 2: 5/32" PORTS 3/8/2009 7,182.0 6,641.7 38.42 FISH 1" DMY Retrieved Latch Only; Body is in 7" CSG 11/28/1985 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,861.0 6,885.0 6,392.6 6,411.1 C-1, 1R-15 10/9/1985 12.0 IPERF 5" HJ II Csg Gun; 120 deg. ph 7,046.0 7,053.0 6,535.7 6,541.1 A-4, 1R-15 10/9/1985 4.0 IPERF 4" HJ II Csg Gun; 90 deg. ph 7,058.0 7,098.0 6,545.0 6,576.1 A-4, A-3, 1R-15 10/9/1985 4.0 IPERF 4" HJ II Csg Gun; 90 deg. ph 7,164.0 7,173.0 6,627.6 6,634.7 A-2, 1R-15 10/9/1985 4.0 IPERF 4" HJ II Csg Gun; 90 deg. ph 1R-15, 1/2/2023 8:20:39 AM Vertical schematic (actual) PRODUCTION; 35.5-7,396.8 FLOAT SHOE; 7,395.1-7,396.8 FLOAT COLLAR; 7,310.5- 7,312.1 FISH; 7,182.0 IPERF; 7,164.0-7,173.0 IPERF; 7,058.0-7,098.0 IPERF; 7,046.0-7,053.0 SOS; 6,952.7 NIPPLE; 6,945.2 PACKER; 6,925.4 LOCATOR; 6,924.4 NIPPLE; 6,913.8 IPERF; 6,861.0-6,885.0 INJECTION; 6,796.9 PACKER; 6,758.3 PBR; 6,744.6 INJECTION; 6,697.6 GAS LIFT; 6,166.4 GAS LIFT; 5,726.7 GAS LIFT; 5,311.6 GAS LIFT; 4,895.1 GAS LIFT; 4,540.9 GAS LIFT; 4,218.3 SURFACE; 37.0-3,804.2 GAS LIFT; 3,800.4 FLOAT SHOE; 3,802.5-3,804.2 FLOAT COLLAR; 3,714.2- 3,716.0 GAS LIFT; 3,067.2 GAS LIFT; 1,811.5 SAFETY VLV; 1,766.7 CONDUCTOR; 38.0-115.0 HANGER; 37.0-41.4 HANGER; 27.5 KUP INJ KB-Grd (ft) 36.59 RR Date 8/13/1985 Other Elev… 1R-15 ... TD Act Btm (ftKB) 7,422.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292138700 Wellbore Status INJ Max Angle & MD Incl (°) 41.96 MD (ftKB) 5,550.00 WELLNAME WELLBORE1R-15 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1R-15 (PTD 185-152) Update and monitor extension Date:Tuesday, February 7, 2023 9:31:46 AM Attachments:AnnComm Surveillance TIO for 1R-15.pdf MIT KRU 1R-15 1-18-23.xlsx From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Tuesday, January 31, 2023 12:26 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: KRU 1R-15 (PTD 185-152) Update and monitor extension Chris, Subsequent the previous email KRU 1R-15 (PTD 185-152) (AIO 2B.088) was BOI for a monitor period during which the well has exhibited no indications of annular communication and has passed all diagnostic and state witnessed testing. CPAI plans to leave the well on injection under monitor for an additional 30 days prior to making a conclusion. Any required paperwork for continued injection or corrective action will be submitted subsequent the monitor period. A wellbore schematic, 90 day TIO trend, and 10-426 are attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 From: Well Integrity Specialist CPF1 & CPF3 Sent: Wednesday, December 28, 2022 10:28 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1R-15 (PTD 185-152) Report of intent to BOI Chris, KRU 1R-15 (PTD 185-152) (AIO 2B.088) was reported and shut in in May of 2021 after failing its SW MITIA. The well underwent a series of diagnostics at the time with no conclusions as the leak did not activate when logging the well. More recently this month the well was being reviewed for RWO and all diagnostic testing passed; MITT, MITIA, MITOA, and IA-DDT. With the passing tests the plan is to bring the well online for a 30 day monitor period to observe whether the leak will reactive or if the well will maintain integrity. Any required paperwork for continued injection or corrective action will be submitted subsequent the monitor period. A wellbore schematic, 90 day TIO trend, and 10-426’s are attached. Please let us know if you have any questions or disagree with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 15d) aJnssaJd {C1d75W Jo ❑d97 aTeN ez-TO=Eroe 9Z -T o -E ZOZ S Z -T o -F zaz OZ -T 0-E ZOZ L i -T O -EEO Z 91-T O=E Z O Z ZT-T O -E EOZ 60-TO-EZOZ 90-T O -E Eoz £ o -T 0-£ Z O Z T£-ZT-zzoz BZ-Z1-zzoz 5Z-ZT-zzoz Zz-Z1-ZZOZ 6I-ZT-ZZOZ y LI-ZT-zzoz t[-Z1-zzoz TT-ZT-z ZOZ 80-Z1-ZZOZ 9o-zT-rZaz ZO-zl-zzoz 6Z-TT-ZZOZ 9z-TT-ZZOZ EZ -T T-ZZOZ 0Z-TI-ZZOZ Li-TT-ZZOZ tri-11-ZZOZ TT-TT-ZZOZ 80-TT-ZZOZ SO-TTrz ZOZ ZO-TT-ZZOZ ■� -�_-_-rte �■ oc� ,111■111■11111111� a o 11■� 1 ,111■111■11111111■ 11■1 1 ,111■111■11111111■ 11■1 1 ,111♦111♦111■111♦ 11♦� 1 ,111■111■11111111.11■1 1 15d) aJnssaJd {C1d75W Jo ❑d97 aTeN ez-TO=Eroe 9Z -T o -E ZOZ S Z -T o -F zaz OZ -T 0-E ZOZ L i -T O -EEO Z 91-T O=E Z O Z ZT-T O -E EOZ 60-TO-EZOZ 90-T O -E Eoz £ o -T 0-£ Z O Z T£-ZT-zzoz BZ-Z1-zzoz 5Z-ZT-zzoz Zz-Z1-ZZOZ 6I-ZT-ZZOZ y LI-ZT-zzoz t[-Z1-zzoz TT-ZT-z ZOZ 80-Z1-ZZOZ 9o-zT-rZaz ZO-zl-zzoz 6Z-TT-ZZOZ 9z-TT-ZZOZ EZ -T T-ZZOZ 0Z-TI-ZZOZ Li-TT-ZZOZ tri-11-ZZOZ TT-TT-ZZOZ 80-TT-ZZOZ SO-TTrz ZOZ ZO-TT-ZZOZ oc� a o a a o 15d) aJnssaJd {C1d75W Jo ❑d97 aTeN ez-TO=Eroe 9Z -T o -E ZOZ S Z -T o -F zaz OZ -T 0-E ZOZ L i -T O -EEO Z 91-T O=E Z O Z ZT-T O -E EOZ 60-TO-EZOZ 90-T O -E Eoz £ o -T 0-£ Z O Z T£-ZT-zzoz BZ-Z1-zzoz 5Z-ZT-zzoz Zz-Z1-ZZOZ 6I-ZT-ZZOZ y LI-ZT-zzoz t[-Z1-zzoz TT-ZT-z ZOZ 80-Z1-ZZOZ 9o-zT-rZaz ZO-zl-zzoz 6Z-TT-ZZOZ 9z-TT-ZZOZ EZ -T T-ZZOZ 0Z-TI-ZZOZ Li-TT-ZZOZ tri-11-ZZOZ TT-TT-ZZOZ 80-TT-ZZOZ SO-TTrz ZOZ ZO-TT-ZZOZ 1R-15 90 -Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 1R-15 2022-12-19 518 110 408 IA 1R-15 2023-01-15 160 200 40 IA CorxocoPhillips Alaska, Inc. CONDUCTOR. SAFETY FLOAT IPERF, Atio.0essal IPERF, ],g ass,705i IPERF,],059.bT02l IPERF', 7us4,01L11TSO� FISX:i,1520- FLOATCOLLAR. 1.310.5 - WELLS ��udlllllpro;„ dlllllllllp i' KUP INJ WELLNAME 1R-15 WELLBORE 1R-15 Well Attributes I Max AngleB MD TO FIeN Name PAR KRIVER NIT Well A"Rawl ,nR0B0I Al arm(K 0 ,K 500292138700 6 0 Comment TancLast X351ppm) Gate M"Em"n Entl pNe KBGN IRI RRDOo Other Les... WO: 36.59 811311985 Annotation Deytb IRKBI 1 Wellbore I End Dole LOT Mad By Last Tag: RKB 6,954.01R-15 11112023 fergusp Last Rev Reason Annotation WelINrt End Dale Lasl Motl By Rev Reason: Pulled REP & Tagged I 1R-15 111111ull fergusp Notes: General S Safety Penetration End Doh 1 Lar Mod By NOTE: SLOW IA X OA COMMUNICATION 121z2Uiu ileliallf NOTE: View Schematic wl Alaska Schema9c9.0 10,18,2010 amens Casing Strings se Deg Dea OD(in) IO lint Set Depth Top (IRe) (RKB) Ser Dow (TVD)(RKrg ..(In.) own. Top Thred CONDUCTOR 16 15.06 38.0 115.0 115.0 62.50 H40 WELDED SURFACE 998 8.921 31.0 3,SU4.21 3,W3.11 36.00 JSS BTC PRODUCTION J 6.28 I 35.5 1,396.8 I 6,811.2 I 26.00 JSS BTC Tubing Strings: string max Indicates LONGEST segment of string Top IRKBI SN Dep[In T5 6,9534 Set Depth... String Me... Tubing Deac,lpfimh .11. 6,463.9 3112 TUBING 3.5x2815 9.30 Gratle Topconrectlon IC(In) J-55 EUEBRD 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top(TVO) Tories) IRKBI OR Top Incl bringingNominal r) Rem Des (Ind Com Make Model ID (in) 21.5 21.5 0.00 HANGER 8.000 FMC GEN III TUBING HANGER 3.500 1,766.7 1)66.6 0.40 SAFETYVLV 5.938 BAKER FVL SAFETY VALVE 2.813 1181115 1,811.4 0.48 GAS LIFT 5.625 MERIA TMPD 2.815 3,061.2 3,066.9 1.51 GAS LIFT 5.625 MERIA TMPD 2.815 3,800.4 3,800.0 1.69 GAS LIFT 5.1325 MERU TMPD 2.815 4,218.3 4,211.6 5.11 GAS LIFT 5.625 MERIA TMPD 2.815 4,540.9 4,532.5 18.32 GAS LIFT 5.625 MERIA TMPD 2.815 4,895.1 4,855.5 26.62 GAS LIFT 5.625 MERLA TMPD 2.815 5,311.6 5,212.5 35.34 GAS LIFT 5.625 MERIA TMPD 2.815 5,126.1 5,530.3 41.62 GAS LIFT 5.625 MERIA TMPD 2.815 6,166.4 5,863.0 41.38 GAS LIFT 5.625 MERIA TMPD 2.815 6,144.6 6,302.8 39.56 PBR 5.125 BAKER PBR 3.000 6,158.3 6,313.4 39.58 PACKER 6.018 BAKER FHL PACKER 3.000 61835.0 6,372.6 39.53 BLAST RINGS 4.500 BLAST RINGS (2) 2.992 6,913.8 6433.3 39.45 NIPPLE 4AM AVA BPL LANDING NIPPLE 2.150 6,916.7 6435.6 39.44 XO Reducing 3.500 CROSSOVER 3.5 x 2.815 2.815 6924.4 6,441.5 39.42 LOCATOR 3.500 LOCATOR 3.000 6,925.4 6,442.3 39.42 PACKER 6.150 BAKER DB PACKER 3.250 6,945.2 6,451.6 39.38 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 6952.) I 6463.4 I 39.36 SOS 3.150 Usual SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Ten OVD) Top(RKB) (RKB) Topincl C) Des Com Me. MwMI SN Run Date ID (in) 6913.8 6'.333 39.5 SLEEVE- OPEN AVA41C ti ISLEEVESET WITH 2.5/32" PORTS 3IW2009 1,182.0 6,641.1 38.2 FISH 1"DMV Retrieved Latch Only; Body is in T' CSG 1126/985 0,000 Perforations & Slots Top IRKBI Stm(RKB) Top(TVD) (MB) Spen ) ,RKB) Lining Zone Date an. Dens IahateRq Type Cam 6,861.0 6,885.0 6,392.6 6,411.1 G1, 113-15 101911985 12.O IPERF 5- HJ II Cap Gun; 120 Lisp. ph 1,046.0 1,053.0 6,535.1 6,541.1 A4, 113-15 101911985 4.0 IPERF 4" HJ II Cap Gun; 90 deg. ph 1,058.0 1,098.0 6,545.0 6,516.1 A4, A3, 1RA5 101911985 4.0 IPERF 4" HJ II Cap Gun; 90 deg. ph 1,164.0 1,113.0 6,621.6 6,634.7 A2, 113-15 101911985 4.0 IPERF 4" HJ II Cap Gun; 90 deg. ph Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1851520 Type Inj W Tubing 1310 1310 1310 1310 Type Test P Packer TVD 6313 BBL Pump 4.1 IA 240 3300 3130 3110 Interval V Test psi 3000 BBL Return 4.2 OA 460 773 754 743 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:MITIA to maximum anticipated injection pressure per AIO 2B.088 Notes: 1R-15 Notes: Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 1R Pad Austin McLeod Miller / Richwine 01/18/23 Form 10-426 (Revised 01/2017)MIT KRU 1R-15 1-18-23 (002) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, February 22, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1R-15 KUPARUK RIV UNIT 1R-15 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 02/22/2023 1R-15 50-029-21387-00-00 185-152-0 W SPT 6318 1851520 3000 1310 1310 1310 1310 460 773 754 743 REQVAR P Austin McLeod 1/18/2023 Two year MITIA to MAIP. AIO 2B.088. 30 MinPretest Initial 15 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 1R-15 Inspection Date: Tubing OA Packer Depth 240 3300 3130 3110IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230118193526 BBL Pumped:4.1 BBL Returned:4.2 Wednesday, February 22, 2023 Page 1 of 1 Two year MITIA to MAIP. AIO 2B.088. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1R-15 (PTD 185-152) Report of intent to BOI Date:Tuesday, January 10, 2023 9:01:13 AM Attachments:AnnComm Surveillance TIO for 1R-15.pdf MIT KRU 1R-15 diagnostic MITs 12-18-22.xlsx From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Wednesday, December 28, 2022 10:28 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1R-15 (PTD 185-152) Report of intent to BOI Chris, KRU 1R-15 (PTD 185-152) (AIO 2B.088) was reported and shut in in May of 2021 after failing its SW MITIA. The well underwent a series of diagnostics at the time with no conclusions as the leak did not activate when logging the well. More recently this month the well was being reviewed for RWO and all diagnostic testing passed; MITT, MITIA, MITOA, and IA-DDT. With the passing tests the plan is to bring the well online for a 30 day monitor period to observe whether the leak will reactive or if the well will maintain integrity. Any required paperwork for continued injection or corrective action will be submitted subsequent the monitor period. A wellbore schematic, 90 day TIO trend, and 10-426’s are attached. Please let us know if you have any questions or disagree with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 6n '-I C H L w 2' A E E 7 U d i m a p p p O 4 Yl (ISd) aJnssa d 0 0 4 0 a d e 4 4 [0A7SW Ja Od9} a7 e1J LZ-Zi-ZZOZ bZ-Zi-ZZOZ TZ-Zi-ZZOz 6T-Zi-ZZOZ 9T-Zi-ZZOz El-Zi-ZZOZ OZ-Zi-ZZOz CO-Zi-ZZOZ bO-Zi-ZZOz TO-Zi-ZZOZ 8Z-ii-zzOZ SZ- Ell -ZZOZ ZZ-ii-ZZOZ 6T-11 i-ZZOZ 9l-ii-ZZOz £T-Li-ZZOZ S OT-ti-ZZOz CO-1T-ZZOZ bc-i i-ZZOz TO-Si-ZZOZ 6Z-Di-ZZOZ 9Z-0 i-ZZOZ £z-Oi-zzOz oz-oz-zzcz LT-Oi-ZzOZ bT-of-ZZOZ TT-OZ-ZZOz 80-Oi-ZZOZ 50-Oi-ZZOZ ZO-Di-ZZOZ 6Z-60-ZZOz 1R-15 90 -Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 1R-15 2022-12-19 518 110 -408 IA KUP INJ WELLNAME 1R-15 WELLBORE 1R-15 Coma0hilhps Well Attributes Max Angle B MD TD Flank- Wellbore APWWI Wellhore 5lalue Icl (°) MO(IIKBI Aci Bim(NKON Alaska, Inc. K PAR KRIVER NIT 21 J IN 1.96 5,550.00 ],4220 comnaupv Cmmmeni X251ppm) Odle MnWvlbn Entl gNe KFUndad Rq Rekece Oa@ SSSV: TRDP Lest WO: 36.59 811311985 iillesteai 11:.1:38 AM I Last Tag Vaal achemcec N -,I) Annotation WMh M(BI End Dab Wellbore Lad and, By Last Tag: SLM ],052.0 A&2014 1R-15 inpanst HANGER, ns Last Rev Reason Ammannon End Date Wellhore Lvi Metl Ry Rev Raason; Set RBP p" "'Li 1R-15 spilcM1 Casing Strings CVIng Deac,lptlm OO and IO llnl Top (M(R) 50 Dep[n MKR) se[Depin (IVO)... WNLen (I... GraI Top Th nal CONDUCTOR 16 1506 38.0 115.0 1150 62.50 HAO WELDED "C�DUCT�-:. Casing Description OD lin) ID (in) Top Nedi Sel Deptn(Ne.t 58D. (NOL.. (L.. Oratle Tap TM1reM 36Len SURFACE 9518 892 37.0 3,8042 3,803.) 3fi.00 J-55 BTC Gaaing Mwripfim OO lin) IO lin) Top (M(6) Set Deptn lflKe) art DepM (NDL.. WVLan(L.. Oratle Tap TM1reatl PRODUCTION ] 6.28 35.5 ],39fi.8 6,811.2 2fi.00 J-55 BTC Tubing Strings Tubing Oeccrpoiom suing Ma...101inl Top (Deal art Depin lit. Set Di (NOL( Wt pren) Grate Top Lome ion TUBING 3.5x2.8]5 3112 2.99 2].5 6,953.4 54fi3.9 9.30 J-55 EUEBRD 6PFETV YLN I.]W.] Completion Details GAS LIFT;1811.5 Top(ND) Tap Incl Nominal Top MKB) (11KD) M man Dea com ID bad GAS UFT; al"'i 27.5 27.5 0.00 HANGER FMC GEN III TUBING WINGER 3.500 1,]66.] 1,766.6 0.40 SAFETYVLV BAKER FVL SAFETY VALVE 2.813 6,744.6 6,302.8 39.56 PER BAKER PBR 3.000 6,758.3 6,313.4 39.58 PACKER BAKER FHL PACKER 3.000 6,835.0 6,372.6 39.53 BI -AST RINGS BLAST RINGS (2) 2.992 GAS UFT; 3,FOR 4 6,913.8 6,433.3 39.45 NIPPLE AVA BPL LANDING NIPPLE 2.750 SUNEACE;57aa.eD1.2- 6,916.7 6,435.6 39.44 XO Reducing CROSSOVER 3.5 x 2.875 2.875 GAS UFT; 4.215.3 6,924.4 8,441.5 39.42 LOCATOR LOCATOR 3.000 6,925.4 642.3 39.42 PACKER BAKER DB PACKER 3.250 C6ASUW;a.5ace 6,9452 fi,45].fi 39.38 NIPPLE CAMCODNIPPLENOGO 2.250 6,952) Q463.4 39.3fi 505 CAMCO SHEAR OUT SUB 2.441 GAS LIFT; 4,80.1 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) GAS LIFT; 5.311.8 Tap Top ITV.) Topincl dmill (11KB) 1°I pea Com Run Date ID (in) SN GAS UFT; 5,721.] 6,790.0 6,337.8 39.56 PLUG 2]2"RBP(]:9'01 5`17/2021 0.000 CPP35198, GPEG35014 GASLrT.6.1M.4 6,913.8 6,433.3 39.45 SLEEVEC AVA 2]5' BPI SLEEVE SET WITH 2: 5`32" PORTS 3`812009 2.300 I69ECTION66 7,162.0 6,641.7 38.42 FISH CSG Y Retrieved Latch Only; Body is in]" 112811985 0.000 Spa PBR, 6,7!0.6 Dens ToMT(TVD) (anotaM PACKER; 6,7SA3 Top(61.0 .K.) nm D.198 ) Type Com BIm885.0 rates) 16,39 (6,411 Ll 6,861.0 6,885.0 6,382.6 6:11.1 1R-15 C-1, 1R-15 t0I9I1885 1201PERF 5"HJ II Csg Gun; 120 tleg. ph PLJ a c.b 7,046.0 7,053.0 6,535.7 6,541.1 ATT 1R-15 10/911985 4.0 PERE 4"HJIICsg Gun;90dag.ph INIECTION;679 7.058.0 7,098.0 6,545.0 6,576.1 A -TA -3,1R-15 10/911985 4.0 PERE 4"HJIICsg Gun;90tleg.ph 7,164.0 ],1]3.0 6,627.6 6,634.7 A-2, 1R-15 101911985 4.0 IPERF 4" HJ II Csg Gun; 90 deg. ph Notes: General & Safety Ent 0We Mnotmon 2I2I2015 NOTE:SLOW IA X OA COMMUNICATION IPENF s.�t.oe,ae5.0- 10/18`2010 NOTE: View Schematic wl Alaska Schematic9.0 NIPPLE; 6913.6 SLEEVENde C: B. LOCATOR;9.Ii PACKER; 65250 NIPPLE'.6.845.2 SOS: %a R.] IPERF',],0GG705GO0 /PERF', 7.N8470000 HERE 7,I..0 -],1T1.0- FISH; 7 1820 PRODUCTION: S5.5 -7386,e Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1851520 Type Inj N Tubing 135 3000 2870 2830 Type Test P Packer TVD 6313 BBL Pump 0.5 IA 518 580 592 590 Interval O Test psi 3000 BBL Return OA 88 90 90 90 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1851520 Type Inj N Tubing 100 437 3300 106 Type Test P Packer TVD 6313 BBL Pump 3.0 IA 590 435 3215 107 Interval O Test psi 3000 BBL Return OA 90 428 3185 106 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1851520 Type Inj N Tubing 95 95 95 95 Type Test P Packer TVD 6313 BBL Pump 1.2 IA 2 4 4 4 Interval O Test psi 1800 BBL Return OA 90 1800 1740 1720 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 1R Pad Miller 12/18/22 Notes:Diagnostic MITT Notes: 1R-18 1R-18 Notes:Diagnostic MITIA 1R-18 Notes:Diagnostic MITOA Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)MIT KRU 1R-15 diagnostic MITs 12-18-22 (002) C:\Users\aebell\Desktop\July 2021 Data Drop\CPA Data Drop 07022021\2021-06-28_20156_KRU_1R-15_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 20156 KRU 1R-15 50-029-21387-00 LeakPoint Survey 28-Jun-21 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 FTP ______________________________ ______________________________________ Print Name 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 Abby Bell ___________________________________ e 37' (6HW By Abby Bell at 12:45 pm, Jul 02, 2021 Originated:Delivered to:28-May-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1D-107 50-029-22983-00 n/a West Sak Plug Setting Record Field- Final 4-Apr-21 0 1 2 1D-116 50-029-22915-00 907099354 Kuparuk River Leak Detect Log Field- Final 17-Apr-21 0 1 3 1D-116 50-029-22915-00 907100262 Kuparuk River Multi Finger Caliper Field & Processed 18-Apr-21 0 1 4 1D-116 50-029-22915-00 907128193 Kuparuk River Packer Setting Record Field- Final 2-May-21 0 1 5 1D-116 50-029-22915-00 907099354 Kuparuk River Plug Setting Record Field- Final 17-Apr-21 0 1 6 1E-14 50-029-20751-00 907087089 Kuparuk River Leak Detect Log Field- Final 12-Apr-21 0 1 7 1E-14 50-029-20751-00 907087419 Kuparuk River Multi Finger Caliper Field & Processed 12-Apr-21 0 1 8 1E-14:50-029-20751-00 907109076 Kuparuk River Packer Setting Record Field- Final 28-Apr-21 0 1 9 1F-06 50-029-20820-00 907045708 Kuparuk River Packer Setting Record Field- Final 2-Apr-21 0 1 10 1R-15 50-029-21387-00 907155263 Kuparuk River Plug Setting Record Field- Final 17-May-21 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 06/01/2021 PTD: 1851520 E-Set: 35186 MEMORANDUM TO: Jim R2� 5661,ldZ P.1. Supperer visor 1 CJ 1 FROM: Austin McLeod Petroleum Inspector Well Name KUPARUK RIV UNIT IR -15 Insp Num: mitSAM210506070627 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, May 13, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. IR -15 KUPARUK RIV UNIT IR -15 Src: Inspector Reviewed By: P.I. Supry Comm API Well Number 50-029-21387-00-00 Inspector Name: Austin McLeod Permit Number: 185-152-0 Inspection Date: 5/52021 , Packer Depth —I —.r Well IR -I5 Type Inj W ,ITVD 6318 1,111) 1851520 ''Type Test SPT Test 1,s 1800 13131, Pumped: 0 ` BBL Returned: 0.5 Interval REQVAR !P/F P Notes: 2 .car MITOA to 1800 psi. A10.2B.088 V Pretest Initial 15 Min 30 Min 45 Min 60 Min Tubing 2486 - 2486 2481 2495 - IA 900 goo 800 _800 A840 2005 1960 - 1940 Thursday, May 13, 2021 Page 1 of I MEMORANDUM TO: JimRegg/ Jellgll P.1. Supervisor FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, May 13, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. IR -15 KUPARUK RIV UNIT IR -15 Sre: Inspector Reviewed By: P.I. Supry Comm Well Name KUPARUK RIV UNIT IR -15 API Well Number 50-029-21387-00-00 Inspector Name: Austin McLeod Permit Number: 185-152-0 Inspection Date: 5/5/2021 Insp Num: mitSAM210506070128 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well — -- 1R-15 ---W 63-1& +Tobin 2483 TYPe Inj TVDp� i PTD 1851520 T e Test sPT.!TCSt sl ✓ IA 770 2483- 2482--- 2484 - 3300 Joao ' � 2980 --T — -- ass llsa 1114 ' 1106' BBL Pumped: BBL Returned: 3.4 OA _ 1 P _� --1----_ Interval..-- REQVAR _ Ir/F F Notes: 2 year MITIA to MAIP. Alt) 26.088. S/I / Thursday, May 13, 2021 Page I of I Wallace, Chris D (CED) From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Wednesday, May 5, 2021 11:28 AM To: Wallace, Chris D (CED) Cc: Earhart, Will C Subject: KRU 1 R-15 (PTD 185-152) Report of failed MITIA Attachments: 1 R-15.pdf; -fi4-1 90 day TIO trend 5.5.21.pdf Chris, KRU 1R-15 (PTD 185-152) (AIO 26.088) Failed it's State Witnessed MITIA this morning. The well will be shut in and freeze protected as soon as possible and diagnostics will begin within the next few days. I have not received the test numbers from the field yet, but the 10-426 will be submitted once that information has been received. A wellbore schematic and 90 day TIO trend are attached. Please let us know if you have any questions or disagree with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg � DATE: Tuesday, July 2, 2019 P.I. Supervisor IAC �C, 7�11SUBJECT: Mechanical Integrity Tests t ConocoPhillips Alaska, Inc. IR -15 FROM: Lou Laubenstein KUPARUK RIV UNIT IR -15 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry IZ NON -CONFIDENTIAL Comm Well Name KUPARUKRIV UNIT IR -15 Insp Num: mitLOL190701134040 Rel Insp Num: API Well Number 50-029-21387-00-00 Inspector Name: Lou Laubenstein Permit Number: 185-152-0 Inspection Date- 7/1/2019 ✓ Packer Depth Well 1R-15 Type Inj w -TVD 6318 PTD 1951520 Type Test SPT Test psi 1800 BBL Pumped: 0.5 "BBL Returned: 0.4 Interval RtpvAR ----- IP/F P , Notes: MI -OA to 1800 psi per AIO 26.088 Tuesday, July 2, 2019 Page 1 of I Pretest Initial 15 Min 30 Min 45 Min 60 Min Tubing, 2386 - 2386 - 2386 - 2386 " IA 1 1160 - 90 ' 1190 - 1180 —� — - —- OA 860 2020 1970 -il_,.- 1950 Tuesday, July 2, 2019 Page 1 of I MEMORANDUM State of Alaska Depth Alaska Oil and Gas Conservation Commission TO: Jim Regg •�/ /I 711G/t� DATE: Tuesday, July 2, 2019 P.I. Supervisor I\�iq SUBJECT: Mechanical Integrity Tests (f ConocoPhillips Alaska, Inc. PTD IR -15 FROM: Lou Laubensteln KUPARUK RIV UNIT IR -IS Petroleum Inspector _ 3000 - IA 7130 3300 ' _ 3190 3100 " Sre: Inspector 34 BBL Returned: Reviewed By: OA 410 680 680 680 P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IR -15 Insp Num: mitLOL190701133715 Rel Insp Num: API Well Number 50-029-21387-00-00 Inspector Name: Lou Laubenstein Permit Number: 185-152-0 Inspection Date: 6/30/2019 1 Tuesday, July 2, 2019 Page 1 of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min - --� Well IR -15 -- - �TYPe Inj w 1TVD --_. 63,18 - Tubing 2x75 2375 1,73, PTD 1 1851520 Type Test I - Seat p81 _ 3000 - IA 7130 3300 ' _ 3190 3100 " BBL Pumped: 34 BBL Returned: 3 1 OA 410 680 680 680 Interval', REQVAR 'iP/F P Notes: MIT -IA to maximum anticipated injection pressure per AIO 28.088 Tuesday, July 2, 2019 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg / // DATE: Monday,June 12,2017 P.I.Supervisor \ b[ 1 z,(e 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1R-15 FROM: Adam Earl KUPARUK RIV UNIT 1R-15 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv,J 1 — NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1R-15 API Well Number 50-029-21387-00-00 Inspector Name: Adam Earl Permit Number: 185-152-0 Inspection Date: 5/27/2017 Insp Num: mitAGE170528120010 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1R-15 Type Inj W TVD 6318 Tubing 2100 2100 . 2110 2110 - PTD 1851520 - Type Test SPT Test psi 1800 - IA 910 950 955 - 960 BBL Pumped: 0.5 - BBL Returned: 0.5 - 6 A7 610 2000 1970 - 1960- Interval REQVAR P/F P ✓1 Notes: MITOA Tested as per AIO 2B.088 SCANNED AUG 1 5 2017 Monday,June 12,2017 Page I of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,June 12,2017 TO: Jim Regg P.I.Supervisor Rem 6,f i 't SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1R-15 FROM: Adam Earl KUPARUK RIV UNIT 1R-15 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1R-15 API Well Number 50-029-21387-00-00 Inspector Name: Adam Earl Permit Number: 185-152-0 Inspection Date: 5/27/2017 Insp Num: mitAGE170528115005 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1R-15 • Type Inj W "ITVD 6318 ' Tubing 2100 2100 - 2100 2100 PTD 1851520 " Type Test SPT Test psi 3000 IA 1200 3300 3190 3165 . BBL Pumped: 3.3 BBL Returned: 3.1 • OA 672 872 . 864 - 860 Interval REQVAR P/F P ✓ Notes: MITIA. Tested as per AIO 2B.088 v SCANNED AUG 1 5L7u Monday,June 12,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,January 06,2016 TO: Jim Regg Supervisor �`6't/ )/l�F J/( SUBJECT: Mechanical Integrity Tests i CONOCOPHILLIPS ALASKA INC 1R-15 FROM: Bob Noble KUPARUK RIV UNIT 1R-15 Petroleum Inspector Src: Inspector Reviewed By: P.I.SuprvJ )1/4(1 . NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1R-15 API Well Number 50-029-21387-00-00 Inspector Name: Bob Noble Permit Number: 185-152-0 Inspection Date: 1/2/2016 Insp Num: mitRCNI60103163120 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IR-15 Type Inj ' W:TVD 6318 - Tubing 2110 . 2110 - 2110. 2100 - PTD L 1851520 Type Test SPT Test psi 1800 - IA 775 - 840 - 860 - 880- Interval REQvAR OA -— — P/F P v 532 2000 1960 - 1955- l Notes: MITOA per AIO 2B.088 to 1800 lbs SCANNEDr Wednesday,January 06,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,January 06,2016 TO: Jim Regg11141/ b �� P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1R-15 FROM: Bob Noble KUPARUK RIV UNIT 1R-15 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv., f2 NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1R-15 API Well Number 50-029-21387-00-00 Inspector Name: Bob Noble Permit Number: 185-152-0 Inspection Date: 1/2/2016 Insp Num: mitRCN160103162543 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1R-15 Type Inj W TVD 6318 !Tubing 2100 ' 2110 - 2090 2100 , PTD 1851520 - Type Test SPT Test psi 3000 _' IA 940 3300 - 3170 1 3140. Interval REQVAR P/F P `/' OA 603 - 814 _ 797 - 789 - Notes: MITIA per AlO 2B.088 to maximum anticipated pressure of 3000 lbs 5CAI4t4ED Wednesday,January 06,2016 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday, May 25, 2011 Jim Regg P.I. Supervisor (e 5(0' Jo( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1R-15 FROM: Chuck Scheve KUPARUK RIV UNIT 1R -15 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J O2-- NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1R -15 API Well Number: 50- 029 - 21387 -00 -00 Inspector Name: Chuck Scheve Insp Num: mitCS110522090731 Permit Number: 185 -152 -0 Inspection Date: 5/21/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1R -15 ' Type Inj. i N 1 TVD 6318 IA 800 2145 ' ( 2110 2100 ' P.T.DT SPT Test psi 1580 ' OA 350 350 350 350 Interval P /F, P , Tubing; 750 750 j 750 750 Notes: }« nn�� t ,�.:�,,NN D M A`r 2' 6 ' O 1 Wednesday, May 25, 2011 Page 1 of 1 • COn ~ . . ocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 31, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 r~;;~; Y~~ w„~". ~~. Y if s,l.J4~. ... r. ~~.o , , 4u+eY~` ., Dear Mr. Maunder: • SEP 0 2 2009 Al~~k~ A~I ~ f~s ~~nss.CornPnission AflGhQ~~ Jt'' • ~ ~ `~- `~ ~ 5 1~~,~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 15~' and 23rd 2009, and the corrosion inhibitor/sealant was pumped August 27~', 28;~ and 29~' 2009. 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, .~-' ~~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor _-- , ~ ~ . ' ~ ~ <, ~ +.~.; ~ ~ . ' C `~`a, ~. . ~ ~ f __ w ~ . ~ . r . _ .~ . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (70-404) Kuparuk Field Date 8/29/09 1R PAD Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top af cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls ft al 1 R-01 B 50029214040200 2001560 13'7" 2.0 26" 8/15/2009 5.1 8l27/2009 1 R-02 50029214050000 1851760 80' 13.30 23" 8/23/2009 4.7 8/28f2009 1 R-03A 50029214060100 2000210 15' 3.00 27" 8/15/2009 5.3 8/28/2009 1 R-04 50029214070000 1851780 15'2" 3.00 26" 8/15/2009 5.1 8J28/2009 1 R-05 50029213300000 1850700 20'9" 2.20 23" 8/15/2009 3.8 8/28/2009 1 R-06 50029213310000 1850710 14' 2.00 23" 8/15/2009 3.8 8/28/2009 1 R-07 50029213320000 1850720 44' S.00 24" 8/15/2009 4 8/28/2009 1R-OS 50029213330000 1850730 8' 1.00 21" 8/15/2009 13.7 8/28/2009 1 R-09 50029213500000 1850950 9' 1.20 25" 8/15/2009 4.3 8/28/2009 1 R-10 50029213510000 1850960 32' 5.40 22" 8/15/2009 3.4 8/28/2009 1 R-11 50029213520000 1850970 47' 6.00 38" 8/15/2009 13.9 8/28/2009 1 R-12 50029213530000 1850980 38' 6.00 24" 8/15/2009 4 8/28/2009 1 R-13 50029213850000 1851500 10' 0.50 25" 8/15/2009 4.3 8/29/2009 1 R-15 50029213870000 1851520 21'4" 4.00 35" 8/15/2009 12 8/29/2009 1R-16 50029213880000 1851530 12'6" 9.00 21" 8l23/2009 3.8 8/29/2009 1R-17 50029222120000 1911140 20" N/A 20" N/A 4.4 8/28/2009 1R-18 50029221880000 1910870 9'4" 1.20 21" 8/15/2009 3.7 8/28/2009 1 R-19A 50029221850100 1910850 18" N/A 18" N/A 10.2 8/29/2009 1 R-20 50029222070000 1911080 8'4" 2.00 19" 8/15/2009 11.3 8/29/2009 1R-22A 50029222060100 1990490 16" N/A 16" N/A 9 8/29/2009 1 R-23 50029222000000 1911010 18'8" 2.30 39" 8/15/2009 13.9 8/29/2009 1 R-25 50029221530000 1910470 7'4" 1.50 26" 8/15/2009 5.1 8/27/2009 1 R-26 50029221930000 1910920 7' 3.50 38" 8/23/2009 13.9 8/28/2009 1 R-27 50029222010000 1911020 18" N/A 18" N/A 5.1 8/28/2009 1 R-29 50029221950000 1910940 18" N/A 18" N/A 4.1 8/28/2009 1R-35 50029230500000 2012100 18" N/A 18" N/A 5.3 8/29/2009 1 R-36 50029230570000 2012270 19" N/A 19" N/A 5.3 8/29/2009 t111~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # s ~'.t ' i1~.~~:{ ~ ' f ~ ~ ~~~ .. ~ ~„ L „ r, ".. Log Description NO.5203 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 3F-03 ANHY-00070 INJECTION ' 20-03 ANHY-00075 PROFILE - ~ e PRODUCTIO 04/04/09 1 1 E-29 3G-13 3F-18 B04C-00030 ANHY-00079 B04C-00031 N PROFILE _ PRODUCTION PROFILE l 9 INJECTION PROFILE {) _ ~/ PRODU 04/10/09 04/14/09 04/15/09 1 1 1 1®-117 8148-00027 CTION PROFILE / INJECTION PROF 04/15/09 1 1D-128 AYS4-00057 ILE Z, - ~-- INJECTION PROFILE 04/16/09 04/16/09 1 1 1H-21 1 D-120 B14B-00028 AYS4-00058 PRODUCTION PROFILE L INJECTION P 04/17/09 1 2K-22 9E-15 AYS4-00059 AYS4-00061 ROFILE IBP/SBHP - INJECTION PR 04/17/09 04/18/09 1 1 1Y-04 3F-02 1 G-04 AYS4-00071 AYS4-00063 8146-00036 OFILE Z. - INJECTION PROFILE PRODUCTION PROFILE ~ - SBHP SURVEY ` ° 04/20/09 04/28/09 04/22/09 1 1 1 iR-03A AYS4-00063 S, L C~ SBHP SURVEY i 3 -L (` ~tg(b -(~~ ~ ~ - 9L/( 04/23/09 04/23/09 1 iG-06 . , ~ 1 6146-00035 SBHP SURVEY ~~ l ~~ .. ~ ~ G ~ 04/23/09 iR-10 6146 00031 ~~ ~ 1 2F-02 1R-15 - AYS4-00060 8146-00032 SBHP SURVEY - ~~ c INJECTION PROFILE ~ L+ .. j U SBHP SURVEY. - ~ `- ~ 04/20/09 04/19/09 04/20/09 1 1 1 04/30/09 i Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 07/23/07 Schlu1l~el'ger NO. 4336 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth dUL 2 5 ZOOï Oil 8, Cons. Commission 5CANNED JUL 2 7 2001 Anchorage Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 U~ /1fç/S"fJ Field: Kuparuk Well Log Description Date BL CD Color Job# ('!:; 2M-20 11629044 PRODUCTION PROFILE 07/11/07 1 3M-20, 11665456 INJECTION PROFILE 07/13/07 1 2M-27 11665457 INJECTION PROFILE 07/14/07 1 1 R-20 11632727 LDL 07/12/07 1 2M-17 11632731 INJECTION PROFILE 07/14/07 1 3M-27 11632732 LDL 07/15/07 1 1R-15 11632734 INJECTION PROFILE 07/17/07 1 2L-327 11665460 TEMPERATURE SURVEY 07/17/07 1 2V-08A 11665459 USIT 07/16/07 1 2Z-16 11665458 SCMT 07/15/07 1 2N-343 11665463 INJECTION PROFILE 07/20/07 1 1L-07 11632735 INJECTION PROFILE 07/20/07 1 1A-09 11632736 INJECTION PROFILE 07/21/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . . . MEl\tl0RAND UM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor Kc?11 k( 4( r) 7 L DATE: Friday, 'vlay It, 2007 SlJBJECT: Mechanical Integrity Tests C01\OCOPHJLUPS ALASKA I~C FROM: Bob Noble Petroleum Inspector IR·15 KlJPARUK RIV UNIT tR·15 -'}- ~" V=' \ct:J Src: Inspector Reviewed By: P.I. Suprx-~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT lR-15 Insp Num: mÍtRCN07051 021 0053 Rei Insp N urn: API Well Number: 50-029-21387-00-00 Permit Number: 185-152·0 Inspector Name: Bob Noble Inspection Date: 5/9í2007 Packer Well I 1R-15 ¡Type Inj. : W ' TVD I __,~_...l I I ~:D' 1851520 iTypeTest ':~~ !_ !~st psi ' Interval 4YRTST P/F p/ Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 6317 IA 1280 2500 2450 I 2440 i ! - -- -~"- ___----,---- ,~_.l-c_~ 1579,25 I OA i 650 650 650 ; 650 -----_..~_.- i _ ------L-____~___ Tubing: 1750 1750 1750 I 1750 I I . Notes: iCANNED JUN 0 6 2007 Friday, May 11,2007 Page 1 of 1 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk I ~G- /5:)- Schlumberger RECEiVED NO. 3615 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth r'-'-' 2 1.. Znn¡::; J t.t... U''';''''' ~ Ci! & Gas C-oos. C-ûmíT;¡~jCf1 And1oæ9-e Field: ~,,-" Well Job # Log Description Date BL 1 Y -19 11144040 PIEZO SONA TOOL 11/19/05 1 1Y-27 11072935 PRODUCTION PROFILE W/DEFT 11/22/05 1 2D-09 >~ « " ",} 11072933 SBHP SURVEY 11/18/05 1 <:1~-~5:~ r<J 11072932 SBHP SURVEY L;¿~ 11/18/05 1 3F-05 N/A PRODUCTION LOG 11/13/05 1 1 L-25 11056689 SBHP SURVEY 09/14/05 1 3F-12 11057064 INJECTION PROFILE 11/06/05 1 3H-01 11056685 PRODUCTION PROFILE W/DEFT 09/10/05 1 1 Q-16 11141232 PRODUCTION PROFILE W/DEFT 12/01/05 1 1 E-33 N/A GLS & BHP 12/04/05 1 3N-13 11141234 INJECTION PROFILE 12103/05 1 2N-329 11141236 SLIM CHFR 12/08/05 1 1 C-07 11141231 PRODUCTION PROFILE W/DEFT 11/30/05 1 1 Q-09 11141233 INJECTION PROFILE 12102/05 1 3B-16 N/A INJECTION PROFILE 12/08/05 1 1 Q-06 N/A PRODUCTION PROFILE W/DEFT 12/10/05 1 "-~ 2A-21 11141237 INJECTION PROFILE 12/12/05 1 2A-24 11144049 PROD PROFILE W/DEFT 12/15/05 1 1 Q-1 01 11144044 MDT 11/24/05 12/20/05 Color CD 1 DATE:ð~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. SIGNED: tjCANNED J~\N 3 0 2006 ; iMEMORANr)UM Stat - of Alaska. ALASKA OIL~-a'D GAS CONSERVATION COMMIS~.~3N dTO: C.V. Chatterton Chairman TH RU: Lonnie C. Smith .':; . -/ /.t .. Commissioner ' " FROM' Doug Amos Petroleum Inspector DATE: November 20, 1986 FILE NO.:. D.'ADA 64 - ~.- .-, . ;,,, -~ , ,z~ . ._ TELEPHONE NO.: · ..,. -- :;';~i . SUBJECT: Mech ·Integrity Test 'ARCO KRU 1R-15 -"-Kuparuk River Field -, ,, SundaY~ November 9~ 1986: While witnessing the six-month safety ~alve test at ARCO KRU CPF #1, I was contacted by ARCO ' representative Les Bailey and asked to witness the MIT on 1R-15 water injection well. This well was successfully tested in accordance with AOGCC regulations 20 AAC 25.030(g), 25.412(c), and 25.252(d), and Area Injection Order No. 2. ,. I filled out an AOGCC MIT form which is attached. In summary, I witnessed the successful mechanical integrity test on. ARCO KRU water injection well 1R-15. 'r-'.-...:.-.. _~'-. , -. ,.:'~:. ~ ~ --. Attachment ,. 02-001 A (Rev 10-84) ALASKA OIL AND GAS CONSERVATI~ (I~MISSION MECHANICAL INTEGRITY TEST PRE~: STAR~ 15 MIN 30 MIN *P *I TYPE OF PKR CASING TBG REQ TBG ~ TIME TIME WELL I *S .-- ANFdI/]S TVD SIZE/WT/GRADE SIZE TEST CSG TBG TBG TBG *M ~N FLUID MD PRESS PRESS CSG CSG CSG , PRESS PRESS PRESS '~'~-I~~ .~ Dt~6& ~ 7";Z&t.J'"6~ ~/Z'/ 1~75 ' ~o .' ~o ZSo z~ ii i ii *TUBING III]FL'l/ON FLUID: ANNULAR FLUID: P - PRODUCE WATER INJ DIESEL S - SALT WATER INJ GLYCOL M - MISCI]SX~ INJECTION SALT WATER I - ~ DB~LTNG MUD ::~,'~.., :..:., . . , . ~ ?.~.. . . ..~ : . . 20 ~ 20 .~C 20 .~¢ 2.5.252(d) · . SGANNgD DF..G 1 MEMORANDUM TO: Dan Seamount Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: September 28, 2000 THRU: Blair Wondzell P.I. Supervisor (.~ FROM: John Crisp ~(~,,,, Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests Phillips Alaska Inc. 1 R Pad 03,06,08,10,15 · Kuparuk River Unit Kuparuk River Field P.T.D.I 1851770 Notes: P.I.D.I 1850710 Notes: P.T.D.I 1850730 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. Type lnj.I N [ T.V.D. 16403 I Tubing 11075 11075 11075 I~0~ 4 TypetestI P ITestpsil 1601 I CasingI 1150I 161o1.16o5I ~6OOl PIE Type testI P I Testpsil 1567 I CasingI 1.210 I 2000 I 1960 I 1950I P/FI_P' Inj.I S I T.V.D. I 6380 I Tubing 12400 I=.=~ !=.=~ I~.=* I,nterva,I 4/ Typetestl P I Testpsil 1595 ICasingl 1240 I 1908' I 1890 I 1875 I PIP I P1 Type _ We,I! 1R-10 I Type,nj.I G I T.V.E~. 16257 I Tubing 13625 I ~'~ I'~ I~ I'nte~va'l 4 ] P.T.D.I 1850960 ITypetestl. P I Testpsil 1564 l CasingI 1000I 2120'I 2080I 2070 I P/F ! --P'~ Notes: / WellI1R-15I Typ. e,nj.! S I T.V.D. 16318 I Tubing 12380 ! :~350 12350 I=~0 I,nterva. I 4 / P.T.D.! 1851520 ITypetestl . P I Testpsil 1580 I Casingl 1325 !,._1925 I 192~ '1 1.940 I P/F ! P t Notes: / Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. ' S = SALT WATER IN J, N = NOT INJECTING Type Tes[ M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Vadance W= Test during Workover O= Other (describe in notes) Test's Details I witnessed 5 successful MIT's on 1R pad in KRU. Testing done in safe & efficient manner by Phillips rep. Jerry Dethlefs. : .I.T.'s performed: 5_ Attachments: none Number of Failures: 0 Total Time during tests: 2 hrs. MIT report form 5112/00 L.G. MIT KRU 1Ra 9-28-00jc.xls .-. 10/3/00 STATE OF ALASKA "'-'" ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: 2. Name of Operator ARCO Alaska. Inc. 3. P. 4. Operation Shutdown M Pull tubing Alter casing Stimulate __ Plugging Perforate m Repair well Pull tubing Other X Address O. Box 100360, Anchorage, AK 99510 Service Location of well at surface 456' FSL, 144' FWL, Sec. 17, T12N, R10E, UM At top of productive interval 1257' FSL, 1242' FWL, Sec. 17, T12N, R10E, UM At effective depth 1466' FSL, 1474' FWL, Sec. 17, T12N, R10E, UM At total depth 1512' FSL~ 1520' FWL~ Sec. 17~ T12N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 13. 5. Type of Well' Development X Exploratory _ Stratigraphic _ 7 4 2 0 feet Plugs (mea~sured) 6 8 3 3' feet 14. Effective depth: measured 7311 ' feet Junk (measured) true vertical 6747' feet ~ Casing Length Size Cemented Structural Conductor I 1 5' I 6" 225 Sx CS II Surface 3804' 9 5/8" 808 Sx PF"E" III & Intermediate 310 Sx PF"C" Production 739 7' 7" 300 Sx Class G & Liner 250 Sx PF"C" Perforation depth: measured 6861 '-6885', 7046'-7053', 7058'-7078', true vertical 6390'-6409', 6533'-6538', 6543'-6573', Tubing (size, grade, and measured depth) 3 1/2" J-55 9.3 #/FT @ 6953' MD-RKB Packers and SSSV (type and measured depth) Baker 'FHL' @ 6752'~ Baker 'DB' @ 6919', Baker 'FVL' SSSV @'1760 Stimulation or cement squeeze summary Convert from producer to water injector. Intervals treated (measured) Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation 6. Datum elevation (DF or KB) RKB 82 7. Unit or Property name Kuparuk River Unit 8. Well number 1R-15 9. Permit number/approval number 85-152/537 10. APl number 5o-029-21387-00 11. Field/Pool Kuparuk River Oil Pool 15, Attachments Copies of Logs and Surveys run Daily Report of Well Operations X M~sured depth True vertical depth 115' 115' 3804' 3804' 7397' 6815' 7173'-7164' MD-RKB 6631 '-6624' TVD-RKB RECEIVED feet FEB 1 5 1990 Alaska 0ii & Gas Cons. C0mfft ,ss ¢ Anchorage Reoresentative Daily Average Production or Iniection Dat~ OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 1225 1436 0 1241 - 6000 1080 16. Status of well classification as: Suspended Oil Gas ~ , , 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~_ ~-~ /~ ~..¢)~~Title'~ Sr. Operations Engineer Form 10-404 ~ev 08/15/88 Tubing Pressure 188 1150 Service Water I nj Date ~' SUBMIT IN DUPLICATE ARC Alaska, nc. ORILLSITE STATUS REPORT DATE: il- ~/-~ TIME: ~--~-OO DRILLSITE I"~% S WELL T Z PRODUCTION WELL STATUS GAS LIFT STATUS NO. A O ... T N U E FTP TEMP!CHOKE 7" CSG 10"CSG GAS INJ METER WELL _ S PSi F BEAN PSI PSi TEMP HCF TOTAL SI/HR REMARK I~ J 150 t~ ~,_~ ~ 5~ ,b ,~ 495 1~ i.~q~ ~3zvfl , . TOTAL ~l~ ' WELL I Z MAXIMUM' ' INJECTION WELL STATUS ALLOWABLE NO. N O .... U N INJ ~ CHOKE CHART TOTAL TOTAL E PSI/ WH TEMP 7"CSG 10"CSG METER CALC INJ INJ WELL / PSI F BEAN PSI PSI TOTAL MMSCF BBLS MMSCF SI/HR I ~ ,L GAS CORR FACTOR = ,8q8'~ HEADER PRESS = &IGO TOTAL FOR D.S. DRILL SITE PROD TEST pROD TEST BATH BLANKET RUN TIME HEATER TEMP TEMP PSI PSI TEMP GAS PSI ,, CHEMICALS TYPE GAL/DAY /O COMMENTS: ARC 3 Alaska, lnc. {) DRILLSITE STATUS REPORT DATE: I ! ' ~ ~ --~& TIME: S T Z PRODUCTION WELL STATUS GAS LIFT STATUS WELL NO. A O T N U E FTP TEMP CHOKE 7" CSG 10"CSG GAS INJ METER WELL S PSI F BEAN PSI PSI TEMP HCF TOTAL SI/HR REMARKI ~ ~o t5 15'o b-b ~o? /a3o ~0 5'0 TOTAL MAXIMUM INJECTION WELL STATUS /~_~_.~_~~ WELL I Z ALLOWABLE NO. N O J N INJ ~ CHART TOTAL TOTAL E PSIJ WH TEMP CHOKE 7"CSG 10" CSG METER CALC INJ INJ WELL /" PSI! F BEAN PSI PSI TOTAL MMSCF BBLS MMSCF SI/HR ~ ' , GASCORR FACTOR = HEADER PRESS = /~5'~ TOTAL FOR D.S. DRILL SITE PROD TEST PROD TEST BATH BLANKET RUN TIME CHEMICALS HEATER TEMP TEMP PSI PSI TEMP GAS PSI TYPE GAL/DAY OUT /&7 13'/ ldO) 17'7 .~ , ! I COMMENTS: OPERATORS SIGNATURE: ~"~~ STATE OF ALASKA '~' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate __ Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 456' FSL, 144' FWL, Sec. 17, T12N, R10E, UM At top of productive interval 1257' FSL, 1242' FWL, Sec. 17, T12N, R10E, UM At effective depth 1466' FSL, 1474' FWL, Sec. 17, T12N, R10E, UM At total depth 1512' FSL, 1520' FWL, Sec. 17~ T12N, R10E, UM 12. Present well condition summary Total Depth: measured 7 4 2 0 feet true vertical 6833' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 82 7. Unit or Property name Kuparuk River Unit 8. Well number 1R-15 9. Permit number/approval number 85-152/537 10. APl number so-02~)-21387-00 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 7311 ' feet Junk (measured) true vertical 6747' feet Casing Length Size Cemented Structural Conductor I 1 5' 1 6" 225 Sx CS II Surface 3804' 9 5/8" 808 Sx PF"E" III & : Intermediate 310 Sx PF"C" Production 73 9 7' 7" 300 Sx Class G & Liner 250 Sx PF"C" Measured depth True vertical depth 115' 115' 38O4' 38O4' 7397' 6815' 13. Perforation depth: measured 6861 '-6885', 7046'-7053', 7058'-7078', true vertical 6390'-6409', 6533'-6538', 6543'-6573', Tubing (size, grade, and measured depth) 3 1/2" J-55 9.3 #/FT @ 6953' MD-RKB Packers and SSSV (type and measured depth) Baker 'FHL' @ 6752'~ Baker 'DB' @ 6919', Baker 'FVL' SSSV @ t760 Stimulation or cement squeeze summary Convert from water injector to water and gas injector. Intervals treated (measured) Treatment description including volumes used and final pressure 7173'-7164' MD-RKB 6631 '-6624' TVD-RKB R:F¢ IVFD FEB 1 5 ]990 AlasEa 0il & Gas Cons. C0mmissi0_B Anchorage 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 5697 1030 2260 13,679 - 1880 3825 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. StatUs of well classification as: Oil _ Gas Suspended Service WAG Inj 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned ~~ ~ ~~~/~'-~~ Title Sr. Operations Engineer Form '10-404 R~(-'(~ 06/15/88 ARGU AlaSKa, Inc. V CPF -/ Date . ,..,_..,2 ~ Time. Status Production Well Status Gas Lift Status Shut-In Well P.T. or TP Choke Temp Last H=S CSG Pre~ssure PSI Gas Inj. Rate # si Zone PSI Bean oF WC% PPMI 7" 10" Temp MeterTotal MSCFD Hfs Reason · - _ q t'°. /z,~ 153._ /../¢ ~ 1~ 4/~. ?'7 ~/~z~ , . , . , . , . -' . . Total //- 0 0 8 < fA S't~F - ~" '-" - "- Injection Well Status ' ' Shut-In Well Gl, PW Inject.Pressure PSI Temp Choke CSG Pressure PSII Meter I Injection Rate # or SW Zone Allowable Actual OF Bean .71.' 10" TotalI BBLSI.Da.y MMSCFD Hrs. Reason __ , - Total / ~/~ I ., SWl Total ,,/~. /~' PWI Total. Drillsite Coil Temperature °F Coil Pressure P~I Bath Blanket Heater Prod Test Prod Test Temp. Gas PSI Run Time ~n /D.,.(., (. ~ ,,, ~0 /~ Out / d --.2 / qr~ ~ ~z~ 17¢ .,t./ ,o .Z./._~ 2-¢ Headers Pr~)duction Water?Injection Gas Injection G~s Lift Drain Pressure ,/...~ ~_~ ..3 ~ ~ (', ,/~ ¢¢ 1-8: Temperature Comments Operater's Signature ~ ~', ~. -~. ~ // Chemicals Type I Gal/Day '7'T' / ,~1 ~ Tank: MeohlDiesel Level I Temp. ¢ "f" 7~' ARCO Alaska, Inc. Date. ,_,,._,..'"/'- "~ CPF ~ St'at~s ' ' Production Well Status Gas .Lift Status Shut-In Well~ P.T. or' TP C~oke Temp Last H=S CSG Pressure PSI Gas'" Inj, Rate # SI Zone PSI Bean OF WC% PPM 7" 10" T.ernp Meter Total M$CFD Hfs Reason ~/~ , , Total ~, 7~1 Status Injection Well Status [ Shut-In Well!Gl, PW Inject. Pressure PSI Ternp Choke CSG Pressure PSI Meter Injection Rate I # orSWZone Allowable Actual OF Bean 7"I 10" Total BBLS/Day MMSCFDiHrs. Reason / I /o ~1 ~ /~ ~o ~ ~. /oo~~ ,~ i,~i ~ ~ /~ ~1 ~ -- ~o ~ .~ ....I~4 q.~.~ Total /~,g g~ /~.~ SWI Total / ~l &'~'~ PWI Total Drillsite Coil Temperature OF Coil Pressure PSI Bath Blanket Heater Prod Test Prod Test Temp, GasPSI RunTime ~n / ,,4 7~' I ~... ~ 7"/' [ Out 17G /5"~ I~.o /4,1 ;=~-(" ~-~ =fi/ ., . Chemicals Headers Production Water Injection Gas Injection" I Gas Lift I Drain' Pressure /5~,~ ;Z~O ~,,J,ke--,t.,) ~000J /~0! 1-8: Temperature J '7~ J , 9-16: Tank: Meoh/Diesel Temp. Comments Operator's Signatb-'~'=:~~~ ~~ ARCO Alaska, Inc. Date: August 19, 1988 Transmittal #: 7264 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge-receipt and return one signed copy of this transmittal. 1 G- 14 Kuparuk Well Pressure Report 8 - 08 - 88 Amerada 3 H- 14 Kuparuk Fluid Level Report 8 - 1 2 - 88 Casing 1G-07 Kuparuk Fluid Level Report 8- 1 3-88 Tubing I R - 15 . Kuparuk Fluid Level Report 8 - 1 3 - 88 Tubing 1C-08 Kuparuk Fluid Level Report 8-1 2-88 Tubing /" ~a ."J~ ~ ~a.~ ~ons. t, ornrnissioa An~,hor,~ge Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: D&M State of Alaska Unocal SAPC Chevron Mobil ARCO Alaska, Inc. Date: August 12, 1988 Transmittal #: 7257 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 31 - 1 2 Kuparuk Well Pressure Report 6 - 1 5 - 8 8 Amerada 1G-04 Kuparuk Well Pressure Report 7-1 6-88 Amerada 2 T- 0 6 Post Frac Job Report 7- 1 8 - 8 8 Allo Frac A-10 3Q-15 Kuparuk Stimulation Summary 8-07-88 #230DS36QL 3J-10 kuparuk Stimulaiton Summary 8-08-88 #230DS36JL 2V-1 I Kuparuk Stimulation Summary 8-03-88 #230DS28VL 1 R- 1 5 Kuparuk Fluid Level Report 8 - 0 9 - 8 8 Tubing I F- 0 7 Kuparuk Fluid Level Report 8 - 0 9 - 8 8 Casing 2 D - 1 3 Kuparuk Fluid Level Report 8 - 0 9 - 8 8 Casing Receipt Acknowledged' DISTRIBUTION: D&M State of Alaska SAPC Chevron Unocal Mobil STATE OF ALASKA ALASi,., OIL AND GAS CONSERVATION COMN,._,$10N APPLICATION FOR SUNDRY APPROVALS Abandon Suspend ' ' Operation Shutdown 1. Type of Request: Time extension Change approved program L~. Plugging ..~ Stimulate Z] Pull tubing ' 2. ~j~r~ ~l(~r~t,Orlnc 3. Address PO Box 100360, Anchorage', AK 99510 4. Location of well at surface 456' FSL, 144' FWL, $ec.17, T12N, R10E, UM At top of productive interval 1257' FSL, 1242' FWL, Sec.17, T12N, R10E, UM ~;~ect~Ld, eP}~74' FWL, Sec.17, T12N, RIOE, UM At total depth 1512' FSL, 1520' FWL, Sec. 17, T12N, R10E, UH feet feet Plugs (measUred) 11. Present well condition summary Total depth: measured 7420' true vertical 6833' Re-enter suspended well ';~ Alter casing Amend order ,r-i Perforate [' Other n~.rC:)~Nm elevation (DF or KB) I~ IXDO¢_. 6. Unit or Property name Kuparuk River Unit _7. Well number 8~._l~esr g i t number feet 9. APl number 029-21387 50-- 10. Pool Kuparuk River 0il Pool Effective depth: measured 7311' feet true vertical 6747 ' feet Junk (measured) Casing Length x xx ~f,r,~rvt~xx x x x 115' Conductor Surface 3804' xxx~<r~~te Production 7397' XXXY,.~XXXX Perforation deplh: measured Size Cemented Measured depth True Vertical depth 16" 225 SX CSII 115' 115' 9-5/8" 808 SX PF"E" & 3804' 3804' 310 SX PF"C" 7" 300 SX CS G & 7397' 6815' 250 SX PF"C" 6861 '-6885' 7046' -7053' 7058'-7078' 7173' -7164' MD true vertical6390-'6409' 6533'-6538' 6543'-6573' 6631'-6624' TVD Tubing (size, grade and measured depth) 3 1/2-" J-55 9.3 #/ft @ 6953' Packers and SSSV (type and measured depth) Baker FHL @ 6752' Baker DB @ 6919' Baker FVL @ 1760' 12.Attachments Description summary of proposal ~ Detailed operations program Propose conversion from water injector to water and gas injector. 13. Estimated date for commencing operation April 13, 1988 14. If proposal was verbally approved Name of approver Date approved ~_,:'-: £ .¥. :-Ggo 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~¢_.~ ,¢'~ .~-v¢..,¢'''~ ~ Title Sr. Operations Engineer Commission Use Only Conditions of approval Notify commission so representative may witness ! Approval I NO, Date Approved by [] Plug integrity [] BOP Test .. '. ':' ~- -" ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 12-1-85 E~ Location clearance .'~pproved Copy Returned -22 Commissioner by order of ~E_~:Tcc- the commission Date -~"/'/----/' - ~/D' Submit in triplicatu ~ Well 1R-15 Application for Sundry Approval April 4, 1988 1. Propose conversion from water injector to water alternating gas injector. 2. No BOP equipment will be required. 3. The estimated static B HP is 2800 psi at 6200' SS based on data taken in August of 1987. 4. No workover fluids will be required. Oil & Gas Cons. ~,nohorage STATE OF ALASKA ALA~,A OIL AND GAS CONSERVATION COM'I~SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend '; Operation Shutdown i i Re-enter suspended well ~ Alter casing E] Time extension Change approved program_.' ' Plugging ~ Stimulate _:-'~ Pull tubing ' ' Amend order ,r~ Perforate r~' Other . Address PO Box 100360, Anchorage, AK 99510 Location of well at surface 456' FSL, 144' FWL, Sec. 17, T12N, R10E, UM At top of productive interval 1257' FSL, 1242' FWL, Sec. 17, T12N, R10E, UM ~tt4~if~ect~vELd,eP~74' FWL, Sec.17, T12N, R10E, UM At total depth 1512' FSL, 1520' FWL, Sec. 17, T12N, RIOE, UM R~BD~m elevation (DI~ or KB) 6. Unit or Property name Kuparuk River Unit 7. Well number 1R-15 i A~ 7 F e_'F / O.'v 8~_1:~1't number 9. APl number 5o- 029-21387 10. Pool Kuparuk River 0il Pool feet 11. Present well condition summary Total depth: measured 7420' true vertical 6833' feet feet Plugs (measured) Effective depth: measured 7311' feet true vertical 6747 ' feet Casing Length Size xxx~~xxxx Conductor 115 ' 16" Surface 3804' 9-5/8" X X X ~r~Yn,~Ye~ ~,t e Production 7397 ' 7" XXXICK~XXXX Perforation depth: measured Junk (measured) Cemented Measured depth True Vertical depth 225 SX CSII 115' 115' 808 SX PF"E" & 3804' 3804' 310 SX PF"C" 300 SX CS G & 7397' 6815' 250 SX PF"C" 6861'-6885', 7046'-7053', 7058'-7078', 7173'-7164' MD true vertical6390,'6409' 6533'-6538' 6543'-6573' 6631' 6624' TVD Tubing (size, grade and measured depth) 3 1/2TM J-55 9.3 #/ft Ca 6953 Packers and SSSV (type and measured depth) Baker FHL Ca 6752' Baker DB Ca 6919' Baker FVL ca 1760' 12.Attachments Description summary of proposal ~ Detailed operations program Propose conversion from water injector to water and gas injector. 13. Estimated date for commencing operation April 13, 1988 14. If proposal was verbally approved Name of approver ,~. 'r'~O~."~ 0il & GaS Cons. C0mmJs~ Date approved Anchcrage 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed _,~. ~.U,,r.~ ,¢'~ .~,~.! ~ Title Sr. Operations Engineer Commission Use Only Conditions of approval Approved by Form 10-403 Rev 12-1-85 Notify commission so representative may witness F! Plug integrity 1~. BOP Test ORIGINAL SIGNED BY Approval No. Location clearance ,~" ,~ .'~ ~ -,pproved Copy Returned ~//--/~'-~-~' by order of Corffr~'issioner Ina commission Date'~/-'--//~/~ ~? Submit in triplicate Well 1R-15 Application for Sundry Approval April 4, 1988 1. Propose conversion from water injector to water alternating gas injector. 2. No BOP equipment will be required. 3. The estimated static BHP is 2800 psi at 6200' SS based on data taken in August of !987. 4. No workover fluids will be required. ATTACIIHENT 1 PAGE I KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE h - INJECTIVITY PROFILES FIRST QUARTER 1987 SUBMITTAL WELL APl NUMBER NUMBER 50-029 DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES INITIAL PROFILE/ PROFILE/ PROFILE/ COMPLETION TAKING INJECTION SURVEY SURVEY ~URVEY WATER INJECTION BWPD ~><1A-13 20700 ~'~lA-15 20711 ;'>"~'1F-02 20881 1F-05 208O7 ..~"1F-10 2098q 02/0q/83 03/26/87 SPINNER FOLLOWUP A&C SS ABC 03/01/83 03/25/87 SPINNER FOLLONUP ABC SS AEC 10/15/85 01/13/87 SPINNER FOLLOWUP ABC SS AEC 10/28/85 03/08/87 SPINNER FOLLONUP ABC SS A&C 08/13/814 01/27/87 SPINNER FOLLO~UP ABC SS A&C ~<~ 1F-11 20993 08/12/814 03/09/87 SPINNER FOLLOWUP A&C SS A&C ~>~1F-13 21020 08/16/814 , 03/19/87 SPINNER FOLLOWUP A&C SS A&C ~ 1F-15 21025 08/16/8q 03/2q/87 SPINNER FOLLO~UP A~C SS A~C I i ..... ~ . i -~ ~ ~ '~r~ ~'~ "~:~~ '~ 10-09 21001 09/1~/8h 02/23/87 SPINNER FOLLOWUP AEC SS *~C 1G'1" 21017 08/2h/Bh 02/2"/87 SURVEY FOLLO~U P A~C SS C 9100 Alaska oil& Gas Cons. Commission Anchorage STATE OF ALASKA ALAS~.~ OIL AND GAS CONSERVATION COM"~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension El Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchoraqe, AK 4. Location of well at surface 99510 456' FSL, 144' FWL, Sec. 17 T12N RIOE UM At top of productive interval ~ ' ' 1257' FSL, 1242' FWL, Sec. 17, T12N, RIOE, UM At effec, tiv¢ depth 1466 FSL, 1474' FWL, Sec. 17, T12N, Rt0E, UM At total depth 1512' FSL, 1520' FWL, Sec,17, T12N, R10E, UM 11. Present well condition summary Total depth: 5. Datum elevation (DF or KB) RKB 82 feet 6. Unit or Property name Kuparuk River Unit 7. Well number 1R-15 8. Permit number Permit #85-152 9, APl number 50-- 029-21387 10. Pool Kuparuk River Oil Pool measured 7420' ND feet Plugs (measured) None R E t: E I V E !) true vertical 6833' MD feet Effective depth: measured 7311' MD feet Junk (measured) None OCT 3 1 tl.986 true vertical 6747' MD feet Alaska_0ii & Gas Cons. C0mff Casing Length Size Cemented Measured depth ~rue ~gi~epth Structural 115' 16" 225 SX CS]::[ 115' MD 115' TVD Conductor 3804' 9-5/8" 808 SX PF E 3804' MD 3804' TVD xx~f~f~xxx & 310 SX PFC Intermediate 7397' 7" 300 SX Class G 7397' MD 6815' TVD xx~'~~x & 250 SX PFC Liner Perforation depth: measured 6861'-6885' MD, 7046'-7053' MD, 7058'-7078' MD, 7173'-7164' MD true vertical 6390'-6409'TVD, 6533'-6538'TVD, 6543'-6573'TVD, 6631'-6624'TVD Tubing (size, grade and measured depth) 3½", J-55, 9.3# w/tail @ 6953' MD Packers and SSSV (type and measured depth) Baker FHL Pkr fa 6752'/Raker DR Par_k~r fa ~qlq'/Rake? "Fyi_" SSSV @ !760' MD 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] Convert well from production service to A & 6 Sand water injection 13. Estimated date for commencing operation October 31, 1986 14. If proposal was verbally approved Name of approver Mr. R. Douglas Date approved 10/28/86 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~ LC-'t.~J / .~-~-~~'~'~ Title Sr. Operations Engineer Date10/29/86 Commission Use Only Conditions of approval Approved by _. Form 10-403 Rev 12-1-85 Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance '~,aturn~d Commissioner by order of ~//~/. the commission Da Submit in triplicate ssion STATE OF ALASKA .... ALASKA O~L AND GAS CONSERVATION COW, MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REVISED OIL I~(x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-152 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21387 4. Location of well at surface 9. Unit or Lease Name 456' FSL, 144' FWL, Sec.17, T12N, R10E, UM Kupaurk River Unit At Top Producing Interval 10. Well Number 1257' FSL, 1242' FWL, Sec.17, T12N, R10E, UM 1R-15 At Total Depth 11. Field and Pool 1512' FSL, 1520' FWL, Sec.17, T12N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 82' RKBI ADL 25635 ALK 2568 12. Date Spudded 08/07/85 13. Date T.D. Reached 08/11/85 14. Date Comp., Susp. or Aband.08/13/85* I15' Water Depth' if °ffsh°re N/^ feet MSL ] 16. No. of Completions 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD)! 19. Directional Survey I 20. Depth whereSSSV set 21. Thickness of Permafrost 7420'HD,6833'TVD 7311 'ND ,6747 'TVD YES E~X NO []I 1767 feet MD 1650' (approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/GR, FDC/CNL, Cai, 6¥ro, CET 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 115' 24" 225 sx CS II 9-5/8" 36.0# J-55 Surf 3804' 12-1/4" 808 sx PF "E" & 310 sx PF "C" 7" 26.0# J-55 Surf 7397' 8-1/2" 300 sx Class G & 250 sx PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7173' - 7164' 3-1/2" 6953' 6758' & 6925' 7098' - 7058' w/4 spf, 90° phasing 7046' - 7053' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 6861' - 6885' w/12 spf, 120° phasing 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 I GAS-OIL RATIO TEST PERIOD II~ I Flow Tubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) 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 MAR 0 1986 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 * NOTE: Tubing was run and well perforated 10/9/85. DAM/WC58 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate / 29. ~ 3O. ' '- GEOLOGIC MARKERS FORMATION 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 6815' 6261' N/A Base Upper Sand 6888' 6417' Top Lower Sand 7030' 6527' Base Lower Sand 7178' 6642' . . I I I I 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation; injection for in-situ combUstion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. J Post Office B(~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 10, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1R-15 Dear Mr. Chatterton' Enclosed is a copy of the 1R-15 Well History (completion details) to include with the Well Completion Report, dated 11/04/85. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU13/L85 Enclosure RECEIVED A!eska 0il & Gas C-ons. Commission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representativ,e test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting District r cou.tyor Parish I State Alaska North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25635 Auth. or W.O. no. ITitle AFE 604658 [ Completion WWS #1 API 50-029-21387 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Complete 10/8/85 lO/O8/85 lO/O9/85 Date and depth as of 8:00 a.m. Complete record for each day reported lO/lO/85 RECEIVED Alaska Oil & Gas Cons. Cornrnissior~ Anchorage Old TO 7" @ 7397' 7312' PBTD, NU BOPE 10.2 ppg NaC1/NaBr Accept rig @ 0000 hfs, 10/8/85. I otal number of wells (active or inactive) on this DSt center prior to plugging and I bandonment of this well I our I Prior status if a W.O. 0000 hrs. [ ND lower tree. NU BOPE. 7" @ 7397' 7312' PBTD, Rn'g tbg 10.2 ppg NaCl/NaBr NU &tst BOPE. RU Schl, perf w/4" gun, 4 SPF, 90° phasing f/7058'-7164', 7046'-7053' perf w/5". gun, 12 SPF, 120° phasing f/6861'-6885'. Make gauge ring/JB run to 7027'. RIH, set DB pkr @ 6919' WLM, RD Schl. RIH w/3½" tbg & CA. cost center code Alaska Well no. 1R-15 7" @ 7397' 7312' PBTD, RR Diesel in tbg & ann Fin rn'g 213.its, 3½", 9.3#, J-55 8RD + 2 jts, 3½", 9.2#, J-55 BTC tbg w/SSSV @ 1767', DB Pkr @ 6925', "D" Nipple @ 6945', TT @ 6953', upper pkr @ 6758'. ND BOPE, NU &tst tree. Displ brine in hole w/diesel. RR @ 1700 hrs, 10/9/85. New TD Released rig Date 1700 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Polential test dala lO/9/85 IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands PB Depth 7 312 ' PBTD K nd of rg Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected Tho above is correct Signature.~r ~,,~'~~ · ] Date JTitle For form preparation an(~distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska. Inc.,,,...~ Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 01-23-86 TRANSMITTAL # 5530 ,~/~.r~rf~itted herewith are the following items. Please acknowledge receipt and ~"¢L~--return one signed copy of this transmittal. Final Prints/ Schl/ CET-CEL'S/ One * of each .~/1R- 14 08-12-85 Run #1 ¥1R- 15 08-'22-85 Run #1 ./2 Z- 9 08-20-85 Run #1 ~ 2Z-10 08-20-85 Run #1 ~2Z-11 08-08-85 Run #1 ~3C-7 08-06-85 Run #1 ~3C-7 08-19-85 Run #1 7494-9104 5543-7306 5095-7186 5689-7696 5793-7377 6481-8748 4776-8748 Post Squeeze Receipt Acknowledged: State of AK*bl/se NSK Clerk*bl Vault*films Alaska Oil & G.-:s [;':.-ns. Commission Drilling*bi ARCO AlasKa. Inc. ~a a Subslchary o1' AllanticRichlleldComl~any ARCO Alaska, Inc. Post Office B~x"P'i'00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 5, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1R-15 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 1R-15. If you have any questions, please call me at 263-4944. Sincerely, O. Gruber Associate Engineer JG/tw GRU12/L73 Enclosure Alaska oil UChorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany STATE Of ALASKA ALASKA O.~' AND GAS CONSERVATION CO,.~jIlSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE i--) '2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-152 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21387 4. Location of well at surface 9. Unit or Lease Name 4567 FSL, 144' FWL, See.17, T12N, R10E, UN Kupaurk River Unit At Top Producing Interval 10. Well Number 1257' FSL, 1242' F'~L, Sec.17, T12N, R10E, UM 1R-15 At Total Depth 11. Field and Pool 1512' FSL, 1520' FWL, Sec.17, T12N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i I Poo] 82' RKB ADL 25635 ALK 2568 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 08/07/85 08/11/85 08/13/85'J N/A feet MSL[ N/A 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set ] 21. Thickness of Permafrost 7420'MD,6833'TVD 7311 'ND~6747'TVD YES I~X NO [] 1767 feet MD[ 1650' (approx) :~2. Type Electric or Other Logs Run DIL/SFL/SP/GR~ FDC/CNL~ Cal~ Oyro~ CRT 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 115' 24" 225 s,x CS !1 9-5/8" 36.0# J-55 Surf 3804' 12-1/4" 808 sx PF "E" & 310 sx )F "C' 7" 26.0# J-55 Surf 7397' 8-1/2" 300 sx Class "C" & :250 ix PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7173' - 7164' 3-1/2" 6953' ~;75l~' & 69~)~' 7098' - 7058' w/4 spf, 90° phasing 7046' - 7053' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. .......... DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 6861' - 6885' w/12 spf, 120° phasing 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 m~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE m~ 28. CORE DATA NONE - - ' '~ g!aska Oil & (~as % Afichor~£e Commission Form 10-407 ~ NOTE: Tubing was run and well perforated 10/9/85. ' TEMP2/WC52 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE '" .30~ 29..- ... GEOr"o~IC': .... MARKERS'. ?. [ . ,~: ,.:'::"~": .::;':::-'-?.:.':~':-::: ,': ' :' ] 'FORI~I~ATi~N::TEs~'S'' · 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 6815' 6:~61' N/A Base Upper Sand 6888' 6417' Top Lower Sand 7030' 6527' Base Lower Sand 7178' · 6642' · I 31. LIST OF ATTACHMENTS W~ll FH~f_nry 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed i~~ ~,L~ Title Associate Engineer Date //-~'(~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company. 4) Well History - Initial Fteport - dally -- '1~ Prepl~e and submit the- "Initial Rm' on the first Wednesday after a well is spudded or wort(over or ';one am ~tlrtld. Dilly worR prior to spudding ghoul ~ummerize~l on the form giving inclusive date@ only. DIItrlct ICounty, pariah or borough ~ I Alaska ' '. I North Slope Borough Ist't' Field ' )Lees~ or Unit ADL 25635 Kuparuk River-s. "©/' - ~'~'"'~ ' Auth. or W.O. no. ITme &FE 604658 I Drill Doyon 9 Alaska Well no. iR-IS APl 50-029-21387 Operator [ARCO W.I. ARCO Alaska, Inc. S~uudedo, W.O.b,eU,Spudded 1o.,. 8/7/85 I"°ur 1815 hrs. ]Prior status if a W.O. Date end depth as of 8:00 a.m. 8/08/85 8/09/85 8/lO/85 thru 8/12/85 8/13/85 Complete record for each day reported 56.24% 16" @ 115' 2010' (1895'), Drl'g WT. 9.8, PV 18, YP 22, PH 8.5, WL 14.8, Sol 10 Move f/1R-14 to 1R-15. NU 20" Hydril & riser. Tst divert@r, PU BHA. Accept Ris @ 1530 hfs, 8-7-85. Spud ~ 18t5 8-7-85. TIH, drl 12¼" hole f/115'-2010'. 16" @ 115' 3820' (1810'), RN'G 9-5/8" CSG WT. 9.4, PV 16, YP 16, PH 9.0, WL 14.2, Sol 8 Drl & srv 12~" hole f/2010'-3820'. CBU, TOH, hole tight & swabbing. Cln stabilizers, LD MWD, TIM. CBU. TOH, RU crew. Rn'g 9-5/8" csg. 9-5/8" @ 3804' 7420' (3590'), C&C Hole f/Logs WT. 10.3, PV 18, YP 12, PH 9.5, WL 5.2, Sol 11 RN & lnd 87 [ts, 9-5/8", 36#, J-55, BTC csg @ 3804', w/FC @ 3714'. Cmt w/l150 sx, PF "E" & 310 sx PF "C", displ bmp plug, press csg 1500 psi; OK. Floats held. Circ 120 bbl PF "E" to surface. ND ann & divert@r, NU starting head & BOPE & tst. PU BHA, TIH tst csg 1500 psi; OK. Drl FC, cmt, FS + 10'. Tst formation to 12.5 ppg. EMW, no leak off, drl to 3850'. POOH. PU kick off assy. TIH, drl f/3850'-4171'. Navi drl & sty 8½" hole f/4171'-7420'. Circ, short trip to 9-5/8" csg shoe. TIH, C&C f/logs. 3800', 4348', 4855', 5232', 5767', 6203', 6735', 7297', 0.9°, S3.75E, 3800 10.6°, N74.~E, 4346 26.5°, N69.0E, 4820 33.2°, N53E, 5147 41.1°, N47E, 5561 40.9°, N45E, 5891 TVD, -12.7 VS, 41S, 15E TVD, +7.1VS, 458, 42E TVD, 172 VS, 8.0N, 208E TVD, 358 VS, 101N, 369E TVD, 693 VS, 325N, 622E TVD, 977 VS, 522N, 829E 39.4°, N48~E, 6296 ZV]:), 1319 VS, N75S, El080 /~,~'f~. 37.7°, N46~E, 6736 TVD, 1667 VS, N995, E1337 %~/' [/C~, 9-5/8" @ 3804' 0 7420' (0'), Rn'g 7" Csg 4~s~aO// ]~r WT. 10.4, PV 16, YP 12, PH ~.5, WL 5.8, Sol 12 ~ dk~. ~ ~ C&C mud, POOH, LD BRA, RU ~c~. P,n DIL/SFL/SP/GR -~c^~ ""~. ~... f/7419'-3804', FDC/CNL f/7419'-5850', 4350'-3804', CAL ..... ~/~ f/7419'-5000'. TIH C&C, TOH, LD DP, RU csg crew. Rn'g 7" csg. The above IS correct Signature /22 . For form p.mpara, t. lon Drilling Superintendent Instructions: Prepare and submit the "Fi 1~3rt" on the first Wednesday after allowable has been assigned '11 ia Plugged, Abandoned, or Sold. "Final Rel~e~' should be submitted also~ . operations are suspended for an indefinite or appreciable length .e. On workover~ when an official te~t is not required upon completion, rermrt cornpleflE~'"'and representative test data in blocks provided. The "Final Reper(~_.~-m may be uud for reporting the entire Operation if space is available. District Alaska Field Kuparuk River l~ounty or Parish Lease or Unit Title North Slope Borough ADL 25635 Accounting cost center code State Alaska IWell no. ].R-15 Auth, or W.O. no. AYE 604658 Drill Doyon 9 Operator ARCO Alaska, Inc, Spudded or W.O. begun A.R.Co. Date Spudded Date and depth es of 8:00 a.m. Complete record for each day reported 8/14/85 AP1 50-029-21387 W.I. rrotal number of wells (active or inactive) on this 56 24% Icost center prior to plugging and I · labandonment of this well IHour ~Prior status if a W.O. 8/7/85 | 1815 hrs. I / 7" @ 7397' 7420' (0'), RR 10.3 Brine Fin r~'g 176 its J-55, BTC, csg w/Fa @ 7397', FC @ 7311'. Cmt w/300 sx Class "G", displ w/brine, bmp plug, tst csg to 3000 psi; ok. CIP 1030 hfs, 8-13-85. Floats held OK, good returns, Release Ri~ @ 1400 hrs, 8-13-85. OldTO ! New TD [ PB Depth II r Released rig Date IKind of rig I 1400 hrs. 8/13/85 Type completion (single, dual, etc.) Single Classifications (oil, gas, etc.) Oil Rotary Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test' Gas per day Pump size, SPM X length Cho'ke size T.P. C.P. ' Water % GOR Gravity Allowable Effective date corrected The above is correct Slgnatu ~/j.~ ~ _ For form preparation an~distribution, see Procedures Manual, Section 10. Drilling, Pages 86 and 87. Date [Title Drilling Superintendent ARCO Alaska, Inc. Post Office B~.~..~J0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 7, 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 on the lA-9 Fracture 1 0/1 7/85 lA-1 2 Fracture 1 0/1 4/85 1R-1 5 Fracture I 0/23/85 1R-1 6 Fracture 1 0/23/85 If you have any questions, please call T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) me at 263-4212. RECEIVED ARCO Alaska, Inc. is a Subsidiary ol AtlanlicRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~fMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 456 ' FSL, 1 44' P-'~IL, Sec. 1 7 T12N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 84' (RKB) 12. 7. Permit No. 85-152 8. APl Number 50- 029-21 387 9. Unit or Lease Name KUPARUK RIVER t.]N I T 10. Well Number 1R-15 11. Field and Pool KUPARUK RIVER F! ELD I 6. Lease Designation and Serial No. KUPARUK R I VER O I L ADL25635 ALK 2568 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). On October 23, 1985, the "A" sands of Kuparuk well 1R-15 were hydraulically fractured and propped to improve production. The treatment consisted of 208 BBLS of gelled diesel as pad and carrying fluid and 750 LBS of 100 mesh and 8,988 lbs. of 20/40 sand as proppant. 61 BBLS of gelled diesel was used as a flush. Prior to pumping, equipment and lines were tested to 7000 psi. Alaska 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~'/~' (~-'~"~'~'-~ Title KtJPARUK OPERATIONS COORD j NATOR The space below for Commission use Date 11/6/85 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1430 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office B6'~-"100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 26, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1R-15 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for 1R-15. I have not yet received the Well History. When I do, I will forward a copy to you. Also, tubing details will be submitted when the well has been completed. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU11/L140 Enclosures RECEIVED OCT 0 Alaska Oil & C~as Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany , · STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CO._.JIISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS i--I SUSPENDED I~X ABANDONED [] SERVICE [] , 2. Name of Operator 7. Permit Number ARCO Alaska, Inc, 85-152 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21387 · 4. Location of well at surface I LOCATIONS 9. Unit or Lease Name 456' FSL, 144' FWL, Sec. 17, T12N, R10E, UMI VERIFIED Kupaurk River Unit '$urf._~ At Top Producing Interval j 10. Well Number 1257' FSL, 1242' FWL, Sec.17, T12N, R10E, UM JB:H.._~ 1R-15 -- At Total Depth 11. Field and Pool 1512' FSL, 1520' FWL, Sec.17, T12N, R10E, UM Kuparuk River Field , ~. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0f 1 Pool 82' RKBI ADL 25635 ALK 2568 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 08/07/85' 08/11/85 08/13/85*J N/A feet MSLI N/A 17. Total Depth (MD+TV'D) 18. PI'ug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7420'MD,6833'TVD 7311'MD,6747'TVD YES [~X NO []I N/A feetMD 1650' (approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/GR, FDC/CNL, Cai, Gyro ,,, 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" 225 sx CS II 9-5/8" 36.0# J-55 Surf 3804' 12-1/4" 808 sx PF "E" & 310 sx I'F "C" 7" 26.0# J-55 Surf 7397' 8-1/2" 300 sx Class "G" r 24. Perforations open to Production (MD+~I'VD of Top and Bottom and 25. TUBING RECORD ¢' interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, 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 el L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-el L RATIO TEST PERIOD II~ Flow Tubing Cas(ng Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAvITY-APl (corr) Press. 24-HOUR RATE "Ir 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED 4 Alaska 0il & Gas Cons. Commission Anchorarj~ Form 10-407 DRH/WC31 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ' 30.- " ~ .... GEOLOGIC MARKERS .... ';- ". i.- ' ;'~ . ,: ' '~ .:.:. !': ' , ~ ~. .: ' · ' FORMATION 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 6815' 6361' N/A Base Upper Sand 6888" 6417' Top Lower Sand 7030' 6527' Base Lower Sand 7178' 6642' 31. LIST OF ATTACHMENTS Cvr~)sr. onic .~urv~.v (2 r. oni~..~ 32, ~ I hereby certify~that the foregoing is true and correct to the best of my knowledge Signed i~ ~ ~ Title ^$$°¢'ate E"g'neer Date q°Z~'~' _.~ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, SUbmersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 RETURN TO: ARCO Alaska, Inc Post OfficeB"6x 100360 'Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 09-24-85 TRANSMITTAL NO: 5365 PAGE 2' OF 2 ARCO ALASKA, INC. KUPARUK OPEKATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEkL~ITH ARE THE FOLLOWING ITEMS. RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. FINAL PRINTS/ SCHL/ ONE BLUELINE OF. EACH OPEN HOLE LOGS PLEASE ACKNOWLEDGE 1R- l~z.~'~ CYBERLOOK 08-06-85 RUN #2 "°~5" DENSITY NEUTRON GR (RAW) 08-06-85 RUN #2 "~'~2" DENSITY NEUTRON GR (RAW) 08-06-85 RUN #2 ~"~5" DENSITY NEUTRON GR (PORO) 08-06-85 . RUN #2 ~'~2" DENSITY NEURTON GR (PORO) 08-06-85 RUN #2. '~'"5" DIL/SFL-GR 08-06.85 RUN #2 '~2" DIL/SFL-GR 08-06-85 RUN #2 CYBERLOOK 08-22-85 RUN #2 DENSITY N~'.UTkON. GR (RAW) 08-22-85 RUN DENSITY NEUTRON GR (i~AW) 08-22-85 RUN $2 DENSITY'NEUTRON GR (PORO) 08-22-85 RUN DENSITY NEURTON GR (PORO) 08-22-85 RUN DIL/SFL-GR 08-22-85 RUN DIL/SFL-GR 08-22-85 RUN #2 CYBE RLOOK 07-31-85 RUN #1 DENSITY NEUTRON GR (RAW) 07-31-85 RUN DENSITY NEUTRON GR (RAW) 07-31-85 RUN #1 DENSITY NEUTRON GR (PORO) 07-31-85 RUN DENSITY NEURTON GR (PORO) 07-31-85 RUN DIL/SFL-GR 07-31-85 ~ RUN $1 DIL/SFL-GR 07-31-85 RUN CYBERLOOK 08-12-85 RUN DENSITY NEUTRON GR (RAW) 08-12-85 RuN #1 DENSITY NEUTRON GR (RAW) 0~-12-85 t<UN DENSITY NEUTRON GR (PORO) 08-12-85 RUN DENSITY NEURTON GR (PORO) 08-12-85 RUN #1 DIL/SFL-GR 08-12-85 RUN DIL/SFL-GR 08-12-85 RUN 8500-9109 4800-9132 4800-9132 4800-9132 4800-9132 4602-9158 4602-9158 7800-9525 4576-9548 4576-9548 4576-9548 4576-9548 4576-9574 4576-9574 8150-8683 8100-8816 8100-8816 8100-8816 8100-8816 4639-8842 4639-8842 6776-7365 3802-7388 3802-7388 3802-7388 3802-7388 3802-7414 3802-7414 ".ECEIPT ACKNOW~,EDGED: DISTRIbUTiON: ~PAE DRILLING* W. PASHER · CURRIER L. JOHNSTON EXXON .HEVRON ~OBIL PHILLIPS OIL & M* NSK CLERK* J. RATHMELL* * ONE BLUELINE COPY AND ONE SEPIA COPY ** ONE MYLAJt FILM COPY ARCO Alaska, Inc. Post Office B~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 19, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & GaS Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1R-15 Dear Mr. Chatterton: Enclosed is the Well Completion Report for 1R-15. I have not yet received of the Well History. When I do, I will forward a copy to you. Also, the bottomhole location, TVDs, geologic markers, and tubing details will be submitted when the gyroscopic survey is run and the well completed. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU11/L81 Enclosure kECE[VED Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~..~ AND GAS CONSERVATION CO...._/IISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED I-~x ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-152 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21387 4. Location of well at surface 9. Unit or Lease Name 456' FSL, 144' FWL, Sec.17, T12N, R10E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is received. 1R-15 At Total Depth 11. Field and Pool To be submitted when gyro is received. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 84' RKB ADL 25635 ALK 2568 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 08/07/85 08/11/85 08/13/85 N/A feet MS LI N/A 17. Total Depth (MD+TVD) 7420' MD 18. Plug Back Depth (MI~TVD)19. Directional SurveY731 1 'MD YES [~X NO [] I20' Depth where SsSV setN/A feet MD I21 ' Thickness °f Permafr°st1650' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/GR, FDC/CNL, Cal, CET, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" 225 sx CS II 9-5/8" 36.0# J-55 Surf 3804' 12-1/4" 808 sx PF "E~' & 310 sx PF "C" 7" 26.0# J-55 Surf 7397' 8-1/2" 300 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 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 I~ Flow Tubing Casing Pressure CALCULATED,,~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit c°re~hi~F"" --',~ F jV None ~ 2 !985 A!aska 0il & Gas Cons. '- Anchoraoe · Form 10-407 TEMP2/WC17 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE '. .GEOL~OGiC M~ARK~:RS ' ': . ".' "' ':": ~'~.' .:::~.~ .~:-'. :': '-:' ' :'. '!': :'.::.FORMAT'i'~N:Ti~S.f:' . . . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRU'E VERT. DEPTH GOR, and time of each phase. . To be submitted wh."n gyro is recei ~ed. N/A : · · 31. LIST OF ATTACHMENTS None - 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ .~~LM Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ~UB-~URFACE DIRECTIONAL SURVEY ~UIDANCE ~JONTINUOUS [~OOL Company Well Name Field/Location ARCO ALASKA INCORPORATED 1R-15 ,(456' F, SL,. 144' FWL, S17, T12N, R10E, .KUPA~.UK.~.. NORTH SL. OPE, ALASKA Job ,Reference No_. 70772 t. ocmed ay: MCBRIDE Oate 28-AuGUsT- 1985 Computed CUDNEY * SrHLU~BER~£R * GCT DirECTIONAL SURVEY CUSTOMER I, ISI'~NG FOR ARCO ALAqKA, INC, 1R-15 KU"A~UK NOPT~ SbOPE,~bASKA SURVEY DATE: 22-AU~-85 FN~INEFR: MCBRID~ METHODS OF C~MPIJTA~iDN TODD DDC~T~ON: TA~G~NmI~b- averaged dev~atlon~>'a~d azimuth ~NTE~POb~TION: LINEAR VERTICAL SECTIOn!: HORIZ, DIST, PROJECTED ONTO A TARGET AZIMUTH OF NORTH 53 DEG 42 MIN EAST crlMPLi~AT i A,WCO ~LASKA, TN('. 1~-!5 KUPARIIK NORTH SI,OPE ~ALASK~ I,NTF. RDOLATF:D VAJ,UF,5 F~R ~'VE~ 100 TRUE .RUR-SgA ~EAStlR~D VFRTICAT. VERTTCAL DEVIATION AT.I~.~JTH DEPTM D~PTH DEPTH DEG o.n0 0.00 -89.00 0 0 ~.! 0 n F 1On.00 100.00 1R.o0 0 1~. ~ 7 46 w 900.00 200.00 11R.00 0 13 M 96 ~ w 100.00 300.0n ~l~.nO. 0 15 N 4~ 30 ? 400.00 400.00 ~l~.n0 0 15 N 24 25 ~ KO0.00 500.00 41~.00 0 19 N 0 5~ F 600.00 599.9q 517.q9 0 19 N 5 55 F 700.00 699.99 617.q9 0 lg N ~2 51 E 800.00 799.9~ 717.~9 0 20 M 52 29 E gO0.00 8q9.gq 917.q9 0 2K K R9 28 ~ lOOO.O0 999.9~ ~17.~ 0 27 $ 56 55 F 1100.00 loqg.gR 1017.~ 0 27 $ 31 52 E 1200.~0 1199.98 1117.98 0 34 S 3 32 W 1~00.00 1299.97 1217.O7 0 37 $ 21 46 W 1400.00 1399,97 1317.07 0 33 $ ~0 32 W 1500.00 1499.96 1417.q0 (') ~6 S 5 ',~ W 1600.00 1599.96 1517.q~ 0 2~ S 5 33 ~ 1700.00 1699.96 1617.~6 0 27 5 2 3~ W 1800.00 1799.95 1717.q5 0 .~1 $ 213 W lgO0.~0 1899.95 1817.95 0 {3 K 1 4~ W 2000.~0 1999.94 1917.Q4 0 ]7 ~ 3 l. W 2100 00 2099.94 2017.~4 0 37 S .t 37 E 2200:00 ~109.93 2J17.~3 0 44 ~ 18 40 E 2~00.00 2299.97 2217.Q2 0 56 S ~9 3R ~ 2400.00 2399.90 2317.q0 1 R S 26 7 ~ 2500.00 24q9 8R 2417.~8 1 33 S Pl JR E 2600.00 2599:8~ 2517.~4 1 35 $ 9 28 K 2700.00 2699.80 2617.R0 1 30 $ ~ 5~ E 2800.00 2799.76 27~7.76 1 2~ S ~0 ~ E 2900.00 2899.74 .2fl17.~4 1 16 S 17 55 ~ 3000.00 2999.7~ 2917.72 1 1~ S 25 3100.00 3099.69 3017.69 I 17 S ~6 47 3200.00 3199.66 3117.66 1 5 3300.00 ,299.65 3217.65 0 4~ 40~.00 ,399,64 3317.64 350u.00 3499'621 3417.62 0 56 $ ~5 ,oo.oo o PAGE I DATE OF SURVEY: ?2-AUG-85 KEI. LY BU~HIN~ EbEVATION: 82.00-FT ENGINeEr: MCBPIDE FE~T OF ~EASIIRF VERI!C~L DOGLEG RECTA SECTION SEVERITY NORTH FFET DEG/100 FE 0,00 0.05 ~.78 ~.70 1.!5 1.50 1.85 ~,27 2.80 3,43 3.8~ 4.03 2.84 1.94 1.29 0.43 -0.15 -0.70 -1.38 -2.02 -2.51 -2.79 -,2.9B -3.52 -4.48 -7.00 -7.88 0.00 0.11 0.25 0.04 0.1l 0.07 0.07 0.15 0.24 0.27 0.22 3 0.35 .2 0.23 1 0.12 0 0.11 0 0.20 1 0.05 1 0.22 2 0.05 3 0.13 4 0.05 0.17 0.37 0.17 0,3~ 0,3~ 0,27 0.20 0,20 0,20 0.15 0,14 0 5~ 0~2~ 0.02 O. 04",,, 0 0* 3 -R.45 -9.28 -9.RO -10.~7 -11,.00 -12.26 -12.93 -13.45 D DMPTH NGUbAR COORDINATES HORIZ. /S~UTH EAST/WEST DIST,. ET FEET FEET":;, .00 N 0.00 R 0,0~ .12 g 0.03 W .47 N 0.00 W 0.4T .78 N 0.30 R 0.84 ,15 ~) 0.5~ E 1.29 .62 N 0.67 F 1, .19 N 0.69 .72 N 0.81M 2,84 .17 N 1.14 E 3.37 .37 N 1.78 g 3.82 .14 N 2 51 E 4.02 .5B N 3:10 g 4.04 .73 N 3'26 E 3.70 ,70 N 3.01 E 3.09 ,26 S 2.60 £ 2.62 .07 S 2.39 F 2.62 .87 S 2.42 E 3,06 ,65 S 2.48 F 3,63 .53 S 2.40 [ .~3 S 2,3q E 5.03 5 6 7 9 10 12 15 2O 22 .49 K .57 06 S 6O S 76 S 44 S ~6 S :65 $ .87 S 2.32 R 5,96 2,32 E 6,97 2,55 £ 8.12 3,19 E 9.60 4.09 E 11.36 5.00 ~ 13.70 5,79 ~ ~6,49 6,11 £ 19,16 6.49 E 21,64 7.02 E 23.92 24 27 28 3O 32 33 35 ~8 97 S 03 S 99 S 48 S 05 S 74 S 34 S 83 S 27 S 73 S 7,86 8.89 9.78 0.22 0,67 1,14 1,56 1.85 2.07 2,50 DEPARTURF AZIMUTH 2 19 W ~'i',10 33 W N:20 42 E ~-'36 59 E 2 29 E 16 32 19 49 E 27 5O E N 38 42 g N 50 12 E N 62 0 g N 76 52 E S 84 17 E S 65 52 g .5 52 22 E 843 4 E S 34 14 E S 28 20 g $ 22 56 E S 19 27 g S 18 17 g S 19 25 g $21 6 g $ 21 24 E S 20 33 S lg 35 S 17 26 E $17 4 g 26 lg 28 45 30 60 32 15 33 78 35,53 37.18 38,69 40,13 41.65 $ lg 12 E S lg 38 E $ 11 25 E S 1 16 E S lg 6 g $17 49 E $ 17 E CDMPUTATInN D~TE: 2~-~UG-~5 APCO ~L~SKA~ TNt, KUPARUK NOR?H S!,.OPE,AT,AeKA,; lr, II~'RPOT.ATED VA[,UFS F[hR EVEN 100 TDUF, ,cUR-SEA '~E~SIIRFD VRRTICAL VERTTCAb DEVIATIO,~ A?I~'IJTH DEPTH DF, PTH DEPTH OEG MTN DFG ,4IN VERTTCAL DOC, SECTION SEV F~ET DEr, 4~0~.00 ]gqg.s& 3q17.56 410~.O0 40q9,55 4017.K5 4200.00 4199,45 4117.45 4300.00 4298,79 4~1~,79 4400.~0 43q7.O4 4315.O4 4500.00 4493,67 441~.67 4600.00 45~8,]~ 4506.~8 4700.00 4680.56 459~.56 480~.00 4770.8~ 468~.~1 4900.00 4860.45 477~.45 1 0 S 4 ~! ~ -14.93 4 12 ~ ~5 10 ~ -19.~3 8 34 N 75 51 W -~.67 12 47 ~ ~6 20 ~ ~4.4! 16 44 N 76 5K ~ 3R.1! ~0 4~ N 76 0 g 67.49 ~4 38 N 74 39 £ J03.47 95 59 N 71 47 F 143.95 ~6 54 N 66 54 F 186.71 ~8 40 ~ ~2 40 E 232,44 30 40 ~] 58 21K ~81.54 32 34 N 52 ,~7 R: 333.93 34 4~ N 47 4~ E 389.05 37 3~ N 44 36 R 447.54 40 47 ~ 45 31 ~ 50~.97 ,41 34 N 45 51 F 575.51 ~1 1~ N 45 50 F 64t.13 40 47 N 45 ~8 R 706.17 40 38 N 45 ,t~ ~ 770.77 40 30 N 45 32 ~ 83~.~4 40 37 M ~5 41 ~ 89~,58 40 4~ ~ 45 5R F 964.72 41 ~ ~ 46 17 R 1029.17 ~0 .37 N 46 t0 R 1094.]0 40 t~ N 46 .~ ~ 1158.44 39 57 N 47 10 E 1222,53 39 30 M 47 ,{1 R 1286,12 ~9 3~ M 47 2~ E ~9 2e N ~7 '2~ ~ 1412.68 ~9 15 N 47 ~2 ~ 1475.77 t8 50 M 47 [0 £ Z53~.t0 t8 2~ ~ 47 L6 F 1600.38 t7 4~ N 47 50 R 1661,41 ~? 41 N 4? 50 R 1722.24 37 4~ N 4? 50 E 1734,41 5000.00 4948 9! 4n66.Qt 5t00.O0 50~5:8~ 4953.~3 5~0A.00 5120,96 5~3R,96 5300.00 K204.27 5{27,77 5400.00 5284.96 590~.96 5500,00 5362 44 5~.4'4 5600,00 5437:4~ 5355.4,'2 5700.00 5512 3~ 5430,]3 5800.00 55~7~75 5~05.75 5900.00 5663,55 5581.55 6000,00 5739,45 5657,45 6100.00 5815,45 5733.45 6~00.00 58~1,22 5~09,:~2 6300.00 5966,76 5884,~6 6400,00 6042.38 5~60.38 6500,00 6118,5~ ~03~.52 6600.00 61~4.90 611'~.00 6~00.00 6271.7~ 6J,~9,76 6P0~.A0 ~349,00 6967,00 6900.00 64~6.01 7000.00 6503.29 642~.~9 7100.00 65~1,00 ~49~.00 7~00,00 6659,08 6577°08 7~00 00 67~8.07 6656.02 7400:00 6817.14 6735,14 7420.~0 68~2.97 6750.~7 PAGE 2 hATE 0¢ SURVEY: 22-AUG-85 KELLY RUSHING EGFVATION: ENGTN~ER: MCBRIDE L~G RFCTA~ E~ITY NORTH/ /100 FEE 0.12 41. 1.67 43. 5.15 44, 4.1~ 41. 4.64 37, 3.92 31 3.15 14. 2.8O 2. i.94 13. 2.60 33 2,63 58: 4.39 87' 3,34 123. 2.83 164. 2.76 209. 0.43 255, 0.08 301, 0.30 347, 0,18 392, 0.24 438. 0,57 4~3. 0.23 529 0.23 574i 619 0 58 0117 664 0.9~ 708: 0 68 751 0:45 7941 0,64 837, 0.59 880, 0.27 923. 1,12 965, 0.00 1007. 0.00 1.048, 0,00 1056, 82,00'FT D D~PTH GULAR COORDINATES HORXZ. DEPARTURr SOdTH E~ST/WEST DIST,' AZIMUTH T FEET FEET PEG 43 S 12.77 E 43,35 $ 17 7 E 17 S 12.96 E 45,08 $ 16 42 E 13 S 16,37 E 47.06 $ 20 20 E 83 S 27.4! E 50 0! $ 3] ~4 E 30 S 45,27 E 58:66 $ 50~1 E 13 $ 70.16 ~ 76,76 $ 66 4 ~ 9~ S 101.36 E 104,15. $ 76 41 21 $ 138,82 E 139.55 $ 84 9 06 i 180.13 E 180.14 $ 89 20 E 94 N 221.44 E 221.8~ N 86 23 E 76 N 263 ~ E 265 77 N ~ 42 E 21 N 306:o. E 312105 N,= 14 m 6~ N 349,99 E 360 79 N 755b £ 35 ~ 392.12 ~ 411:07 N 72 32 E 45 N 434.51 ~ 464,58 N 69 16 E 28 N 479,04 $ 5~2,76 N 66 ~4 E 4~ N 5~6.47 ~ 585.16 N 64 7 £ 5~ N 574.0~ E 648.40 N 62 !? E 31. N 6~1,10 ~ 711 6! N 60 47 £ 87 N 669.82 ~ 774179 N 59 ~2 E 37 ~ 7~4. 86 ~ 760 32 ~ 807 73 N 854 77 N 902 23 N 949 33 ~ 996. 60 M 1043 53 N 1090~ 63 ~ 1137. 78 E 901.6! N 57 ~2 £ 60 E 1222,68 N 54 3 72 ~ 12~6,18 N 54 14 53 E 1349.27 h 53 55 E 57 ~ 1412.68 N 53 38 E 56 N 1184,3i E 1475,80 N 53 22 E 24 N 1230.54 E 1.538.38 N 537 E 74 N 1276,35 ~ 1600,54 N 52 53 E 13 N 1321,68 E 1661,67 N 52 41 E 18 N 1367,01 E 1722,6! N 52 31 E 39 N 1376,07 ~ 17~4,80 N 5~ ~9 E cnMPUTATION D~TE: ARCP /~LASKA, TNC. 1R=~5 KUPARIIK Nr)ETH SI.OPE,ALASKA PAGE 3 hATE OF SURVEY= ~2-AUG-85 KELbY BUSHTNG FLEVATION: ENGINEER: MCBRIDE 1NTERPOLATgD VAI,UES FnR EVEN 1000 FEE~ OF MKASUR 0 1000 2000 3000 40OO 5000 6oon 700O 7420 TR(J~ SUg-SEA RFD V~R?ICA~ VERTTC~ D~PTH DEPTH COURSF VCRTTC~L DO~LRG RECTA DEVIATION A~I"OTH SECTInN SEVERITY NORTH DEG HIN D~G MTN FEET .DE~/1.00 YE 0 0 N 0 n E n.O0 0.00 0 0 27 S 56 55 ~ 3.g8 0.22 3 0 37 S 3 1 w -1.38 0.05 5 1 19 S ~5 3 E -9.45 0.15 24 1 0 S 4 ~1 r -14.~3 0.1~ 41 ~8 40 N 62 40 K ~32.44 2.60 33 40 3~ N 45 32 E 835.~4 0,24 4]8 ]9 15 M 47 2~ E 1475.77 0,59 880 37 4~ N 47 50 E 1734.41 0.00 1056 .00 o.on -87.o0 .00 999 9q q~7,~9 ,00 1999~94 lqlT.q4. .nO ~999.7~ 2~17.72 .00 39~9.56 ~q17,56 ,00 4948.9~ 4866,ql .O0 57]9,45 5R57,45 ,Oo 6503.29 6421.~9 .00 68~2.97 6750,07 82.00-FT E~ DEPT NGULAR COORDINATES HORIZ, 'DEPARTURE /SOUTH EAST/WEST ~T FEET .00 N 0.00 .4g S 2.32 .97 $ 7 86 ,43 $ 12:77 .76 N 2~3,61 °3? N 7~4,36 .56 N 11R4.31 ,39 N 1376.07 PAGE 4 ARCO. ~LASFA, TN('. KUPARIIK NORTH SLOPE, AT,ASKA DArE OF SURVEY: 22-AUG'85 KELbY BUSHING £bEVATION: ENGTNEER~ MCBRIDE 82.00 I~JTF, RPO[,ATED VALUES FOR EVEnt 100 FEFT OF SUB-SEA DEPTH T~UF SU~-$EA COU~SF EA$IIRFD V~R?ICAL VERTICAL DEVIATION AZI"UTH DEPTH D~PTH DEPTH DEG MIN DFG MIN 0.00 0,00 -8~.00 0 0 ~ 0 0 ~ BP.nO 82,00 0.00 0 9 N 1~ 5 w 182.n0 1~2.00 100.00 0 12 N 15 O E 282.00 282.00 200,00 0 i5 N 47 14 ~ 382.00 382,00 300.00 O~ 1~ N 29 42 E 482.00 482.00 400.00 0 18 " 3 47 E 582,01 5~2,00 500,00 0 19 ~ 3 45 F 68~.01 682,00 600.~0 0 18 N 1.8 34 E 78~,0! 782,00 700.00 0 20 N 46 3~ E ~8~.0! 8~2,00 80o,00 0 24 ~ 83 53 r V£RfICAD DUGbEG RECTANGULAR SECTION SEVERITY NORTH/SOUTH FFET DEG/~00 FEET ri.n0 0.00 0.00 0.03 0.25 0,07 0.~2 0.28 0.41 0.62 0.03 0,73 ~.07 0.14 1,07 1.45 0.16 1,52 ~.78 0.07 2.09 2.18 0.13 2.63 2,70 0.19 3.10 3.33 0,29 3,37 CnORDINATES HOR.IZ-DEPARTURE EAST/WEST DIS~'.,..< :AZIMUTH 0.00 £ 0.00'::~ H"';0 0 £ 0,02 ~ 0,07 '.N ..14 44 ~ 0.0~ ~ 0o4! 'N"',4 46 ~ 0,2~ ~ 0,?~ ~'.~? $6 0,54 £ t,~o..*,N;~:.~.~ $5 S 0,68 E 2.20','~,~ ~7 59 ~ 0,78 E 2.74 r'N'16 24 1.07 £ 3,28 N 19 ! E 1,65 E 3,76 N 26 6 E 982.01 982,00 900,00 1082,02 1082,00 lO00.OU lj82.02 1182 O0 1100,o0 128~,03 1282:00 120o.00 1182,03 1382o00 1~0o,00 1482,04 1482.00 1400.~0 1587,04 1582,00 1500.00 1682.04 1682 O0 1600,nO 178~.05 1782!00 1700,()0 188~.05 1882 O0 1800.00 0 27 ~ 61 40 ~ 0 27 S 38 1 E 0 32 S I 7 g 0 37 S 19 55 w U 34 $ 21 54 W 0 26 $ 8 44 w 0 27 S 4 47 F 026 S ! ~ F 0 31 $ 3 25 w 0 3~ S 0 48 W 3.R3 0.27 3.21 4.02 0,2R .2.69 ).77 0.32 1.91 3.01 0,21 0,88 ~,09 0 08 0.10 1.39 0:20 0,94 0.92 o 1.72 0.~3 0:33 2.51 '0.05 0.08 3,37 '0.59 0.14 4,26 2.39 3,0,~ .09 2.67 2.4! 2,4] 2,49 2.4~j 2.3 4.01 N 36 39 g 4,04 N 48 11 £ 3.79 N 59 45 E 3.21 N 74 1 g 2.67 S 87 55 E 2,59 S 68 42 E 2,95 S 54 29 f 3 53 S 44 51E 4:14 S 35 35 E 4;89 S 29 16 g lq87.06 1982.00 lq0n. O0 208Q.06 2082,00 2o0n.~0 2182.~7 2182,00 2100,n0 2~8~.n8 22~2 On 2700,~0 2382.09 23R2:0n 2~On.00 2487.~2 ~4~2.00 2400,00 2582.~6 ~5~2.00 2KO0.O0 2&8~o~.9 ~682,0n 2600.00 '11.25 0.05 5,30 '1.91 0,10 6,37 '2.44 0.28 7,50 '2.75 0.19 8.80 "2.92 0,33 10 29 -3,40 0.40 12:30 -4,~6 0,37 14: 95 '5.59 0,17 17 69 '6,80 0,17 20.22 '7,75 0.23 22,49 2.34 2,3~. 2 49 3:06 3.93 4.81 5,70 6'06 6,41 ~,90 5,79 $ 23 47 E 6,78 S 19 54 E 7,90 $ 18 20 g 9'01 $ 54 E II 13!21. S 21 22 ~. 16 O0 S 20 52 18 70 $ 18 54 21,22 $ 1735 g 23,53 $ 17 3 g 298~.28 2982 00 2900.00 3082,31 30~2:00 3000.00 31.82 33 31~2,00 3100.o0 3282:35 3282,00 3~00,o0 3382.36 3382.00 3~00.00 3482.38 3482'00 3400,00 3582,39 3582.00 3500,00 3682,40 3682.00 3600.00 378~.41 3782.00 3700,~]0 3~82.42 3882,00 3800.00 1 1~ S .9,3 56 ~ 1 18 $ ~6 57 F 1 g $ 20 53 E 0 48 $ 16 30 E 1 ] 5 15 31. E 0 57 S 15 20 ~ 057 S 14 11F 0 50 S 8 41 E 0 5n S 10 ]1 ~ 0 5~ S 18 ~4 F, -8.37 0.12 =~.77 0,15 -9.19 0.39 -9.73 0,23 -10.26 0,04 -10,89 -~1.~o ~',',15' -12.!3 0"10 -12,82 0,15 -1~.36 2~ 6O 26:67 28 66 30 25 31 74 33 46 35 05 36 58 38 02 39 47 7 69 9,65 ~.0,16 10,59 11.06 11,48 11.81 li,02 1 ,42 25 28 3O 31 33 35 36 38 39 41 8 S 17 21 E ~6 $ 18 5 E 24 S 18 36 E 91 24 $ IS 17 E 89 $ 18 8 E ARCO ALASKA, TNC. 1~-15 KUPARIJK NORTH ST,OPE,ALASKA C n i,'l P U 'T' A '"P I ") N D A TF,, ." IN'£ERPOT,ATED VA.r,UE$ FOR EVEN lO0 FEE TRUE SUR-SEA C[hURSE ~EASI~R~D VI:'RT][CAL VERTTCAb DEVTAT[P.,N DEPTN D~P~H 3989.44 3982.00 3900.00 1 4082.45 4082.00 4000.0'0. 1 4182,~1 4182.00 4100.0'0' 3 24 4283,04 42~2.00 4200.00 7 51 4384.~9 4382.00 4300.n0 12 4 4487.81 44~2,00 440~.00 ',16 16 4593.17 4582.00 4500.00 20 25 4701.59 4682.00 4600,00 ~4 40 4~17.44 4782.00 4700.00 25 57 4q24.?1 4882,00 4800.00 27 iR 5037 82 49~2.00 4~00.00 79 21. 5151397 5082.00 5000.00 ~1 43 5273.02 5182.00 5100.00 34 2 5396.25 5282.00 5~00.00 ~7 37 5525.98 5382.00 53on.no 41 20 5659.64 5482 O0 540~.o0 '~1 27 5792.40 5592:00 550o.0,) ~0 50 5924.31 5682,00 5600,00 40 3~ 6055,~4 5782,00 5700,00 ~0 39 6187,81 5882,00 58On.nO 40 50 V6aTICRL DOG A?I~dT~ SECTION Sgv DEG ,4IN FrET DEG $ 5 ~2 E -14.07 S 12 44 r -14.98 R P7 ~3 r -13.78 N 70 t~ r -4.90 N 76 [8 F 11.33 N 76 29 ~ 34.90 N 76 7 F 55.93 N 74 37 E 10a.10 N 70 57 E 149.15 ~) 65 58 E 197.48 N ~0 54 E 250.56 N 55 51 F 309.42 ~ 48 {8 E 373.91 )I 44 38 F 445.27 N 45 45 F 526.90 N 45 52 E 614.75 ~ 45 4~ E 701.25 ~ ~5 ]9 ~ 786.44 ~ 45 34 E 871.1.8 N a5 56 E 956.]2 N 46 22 E 1042.31 ~ 46 41. E 1127.67 N 47 ? E 1211..81 ~ 4,17 ]0 E 1294.49 M 4'1 29 g 1376.44 ~ 47 24 E 145~.43 ~ 47 10 E 153~.10 N a7 24 E 161~.3~ ~! ~7 50 ~ 1695.22 N 47 50 F 1734.41 6320.19 ~982.00 590n.o0 40 5~ 6452.~0 60R2,00 6non.nO ~0 23 6583.19 61R2,00 6100.o0 40 6713.25 62~2 O0 6~00,{~0 39 25 6~49.~5 63~2~00 63On.nO 39 41 6~7~.48 6482 O0 540n.o0 39 71,0~.28 ~582~0n 6500.o0 tB 4q 7229 ~7 6682,00 660A O0 17 50 7355:58 6782,00 670~:00 ~7 7420.00 6832,97 6750.~7 37 41 PAGE 5 DATE OF SURVEY) 22-AUG-B5 KELLY RUSHING ELEVATION: ENGINEER: MCBRIDE T OF SUR-$EA DEPTH LEG RECTA~ ERITY NORTH/ /100 0.17 41, 0.90 42. 5.15 44 4.34 42: 4,63 38, 3.90 31. 4.38 24. 3.06 14. 2.98 0. 2,62 18. 3.28 42, 3.86 73, 2,9~ 1~3. 2,80 162. 1.21 221. 0.95 2~2. 0.40 343. 0.28 403. 0.35 463. 0.28 523. 82.00 FT 0.33 0.26 1,12 0,38 0 33 0~31 0.27 2.29 0 O0 0~00 GULAR COORDINATES HORIZm'.'DEPARTURF. SOUTH EAST/WEST DI$~,-':.", AZIMUTH T FEET · . .;, i . .:. '.. "' ,', ' . 12 S 12.75 E 43 86 S 12.89 E 44 15 $ 15.33 E 46 40 S 25,07 E 49 06 S 42,02 E 56 91 S 66.75 E 73 58 S 98,99 E 102 03 S 139.47 E 140 28 S 185.27 E 185 35 N 231,56 E 232 9'8 '$ 64 26 ~ oo ,s 76 3 18 S 84 15 27 s 89 54 E 28 ~ 85 28 E 38 N 279.77 28 N 330.10 20 N 380,79 81N 432.90 22 N 491,28 99 N 554.91 84 N 617,53 88 N 679.14 79 N 740.28 78 N 801,85 282 96 338 14 397 26 462 50 538 79 622 91 7O6 81 790 16 873 56 957 76 N 81 23 g N 77 29 g N 73 N 69 26 2 3 ~ g 65 45 E N 62 58 E N 60 $3 E N 59 i5 E N 57 5 5 N 56 50 E 583. 042. 700, 757. 813, 868. 923. 977. 1029, 105b, 88 N 864,40 98 N 926,91, 99 N 988,69 28 N 1049.93 O0 N 1110,69 75 N 1171,47 79 N 1231,13 96 N 1289,63 95 N 1.346 87 39 N 1376:07 1043,12 1128,09 1211.9~ 1294.53 1376,44 1458.45 1539.18 1618 50 1695!54 1734 80 N 55 57 E N 55 N 54 ! N 53 7 ~ N 5:2 49 E 5 £ N 52 ]9E N 52 ARCO ALASKA, TNt, KI!P~RI~K NORTH SLOPE,A~,AgK~ ~AI~K~R TOP UPPrR BAS~ UPPER TOP LOWER BASE LOWER Tm SAND SAND S~ND SAND 70~0.06 717~.00 73~1.00 74~0.00 ORTGTN: 456' TVD F~O" KB SUB-SEA 63~0.57 627~.57 6416.74 6334,74 6526.54 6444,54 664~.86 6559.86 6746.72 6664.7~ 6R3~.97 6750.97 PAGE 6 OATE O~ SURVEY: ~2-AUG-85 KELLY BUSHING ELEVATION: R2,00 'FT ENGINEER: MCBRIDE SURFACE LOCATION FSL,144' FWL,S£C RECTANGUEAR NORTH/SOUTH 101~.65 N ' ~ 1056.39 N ~ 6. £ ~IIP~RUK NORTH $~OPE,A~,ASKa 2~-ALJG-~5 r, PAGE DATE O~ SURVEY: 22-AUG-85 ENGINEER: MCBRIDE 82,00 FT 'ARK~R Trip UPPER SAND B~SE LOWE~ SAND PaTO 6~88.on 7030.00 7178.oo 7311.oo 7,t7o.oo FRO~ SURFACE LOCATION AT nRTGIN= 456' FS[:,14~' F~L.SgC ]7,~12N.RIOE U~ · V~ RECTANGULAR~ KB SUB-SEA NORTH/SOUTH 6360.57 6416.74 6526.54 6641.86 6746.72 6~37.97 09i,58 6278.57 $00.97 N :.,.95 E 6334.74 8~.48 N 'i1'31, 6444.54 6564.72 1011,65 N ''! 6 E 6750.97 1056,39 N 1 .07 g FINAI, DEPTN 7420.00 V~RTICAT, O~PTH b~37.97 AT .rD: SUB-SE~ VERTTCI5 DEPTW &750.97 ttORTZONTAI, DEPARTURE D£ST~NCE AZTM~ITH 1734.~0 N 5~ 29 g - . . 'SCHLUMBEROER . 01RECT I ONAL SURVEY COMPANY~ WELL FIELD ARCO ALASKA INC . 1R-IS KUPARUK COUNTRY USA RUN ONE DATE LOOOEO 2£-AU0-85 REFERENCE OOOO'70"7'7~> .o WELL NAME: 1R- 15 SURFACE' LOCATION: 45'6' FSL, 144' FWL, S1-7, T12N, R10E, UM VERTICAL PROJECTION .-. 1000 1 SO0 2000 PROJECTION ON VERTICAL PLANE 53. - Z33. SCALED IN VERTlCAL OEPTHS HORIZ SCALE = I/SO0 IN/FT 0 ... WELL NAME: 1R-15 . 'SURFACE LOCATION: -456' FSL, 144'- .FWL, S17, T12N, R10E, UM . HORIZONTAL PROJECTION ' :"" 5C~-£ = ! / ~OO I N/FT 1000 500 -500 -1000 SOLffH -1~00 . J i J ! i I J ~ , :: i i i ': ~ :' ~ I -'.i j i J J J [ J i J J J I iTT'.".-"'"[TTT'-...'-F"T~---Ti"T'T-' .."TTT-F' "T'i"T"TTT'T"i~T'" ' ~ ~ i : ' i ; i ~ -~ :' ~ i ; ' : : : [ :' [--~ ~ i i '?--~-'~.-? .-?~'l-T-*--s'-'~- ., :- ,'., I., :' .-- ,- ..- ~I-..:..~ ..- ~ .- ........- ~ , _.. =- .- ..' , ~ I _: _.' I =-_.' ..- ..' I :- ..' ..- ~ I ~ :. , : '" ~ -" -" ~ :' : i i ': ....... _j ! ! i. J j [ :.j ;jt~ ! -" 'i i J ..' Li!'_,.Ji i ~ [ _! J ;_l. J ; ; i_ lili ~.liJ_; i ; ~ ! ! t i ; ; ; ; il j ; i [ t :' ! t .j....i./i ~ [ ~ J; [ i ~ ;T~~ [ [ [il ~ ; [ i .TT~ .T 'T-_.. ~; "T..~ ,.~Z-"-:' T- TT~ TS."I-Z_~"~ F'T-T'qTi'~'T" '?."~" '"?"?.."-F-r .... lJlJl jjj.j jjJJlJJJi iijjljjjj fiji JiJJ JJJJ iJJl! ,JJJJ iii! !ill lj[ilJJ]~ ~ ..~L"-~ J i ! !'j j j ~ j j j ! '.: I ~ i i ~ j j ! ! I J i J i i i i i J ! i J I i J J J J i ! ! ! j ! j t J i J 1 J J I i 1 I i j i i j J J ] j i i j"~ ,,,,,_...::..-~-.~_;-tL.-.:.;_ : .:,~ ...... ,, ...... _,_,, ,,_..: , : ,T:. -.._,~ ,~ ]J.,__u -- ' ............... I ...... ~ ....... ' ..... I' '~ '-I T-~-I-~/ , ; Iiillj] ~~.'-' ..:: : : : : · z : : : : : : ! : ~ : : : : , I : : : , ! : : : ..... I , ' . ~"~.:T'?': i i i i i i~-~'~ '~~-F. T~TT~'i-'~~' ~ t i ! J J i i T-T ,..-~Ci ? i i i i i t i i 'i i :~1.-T.!-~-.~.~-!-..t--i~.~.` ~..~..~-----i-~.. ~--~~~.-~...-'~I-~---~ p;~ : ~i ; : i ; : jm~t' i ~ ': .'- ;-i-4-~---4-4M-4-~.. ! f . :. ! i .:' .'-'4-4-4-4-4--~.4--~J-~--i4-t--i-~b~l~ ! i i i ~,~ ~ I i~ i :...i-4..- , ~: ~ .~- -:-?-.~s-: - -~: ~--.-s-~: 4M---.':--i--4-.--~-?-s---~-+ .~-.~+' ~- _+..:_~4-. ~+ .~?. ~.?+-+.. ~-/'.-4--~-.-;--+-+--~ .... + ...... +-s-.;+.---~...I .+_.,.+, +, ~++ ..... ~' .~..'"t-l~i~i. '*' :'-~+"~r'~"': ...... -??'-t-?'l-~-~-~.*. ................ -?t~"~-l-t-~,~-?"~ .... ~':.: ?"f-J'"r ~'"f- ......... -'f-~-f~'l ~': : :~"f'+'+~'-9-'~-+~'- ............ "~H'.~ "--~-~ '-~'~'~" F: ~ !.i't'"r~-?- -~..~-~-~ ~J.-+-.;--,-;-~. ~-.--~..~-q--.' ~-;z-4-4-f-/-.~.~- =~-~'~-~.-'-: ~---~- .-~..~-~-4-.4-~- -4-4-/-: ' .4--/-./-.-/-- ~4-4.-4-~- .4-.4.-~-~-- -4..-~--~--~- --++.,-+~--~.+H ........ :--.,:--+~---! ................. I-'-"'"* ........... * ............. ~~!---i--..--; ......... ;-+--;---;~---~ ......... **.-.~-+..~-~..; ........ ~---;.-.~.....~-~ ......... :.-..~-,-*-.4-.,--~.+, .... -~,.-,~-.-~. ~.- -~-4..~ --~- -.~ ' ;, , 4 i :. ~,__ ~. -4.-4- .i.- 4, -4-4-.4-- -4-i--4-4.- 4-.4.-4--4-- ~ 4~ · · 4, -.;--' -.i-.. ' '- ' ' - '-'- ' · - 4 ,i ' ' -~ .... -' ' · · - ~. .... ~ ............ t .... F ........ t- ...... ~ .... -.~..4--k:,,--;- . .-.,-, -4--~--L--i_~..i...:'.....~._i. ....... i..-=.-.!..: ~ .- i-.-z..-~-.;.-.J.-;-4-4.-L-4.-4--.-.=-.-.-.~.--~,--L4--F..~-4.-J...:' .... ~..4.-Lj-,L-.L.4-.4....~_-..L..i..-i..4-4-..~_J-L,.i ....... l....i....~-.~..J,-,4..-L.4---i--...k-4--,~_.L..-' .L..i ..... -~-~(4.g-4--~--i--.'".-4-~-~-44---;--;4---t-4444-.-Pk;-i ~ ~'.; ! l: i i: i 4..~4.--H-~-.':--~-~-.-4-.i-4..~:-~L~-..i..-:"-1.44--.-.'"44 ..;.;..".;4'- !-~.'..I-;. :...4-,--. :::::::::::::::::::::::: :H:i:::!:~H: :::::::::::::::::::::::::::::::::: :~±~J~:?. ::~.:i:2:i~:~:~..-. ::::::::::::::::::::::::::: :::::::::::::::::::::::::::: ::H~:l::t::!::!' i: i i i~-.5+-F-5-~.--~-+-f-i---~-~---::--~-l~---h~+~5-.:"¢~-+iii, i i ill ii i-~--H-H--+-+~--f~---~..-F-~--+-f~++-t~-~--+.1.-~ ....... .4-.~.4-4-4---~.-.:'....~4.-~--%4-.4--: -4-=. -...;-.-?!-~-.;-..~-.~-~-i-~-~-4- -i-i-4-4-4 -i-4-i-4- ..~..4--i-4-4-.4-4-4-.i ...... ~-.4..4--~-,...;-4..4 ...... ;-.-4...z.-;-.4.-..i..~--&..&.. -~--&-4..-~.4--; ........ ; · 44-~2.LL4~..%L.~...i _LLi__:._~..Li i I i ! ! i ii i i4~4 i i i i i..LLLLi..L..Xi ._L;q..LLi..;...i:.L&..L.i...L&;_uL...~.LN...i....; :~:~5~:"r':~::~::l:T~::T:i: :i:;:!;: i":;::~:::~:~::-'.:Z~:~¢7 ~---'½..T.~5~.;:'.:: ::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::: !.: :::::::::::::::::::::::::::::::::: :::::::::::::::::::::: ~Z-:-~-~TTT'~'";'"?",'-~' ?' 'i-T"i'"7'T' 7T"f-;" 7'T"?TY"i'TT-!'T'i-.'.-'-¥~-? :--~.~7::'"'-T'TTT-*...'"TT-:'"'-.-i-7-;'";"TTT'?'F'! I"; ";";"'F"~": "?"T'7" "'?'T'T'T"!" ;'"'": _J ~ ~ i s i ~ i ~ '-'~.-I~ ~ ! ! ..... ..... ............. -'- '-' ~.4~-,~ : : :~_.Z ~_;, 4-4- ' ~ ~.- 4-.1-: : .~.4. I-4.-.P4-~-.~Z-q-.L-~- ~ ~.~.,~-i...,M,,.4, .~- .4 .4.4-4-- .~-.~-..~..;..-.'...~...-~ .:...~..,..~-.~-...~ ~...4....,-~.,..~ ..... ..... ........ ?, ....... ..... :".'"? ..... NEST -1500. -1000 -500 0 500 ]000 ]500 2000 2SO0 EAST Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OR, WELL I~AME AND ~NUMBER Reports and Materials to be received by: V-- l~-- Date Required Date Received Remarks Completion Report Samples ._ -.... - Mud Log Core Chips Core Description Registered Survey Plat 'Directi°nal Sur~ Production Test Reports X~ X,X~-.~ ~.--_-~--_.~..~U{~/~ Digitized., , Data~ ARCO Alaska, Inc. Post Office Bc J0360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 13, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton: Enclosed are the August monthly reports for the following wells' 2A-15 3C-7 1R-14 6-9 (workover) L1-2 L3-5 2A-16 3J-1 1R-15 6-10 (workover) 11-14 WSP-4 3A-1 3J-2 1R-16 9-30 L2-20 WSP-6I 3C-4 1R-1 2Z-9 ' 9-31 L2-24 WSP-20 3C-5 1R-2 2Z-10 11-9 (workover) L2-26 If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU11/L62 Enclosures Nasl(a 0i~ & Gas Cons. Commiss~0n Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRIchfleldCompany - STATE OF ALASKA ALASKA O .~.--AN D GAS CONSERVATION CON._.,-'ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wel~(J~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-152 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21387 4. Location of Well at surface 456' FSL, 144' FWL, Sec.17, T12N, RIOE, UM 5. Elevationinfeet(indicate KB, DF, etc.) 6. Lease Designation and Serial No. 84' RKB ADL 25635 ALK 2568 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1R-15 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. August , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1815 hrs, 8/7/85. Drld 12-1/4" hole to 3820'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 7420'TD (8/11/85). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 7311'. Secured well & RR ~ 1400 hrs, 8113/85. 13. Casing or liner run and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 115'. Cmtd w/225 sx CS II. 9-5/8", 36.0#/ft, J-55, BTC R-3 csg w/shoe @ 3804'. Cmtd w/808 sx PF "E" & 310 sx PF "C". 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 7397'. Cmtd w/300 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/SP/GR f/7419' - 3804' FDC/CNL f/7419' - 5850' & 4350' - 3804' Cal f/7419' - 5000' RECEIVED 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~/r)//~J~/~-' ~.~)¢~)'Lj TITLE Associ ate Engi neet DATE ¢'/~ -c'~'- NOTE--Reporl~on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by tl~lM~t,)h/~l~tt~ succeeding month, unless otherwise directed. Form 10~104 Submit in duplicate ARCO Alaska, Inc~...... Post Office ['~x 1003G0 Anchorage,, Alaska 99.510-0360 Telephone 907 276 1215 DATE: 08-30-85 TRANSNITTAL NO: 5317 RUTU l-d~ %'0: ARCO ALAbKA, INC. KUPARUK OPE RATIONS RECORDS CLERK .,~TU- 11 P.O. sox 100360 ANCHORAGE, AK 99510 ENGINEERING. ~" l~N SN I TTED RECEIPT AND OPEN HOLE LI 2Z-9 08-11-~5 22,-10 0~-04-85 3C-~ 07-23-85 1R-16 08-19-85 1R-15 08-12-85 1K-14 0~-06-85 2A-16 08-18-85 2A-14 07-28-85 2A-15 0~-08-85 tJF.'kE~IT[i ARE 'i'JJL FOLLO%~ING ITl'MS. PLEASE ACKNO~L-EDGE kE'I'UI~I~ ONE SIGNED COPY OF THIS ~RANSMITTAL. S TAPES AND LISTING/SCHL/ONE COPY OF EACH RUN #1 3487.0-7357.0 REF # 70730 I~,UN #1 3790.0-7866.0 REF ~ 70712 F, UN #1 5184.0-10065.5 I<EF # 70683 RUN #1 4062.5-8463.5 REF # 70754 RUN #1 3788.0-7442.5 REF # 70738 KUN ~i2 4602.U-9158.0 REF ~ 70726 RUN #1 8979.0-9789.5 R£F # 70753 ~UN ~1 7170.5-7871.5 R£F # 70705 RUN #1 7420.0-8142.0 REF # 70731 RECEIpr£ ACKNO}~LEDGUD: DISTRIBUTION: BPAE DRILLING W. PASHER B. CURRIUR L. JOIiNSTON EXXON CIJUVRON b,OB1 L PIIILLIPS OIL D & l,'~ NSK CLEi~K J. RATiIi.'IELL 501110 UNION K. TULIN/VAULT July 2, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Uni~ 1R-15 ARCO Alaska, Inc. Permit No. 85-152 Sur Loc 456'FSL, 144'F%.~L, Sec 17 T12N, R10E UM. Btmhole Loc. 1492'FSL, 1554'FWL, Sec. !7, T12N, R10E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their.drainage systems have been classified as important for the spawnJmg or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgate~ thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. Ke~in Kuparuk River Unit 1R-15 -2- July 2, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly y~o~s, C. V. Cha~-tertSn Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office Bo-...~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 19, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1R-15 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk a $100 application fee o Diagrams showing the proposed horizontal projections of the wellbore o A proximity plot o A diagram and description of the surface system ° A diagram and description of the BOP We estimate spudding this well on July 26, questions, please call me at 263-4970. erely, Area Drilling Engineer JBK/HRE/tw : PD/L113 Enclosures 1R-15, along with and vertical hole diverter equ i pment 1985. If you have any R£C£ VED N 2 B I B5 Gas Cons. c0mmission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKAi:::rrL AND GAS CONSERVATION C~MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL I~X DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, ^nchorage, Alaska 99510 4. Location of well at surface /+56' FSL, 14/+' FWL, Sec.17, T12N, R10E, UN At top of proposed producing interval 1265' FSL, 12/+5' FWL, Sec.17, T12N, R10E, UN At total depth 1492' FSL, 155/+' FWL, Sec.17, T12N, R10E, UPI 9. Unit or lease name Kuparuk River Unit 10. Well number 1R-15 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 84', PAD 47' I ADL 25635 ALK 2568 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 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse 1R-14well 60' @ surface feet 16. Proposed depth (MD & TVD) 7375' MD, 6767' TVD 18. Approximate spud date 07/26/85 19. If deviated (see 20 AAC 25.050) 2818 psig@ 80°F Surface ' KICK OFF POINT /+100 feet. 3235 psig@ 63/+.5 ft. TD (TVD) 14. Distance to nearest property or lease line miles 3726' @ TD feet 17. Number of acres in lease fe~.t 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 42 o (see 20AAC25.035 (c) (2) Proposed Casing, Liner and Cementing Program 21 ~ SIZE -- CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 124" 16" 62.5# H-40 Weld 80' 35' I 35' 11511 115' · 200 cf !12-1/4" 9-5/8" 36.0# -55/HF-EItW BTC 3765' 35' I 35' 3800~ 3800' 1150 sx PF "E" & ~ I i I I 310 SX PF "C" I ,, 7" ' 18-1/2 26.0# .-55/HF-EI[W BTC 7341' 34' lI 3/+' 7375~ 6767' 260 sx 61ass 6 neat I I I 22. Describe proposed program: ARCO Alaska, Irc., proposes to drill a Kuparuk River Field development well to approximately 7375' MD (6767' TVD). Selected intervals wi]] be logged. A 20", 2000 psi annular diverter w~]l be instal]ed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2818 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 1R-15 will be 60' away from 1R-14 at surface. There are no closer wellbores anywhere downho]e. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby certify that the foregoing is true and correct to the best of my knowledge CONDITIONS OF APPROVAL Samples required [] Y ES / Permit number APPROVED BY L_. F // / ........ % '../. L Form ~0-4~ -(HR~ PD/PD11~ Mud log required [~YES ~ Approval date ~ .~ 0 7/~0 2/~8 5 Directional Survey required I APl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE July 2, 1985 by order of the Commission Submit in triplicate PERMIT TO DRILL 1R-15 (cont' d) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 200 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" x 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve wi]l be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. HOR I ZONT AL '-'ROJECT I ON: SCALE I IN.'~''" 1000 FEET IR' WELL NO~ I$ PROPOSED UK FIELD. NORTH SLOPE, ALASKA _ EASTMAN WHIPSTOCK, iNC. 3000 1000 _ 1000 0 2000 ii I WEST-EAST ~ooo 3000 ~.OGGtlIG Pt) ....... TVD~644~ : · m~.em43 EAST 1ITS SURFAC~ LOP, AT.I Oil* 456' FSI., 144' FIR. SEC. IT. 1"12N, RIOE TARG~'T LOCATION, 1320e iFIL. 1320' SEC. I?. Tl~lb RII:~' N 53 DEl3 1459' (TO 42 MI N E TARGET) ~k~sV, a 0~t 8, G~s Cons, /d~G0 ALASKA, PAD' tR. k/ELL NO, 15 PROPOSED KUPARUK FXELD,. NORTH SLOPE, ALASKA. EASTI"IA~ I, MI~$TOCKi. INC. BASE PERI'IAFROST* TVD-1634 $000-. 6000. 7000 TOP UG#U S#DS TVD"2?3~ TOP t,/ SAK SND$ TVD-3364 K-12 TVD-3694 --~SG PT TVD-3600 ~ ' ..AVERAGE ANGLE KOP TVD-4100 THD-4100 DEP'O" 42 DEG' 10 3 'X% :se, EOC TVD-$382 Tt'ID-5506 DEP-495 .'/~x~k'~ K,$ rvo-5584 TI'ID'$Z78 DEP"e?7 '" ' ' '~ . TOp UPPR 'SNOS TVD-6345:T~-6805 DEP-~36r _ '~ TARGET CNTR TVD-6447 THD-6943 DEP-1459 x %,** ", TOP LOt, IR SNDS TVD-6505. TI'ID-?021 DEP-1512 'x~. ' BASE KUP SNDS TVD-6619 TtlD-?I?5 DEP-1615 "%- TD (LOG PT) TVD-6?6? TI'ID-?3?5 DEP=1749 ' ' RECEIVED 0 1000 2000 VERTICAL SECTION JUN2$ ~,[ Alaska. Oil & Gas. Cons. Commission Anchorage 0 100 '00 _ ~:'00 _ 500 _ ¢~00 _ ~00 _ 200 . .NO'RTH ! O0 200 300 400 I I I I . , I! /,,o, !. / f I '/ '~ ~4~ /.!/,..,; ',,. .... 28TT 3055 3141 50O I, 3223 600 33T8 3302 700 I 3,~51 ARCO ALASKA, INC. PAD 1, R, WELL NOi 13"14-15-16 PROPOSED KUPARUK FIELD. NORTH SLOPE. ALASKA EASTPIAN WHIPSTOCK. INC. WELL, P.ATHS.E>tTEND BEYOND_. THIS_VIEWING WINDOW 800 900 1 DO0 Surface Dive.er System - 2000 ~$i Tankco starting head. Tankco quick connect assy. x 20' 2000 psi double studded ada;tar. 2000 psi ~rtlling. spool w/10' side e~. ' ball valves, hydraulically act~ate~, w/10' lines to ~se~e pit. Valves ~ open auto~i~lly upon closu~ of annular p~ventar. ~O00 psi annular'p~ventar. · 7. Z0' bell nipple. Mat ntenance & 0Derati on Upon initial tnsl'~llation close annular preventer and veri~y ~at ball valves have o~ened properly. 2. Close annular preventer and blow &ir t~rougb dj verier lines 'every 12 hours. 3. Close-annular preventer in ~e evenc.~at gas or fluid fl~ to su~ace is detect~. If necassa~. ~numlly ove~de end close ball valve to u~ind dive.ar line· Oo not s~ut in ~11 un,er any ci~tancas. [6" Conc~uctor RECEIVED JUN2$ A!aska 0[i & Gas Cons. commission Anchorage 7 6 DIAGRAM #1 1,3-5/8--~~ PSI RSRRA BOP STACK I. 16" - 2000 PSI TAb, CO STARTING HF_AD 2. Il' - 3000 PSI CASING HEAD 3. 11' - 3000 PSI X 13--5/8' - 5000 PSI SPACE~ SPOOL 4. 13-5/8' - 5000 PSi PIPE P. AM~ 5. 13-5/8' - 5000 PSI DRILLING SPOOL W/CHO(E AAD KILL 6. 13-5/8' - 5000 PSI DOUBLE RAM W/PIPE RAMS CH TOP. 7. 13-5/8' - 5000 PSI At~LM_AR ,.ACO.IVtJL. ATOR CAPACITY TEST I. CHECK ~ FILL ACCL~TDR RESF_RVOIR TO F~ LEVEL WITH HYDRAIX. IC FLUID. 2. A~ THAT ACC~TC~ F~~ IS ~300 PSI WITH 3. ~VE TI~E, T~ CLOSE ALL UNITS SINIJLTANEOUSLY A~ RE(~ TH~ TI~ A~ F~ RE~INING AFTER ALL UNITS ARE CLOSED WITH CHAROING F~ OFF. 4. RECCRO CN NAD(: REPDRTo THE ACCF_PTABLE LO/dER LIMIT IS 4S SE(X]q:~ CLOSING TIN~ AED 1200 PSI REMAINING 5 4 2 13-5/8"' BOP STACK TEST FILL BOP STACK AI~ CHO(E MANIFOLD WITH ARCTIC DIESEL. CHECK THAT ALL LOCK DOf~ ~ IN VME]_~ ARE FULLY RETRACTED. SE. AT TEST PLUG IN WITH FB..t~ING Jl' AAD RUN IN LCX:XI:X3~ SCREV~. 3. CLO~ A~ ~ A~ MANUAL KILL AhD C~ LIE VALVES ADJACENT TO 8~P STACX. ALL VALVES AND ~S SNOIJLD BE OPE:N. 4. PRE~ UP TO 2.50 PSI AhD HOLD FOR I0 MIN. IN.-- CREASE PRESSURE TO 3000 PSI ~ HOLD FDR I0 MIN. BLFF'D PRE~ TO 0 PSI. 5. OPEN Ah/C.LAR PREVENTER AAD MAt, IJAL KILL AAD Q-K]KE LIhE VALVES. CLOSE TOP PIPE RAMS AAD HCR VALVES CIN KILL AI',D CHOKE LI~ES. 6. TEST TO 250 PSI AAD 3000 PSI AS IN STEP 4. 7. CONTI~ TESTING ALL VALVES, LIhES, ~ Q-E~ES WITH A 250 PSI LOW AAD 3000 PSI HIGH. TEST AS IN STEP 4. EX3 NOT PEE~ TEST ANY CI-E3KEcI~THATyIR NOT A FULL CLOSING POSITIVE SEAL ~ION TEST CH(:KI~S THAT DO NOT FULLY CLOSE. 8. OPEN TOP PIPE RAMS AhD CLOSE BOTTCI~ PIPE TEST BOTTCI~I PIPE RAMS TO 250 PSI AhD 3000 PSI. 9. OPEN BOTTC~ PIPE RAMS° BACK OUT RUNNING JT AAD PtJLL OUT OF HOLE. I0. CLOSE BLIhD RAMS AND TEST TO 250 PSI AAD 3000 PSI. I1., CPEN BLIND R/~,4S /LND RETRIEVE TEST PLUG. MAKE SURE MANIFCLD AhD LIhES ARE FULL .OF .NON-FREEZING FLUID.' SET ALL VALVES IN. DRILLING.POSITION.- 12. · TEST STAhDPIPE VALVES, KELLY,' KELJ_Y COCKS° DRILL- PIPE SAFETY VALVE, AhD INSIDE BOP TO 2.50 PSI' AAD 3OO0 PSI. RECCRD TEST IhF~TIC~ CH BLCWOIJT PREVENTER TEST FOI:~, SIGNo AhD SEhD TO DRILLING SLPERVISDR. PERFC~ O2N~ETE BOPE TEST AFTER NIPPLING l.~ AhD JEKLY THEREAFTER FUh~IC~LLY OPERATE BCPE DAILY. 510084001 REV. 2 MAY 15° 19G5 ARCO Alaska, Inc Post Office't~Ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 20, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 1R Pad Wel 1 s 1-16 Dear Elaine' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L115 Enclosure If ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichlieldCompany ~ WELL I'~ ¥:5,991,050.09 Lat.-- 70°23'11.370'' X = 539,829.76 Long.-- 149o40'33.808" ~ SEC. 20 -- 154'FNL, 139'FWL N O R T H I. WELL 2 Y= 5,990,990.16 L~I. = 70°23'10.781" i x = 539,829.82 Long. = 149°40'$3.816 ; SEC. 20-- 214'FNL, 13S'FWL WELL 3 ¥= 5,990,930.24 Lat = 70°23'10.192'' ~ "~ X = 5~9,829.78 Long. = 149°40'33.826'' SEC. 20-- 274'FNL, 138'FWL .~,z ~ ,~ WELL 4 ~= 5,990,870.26 Lot. = 70023'09.602 ' x= 539,829.77 Long. = 149°~'33.836" ~ ~4~/~/ SEC. 20 -- 334' FNL, 137' FWL "~,o ,~y WELL 5 T= 5,990,870.21 Lat. = 70023'09.620" s ~6~ X= 539~469.75 Long.= 149°~'44.377" ' SEC. 19- 352'FNL~223'FEL : WELL 6 Y=5,990,930.21 L~t. = 70°23'10.210" ~ X= 539~469.74 Long. = 149°~'44.368'' . ~ ~ SEC. 19 -- 272' FNL~ 222'FEL WELL 7 ~: 5,990,990.23 Lot.-: 70°23'10.800" X: 539,~9.76 Long.: 149°~'~.358" ~1~,~ SEC. 19 -- 212' FNL, 222'FEL -- s~9 820 WELL 8 Y= 5,991,050.20 Lat. = 70°23'11.390" ~ X= 539,469.73 Long. = 149°40'~.350 ; .~ SEC. 19-- 152'FNL, 221'FEL ~, e ~ - ' WELL 9 ~= 5,991,600.16 Lat. = 149040'44.259"70°23'16'8~" ~7 ~ 2~ X = 5~9~ ~9.91 Long. = ' SEC. 18 ~ 398' FSL~ 216'FEL ~ WELL 10 y= 5,991,660. II Let. = 70°25'17.389" X = 5~9~469.82 Long. = 149°40'~.253" SEC. 18 -- 458' FSL~ 216~FEL ~ ~ WELL i i ~= 5,9~,7~0.~7 L~t. = 70°2~' ~7.~e0" , X = 539~9.81 Long.= 1~9°~'44.2~4'' ~ , , ,' SEC. I8 -- 518'FSL,~I5'FEL :[~ WELL 12 v= 5,991,780.16 ~t. = 7~23'18.570" x = 539~469.78 Long. = 149°40'44.255" SEC. 18 -- 578' FSL, 215'FEL DRILL SITE ,"=,oo' WELL 13 Y= 5,99,,7~0.~6 Lot. = 70°~',~.55~" X = 539,829.73 Long. = 149040'33.695" AS-BUILT CONDUCTOR L~ATIONS s~c.~7-- 576'FSL, 145'F~ WITHIN SECTIONS 17,18,19 a 20, TI2N,RIOE, U.M. WELL 14 Y=5,991,720.13 Lot. = 70°23'17.961" X= 539~829.71 Long.= 149°40'~3.705''' NOTE: SEC.17 -- 516' FSL, 145'FWL C00EDINATES ARE ALASKA STATE PLANE, ZONE4. WELL J5 Y=5,991,660.19 L~t. = 70023'17.371'' SECTION LINE DISTANCES ARE TRUE. X= 5~9~829.71 Long. =-149°40'33.715'' HORIZONTAL 6 VERTICAL POSITIONS PER L.H.E SURVEYOES~ SEC. 17 -- 456'FSL, 144'FWL O0CUMENTN0.129:NI9+69 NI7+25 WELL [6 Y=5,991,600.20 L=t. = 70°23'16.781" E 9+56 ~ E 15+25 X = 539~829.77 Long.= 149°40'33.722" EL.50.39 EL.38.75 SEC. 17-- 396'FSL~ 144'FWL CERTIFICATE OF SURVEYOR: I HEREBY CERTIFY THAT I AM PROPERLY . SURVEYING IN THE STATE OF ALASKA ~O THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND ~ ..11 ~.~ SURVEYED FOR. AK~U ~IOSKG- IRC. oon,c~7~:- ~~~~~~ IKil" ~ o,~, MAYg,19851 . :'~ ~ ?, m-~ JUil o.~w. dDAVISIPREPAREDFOR: ~S~OILF/ELD " ........ ;-?, ~ ~ .... ';~ I " ~CHECK IfIST~:FOR NEW.'WEL"L [pERMITS:' i.. COmpany (1) Fee (2) Loc ,, APPROVE DATE ? (.~ thru 8) Lease' &: Well YES NO -. -- ., 1 ' Is the permit fee attached . · ' ee®®e®eee® ee~eeee · eeeeeeeee~ eeee.®eeee e®e 2. Is well to be located in a defined pool ............. ... 3. Is well located proper distance from property linei!!~ ~! !!! !i 4. Is well located proper distance from other wells . ..~.. 'i..' 5. Is sufficient undedicated acreage, available in this pool .......... 6. Is well to be deviated and is wellbore plat included- . ....... . ...... 7. Is operator the only affected party ................................ · 8. Can permit be approved before ten-day wait ............. (3) Admin d~- V -~~9 -(~ thru 12) 10! 12. 13. ' 14. 15. 16. 17'. 18. 19. 20. '21. 22. 23. 24' 25. 26. '27. (10 and 12) (4) Casg ~.~. 4~. (13 th'ru 21) REMARKS (22 thru 26) · · Does operator have a bond.in force .................... . .............. ~r Is a conservation order needed ...................................... Is administrative ·approval needed . eeeeeeeeeeeeeeeeeeee~ee~e®eeeeeeeee Is the lease number appropriate ..... · ............................... /~ Is conductor string provided ........................................ ~ Is enough cement used to circulate on conductor and surface ......... ~_ Will cement tie in surface and intermediate or production strings ... Will cement cover 'all known productive horizons ....... .......... ,...~ Will surface casing protect fresh water zones ................... ~ .... ~ Will all casing give adequate safety in collapse, tension and burst'. ~ Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ ~ Is a diverter system required ................ ~ ........ · ............ ,. ~ Are necessary diagrams, of d'iverter and BOP equipment attached .... ' ii'/~,~ ' Does BOPE have sufficient pressure rating'- Test to ~ psig . __ Does the choke manifold comply w/API RP-53 (Feb. 78) ......... ......... Is the presence of H2S gas probable ................................. Additional requirements ' leeeeeeeeeee~eeeeeeeeeeeeeeeeeeeeeeeeeeee~eee ,& .. , 0 Additional Remarks: Geology: Engineering: ,- WVA ~MTM'~ HJH /,' JAL~ ' . rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE .. Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. LIS TAPE VERIFICATION LISTING LVP OlO.H02 VERIFICATION 'LISTING PAGE 1 · ~ REEL HEADER SERVICE NAME :EDIT DATE :85/08/17 ORIGIN : REEL NAME :1.49139__ CONTINUATION # :01 PREVIOUS REEL COMMENTS :LIBRARY TAPE ~-~.~ TAPE HEADER ~: SERVICE NAME :EDIT DATE :85108/17 ORIGIN :0000 TAPE NAME :0738 CONTINUA'TION # :01 PREVIOUS TAPE : COMMENTS :LIBRARY TAPE ~ FILE HEADER ~.~ FILE NAME :EDiTi .001 SERVICE NAME : VERSION ,~ : DATE : MAXIMUM LENGTH : 1024 FiLE TYPE : PREVIOUS FILE : INFORMATION RECORDS MNEM CONTENTS CN : ARCO ALASKA INC WN : 1R-15 FN : KUPARUK RANG: IOE TOWN: 12N SECT: 1T COUN: N.SLOPE STAT: ALASKA CTRY: USA MNEM CONTENTS PRES: E ~: COMMENTS UNIT TYPE CATE SIZE CODE 000 000 016 065 000 000 006 065 000 go0 008 065 000 000 004 065 000 000 004 065 000 000 002 055 000 000 012 065 000 000 006 065 000 000 004 065 UNIT TYPE CATE SIZE CODE 000 000 001 065 LVP OlO,.H02 VERIFICATION LISTING PAGE 2 ',- SCHLUMBERGER ~ A'LASKA COMPUTING CEN'TER -,--,.-,-.~.~.~. q-.,..,c%,~.~.,.~:.,.~k~&.,.~ ~-v , ~ ~, ~ COMPANY = ATLANTIC RICHDIELD;'COMPANY WELL' = 1R-15 FIELD : KUP:~RUK COUNTY = NORTH SLOPE BOROUGH STATE = ALASK,~ JOB NUMBER AT ACC:,.70738 RUN #1, DATE LOGGED: 12 AUG 85 LOP: L. B. CUDNEY CASING TYPE FLUIO DENSITY VISCOSITY PH FLUZD LOSS = 9.625" @ 3804' - BIT SIZE = 8.5" TO 7~18' = X-C POLYMER : 9.'% LB/G RM = 2.910 @ 66.0 DF' = 36.0 S RMF = 2..490 ~ 66.0 DF : 9.5 RMC = 3°270 @. 66,0 DF = 5.6 C3 RM AT BHT = 1.465 @ 138' DF M4TRIX S,~NOSTONE LVP OIO.H02 VERIFICATION LISTING PAGE 3 THIS DATA HA.S NOT BEEN DEPTH SHIFTED - OVERLAYS FIE'LO PRINTS ~,~,~ SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC TAPE: DUAL INDUC'TION. SPHERiCALLY FOCUSED L~G (OIL) DATA AV~I'LABLE: 3802' TO 7414' FORMATION DENSITY C'DMP'ENS~TED LOG (FDN) CDMPENSAT'ED NEUTRON LOG (FDN) DATA AVAILABLE: 3802' TO 7388' ~ DATA FORMAT RECORD ~* ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 1 66 0 4 1 66 1 8 4 73 60 9 4' 65 ,.liN 15 1 66 1 0 1 66 0 LVP OlO.H02 VERIFICATION LISTING PAGE 4 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API ID ORDER J LOG T DEPT, FT O0 SFLU DIL OHMM O0 ILO OIL OHMM O0 ILM OIL OHMM O0 SP OIL MV. O0 GR DIL GAPI O0 GR ~ON GAPI O0 CALI FON IN O0 RHO8 FON G/C3 O0 DRHO FDN G/C3 O0 NRAT FON O0 RNRA FON O0 NPHI FON PU O0 NCNL FDN CPS O0 FCNL FON "CPS O0 DATA DEPT 7442,5000 SFLU -99 SP -999,2500 GR -99 RHOB -375.2,5000 DRHO -380 NPHI 40,869~ NCNL -58 A. PI API YPE CLASS 000 O0 220 O1 120 46 120 44. 010 O1 310 O1 310 O1 280 O1 350 02 356 O1 420 01 000 O0 8'90 O0 330 31 330 30 9.2500 9.2500 4.5000 2.6875 DEPT 7400'0000 SFLU 2 SP -11.9980 GR 77 RHOB 2.5334 ORHO 0 NPHI 42,7734 NCNL -582 DEPT 7300.0000 SFLU 2 SP -30.9951 GR 97 RHOB 2,4651 DRHO 0 NPHI 33.8379 NCNL 2079 DEPT 7200,0000 SFLU 2 SP -21.2451 GR 100 RHOB 2,4846 DRHO 0 NPHI 47.6074 NCNL 1767 DEPT 7100.0000 SFLU Z! SP -22.4639 GR 76 RHOB 2.3206 DRHO -0 NPHI 27.4902 NCNL 2641 DEPT 7000.0000 SFLU 5 SP -19,4795 GR 84 RHOB 2.4475 DRHO 0 NPHI 30.0781 NCNL 2361 OEPT 6900,0000 SFLU 5 SP -14,9902 GR 75 .8557 .9648 .1904 .6875 .6370 .6523 .0122 .5000 .3674 .9648 .0806 .6875 .8330 .4023 .0029 .5000 .5984 ,7148 .0151 .5000 .8992 .4648 AP I MOD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ILO GR NRA'T FCNL ILO GR NRAT FCNL ILO OR NRAT FCNL ILD GR NRAT FCNL ILO GR NRAT FCNL ILO GR NRAT FCNL ILO GR FILE NO. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 S I -999. -26. 3. -157. 2~ -26. 3. -157. 0 96. 3. 664. . 100. 3. 437. . 57, 2, 952 · . 760 · . ZE SPL REPR PROCESS CODE (OCTAL) 4 i 68 00000000000000 4 I 68 00000000000000 4 1 68 00000000000000 4 I 68 00000000000000 ¢ 1 68 00000000000000 4 1 68 0000000000.0000 4 1 68 0000~0000~000000 4 1 68 00000000000000 4 1 68 000000000000:00 4 1 68 00000000000000 4 1 68 00000000000000 4 1 68 00000000000000 4 i 68 O000000OO00000 4 1 68 00000000000000 4 1 68 00000000000000 2500 ILM -999.2500 3,232 CALI 8,5020 3733 RNRA 3.7034 3125 4553 ILM ,2.5217 3232 CALI 7.0476 3733 RNRA 3.7034 3125 3752 ILM 2,4866 OBgB CALI 8,9160 0237 RNRA 3,1292 3125 2014 ILM 2,3245 5898 CALI 9,0645 7874 RNRA 4.0359 8906 7363 ILM 10.7129 9023 CALI 8.5957 5823 RNRA 2.7717 3125 3015 ILM 4.5789 8398 CALI 9.2207 8049 RNRA 3.1038 3125 7937 ILM 6.0359 1523 CALI 8.9082 LVP OlO.H02 VERIFICATION LISTIN~ PAGE RHOB 2,4260 DRHO NPHI 32.4219 NCNL. DEPT SP RHOB NPHI 68.00.0000 SFLU -17,4951 GR 2.6819 DRHD 36.7188 NCNL DEPT SP RHDB NPHI 6700'0000 SFLU -12,9980 GR 2.3831 ORHD -999,2500 NCNL OEPT SP RHOB NPHI 6600-0000 SFLU -14,2715 GR 2,3772 DRHO -999.2500 NCNL DEPT SP RHOB NPHI 6500'0000 SFLU -22.7451 GR 2.3303 DRHO -999.2500 NCNL' DEPT SP RHOB NPHI 6400.0000 SFLU -29.0107 GR 2.4221 DRHO -99'9.2500 NCNL DEPT SP RHOB NPHI 6300.0000 SFLU -21.9951 GR 2.4182 ORHO -999.2500 NCNL DEPT SP RHOB NPHI 6200.0000 SFLU -21.5264 GR 2.4124 DRHO -999.2500 NCNL DEPT SP RHOB NPHI 6100.0000 SF'LU -26.5420 GR 2.3928 DRHO -999.2500 NCNL DEPT SP RHOB NPHI 6000.0000 SFLU -27.2607. GR 2.4202 DRHO -999.2500 NCNL DEPT SP RHOB NPHi 5900.0000 SFLU -29.2607 GR 2.4280 DRHO -999.2500 NCNL DEPT 5800.0000 SFLU 0.0122 NRAT 2301.5000 FCNL. 3.3538 ILO 102.3398 GR 0.0049 NRAT 2499..5000 FCNL 1.8839 ILD 125.8398 GR 0.0073 NRAT 1785.5875 FCNL' 1.3594 ILO 119.2148 GR -0.0015 NRAT 1611.6875 FCNL 2.5569 ILO 126.9023 GR 0'012'7 NRAT 1516.6875 FCN'L 2.3538 Ikg 208.4375 GR -0.0044 NRAT 1.609.6875 FCNL 2.4495 I.LD 99.6523 GR -0.0063 NRAT 2101.5000 FCNL 2.0198 ILD 103.8398 GR 0.0029 NRAT 2111.5000 FCNL 1.7589 iLD 100.0273 GR 0.0127 NRAT 1884.6875 FCNL 1.8975 ILD 80.5273 GR 0.0059 NRAT 2000.6875 FCNL 2.0725 ILO 83.2773 GR 0.0229 NRAT 1893.6875 FCNL 1.8194 ILD 2.9358 '764.8125 2.9026 98,2773 3.2522 662.8125 1'6876 1,21.3398 -99'9.2500 420'1406 1.2618 109.0273 -999.2500 400.890,6 2.3010 126.9023 -999,2500 425.3906 2.~0725 208.4375 -999.2500 451.6406 2.2854 99.6523 -999.2500 692.312.5 2.0706 103.8398 -999.2500 709.3125 1.8505 100,0273 -999.2500 601.3125 2.0295 80.5273 -999.2500 611.8125 2.0901 83.2773 -999.2500 559.8125 1.6846 R NRA ' iLM C~LI RNRA ILM CA.LI RNRA iLM RNRA I LM CALI R N:R4 ILM CALI RNRA ILM C AL I RNRA ILM CALI RNRA ILM CALl RNRA ILM CALI RNR~ ILM CALI RNRA ILM 3.0081 3,0764. 9.7988 3,7698 1.7540 9.5020 4.2507' !.3253 9..0879 4.0203 2. '37 92 9.0879 3. 5647 2.1545 9.2676 3.5627 2,3967 9.1816 3,0334 2.1721 9.2285 2.9749 1.9151 9.2598 3.1350 2.1057 9.2051 3.2698 2.1467 9.2207 3.3831 1.7227 LVP OlO.HO2 VERIFICATION LISTING PAGE 6 RHOB NPHI OEPT SP RHOB NPHI DEPT SP RHOB NPHI DE PT SP RHOB NPHI DEPT SP RHOB NPHI DEPT SP RHOB NPHI OEPT SP RHOB NPHI DEPT SP RHOB NPHI DEPT SP RHOB NPHI DEPT SP RHOB NPHI DEPT SP RHOB NPHI -28.5576 GR -999.2500 DRHD -999.2500 NCNL 5700..0000 SFLU -28.7295 GR -999.2500 ORHO -999.2500 NCNL 5600'0000 SFLU -45.5195 GR -999.2500 DRHO -999.2500 NCNL 5500.0000 SFLU -50.0508 GR -9,99.25001 DRHO -999.2500 NCNL 540'0.0000 SFLU -62.2695 GR -999.2500 DRHO '-999.2500 NCNL 5300.0000 SF'LU -68-7552 GR · -999.2500 DRHO -999.2500 NCNL 5200.0000 SFLU -64.7227 GR -999.2500 DRHO -999.2500 NCNL 5100.0000 SFLU -64.0352 GR -999.2500 DRHO -999.2500 NCNL. 5000.0000 SFLU -72.5352 GR -999.2500 DRHO -999.2500 NCNL 4900.0000 SFLU -68.7852 GR -999.2500 DRHO -999.2500 NCNL 4800.0000 SFLU -78.4727 GR -999.2500 DRHO -999.2500 NCNL 106. -999. -999. . 110. -999. -999. . 1 ! 7. -999. -999. 3 . '104. -999. '-999. . 108. -999 · -999. , 100. -999. -999. . 100. -999. -999. . 96. -999. -999. . 96. -999. -999. . 91. -999. -999. . 127. -999. -999. 8398 2500 25 O0 9844 71,48 2500 2500 9475 2148 2500 2500 0471 5898 2500 2500 7971 4648 2500 2500 9026 4023 2500 2500 0334 152.3 2500 2500 1506 0898 2500 25O0 8206 6523 2500 2500 2717 2773 2500 2500 0022 3398 2500 2500 GR NRAT FCNL ILO GR NRAT FC NL ILO GR N RAT FCNL ILD GR , NRAT FCNL ILO NRAT FCNL ILO GR NRAT FCNL ILD GR NRAT FCNL ILO GR NRAT FCNL ILD GR NRAT FCNL ILO GR NRAT FCNL ILD GR NRAT FCNL -999.2500 -999.2500 -999.2500 1.6983 -999.2500 -999.2500' -999.2500 2.9104 -999.2'500 -999.2500 -999.2500 2.9456 -999.2500 -999.2500 -999.2500 3.3635 -999.2500 -999.2500 -999.2500 2.8948 -999.2500 -999.2500 -999.2500 3.0471 -999.2500 -999.2500 -999.2500 3.0100 -999.2500 -999.2500 -999.2500 2.9163 -999.2500 -999.2500 -999.2.500 2.3381 -999.2500 -999.2500 -999.2500 2.8264 -999.2500 -999.2500 -999.2500 C ALI RNRA ILM, CALI RNRA ILM CALI RNRA ILM, CA'LI RNRA I LM CALI RNRA I LM CALI RNRA iLM RNRA ILM CALI RNR~ ILM CALI RNRA ILM CALI RNRA ILM CALI RNRA -999.2500 -999.2500 1.7764 -999.2500 -999.2500 2.9768 -999.2500 -999.2500 3.0374 -999.2500 -999.2500 3.6018 -999.2500 '-999.2500 2,9631 -999.2500 -999.2500 3.'09T9 -999.2500 -999.2500 3.0842 -999.2500 -999.2500 2.9709 -999.2500 -999.2500 2.4104 -999.2500 -999.2500 2.8967 -999.2500 -999.2500 LVP OlO.H02 VERIFICATION DEPT' 4700.0000 SFLU SP -69.5352 GR RHOB -999.2500 DRHO NPHI -999.2500 NCNL DEPT 4500.0000 SFLU SP -65.5352' GR RHO8 -999.2500 DRHO NPHI -999.2500 NCNL DEPT 4500.0000 SF'LU ,SP -67.5352 GR RHOB -999.2500 DRHO NPHI -999.2500 NCNL DEPT 4400.0000 SFLU SP '.~' -55.2852 GR RHOB -999.2500 DRHD NPHI -999.2500 NCNL 9EPT 4300.0000 SFLU SP -57.0195 GR RH00 2.2678 ORHO NPHI -999.2500 NCNL' DEPT 4200.0000 SFLU SP -60.0820 GR RHOB 2.3147 DRHD NPHI -999.2500 NCNL DEPT 4100.0000 SFLU SP -66.7852 GR RHDB 1.8077 DRHD NPHI -999.2500 NCNL OEPT 4000.0000 SFLU SP -59.3477 GR RHOB 2.1956 DRHO NPHI -999.2500 NCNL OEPT 3900.0000 SFLU SP -79.0352 GR RHDB 1.8848 DRHO NPHI -999.2500 NCNL DEPT 3800.0000 SFLU SP -86.5352 GR RHOB 2.0764 DRHD NPHI -999.2500 NCNL DEPT 3788.0000 SFLU SP -84.2552 GR RHDB 2.0959 DRHO NPHI -999.2500 NCNL LISTING 2-6213 ILD 101.4648 GR -999.2500 NRA?:: -999.2500 .FCNL 2.1155 ILD 103-6523 GR -999.2500 NRA? -999,2500 ECNL 2.1545 ILD 96.2773 GR -999.2500 NRAT -999.2500 FCNL. 2.4651 ILO 79'9648 GR -999.2500 NRATI -999.2500 FCNL. 2.3030 ILD 94.0898 GR 0'0581 NRAT 1433.6875 FCNL 3o3401 ILD 92.0273 GR 0,0435 NRA'T 1479.687.5 FCNL: 2-0725 ILD 88.8398 GR -0.0005 NR&T 1423.68'75 FCNL 2.3772 ILD 88.6523 GR 0.0791 NRAT 1405.6875 FCNL 3.6252 ILO 78.7773 GR 0.0493 NRAT 1304.6875 FCNL 2.2698 ILO 43.4805 GR -0.4292 NR.~T 1276.6875 FCNL 2.9924 ILD 58.7930 GR -0.4336 NRAT 715.3125 FCNL 2.4?29 -999.2500 -999.2500 -9'99.2500 2.15o6 -999.2500 -999.2500 -999o2~00 2.2913 -999.2500 -999.2500 -999.2500 2.5081 -999.2500 -99'9.2500 -999.2500 1'5645 94.08'98 -999.2500 420-6406 2.7229 92.0273 -999.2500 450.6406 1.7442 88.8398 -999.2500 368.6406 2.4260 88.6523 -999.2500 366.3906 3.6213 78.7773 -999.2500 336.8906 52.9492 43.4805 -999.2500 356.1406 48.5742 58.7930 -999.2500 314.1406 ILM .CALI .RNRA ILM CALI RNRA ILM CALl RNRA ILM CALI RNRA ILM CALl RNRA ILM CALI RNRA ILM CALI RNRA ILM CALl RNRA ILM CALI RNRA ILM CALI RNR~ ILM CALI RNRA PAGE 2.5237 -999.2500 -999.2500 2.1233 -999.2500 -999.2500 2-2268 -999.2500 -999.21500 2.4963 -999.2500 -999.2500 1.6'983 10,5566 3.4065 2.7913 9.6650 3.2815 1-7715 12.?363 3.8616 2.3577 9.8770 3.8362 3.5471 12.8457 3.8713 2000.6875 8.9082 3.5842 2000.6875 8.9082 2.2756 LVP 010.HOZ VERIFICATION LISTING ' PAGE 8 ~ FILEiTR.AILER FILE NAME :EDIT .001 SERVICE NAME VERSION ~ : OATE : MAXIMUM LENGTH FILE TYPE : NEXT FILE NAME : ~ TAPE TRAILER ~ SERVICEiNAME :EDIT DATE :85/08/17 ORIGIN :0000 TAPE, NAME :0738 CONTINUATION # :01 NEXT,r TAPE NAME :: COMMENTS :LIBRARY TAPE ,~ REEL TRAILER ~ SERVICE NAME :EDIT DATE: :85/08/17 ORIGIN : REEL NAME :149139____ CONTINUATION # :01 NEXT REEL NAME : COMMENTS :LIBRARY TAPE
