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188-091
ORIGINATED TRANSMITTAL DATE: 7/30/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5538 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5538 1Y-29 50029218520000 Plug Setting Record 27-Jun-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 188-091 T40724 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.30 15:06:37 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com 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: Plug to CTRL Fluid Mvmnt 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 7708'feet 7305'feet true vertical 6415' feet None feet Effective Depth measured 7305'feet 6859', 7208'feet true vertical 6089' feet 5733', 6011' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 7249' MD 6043' TVD Packers and SSSV (type, measured and true vertical depth) 6859' MD 7208' MD N/A 5733' TVD 6011' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 2 gal Ceramic Beads and 16 gal of 17 ppg Cement dumped on Neo Basket Plug @ 7300' 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River 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: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 15802 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 7300-7310' MD Packer: Baker FHL Packer Packer: Baker F-1 Packer SSSV: None Jan Byrne Jan.Byrne@conocophillips.com (907) 265-6471Staff Well Intervention Engineer 7272-7279', 7284-7299', 7311-7354', 7316-7336', 7392-7405' 6062-6068', 6072-6084', 6093-6128', 6097-6113', 6159-6169' 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) 62 Gas-Mcf MD 983 Size 110' 1813 1123973 54 1521951 154 measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 188-091 50-029-21852-00-00 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: ADL0025646 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1Y-29 Plugs Junk measured Length Production Prod TieBack 7516' 2520' Casing 6287' 7" 7549' 4069' 110'Conductor Surface Intermediate 16" 9-5/8" 74' 4104' 3575' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 9:15 am, Jul 22, 2025 Digitally signed by Jan Byrne DN: OU=Wells Group, O=ConocoPhillips, CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2025.07.22 08:51:50-08'00' Foxit PDF Editor Version: 13.1.6 Jan Byrne JJL 8/12/25 RBDMS JSB 072525 DSR-7/24/25 DTTMSTART JOBTYP SUMMARYOPS 6/24/2025 OPTIMIZE WELL PUMPED 70 BBLS SEAWATER FOLLOWED BY 19 BBLS DSL DWN TBG 6/27/2025 OPTIMIZE WELL RUN 1: PERFORM CROSSFLOW CHECK. WHILE CHECKING INITAL PRESSURES NOTICED THE GAS LIFT HAD REMAINED ONLINE AFTER TAKING WELL OFFLINE AND LOADING WITH WATER, SHUT IN GL. RIH W/ PL TOOLS TO FIND FLUIDS LEVELS AND DETERMINE CROSSFLOW. FLUID AT 5430' AND WATER AT 6260'. NO CROSSFLOW OBSERVED. RUN 2: SET NEO BASKET PLUG AT 7311' JOB IN PROGRESS 6/28/2025 OPTIMIZE WELL RUN 3: DUMP 2 GALLONS OF BEADS AND 3 GALLONS CASING CLEANER. EST. TOP OF BEADS AT 7310' RUN 4: DUMP 4 GALLONS OF CEMENT ON TOP OF PLUG. EST TOP OF CEMENT AT 7307.5' ***CEMENT DUMPED AT 12:00, MUST WAIT 18 HRS BEFORE PROCEEDING W/ NEXT RUN*** JOB IN PROGRESS 6/29/2025 OPTIMIZE WELL RUN 5: DUMP 4 GALLONS OF CEMENT ON TOP OF PLUG. EST TOP OF CEMENT AT 7305' ***CEMENT DUMPED AT 9:00, MUST WAIT 10 HRS BEFORE PROCEEDING W/ NEXT RUN*** JOB IN PROGRESS 6/30/2025 OPTIMIZE WELL RUN 6: DUMP 4 GALLONS OF CEMENT ON TOP OF PLUG. EST TOP OF CEMENT AT 7302.5' RUN 7: DUMP 4 GALLONS OF CEMENT ON TOP OF PLUG. EST TOP OF CEMENT AT 7300.0' ***WELL NEEDS TO STAY SHUT IN MINUMUM OF 5 DAYS PRIOR TO BRINGING ONLINE*** JOB COMPLETE 1Y-29 Cement Plug Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est. 19' of Rat Hole) 7,424.0 1Y-29 11/15/2022 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Neo Plug and Dump Bail Cement 1Y-29 6/30/2025 bworthi1 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 36.0 110.0 110.0 68.00 H-40 WELDED SURFACE 9 5/8 8.92 35.0 4,103.5 3,574.8 36.00 J-55 BTC PRODUCTION 7 6.28 33.0 7,548.9 6,286.5 26.00 J-55 BTC PRODUCTION TIE- BACK 7 6.28 33.0 2,619.8 2,434.7 26.00 L-80 TC-II Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 30.3 Set Depth … 7,248.5 Set Depth … 6,043.1 String Max No… 3 1/2 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 30.3 30.3 0.09 HANGER 7.000 GEN VI TUBING HANGER W/' pup FMC Gen Vl 3.000 504.3 504.3 1.04 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO DS 2.875 2,844.7 2,607.1 38.91 GAS LIFT 5.968 CAMCO MMG CAMCO MMG 2.920 4,383.9 3,798.2 37.18 GAS LIFT 5.968 CAMCO MMG CAMCO MMG 2.920 5,484.3 4,660.3 38.93 GAS LIFT 5.968 CAMCO MMG CAMCO MMG 2.920 6,242.9 5,250.0 39.15 GAS LIFT 5.968 CAMCO MMG CAMCO MMG 2.920 6,776.3 5,667.7 37.56 GAS LIFT 5.968 CAMCO MMG CAMCO MMG 2.920 6,833.1 5,712.8 37.46 SEAL ASSY 3.980 80/40 PBR SEAL ASSEMBLY w/7 ft out for seal expansion BAKER 80/40 2.990 6,835.9 5,715.0 37.46 PBR 5.010 80/40 PBR BAKER 80/40 4.000 6,859.1 5,733.4 37.43 PACKER 5.930 BAKER FHL PACKER BAKER FHL 2.970 6,944.1 5,800.9 37.38 GAS LIFT 5.968 CAMCO MMG CAMCO MMG 2.920 7,059.4 5,892.6 37.31 Blast Joint 3.500 3.5 X 9.2 # IBTCARBIDE RING BLAST JT. = 3 jts Carbide T&C Non- Upset 2.992 7,180.9 5,989.2 37.27 SLEEVE 4.500 CAMCO 2.81" DS SLIDING SLEEVE BAKER CMU W/ DS profile 2.810 7,207.3 6,010.2 37.21 SNAP LATCH 3.980 80/40 S-22 ANCHOR SEAL ASSEMBLY BAKER S-22 Anchor S/A 2.950 7,208.0 6,010.8 37.21 PACKER 5.370 BAKER F-1 PACKER BAKER F-1 4.000 7,211.4 6,013.5 37.18 PBR 5.500 BAKER 80/40 PBR BAKER 80/40 4.000 7,235.7 6,032.9 36.99 NIPPLE 4.520 D NIPPLE CAMCO D 2.750 7,247.2 6,042.1 36.90 MULE SHOE 4.520 MULE SHOE WEG WEG 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,305.2 6,088.6 36.43 PLUG NEO UMBRELLA PLUG, BASKET AT 7311' RKB, TOP OF PLUG AT 7305.2', BOTTOM OF PLUG AT 7313.6' RKB, PLUG OD 1.69", OAL 100.5", WITH 2 GALS OF CERAMIC BEADS DUMPED ON PLUG BASKET 6/26/2025 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) 2,844.7 2,607.1 38.91 1 GAS LIFT GLV RK 1 1/2 1,321.0 7/3/2016 CAMCO MMG 0.188 4,383.9 3,798.2 37.18 2 GAS LIFT GLV RK 1 1/2 1,301.0 7/3/2016 CAMCO MMG 0.188 5,484.3 4,660.3 38.93 3 GAS LIFT GLV RK 1 1/2 1,281.0 7/2/2016 CAMCO MMG 0.188 6,242.9 5,250.0 39.15 4 GAS LIFT OV RK 1 1/2 0.0 6/2/2023 CAMCO MMG 0.188 6,776.3 5,667.7 37.56 5 GAS LIFT DMY RK 1 1/2 0.0 7/3/2016 CAMCO MMG 0.000 6,944.1 5,800.9 37.38 6 GAS LIFT DMY RK 1 1/2 0.0 8/12/2014 CAMCO MMG 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,272.0 7,279.0 6,062.0 6,067.6 A-5, 1Y-29 1/24/1989 4.0 IPERF 180°, Phase; 2 5/8" Atlas SlimKon 7,284.0 7,299.0 6,071.6 6,083.6 A-4, 1Y-29 1/24/1989 4.0 IPERF 180°, Phase; 2 5/8" Atlas SlimKon 7,311.0 7,354.0 6,093.3 6,128.0 A-3, 1Y-29 1/24/1989 4.0 IPERF 180°, Phase; 2 5/8" Atlas SlimKon 7,316.0 7,336.0 6,097.3 6,113.4 A-2, 1Y-29 1/6/2015 6.0 APERF 2.5" 6 SPF 60° Phase TITAN 7,392.0 7,405.0 6,158.8 6,169.4 A-2, 1Y-29 1/24/1989 4.0 IPERF 180°, Phase; 2 5/8" Atlas SlimKon Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 7,272.0 7,405.0 1 Hydraulic Fracture 1/10/2015 0.0 0.00 0.00 1Y-29, 7/22/2025 8:45:04 AM Vertical schematic (actual) PRODUCTION; 2,616.0-7,548.9 FLOAT SHOE; 7,547.2-7,548.9 FLOAT COLLAR; 7,468.1- 7,469.9 IPERF; 7,392.0-7,405.0 Hydraulic Fracture; 7,272.0 IPERF; 7,311.0-7,354.0 APERF; 7,316.0-7,336.0 PLUG; 7,305.2 *NOT IN LIBRARY; 7,300.0 ftKB IPERF; 7,284.0-7,299.0 IPERF; 7,272.0-7,279.0 Squeeze – Formation Squeeze; 6,957.0 ftKB Squeeze – Formation Squeeze; 6,957.0 ftKB MULE SHOE; 7,247.2 NIPPLE; 7,235.7 PBR; 7,211.3 PACKER; 7,208.0 SNAP LATCH; 7,207.3 SLEEVE; 7,180.9 XO Thread; 7,172.7 Primary – Full Bore; 6,700.0 ftKB Cement; 7,084.0 ftKB Cement; 7,084.0 ftKB GAS LIFT; 6,944.0 PACKER; 6,859.1 PBR; 6,835.9 SEAL ASSY; 6,833.1 GAS LIFT; 6,776.3 GAS LIFT; 6,242.9 GAS LIFT; 5,484.3 GAS LIFT; 4,383.8 SURFACE; 35.0-4,103.5 FLOAT SHOE; 4,024.5-4,026.2 FLOAT COLLAR; 4,022.4- 4,024.5 GAS LIFT; 2,844.7 PRODUCTION TIE-BACK; 33.0- 2,619.8 Screw in sub; 2,618.7-2,619.8 FLOAT COLLAR; 2,606.1- 2,609.1 Primary – Full Bore; 879.0 ftKB Squeeze – Behind Casing Squeeze; 1,852.0 ftKB NIPPLE; 504.3 CONDUCTOR; 36.0-110.0 HANGER; 35.0-38.9 HANGER; 30.3 KUP PROD KB-Grd (ft) 36.80 RR Date 11/26/198 8 Other Elev… 1Y-29 ... TD Act Btm (ftKB) 7,708.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292185200 Wellbore Status PROD Max Angle & MD Incl (°) 41.53 MD (ftKB) 3,300.00 WELLNAME WELLBORE1Y-29 Annotation Last WO: End Date 7/7/2014 H2S (ppm) 149 Date 3/13/2022 Comment SSSV: NIPPLE Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,700.0 7,549.0 5,607.3 6,286.6 Primary – Full Bore Tail 250 sx 15.8 ppg Class G ... Test lines to 4000 ps. Pumped 10 bbls of cw 100 followed by 20 bbls of spacer 3000 mixed in 12.2 ppg slurry. Dropplug. Pumped 250 sx ClassG + 3% KcL + .9% D 127+ .55% D13 + .2% D-46 mixed in 15.8 ppg slurry. Displaced cmt with 11.2 ppg brin. Bumped plug @ 093 hr with 3500 psi. He for 15 minutes. Check floats OK. ^^Csg OD=7 879.0 4,104.0 878.9 3,575.2 Primary – Full Bore Lead 900 sx 12.1 ppg Arctic Set III + Tail 350 sx 15.8 ppg Class G... Tested line to 3500 psi. Pumped 80 bbl fresh water spacer ahead followed by 900 sx AS III mixed in 12.1 ppg slurry. Pumped bottom plug. Pumped 350sx ClassG + 2%, .2% D-46 mixed in 15.8 ppg slurry. Displaced cement w/ water. Had full returns. Last 10 bbls had 11.4 ppg cemet returns. Bumped plug @ 1100 hrs w/ 2000 psi. Held for 15 min. Check floats OK. Displaced water w/ polymer mud. Tested shoe to 12.5 ppg EMW. 775 psi for 5 min. **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=9.625 1,852.0 2,846.0 1,799.3 2,608.1 Squeeze – Behind Casing Squeeze Top Job 29 bbl 15.7 ppg Arctic Set I + Tail 55 bbl 7.7 ppg Arctic Pack... Total accumulated mud volume injected: 75 bbls diesel. Water wash volume injected: 300 bbls - rate 10 bpm; 1300 psi. Surface csg depth: 4104' ft. Depth of arcticpack/ cement interface: 1850 md ft. Pump rate: 5 bpm. Pump pressure initial: 650 psi. Final: 1200 psi. CIP @ 10:50 10/31/88. Pressure results: Start test 0 psi. Pumped 20 gal diesel- 1000 psi- held 1hr- 940 psi. Good test. **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=7 7,084.0 7,150.0 5,912.1 5,964.7 Cement Doubtful of successful; didn't pressure up 7,084.0 7,150.0 5,912.1 5,964.7 Cement 6,957.0 7,549.0 5,811.2 6,286.6 Squeeze – Formation Squeeze Single Stage 31.6 bbl 15.6 ppg Class G ... Pump totalof 460 bbls SW into well since beginning o job. Freee protect coil pump out to tanks. Cement QC: FL = 90, FC = 0.97", thickening time = 9 hrs 54 min. PT cement lines to 4000#. Pump the folloing at 1.0 BPM: 5 bbls SW,10 bbls neat cmt, 27.7 bbls cmt w/20 lb/bbl aggregate w/ following additives:15.6#, Cass G, 1% D20, .15 GP D47, .2% D65,2 GPS D135, .85% D600, .36% D800, flush w/ 5 bbls sw and 15 bbls 1.5# biozan. nozzle at flag when cmt at nozzle. take returns to allow 4 bbls cmt avove nozzle. SI returns and pull upto 7090 while bullheadng cemnt into prfs at 1.0 bpm. Rec from 7090 - 7120 while bullheading cmt. whp increased to 1600# after 17.7 bbls cmt ou nozzle. Start taking returns at 1:1 layin in cemet. Layed in total of 18 bbls cement. Begin hesiation cycles. hesitate squeeze total of 13.9 bbls into perfs. Bul squeeze pressure to 2000#. Held last stage for 25 minutes. Final whp after 25 min = 1900#. wit heitations, total cement behind pipe= 17.7+13.9 = 31.6 bbls. CLEANOUT- displacing biozan out o well. Switch over to 10% tea. pump 10 bbls total. Nozzle at 7100'. Pumping at 1.0bpm, 5 bbls sw arund and2bbls tea out nozzle and pull up to 7050'. SW coming out of nozzle and stat POOH. Switch to diesel. Diesel at nozzle when at 3000'. INC whp to 1450#. Still getting 1:1 returns. Daily Summary: Squeezed C sand perfs with 15.6 ppg Class G cement. Laced 31.6 bbls cement behind pipe. Final squeeze pressure = 2000#. Cleaned out cement to 7100' RKB (50' C snd perfs covered w/ cement.) Tagged hard cement at 7100'. Turned well over to dso to be left SI. 10/14/96. **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=7 6,957.0 7,549.0 5,811.2 6,286.6 Squeeze – Formation Squeeze Single Stage 31.6 bbl 15.6 ppg Class G ... Squeezed C san perf woth 15.6 ppg cass g cement, placed 31.6 bbls cement behind pipe. Final squeeze pressure= 2000#. Cleaned out cement to 7100 RKB (50'C sad perfs covered w/ cement) tagged hard cement at 7100'. Turned well over to dso to be left SI. **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=7 7,549.0 7,549.0 6,286.6 6,286.6 Squeeze – Formation Squeeze ... Milled cement to 737' ctm, 7170' rbk, plan to return to finish milling cement and clean out sand from 'A' sands perfs. 10/30/96 **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=7 7,300.0 7,310.0 6,084.4 6,092.5 *NOT IN LIBRARY DUMP BAIL 17 PPG CEMENT ON TOP OF NEO UMBRELLA PLUG (16 GALS, ~10') 6/28/2025 1Y-29, 7/22/2025 8:45:05 AM Vertical schematic (actual) PRODUCTION; 2,616.0-7,548.9 FLOAT SHOE; 7,547.2-7,548.9 FLOAT COLLAR; 7,468.1- 7,469.9 IPERF; 7,392.0-7,405.0 Hydraulic Fracture; 7,272.0 IPERF; 7,311.0-7,354.0 APERF; 7,316.0-7,336.0 PLUG; 7,305.2 *NOT IN LIBRARY; 7,300.0 ftKB IPERF; 7,284.0-7,299.0 IPERF; 7,272.0-7,279.0 Squeeze – Formation Squeeze; 6,957.0 ftKB Squeeze – Formation Squeeze; 6,957.0 ftKB MULE SHOE; 7,247.2 NIPPLE; 7,235.7 PBR; 7,211.3 PACKER; 7,208.0 SNAP LATCH; 7,207.3 SLEEVE; 7,180.9 XO Thread; 7,172.7 Primary – Full Bore; 6,700.0 ftKB Cement; 7,084.0 ftKB Cement; 7,084.0 ftKB GAS LIFT; 6,944.0 PACKER; 6,859.1 PBR; 6,835.9 SEAL ASSY; 6,833.1 GAS LIFT; 6,776.3 GAS LIFT; 6,242.9 GAS LIFT; 5,484.3 GAS LIFT; 4,383.8 SURFACE; 35.0-4,103.5 FLOAT SHOE; 4,024.5-4,026.2 FLOAT COLLAR; 4,022.4- 4,024.5 GAS LIFT; 2,844.7 PRODUCTION TIE-BACK; 33.0- 2,619.8 Screw in sub; 2,618.7-2,619.8 FLOAT COLLAR; 2,606.1- 2,609.1 Primary – Full Bore; 879.0 ftKB Squeeze – Behind Casing Squeeze; 1,852.0 ftKB NIPPLE; 504.3 CONDUCTOR; 36.0-110.0 HANGER; 35.0-38.9 HANGER; 30.3 KUP PROD 1Y-29 ... WELLNAME WELLBORE1Y-29 Originated: Delivered to:10-Apr-25 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 # E SET# 1 1Y-27 50-029-22379-00 909953476 Kuparuk River Packer Setting Record Field- Final 1-Apr-25 0 1 2 1Y-27 50-029-22379-00 909915690 Kuparuk River Packer Setting Record Field- Final 20-Mar-25 0 1 3 1Y-27 50-029-22379-00 909953476 Kuparuk River Packer Setting Record Field- Final 31-Mar-25 0 1 4 1Y-29 50-103-21852-00 909915382 Kuparuk River Multi Finger Caliper Field & Processed 23-Mar-25 0 1 5 2A-04 50-103-20026-00 909976821 Kuparuk River Multi Finger Caliper Field & Processed 31-Mar-25 0 1 6 2K-20 50-103-20120-00 909966603 Kuparuk River Multi Finger Caliper Field & Processed 26-Mar-25 0 1 7 2T-20 50-103-20215-00 909915691 Kuparuk River Multi Finger Caliper Field & Processed 13-Mar-25 0 1 8 2V-10 50-029-21310-00 909915383 Kuparuk River Packer Setting Record Field- Final 17-Mar-25 0 1 9 3T-731 50-103-20905-00 909991288 Kuparuk River Cement Evaluation with CAST Field & Processed 2-Apr-25 0 1 10 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: 193-088 188-091 184-053 189-118 195-029 185-048 224-156 T40310 T40310 T40310 T40311 T40312 T40313 T40314 T40315 T40316 4/10/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.10 14:23:59 -08'00' 41Y-29 50-103-21852-00 909915382 Kuparuk River Multi Finger Caliper Field & Processed 23-Mar-25 0 1 188-091 Originated: Delivered to:2-Jan-25 Alaska Oil & Gas Conservation Commiss 02Jan25-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 1G-103 50-029-20824-01-00 219-110 Kuparuk River WL WFL FINAL FIELD 9-Dec-24 1G-01 50-029-20805-00-00 182-130 Kuparuk River WL IPROF FINAL FIELD 11-Dec-24 1F-08 50-029-20836-00-00 182-162 Kuparuk River WL RBP FINAL FIELD 15-Dec-24 1F-14 50-029-21022-00-00 183-146 Kuparuk River WL PPROF FINAL FIELD 17-Dec-24 1F-08 50-029-20836-00-00 182-162 Kuparuk River WL RBP FINAL FIELD 18-Dec-24 1L-05 50-029-21155-00-00 184-123 Kuparuk River WL IPROF FINAL FIELD 19-Dec-24 1Y-29 50-029-21852-00-00 188-091 Kuparuk River WL PPROF FINAL FIELD 20-Dec-24 2T-10 50-103-20064-00-00 186-096 Kuparuk River WL IPROF FINAL FIELD 21-Dec-24 2H-05 50-103-20043-00-00 185-168 Kuparuk River WL PPROF FINAL FIELD 22-Dec-24 1Q-12 50-029-21210-00-00 184-193 Kuparuk River WL LEE-IPROF FINAL FIELD 23-Dec-24 MT7-91 50-103-20881-00-00 224-020 Greater Mooses Tooth WL TTiX-IPROF FINAL FIELD 29-Dec-24 MT7-92 50-103-20872-00-00 223-114 Greater Mooses Tooth WL TTiX-PPROF FINAL FIELD 31-Dec-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39899 T39900 T39901 T39902 T39901 T39903 T39904 T39905 T39906 T39907T39908 T39909 1Y-29 50-029-21852-00-00 188-091 Kuparuk River WL PPROF FINAL FIELD 20-Dec-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.03 08:13:20 -09'00' • • `„PIt ��-� Regg, James B (DOA) «� (Q From: NSK Fieldwide Operations Supt <n2072@conocophillips.com> Sent: Wednesday, November 23, 2016 10:19 AM To: Bixby, Brian D (DOA); Regg,James B (DOA) 2 u(ZOr'(a Cc: NSK Prod Engr Specialist Subject: RE: Kuparuk 11Y-Pad Deficiency Report follow-up Attachments: 20161123103221.pdf; 20161123103153.pdf Brian, Jim, Attached is the completed deficiency report and supporting follow up information noting the following: • 1Y-17: No active leak could be identified after cleaning the area and checking the torques. • 1Y-29 and 1Y-30: Signs have been installed. Please let us know if there are any questions. Thanks Scott Fahrney/Larry Baker NSK Fieldwide Operations Superintendent (907) 659-7042 From: NSK Prod Engr Specialist SNE JUN 2 7 2017. Sent: Friday, November 18, 2016 1:44 PM To: Bixby, Brian D (DOA)<brian.bixby@alaska.gov> Cc: NSK Fieldwide Operations Supt<n2072@conocophillips.com> Subject: Kuparuk I 1Y-Pad Deficiency Report follow-up Brian, Thank you for taking the time to stop in on Wednesday, it was a pleasure meeting you. The items you identified on 1Y- Pad are currently being addressed and we'll let you know when they're resolved. In the meantime don't hesitate to contact us if you have questions or need anything additional from us. Enjoy your time off! Cheers, Matt Matthew Raiche/Darrell Humphrey Production Engineering Specialist ConocoPhallips Alaska Ph:907.659.7535 I Pg:924 I Mail: NSK 69 1 e(( z)7 pm l€ddj(O State of Alaska Oil and Gas Conservation Commission Deficiency Report 3I`w Location: 3 --poktoilw A) - Date: 6 i t..,14�1/e PTD: 1 Operator: 644Cdo ?NM") Type Inspection: Operator Rep: AlQ4 Rae, Inspector' iA /4J Position: fieDlah01,/ f4JJ11Cef'ERf/ e ,/�3` Op,Phone: 1s07� be?- 175335 Correct by(date): gliC Op.Email: n /13?eepitOevidigivr co/ti Follow Up Req'd: yEs Detailed Description of Deficiencies Date Corrected 7-41:0 l<eratt. WELL 11-a-a AZAdtle Le"64 OA) .idit wEAA N€ s i-bee &. (11z6f Ito t. 11.29 de‘Ar WrstS' (Ser or 4Ahc.L.is rag Iy-o ) irtz3[10, 1— >, W 6i.c. /lees 1 toioo �tlw! I r 6(1 cp 5icr .� Attachments: ev‘., Operator Rep Signatures: ' '/�fix l '�`'� 464� / AOGCC Inspector *After signing,a y of this form is to be left o r. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. include the"Date . Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification(Attention:Inspection Supervisor).Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for foliow-up action. • Revised 2/2016 i • ConocoPPhullips Alaska AOGCC EXCEPTION REPORT Location: ,:pit pp Date: \1 ij6/162 AOGCC Inspect! S ticvl g5t X ly instructions:All exceptions listed below must be corrected within 7 days of receipt of this notification. Documentation of the work performed is to be entered into the'Action Taken'section below. Note-Failure to comply with these instructions may constitute a violation of SOA regulations and may be subject to enforcement action under 20 AAC 25.535 EXCEPTIONS NOTED: (.._siv VI, o .) (L) -' 1Y-- 2 CI W ePAS \ \lau.S 5stLy n ‘15' r tY —09-7) Wel{ I Y-50 30 exl s �l[ Lkw- 5 Action Taken to Correct Problem: /7No1N. cDoSztJ cFNoF[ +dNsperc srtGlr . Date:,?p#.Joq( Initials: •<-01----- A)6.-'7/ '/- 7 2O, t, DHD < <CToaaye.,F PC F-137.ALLO iL 519ni I2� - At Re- Yet) ` Date: 26'JO V l4 Initials: 7'' - I�Jeif , 2.9 A+a b IoEciN4 rd uls fa to 5(4^i E Nf1^-t /2' v Date: 2.0 aou ref Initials: - - kJ 2-L- 1 "1- 30 o beui 4464 uleti +a 1+�5 y -Zq Date: z31-.50 lG Initials: SPF I y -3o S t y l us-z ((e0 Date: 23 x.100 141nitlals: S'F Date: Initials: Return completed form to Prod.Engr.Specialist: nil39(con o cophi l tIps.corn Distribution: CPF DSLT CPF OPS Supv Prod. Engr.Specialist C.C. CPF9&2 Ops Supt CPF3 Ops&DOT Pipelines Supt NSK Fieldwide Operations Supt 2-5 3`6� WELL LOG TRANSMITTAL DATA LOGGED 2i /2015 M K.BENDER To: Alaska Oil and Gas Conservation Comm. February 4, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 F ICED FEB 0 4 2015 RE: Perforation Record: 1Y-29 Run Date: 1/6/2015 L\6•..,3f.L1 1 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1Y-29 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21852-00 y `--r M T -.y PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: (i/iiitiza-Ato4-4) 6-e-teat ' STATE OF ALASKA • AU. OIL AND GAS CONSERVATION COMI_ _ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed' Abandon r Repair w ell r Rug Perforations r Perforate rOther FFrac Treatment Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number ConocoPhillips Alaska, Inc. Development F Exploratory r 188-091 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-029-21852-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25646 KRU 1Y-29 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s) none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7708 feet Plugs(measured) none true vertical 6416 feet Junk(measured) none Effective Depth measured 7548 feet Packer(measured) 6859,7208 true vertical 6286 feet (true vertical) 5733,6011 Casing Length Size MD ND Burst Collapse CONDUCTOR 74 16 110 110 SURFACE 3984 9.625 4104 3575 PRODUCTION 7513 7 7549' 6287 SCANNED r L :ii . 2 0'5 RECEIVED Perforation depth: Measured depth: 7272-7279,7284-7299,7311-7354,7392-7405 JAN 2 7 2015 True Vertical Depth: 6062-6068,6072-6084,6093-6128,6159-6169 AOGCC Tubing(size,grade,MD,and ND) 3.5, L-80, 7249 MD,6043 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL PACKER @ 6859 MD and 5733 TVD PACKER-BAKER F-1 PACKER @ 7208 MD and 6011 ND NIPPLE-CAMCO'DS' NIPPLE @ 504 MD and 504 TVD 12.Stimulation or cement squeeze summary. Intervals treated(measured): 7272-7405 Treatment descriptions including volumes used and final pressure: 140000#of 16/20 frac sand 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 233 1143 78 187 188 Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r- 16. 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C O.Exempt 314-648 Contact Robert Blakney A 265-6417 Email Robert.G.BlakneyAconocophillips.com Printed Name Robert Blakn- . Title Completions Engineer Signature - Phone:265-6417 Date &77(5 vrt. z //(/ iS Form 10-404 Revised 10/2012 "" �g�� Submit OrigirNI Only RBDMS3tt JAN 3 0 2015 KUP PROD 1Y-29 ConocoPhillips '-1 Well Attributes Max Angle&MD 'TD Alaska,hie. Wellbore API/UWI Field Name Wellbore Status II ncl(°) MD(ftKB) 'Act Btm(ftKB) �. 500292185200 KUPARUK RIVER UNIT PROD 41.53 3,300.00 7,708.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 18-29,1/1700158.59.41 AM SSSV:NIPPLE 240 7/10/2009 Last WO: 7/7/2014 36.80 11/26/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,448.0 12/30/2014 Rev Reason:FRAC hipshkf 1/17/2015 ...HANGER;303 t^t 1 1 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(060) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCT R 15 36.0 110.0 110.0 68.00 awns Casing De crriiption -OD(in) 16 ID(in)062- 35.0 4,103.5 3,574.8 36.00 J H-40 WELDED 1 SURFACE 95/8 8.921 I I Top(ftKB) Set Depth(ftKB) Set Depth .WVLen(I0 Grade Top Thread p( ) Depth(ftKB) p 1 ` + J-55 BTC To Grade Top Thread II PRODUCTION 7 6.276 33.0 7,548.9 6,286.5 26.00 J-55 BTC Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION TIE- 7 6.276 33.0 2,619.8 2,434.7 26.00 L-80 TC-II 'M^CONDUCTOR;36.0-110.0" BACK Tubing Strings Tubing Description I String Ma...'ID(In) I Top(ftKB) I Set Depth(ft..I Set Depth(TVD)(...IWt(lb/ft) 'Grade !Top Connection NIPPLE;504.3 ._:k;. TUBING WO 31/2 2.992 30.3 7,2485 6,043.1 930 L-80 Il EUE 8rd Completion Details Nominal ID Top IR(S) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 30.3 30.3 0.09 HANGER FM GEN VI TUBING HANGER WP pup 3.000 PRODUCTION TIE-BACK;33A I 504.3 504.3 1.04 NIPPLE CAMCO DS NIPPLE 2.875 6,833.1 5,712.8 37.46 SEAL ASSY 60/40 PBR SEAL ASSEMBLY w/7 ft out for seal 2.990 I expansion 2,619.8 6,835.9 5,715.0 37.46 PBR 80/40 PBR 4.000 GAS LIFT;2.844.7 6,859.1 5,733.4 37.43 PACKER BAKER FHL PACKER 2.970 J 7,059.4 5,892.6 37.31 Blast Joint 3.5 X 9.2#IBTCARBIDE RING BLAST JT.=3 jts 2.992 7,180.9 5,989.2 37.27 SLEEVE CAMCO DS SLIDING SLEEVE 2.950 7,207.3 6,010.2 37.21 SNAP LATCH 80/40 S-22 ANCHOR SEAL ASSEMBLY 2.950 7,208.0 6,010.8 37.21 PACKER BAKER F-1 PACKER 4.000 SURFACE.350-4.103.5 - 7,211.4 6,013.5 37.18 PBR BAKER 80/40 PBR 4.000 7,235.7 6,032.9 36.99 NIPPLE D NIPPLE 2.750 GAS UFT,4.3836 . 7,247.2 6,042.1 36.90 MULE SHOE MULE SHOE WEG 3.000 Perforations&Slots shot Dena GAs LIFT,s.4aa3 Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,272.0 7,279.0 6,062.0 6,067.6 A-5,1Y-29 1/24/1989 4.0 IPERF 180 deg.Phase;2 5/8" Atlas SlimKon 7,284.0 7,299.0 6,071.6 6,083.6 A-4,1Y-29 1/24/1989 4.0 IPERF 180 deg.Phase;2 5/8" GAS UFT.6.2429 F Atlas SlimKon 7,311.0 7,354.0 6,093.3 6,128.0 A-3,1Y-29 1/24/1989 4.0 IPERF 180 deg.Phase;2 5/8" - Atlas SlimKon - 7,316.0 7,336.0 6,097.3 6,113.4 A-2,1Y-29 1/6/2015 6.0 APERF 2.5"6 SPF 60 DEG GAS LIFT;6,776.3 PHASE TITAN 7,392.0 7,405.0 6,158.8 6,169.4 A-2,1Y-29 1/24/1989 4.0 IPERF '180 deg.Phase;25/8" Atlas SlimKon •- Stimulations&Treatments SEAL ASSY;6,833.1 Min Top Max Btm Depth Depth Top(TVD) Btm(TVD) PBR;6.835.0 (ftKB) (ftKB) (ftKB) (066) _ Type Date Com PACKER;6,859.1 7,272.0 7,405.0 6,062.0• 6,169.4 Hydraulic 1/10/2015 FRAC 7272'-7405',140,000#OF 16/20 FRAC SAND Fracture PLACED IN 1-7 PPA STAGES Cement Squeezes Top(TVD) Btm(ND) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com GAS LIFT;6144.0 ICE 7,084.0 7,150.0 5,912.1 5,964.7 Cement Squeeze 11/10/199 •C-4,C-2,C-I PERF'D SANDS 1 --- 7,084.0 7,150.0 5,912.1 5,964.7 Cement Squeeze 10/14/199 °C-4,C-2,C-1 PERF'D SANDS 6 y Mandrel Inserts u nSt XO Thread;7,172.7Ion ati SLEEVE;7.1809 Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sam Type Type (in) (psi) RunDate Com 1' 2,844.7 2,607.1 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 1/2/2015 2 4,383.9 3,798.2 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 1/2/2015 3 5,484.3 4,660.3 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 1/2/2015 4 6,242.9 5,250.0 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 1/2/2015 SNAP LATCH;7,207.3 5 6,776.3 5,667.7 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 1/52015 OCR- PACKER;7.206.0 1 PBR;7211.3 6 6,944.1 5,800.9 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 8/12/2014 I Notes:General&Safety End Date Annotation NIPPLE;7,235.7 Pt 10/28/2010 NOTE:View Schematic w/Alaska Schematic9.0 MULE SHOE;7,247.2 [Y..- IPERF; IPERF;7,272.0.7,279.0 IPERF;7,284.0.7,299.0 APERF;7,316.0-7,336.0 IPERF;7,311.0.2354.0 Hydraulic Fracture;7,272.0 IPERF;7,392.0.2405.0 PRODUCTION;2,616.0-7,548.9 1Y-29 FRAC SUMMARY • DATE SUMMARY 12/30/2014 TAGGED @ 7448' SLM. SET CA-2 PLUG @ 7235' RKB. SET CATCHER ON CA-2, IN PROGRESS 1/2/2015 DELAYED START DUE TO SNOW REMOVAL. PULLED 1.5" GLV'S @ 6242' &5484' RKB. IN PROGRESS 1/3/2015 PULLED 1.5"GLV'S @ 4383' &2844' RKB. SET 1.5" DV'S @ 2844',4383', 5484' &6242' RKB. PULLED 1.5"OV @ 6776' RKB. IN PROGRESS 1/4/2015 CIRC OUT W/ 146 BBLS SEAWATER& 95 BBLS DIESEL, TO U-TUBE TO FREEZE PROTECT. IN PROGRESS. 1/5/2015 SET 1.5" DV @ 6776' RKB. PERFORMED MIT-T(4000 PSI) & MIT-IA(3000 PSI) BOTH PASSED. PULLED CATCHER& PRONG @ 7211' SLM. PULLED 2.75"CA-2 PLUG BODY @ 7235' RKB. JOB COMPLETE. 1/6/2015 CORRELATE TO CEMENT EVELUATION LOG DATED 6 NOV 1988. PERFORATE 7316'-7336'WITH 2.5" 6SPF, 60 DEG PHASING TITAN GOOD HOLE CHARGES. 1/10/2015 Performed fracture stimulation treatment @ 20 bpm per design. 140,000#of 16/20 frac sandplaced in 1-7 ppa stages. Well freeze protected w/ 18 bbls of diesel. 1/12/2015 TAG FILL W/2.25" BAILER @ 7336' RKB (EST. 44' OF FILL). READY FOR CTU (FCO) 1/16/2015 RIH TAG @ 7360' CTMD, CLEAN OUT TO 7500' CTMD, POOH CHASING @ 80% TO SURFACE. WELL FREEZE PROTECTED. ****TURN OVER TO DSO**** 1/18/2015 TAG TD @ 7433' SLM; SET 2.75"CA-2 PLUG W/SINGLE SPARTEK GAUGE @ 7235' RKB; SET 2.70" BAIT SUB W/2.5"JD ON TOP OF PLUG; PULLED DV& SET OV @ 6776' RKB. IN PROGRESS. (n C a) E E C7.) U V oG >, = #1 O O Cb M I� O N C d' V N .0 # M N V M O N M M M M (n V r M CO CLO N CV CO LU ) MO g w E -3 ,- E v- 0 E O. O -o co t- N O o 0 0 N.- 0 0 O "" ,.. O •5 cu OO o6 O o 0 0 ci o O o 0 W ., 0 U = Q o 0 ci ♦A .5 Q 2� 'co in LU CO N In CO O ^ O N Crin V V V CVN O AC 16. 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O N N C) (f) O M d' t` Mco 0) 7 O M CO 7 OO) Le) (OO V LI) O O O COO 4 O a d co 1 N a0)) M M1 , ti co N- Mi N CO N V co 4 f y O- M O) O 00 CO N- O V N- N C` CO N O CD N- y O- M h O) O CO V CO O M C c000s- oo44 L 7 co V CO O N CD CD Xr 0 0 0 CO N- CD VV V o N (C CO <- ,- ,- CA J- N- r O N N ,-N. L O _Tu C ,•,- a) a Y "ON 4. OaN Y C j N >-, 8 c (0 X - NU a (0 = 7 O C >, 0 7 E To E -Cu' '? C O- a? N E f0 X -C a _T U T W c a E CO a o Q T _O = O N L (0 L O CU L O N E 3 >, C L O N a r UO O . CQ N ., N -O (o "" co L o 'o 03 . E "O g) E T6'X C - O ` U >U L O Oa O ' 'w O O OA 0 0 " o o O O _ O (0 c yICO N M0 ._ L TVOO _OO E0 E LCO LU U0 ; Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. I yy- U 1 j Well History File Identifier Organization (done) A Two-Sided RESCAN ❑ Color items: ❑ Grayscale items: ❑ Poor Quality Originals: ❑ Other: DIGITAL DATA ❑ Diskettes, No. ❑ Other, No/Type TOTAL PAGES: 100 NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL Project Proofing III IIIII� IIII Y PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL Scanned (done) IIIVIIIIIIIIIIInI PAGES: I ()® (at the time of scanning) SCANNED BY: BEVERLY BREN VINCENT SHERYLMARIA LOWELL Rescanned(done) DATE: Rescan Needed NIIIIIUIIIIAIIN OVERSIZED (Scannable) ❑ Maps: ❑ Other items scannable by large scanner OVERSIZED (Non -Scannable) ❑ Logs of various kinds ❑ Other /S/ El Staff Proof By: Date: DATE: 9 '� 4 /S/ RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: General Notes or Comments about this file: PAGES: i OD /s/ Quality Checked (done) 111111111111111111 Rev1NOTScanned.wpd e N. ojS. .t5...n€' ,`x, s au s,.uk'�n.', `•h: :z' 07 7r (WC\"V/7; L HE _" F L C V.It 333 \Nest Seventh Avenue , p L Anchcraae Alaska 9930' .572 ( r :n � C r '1=' AUC, 0 '72O Jake Voss Wells Engineer It IConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1Y-29 Sundry Number: 314-266 Dear Mr. Vaughan: Enclosed is the approved application for sundry approval relatingto the above referenced well. PP Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a.7Cathy Poerster Chair DATED this day of April, 2014. Encl. t STATE OF ALASKA :f. a-` _ - } " V;: AL A OIL AND GAS CONSERVATION COMMV, ON APPLICATION FOR SUNDRY APPROVALS • 20 AAC 25.280 � '3 '9-17 11 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r A- Change Pr�J!!ed 66m r Suspend r Rug Perforations r Perforate r Pull Tubing F . Time Extension r Operational Shutdown rRe-enter Susp.Well r Stimulate r Alter casing 'Other: 5"45 r Ln tir lrG�'Iu r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: VVF ConocoPhillips Alaska, Inc. Exploratory r Development F- 188-091 • 4125114 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-21852-00 - 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r- No r / KR(A.,1Y-29 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25646 • Kuparuk River Field/Kuparuk River Oil Pool. 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(fj Effective Depth TVD(ft): 4i Plugs(measured): Junk(measured): 7708 6416 751/$. r� (e23<a none 2775' Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 110' 110' SURFACE 4069 9.625 4104' 3575' PRODUCTION 7516 7 7549' 6287' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7272-7279,7284-7299,7311-7354,7392-7405. 6062-6068,6072-6084,6093-6128,6159-6169 4.5 x 3.5 J-55 6937 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER HB RETRIEVABLE PACKER MD=6863 TVD=5737 SAFETY VLV-AVA 4"SIDE GUARD TRDP SAFETY VALVE(LOCKE MD=1823 TVD=1774 12.Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic E Development r' Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/5/2014 Oil r✓ ' Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r— WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jake Voss @ 265-6935 Email: Jake.Vossaconocophillips.com Printed Name /Jake Voss Title: Wells Engineer / Signature 1:r. V------- Phone:265-6935 Date 40 r.4///Lj ✓ Commission Use Only / Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 2j\'*-2 In Plug Integrity r BOP Test rt' Mechanical Integrity Test r Location Clearance r Other: Sap i-c-5 f' 7C 3 D C o p s r RBDMS ANY 0 S 2014 Spacing Exception Required? Yes ❑ No Subsequent Form Required: `C — 4 Ci 4 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 4 -2_9 - ) Approved application Is valid tor 12 mo, trtst1o7) he date of approval. Form 10-403(Revised 10/2012) ORIGINAL t''�/ ,,tt Submit Form and Attachments in Duplicate VI-c 4/24/1 I ConocoPhillips AOOGC April 24, 2014, Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Producer 1Y-29(PTD: 188-091). Well 1Y-29 was originally completed in 1989 as a single completion commingling the Kuparuk A- and C- sands. In 1996 a successful cement squeeze of the C-sand perforations was performed due to water production in the C-sand. A remedial cement squeeze of the C-sand was completed 1998. In 2001, the C-sand began to leak. In 2010 a surface casing leak was identified at 594' MD. The well was waivered to continue production without gas lift; however, it was unable to naturally flow. The well was shut in November 2011. The objective of this workover is to pull the existing gas lift completion, cut and pull the 7" production casing above the top of cement, tie-in and cement a new 7" TC-II threaded production casing from the back-off and run a new 3 1/2" selective gas lift completion. If you have any questions or require any further information, please contact me at 265- 6935 or Jake.Voss@conocophillips.com. Sincerely, Jacob Voss Wells Engineer CPAI Drilling and Wells s" 1Y-29 Rig Workover, Subsidence Repair (PTD #: 188-091) Current Status: The well is currently shut in. It has leaks in the surface casing. Scope of Work: Pull the existing gas lift completion,cut and pull the 7"production casing above the top of cement, tie-in and cement a new 7"TC-II threaded production casing from the back-off,and run a new 3 '/2"selective completion. General Well info: MASP: 1,868 psi(using 0.1 psi/ft gas gradient) Reservoir pressure/TVD: Kuparuk A/C-Sands—2,476 psi/7,300' TVD(7.83 ppg EMW)measured 11/09/2013.Have requested an updated SBHP before RWO. Wellhead type/pressure rating: FMC Gen IV,71/16" 5M Top x 11"3M Bottom Nordic 3 BOP Config: Annular/7"Pipe Rams/Blind Rams/Mud Cross/Variable Pipe Ram MIT results: MITxIA—Passed 05/02/2013 Well Type: Producer Estimated Start Date: June,05,2014 Production Engineers: David Lagerlef/Dana Glessner Workover Engineer: Jacob Voss(265-6935/Jake.Voss@conocophillips.com) Proposed Pre-Rig Work: 1. RU Slickline 2. RIH w/Dual Panex Gauges and get updated A/C-Sand SBHP. 3. RIH and pull DV from GLM#8 at 6,800' MD. Leave pocket open for circulating. 4. Set BPV w/i 24 hrs of rig arrival. 5. RDMO Slickline. Proposed Procedure: 1. MIRU. 2. Pull BPV. Circulate KWF to kill well. 3. Install BPV. ND tree. 4. Install the blanking plug. NU BOPE and test. 5. MU landing joint,BOLDS,POOH laying down tubing,and spooling control line. a. If tubing will not pull free,RU E-line and cut tubing in the middle of the first full joint above the PBR 6. RIH with 7"casing scraper on DP to the top of the PBR or tubing stub,circulate well clean. 7. RU E-line: RIH with caliper, gyro and CBL. Log from top of PBR/tubing stub' to surface to determine TOC. Fire string shot across the second collar above the TOC. RD E-line. 8. RIH and set RBP#1 just above PBR or tubing stub. PT to 2500 psi and drawdown test(DDT)to 0 psi. 9. RIH and set RBP#2 below the TOC. PT to 2500 psi and DDT to 0 psi. Dump 50' of sand on top of plug. 10. ND BOP stack, ND tubing head using Hydratight, spear the 7" casing and re-land in slips. Cut off excess casing growth. Sv-Ace, e 4 s �9 it N k 11. NU BOP stack to the casing head(cannot test break due to SCL, BOP stack will be considered a diverter,there are 2 barriers in the well at this point). 12. RIH with multi-string cutter(MSC)and cut the 7"casing above the top of cement. 13. Spear the casing and circulate out the Artic Pack from the OA with heated diesel followed by heated seawater. 14. POOH laying down 7"casing. 15. Set test plug in the casing head and PT to 250/3000 psi(test pressure limited by 3M casing head). 16. RIH with 9-5/8"casing scraper to the top of the 7"stub and circulate well clean. 17. RIH with tandem string mill to gauge the 9-5/8"casing for the ES cementer,dummy drift the ES cementer. 18. RIH with the back-off tool to the top of the 7"casing stub,engage the stub,and back-off the casing stub. 19. RIH with 7"casing spear and retrieve 7"casing stub. I 1Y-29 Rig Workover, Subsidence Repair (PTD #: 188-091) 20. RIH with new 7"TC-II casing and ES cementer. Screw into top of 7"casing and PT casing to 3000 psi. 21. RU SLB cementers: cement the 7"x 9-5/8"annulus to surface. RD SLB cementers. WOC. 22. ND BOP stack, pull 7" casing in tension and land in the slips. Cut off excess 7" casing. NU new tubing head and BOP stack,PT BOP. 23. RIH with 6-1/8" mill tooth bit to the TOC, drill up cement, closing plug, and ES cementer. RIH with 6-1/8" concave mill and dry drill any remaining debris on top of the sand. RIH with wash string assembly and circulate out sand on top of the RBP#2. 24. RIH with RBP retrieving head to the top of the plug,engage RBP#2 and pull to release. 25. RIH with RBP retrieving head to the top of the plug,engage RBP#1 and pull to release. b. If tubing was cut,MU overshot dressed for 3-1/2"tubing and RIH on DP to the top of the tubing stub. Jar seal assembly from the PBR. 26. RIH w/PBR retrieving tool,engage the PBR,jar HB packer free,POOH standing back drillpipe. 27. RIH w/double string mills and cleanout to 7385'MD. Reverse circulate until well is clean. 28. MU tailpipe assembly and F-1 packer, 29. RU E-Line and RIH with tailpipe/packer to—7177' MD. Set packer. 30. Release from packer and POOH,RD E-line. 31. MU FHL straddle packer assembly and single in on 3 '/2"tubing to just above the F-1 packer. 32. Swap the entire well over to corrosion inhibited 8.6 ppg seawater. 33. Sting into SBE until fully located, space out 1 ft from fully located, drop ball&rod,set the FHL packer. PT the ,/ IA. Shear the PBR. 34. Space out w/pups,MU hanger&land,RILDS. 35. PT the tubing&IA, shear the SOV. ✓ 36. Install BPV or two-way check,ND BOPE. 37. NU tree. If BPV is installed,pull BPV&install tree test plug. Test tree. Pull test plug/two-way check. 38. Freeze protect well w/diesel. 39. Set BPV. 40. RDMO. Post-Rig Work request: 1. Reset well house(s)and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: a. Pull SOV and run GLD b. Pull CA-2 Plug from XN-nipple 4. Return well over to operations. 1 Y-29 ConocoPhiIIips _ Planned Subsidence E Nordic 3 DS Nipple, 2.875" @ 500' MD/500'TVD — Casing—9-5/8"36#, J-55 BTC @ 4,104' MD NIP Tubing—3-%" 9.3#, L-80, 8rd EUE 80-40 PBR @ 6,824' MD cizE I J, Baker Premium Packer @ 6,844' MD ?� Camco High Burst APCV Sliding Sleeve 2.812"X 7 @6,968' MD C-4, C-2, C-1 Perf Cemented @ 7,084'-7,150' Carbide Blast Rings- 80' (7,078'-7,158') mom Camco High Burst APCV Sliding Sleeve 2.812"X i @7,164' MD 3.5" 9.3#TN-110SS EUE 8rd Tbg - ,. f Baker F1 Permanent Packer @ 7,177' MD SBE @ 7,205' MD I 2.75"XN-Nipple @ 7,215' MD (with 2.75" CA-2 Plug) I Wireline Entry Guide @ 7,251' A-5 Perf @ 7,272'-7,279' --► A-4 Perf @ 7,284'-7,299' A-3 Perf @ 7,311'-7,354' A-2 Perf @ 7,393'-7,405' LCasing—7"26#, J-55 @ 7,549' MD Date: April 23,2014 Drawn By:Jacob Voss �tiry'� '� 1 KUP PROD 1Y-29 /' Conoc hiIIis ,' Well Attributes Max Angie&MD ,TD �� *1°',.:i Wellbore API/UWI Field Name Wellbore Status .-ncl() MD(868) Act Btm(ftKB) NaSka,InC. '.y 500292185200 KUPARUK RIVER UNIT PROD 41.53 3,300.00 7,708.0 ,...r,,,,..,..„,,,, s. • °." Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 11-29.11/1320134:49'53 PM SSSV:LOCKED OPEN 240 7/10/2009 Last WO: 35.01 11/26/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .. .._.__ _.___ _..._.. . __._._....Last Tag:SLM 7,362.0 11/9/2013 Rev Reason:TAG lehallf 11/13/2013 HANGER;30.3 :!j1: easing Strings Casing Description OD(in) ID(in) Top((MB) Set Depth(ftKB) Set Depth(TVD)... WVLen(I...Grade Top Thread iI CONDUCTOR 16 15.062 36.0 110.0 110.0 68.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 35.0 4,103.5 3,574.9 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WVLen(I...Grade Top Thread PRODUCTION 7 6.276 33.0 7,548.9 6,286.5 26.00 J-55 BTC W. ,.Tubing Strings CONDUCTOR;36.0-110.0 Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(INH) Grade Top Connection TUBING 4x3.5 I 4I 3.4761 30.31 6,936.91 5,795.21 11.001 J-55 I DSS-HTC Completion Details SAFETY VLV;1.823 3 a1: Nominal ID -- Top MB) Top(TVD)(ftKB) Top Incl("I Item Des Com (in) 30.3 303 0.09 HANGER FMC GEN IV 5K TUBING HANGER 4.000 - 1,823.3 1,773.9 27.80 SAFETY VLV AVA 4"SIDE GUARD TRDP SAFETY VALVE(LOCKED 3.250 FISH,2.775.0 • OPEN 6/4/2004) GAS LIFT;2,774.7 4,018.7 3,507.9 38.47 XO Reducing CROSSOVER 4 x 3.5 3.500 6,849.2 5,725.6 37.44 PBR BAKER PBR 3.000 6,863.0 5,736.5 37.43 PACKER BAKER HB RETRIEVABLE PACKER 2.890 6,902.1 5,767.5 37.39 NIPPLE CAMCO D NIPPLE NO GO 2.750 6,936.0 5,794.5 37.38 SOS BAKER SHEAR OUT SUB,ELMD TTL @ 6935'during 3.000 PPROF on 4/282006 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SURFACE;35.04,103.5-+ e Top(TVD) Top Incl H Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 2,775.0 2,553.2 39.68 FISH LOST JD DOG 8 PIECE OF SKIRT @GLM#1 6/3/2004 0.000 GAS LIFT,4,296.6 Perforations&Slots Shot ^-( Dens Top(TVD) Btm IND) (shots# Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,272.0 7,279.0 6,062.0 6,067.6 A-5,1Y-29 1/24/1989 4.0 (PERF 180 deg.Phase;2 5/8" GAS LIFT,4,798.911 Atlas SlimKon 7,284.0 7,299.0 6,071.6 6,083.6 A-4,1Y-29 1/24/1989 4.0 IPERF 180 deg.Phase;2 5/8" ,--, Atlas SlimKon 7,311.0 7,354.0 6,093.3 6,128.0 A-3,1Y-29 1/24/1989 4.0 IPERF 180 deg.Phase;2 5/8" 11 Atlas SlimKon GAS LIFT,5.194.2 4 7,392.0 7,405.0 6,158.8 6,169.4 A-2,1Y-29 1/24)1989 4.0 IPERF 180 deg.Phase;25/8" Atlas SlimKon Cement Squeezes Top(ND) Btm(TVD) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com GAS LIFT;5.600.2 1147,084.0 7,150.0 5,912.1 5,964.7 Cement Squeeze 11/10/199 C-4,C-2,C-1 PERF'D SANDS i 1 7,084.0 7,150.0 5,912.1 5,964.7 Cement Squeeze 10/14/199 C-4,C-2,C-1 PERF'D SANDS 6 it Mandrel Inserts GAS LIFT.6.005.9 St ti C eeTop(TVD) Valve Latch Port Size TRO Run o N. Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m 1 2,774.7 2,553.0 OTIS 4 x 1 1 GAS LIFT DMY BK 0.000 0.0 5/14/2010 IdE 2 4,286.6 3,720.7 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/14/2010 GAS LIFT,6.406.7 3" 4,788.9 4,121.7 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/4/2010 4 5,194.2 4,435.6 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 11/25/1988 5 5,6002 4,750.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/13/2010 6 6,005.9 5,066.1 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 11/25/1988 GAS LIFT,6,799.9 7 6,406.7 5,377.3 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 11/25/1988 8 6,799.9 5,686.4 CAMCO MMG-2 1 1)2 GAS LIFT DMY RK 0.000 0.0 7/16/1998 Notes:General&Safety End Date Annotation -- 8/252010 NOTE:WAIVERED WELL IA x OA x FORMATION COMMUNICATION 10)28/2010 NOTE:View Schematic w/Alaska Schematic9.0 PER,6,863.0 iiiii PACKER,6,863.0 NIPPLE,6,902.1 SOS,6,936.0 IM9i Cement,7084.0 Cement;7084 0 N 11 r IPERF,7,272.0-7,279.0- F" IPERF,7.284.0-7.299.0- IPERF,7,311.0-7,354.0 - IPERF;7,392.0-7.405 0- 1 PRODUCTION;33.0-7548.9 • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 14, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7t" Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • 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 20th - Sept 11th, 2008. The corrosion inhibitor/sealant was pumped Sept 12 - 13t ,2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry ei. ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Kuparuk Field Date 9/14/2008 Well Name PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 1C-178 203-041 8' 1.50 8" 9/11/2008 4.68 9/12/2008 2F-17 196-204 12' 10" 2.25 8" 9/11/2008 7.65 9/12/2008 3R-20 192-022 9-4" 1.50 16" 9/11/2008 1Y-27 193-088 11' 9" 3.00 20" 8/24/2008 2.97 9/12/2008 1Y-29 1 188-091 41' 6.00 5' 8/20/2008 10.20 9/12/2008 1Y-32 188-093 27'8" 4.40 32" 8/20/2008 6.80 9/12/2008 1Y-34 193-091 8' 1.10 27" 8/20/2008 5.95 9/12/2008 1 E-33 197-151 9-6" 2.10 20" 8/24/2008 7.23 9/12/2008 1 E-104 204-227 7' 1.40 9" 8/24/2008 1.70 9/12/2008 2X-01 183-084 10" NA 10" NA 3.40 9/13/2008 2X-02 183-103 23" NA 23" NA 3.40 9/13/2008 2X-03 183-109 6" NA 6" NA 1.28 9/13/2008 2X-05 183-107 8" NA 8" NA 5.10 9/13/2008 2X-06 183-110 6" NA 6" NA 1.70 9/13/2008 2X-07 183-113 6" NA 6" NA 1.28 9/13/2008 2X-08 183-114 6" NA 6" NA 1.28 9/13/2008 2X-17 195-171 6" NA 6" NA 1.70 9/13/2008 n j-1 JiJv Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # NO. 3792 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman aXa z ; ri",}a 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 05/09/06 1Y-29 11213739 PRODUCTION PROFILE W/DEFT Orv- 04/28/06 1 3M -25A N/A SHUT IN BHP - G(c 04/23/06 1 2N-303 1 R-21 3F-07 N/A 11213737 N/A LDL , (-� - -- PRODUCTION PROFILE W/DEFT i t— L 1 INJECTION PROFILE I , "--^ t(, " 04/21/06 04/25/06 04/23/06 1 1 1 1B-16 11235353 PRODUCTION PROFILE W/DEFT < _ 04/04/06 1 3B-15 11213741 INJECTION PROFILE 1- - 04/30/06 1 1 G-07 N/A PRODUCTION LOG W/DEFT - 04/19/06 1 1A-20 11235356 PRODUCTION LOG W/DEFT I 04/26/06 1 1H-18 N/A INJECTION PROFILE 04/24/06 1 IR -12 1Y-13 11213738 11213740 PRODUCTION LOG W/DEFT--�L� INJECTION PROFILE )A6 - ' 04/27/06 04/29/06 1 1 2N-318 11213742 LDL a 0 U -! U U 05/01/06 1 1Q -08A 11213743 INJECTION PROFILE 05/02/06 1 1G-01 11213744 INJECTION PROFILE iYa - D 05/03/06 1 3J-17 11258704 PRODUCTION LOG W/DEFT - '-(' 05/04/06 1 1 R-26 11258705 INJECTION PROFILE �` - 1 05/05/06 1 2A-04 11249902 INJECTION PROFILE 05/06/06 1 1 G-06 11249903 INJECTION PROFILE Y - 05/07/06 1 1E-18 11216193 MEMORY PRODUCTION PROFILE - 05/07/06 1 1G-14 11249904 INJECTION PROFILE - I 05/08/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • NO. MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission \fix I \ Julie Heusser, # .� Commissioner 6\ DATE: THRU: Tom Maunder, P. 1. Supervisor FROM: John Crisp, SUBJECT: Petroleum Inspector May 17-18,2001 Safety Valve Tests Kuparuk River Unit 1Y Pad May 17 & 18. 2001: 1 traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, the LPP failed to trip above 50% of primary separator pressure. The pilot was re -tested & passed the re -test. The AOGCC test report is attached for reference. 1 conducted 25 well house inspections on 1Y Pad. The majority of the houses were in good shape w/ no problems witnessed. Well houses # 30 & 22 were found w/ the well house lids resting on the tree cap gauges. The VSM for the flow line on well # 29 looked as if it had shifted up & had the line in a slight bind. I asked Phillips Rep. Pete Nezaticky to inspect this line. Prudhoe Bay Field has had problems w/ VSM's shifting up & I wanted to make sure KRU Rep's were aware of this problem. SUMMARY: I witnessed SVS testing in Kuparuk River Field. 16 wells, 32 components tested. 1 failure witnessed. 3.13% failure rate. 25 well house inspections conducted. Attachments: SVS KRU 1Y 5-17 & 18-01jc cc: NON-CONFIDEt4TIAL SVS KRU 1Y 5-17 & 18-01jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Operator Rep: Ernie Barndt . AOGCC Rep: John Crisp Submitted By: John Crisp Date: 5/17 & 18/01 Field/Unit/Pad: Kuparuk River Unit 1 Y Pad Separator psi: LPS 85 HPS MMIK Well Permit Number Number Separ PSI Set PSI L/P Trip Test Code Test Test Code Code Date Passed Oil, WAG, GINJ, GAS or CYCLE 1 Y-01 1830500 1 Y-02 1830590 IY-03 1830610 3750 2000 1800 P P WAG 1Y-04 1830660 1 Y-05 1830870 1Y -06A 1971340 85 70 55 P P OIL 1Y-07 1830680 1Y-08 1830620 1Y-09 1830520 IY-10 1830510 3750 2000 1750 P P WAG 1Y-11 1830410 1 Y-12 1830260 1Y-13 1830150 1Y-14 1830230 1Y -15A 1981860 85 70 50 P P OIL 1Y-16 1830420 1Y-17 1930680 85 60 60 P P OIL 1 Y-18 1931060 IY-19 1931070 85 60 65 P P OIL IY-21 1931020 85 70 65 P P OIL IY-22 1930700 85 60 55 P P OIL 1Y-23 1930710 85 70 28 3 P 5/18/01 OIL 1Y-24 1930720 85 70 78 P P OIL 1 Y-25 1880890 1Y -26A 1881160 85 70 50 P P OIL 1Y-27 1930880 85 70 64 P P OIL 1 Y-28 1930890 1880910 85 70 60 P P OIL 1Y-30 1880900 85 70 70 P P OIL 1Y-31 1930900 1Y-32 1880930 85 70 70 P P OIL 1Y-34 1930910 85 70 65 P P OIL Wells: 16 Components: 32 Failures: 1 Failure Rate: 3.13° ❑ 90 Day RJF *s: Pam Iaf-2 -vKRI I I y 517 & I S_Ql;G Well Permit I Separ I Set Number I Number I PSI PSI RE 1/16/01 UP I Test I Test I Test trip Code Code Code Page 2 of 2 Date oil, WAG, GINJ, Passed I GAS or CYCLE SVS KRU 1Y 5-17 & 18-01 jc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate — Plugging Perforate _ Pull tubing Alter casing Repair well Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X ARCO Alaska, Inc. Exploratory _ RKB 100 f eet 3. Address Stratigraphic _, 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service Kuparuk River Unit 4. Location of well at surface 8. Well number 208' FNL, 1104' FWL, Sec. 1, T11 N, R9E, UM 1 Y-29 9. Permit number/approval number At top of productive interval 312' FSL, 2366' FEL, Sec. 35, T12N, R9E, UM 88-91/93-018 10. API number At effective depth 330' FSL, 2595' FEL, Sec. 35, T12N, R9E, UM 50-029-21852 11. Field/Pool At total depth 344' FSL 2547' FEL, Sec. 35, T12N, R9E, UM Ku aruk River Field/Oil Pool 12. Present well condition summary Total Depth: measured 7708 feet Plugs (measured) None true vertical 6415 feet Effective depth: measured 7468 feet Junk (measured) None 0 R G I IN'A L true vertical 6220. feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 115' 16 " 181 SX AS 11 115' 1 1 5' Surface 4063' 9 5/8" 900 SX AS III & 4104' 3547' Intermediate 350 SX AS I Production 7516' 7" 250 SX Class G 7549' 6286 Liner Perforation depth: measured 7084'-7150', 7272'-7279'9 7284'-7299', 7311'-7354', 7392'-7405' true vertical . 5912'-5964'9 6062'-6068', 6072-6084'1 6094'-6129'9 6159'-6170' Tubing (size, grade, and measured depth) 4", 11#, J-55 @ 4019', 3.5", J-55 @ 4019' -6937 - Packers and SSSV (type and measured depth) PKR: Baker 1413@ 6863' • SSSV: AVA 4" Side Guard @ 1823' RECEIVE) 13. Stimulation or cement squeeze summary Pump Maraseal Gel Sqeeze treatment Unsuccessful attempt 3/19/93. CICT _ 6 1994 Intervals treated (measured) 708-4'-7150' Oa Coni. Commission �1 Treatment description including volumes used and final pressure An-hor n Pum ed 100bbis Maraseal at 1200psi 14. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 70 8669 10835 800 250 Subsequent to operation 76 6877 9675 800 250 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations X Oil X Gas Suspended Service 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Wells Superintendent Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. �i Subsidiary of Atlantic Richfield Comvanv KUPARUK RIVER UNIT WELL SERVICE REPORT WELL 1Y-29 DATE 6/29/94 DAY 1 DESCRIPTION OF WORK AFC/CC# - SCA# PUMP MARASEAL GEL SQUEEZE TREATMENT 230DS10YL-10417 CONTRACTOR / KEY PERSON FIELD COST EST. ACCUMULATED COST VECO-KARL $15,197 $15,197 PBTD (RKB) LAST TAG (RKB) - DATE SSSV TYPE / STATUS TIME 0900 0925 LOG ENTRY MIRU VECO PUMP, PEAK TRANSPORTS SEAWATER AND MARASEAL START PUMPING SEAWATER, ENCOUNTERED 1750 PSI AT 1.25 BPM WELL HAD A GAS HEAD, AFTER LOADING TUBING, PUMPED - SEAWATER AT 1.0 BPM AT 1125 PSI, PUMPED TOTAL 0F1 10 BBLS, 74 DEGS. 1122 START PUMPING MARASEAL AT 1.0 BPM AND 1200 PSI, PUMPED 100 BBLS , 64 DEGS. 1244' START PUMPING DIESEL FLUSH AT 1.0 BPM AND 1250 PSI FOR 30 BBLS , REDUCE RATE TO .5 BPM AT 1450 PSI , FOR 30 BBLS , REDUCE RATE TO.25 BPM AT 1550 PSI FOR 17 BBLS. PUMPED TOTAL OF 77 BBLS DIESEL FLUSH. 1530 RDMO START: 7" ANNULUS 1100 PSI, 10" ANNULUS 200 PSI END: it 850 PSI of200 PSI SUMMARY: PUMPED MARASEAL GEL SQUEEZE TREATMENT, PLAN TO LEAVE WELL SHUT IN FOR 3 DAYS CROSSLINK f y Commission Gas ccnq. WiiAlli 67iJi�+�• clor CHECK THIS BLOCK IF SUMMARY IS CONTINUED ON BACK I X1 COMPLETE77 INCOMPLETE Weather D'a^^•-* Temp. Chill Factor I Visibility I miles Wind Vel. mob Signed 'T2i oa.A cS ,q0 91 !2VcS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISciiON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Perforate Pull tubing Alter casing Repair well Other _X_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development 2L ARCO Alaska. Inc. Exploratory — RK13 100feet 3. Address Stratigraphic , 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service Ku aruk River Unit 4. Location of well at surface 8. Well number 208' FNL, 1104' FWL, Sec. 1, T11 N, R9E, UM 1 Y-29 9. Permit number/approval number At top of productive interval 312' FSL, 2366' FEL, Sec. 35, T1 2N, R9E, UM - - 88-91/93-018 10. API number At At effective depth 330' FSL, 2595' FEL, Sec. 35, T1 2N, R9E, UM -029-21852 At total depth 11. Field/Pool Kuparuk River Field/ 344' FSL, 2547' FEL Sec. 35 T1 2N, R9E UM Ku aruk River Oil Pool 12. Present well condition summary Total Depth: measured 7708 feet Plugs (measured) None true vertical 6 415 feet Effective depth: measured 7468 feet Junk (measured) NOW true vertical 6220 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 115, 1 6 " 181 SX AS 11 115, 115, Surface 4063' 9 5/8" 900 SX AS III & 4104' 3547' Intermediate 350 SX AS I Production 7516' 7" 250 SX Class G 7549' 6 2 8 6' Liner Perforation depth: measured 7084'-71501, 7272'-7279, 7284'-72990, 7311'-7354', 7392'-7405' true vertical 5912'-5964', 6062'-6068'9 6072-6084', 6094'-6129'9 6159'-6170' Tubing (size, grade, and measured depth) 4", 11#, J-55 Qa 4019', 3.511, J-55 @ 4019'-6937' Packers and SSSV (type and measured depth) PKR: Baker HB @ 6863' ; SSSV: AVA 4" Side Guard @ 1823' 13. Stimulation or cement squeeze summary j< t C I V E 1) Unsuccessful polyacrylamide gel squeeze to isolate "Cl" sand on 3/8-9/93. Intervals treated (measured) N/A JUN 25 1993 Treatment description including volumes used and final pressure N/A Alaska Oil &Gas Cons. uuicirniss 14. Representative Daily Average Production or Injection Data Ancnorage Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 2300 4000 7000 1 650 250 Subsequent to operation 2300 4000 7000 1 650 250 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run , Daily Report of Well Operations_, Oil � Gas Suspended Service 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. � jt2 Signed �"("" Title ��� ��)1"'n ?�� Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT WELL PBDT FIELD - DISTRICT - STATE DAYS DATE � 9 7�l�8' u,0A,euu A yr e �. 3- �%- CONTRA /'OR OPERATION AT REPORT TIME AkCTcdoik,Ee 13i,UG ODsicv REMARKS P42CZtWee 'Al- C'oe,5 - 2300S10 VL / /03/'7 LCS T. 60 S r : Z ! 7,09. Dd �i1�rJ • C��S% 6 i, �S.S ba 2�a.JA %041:moo .%,,;C',t'��C' �l IDA IK PFTROLEUM ENGINEERING 0630 P.T. Tv QCQ-A'0 GCCd TeS7. ;2 dh s.z1eS€t Pc1mPE.b, 08AJ5 R114 W -31JV eTa / Tu/3wc, T 1c I.oeAT&,q/ Nvb. AsccuuEc7/(2E-m6gT kFT,1.4,1 ".e/,G/) 1,UFtA%A,QL� �ACtKcr.P . aS%AAT .D1SA�ACi�t/G tU/ �VAi2/Y1 �/�SFL 5� ° 457-,qQ7 PUmP1A/G 7Nh'U C'O/t C / app 2a/6!/C'7-U 1,200 `/wNP 9 APM 6920 2/60' /00 FPl .34abViAwAv 2c*2tzeTU 11oC!Lw- NP y 9tilG v/1� Acs mP1tiG 016'rSeL 56 8,61g - QU)4 Il aswi /CN 0Vek /0 45FAWIQTe-k- F-' , 0g45- 4) 2oc4.)Ai CTU Cd / A9 AM as%A,Q Aun-,0j'uG Sic) 26u.W CT/i8c,- Q V vULdS , a-73 6,01n oyj'C e Tll & 1.5 43P/r1 31co 6-3Ata' i�G/CTU A,s,uu,taS 4J9,3 ,Qpm //-5— �c�P ICC3 il,!T- 6-46 X Cv 60C13/�?, CCC# , CioiyT , j. q l0/G i6NT SnoT ewcoccivTM6,b AGA1y r 610 ,,c7mb , 6130'. 6135 /0/5' C a % e -7 -ti k.4'76 T S 6PM 614(2' 3. C &m .ZOCu,y 7,(36CTC1 1030 615y" . BLM, 7a 3•C 60M T6a�ZCTu 920 Vii vP 100,2!4 -TU 103-7 6 /6 / ' �- y 76' lCTu 3.O ,3P1n r�%'Tu /o yo /wNP �s6o /CTS! 1645- ect 7 'T8G/C Tu Xg r r /. 5,6Pm 0 6P/n C %u (o /6 y ' //CC 6169'r 3-0601n 7/3G/07'u 0 6P/rI/ CTGI a0 7 Q61s . Slt/ TSG/G' TCl e,a &ls G`' 7U 126 S/b PUMPIA16 664 40 ,D0U),(J CCU .4AJAJG I -US , oyw,7 N T , jes,�,,C 66 6bls• PumPeb ,qku GTu Vc6 Pumpeb 7 -y - Ra %6G/C'V R,vAlakus, l,-q/S Peod cwt CTU ,,sTAieT PummAiG Ziese zo L)AJ CT11 fo,e «FFz?6 Pkc7–ecT I)U m peb aC 8bis. alEssL . %DCwA1 C T Z1 /TaG . AAj,u uj-us . I -S J 5' c,r. k w4 -A ex w,�.. /y.� ?J/'� �iJ/ 3 tA'yw.�risr , (r ' rfi�w�e� y� � 2.50 jazsle. �� - ��► � Ira/��_ G.T a.+rrwi� AMP" ta.,wK ✓, a OR � aLAAjoy fiis/� fa s /L f � G LG 7' G.T' l y! 'T i►� � � •+-+r► e i s.�.� �.� �� �ev� tiy` ✓.,,A&r,.. 4--!22& to �1 4-�......c- cel T'",�. >k. —�1�� /%jet r. r'i►.�� ��si it: L lG tw/.a r . 7.t' �s � �sr .3�� ii, .. D t»tt At I -L t G� Lc) S l -njrs 0 ..9 3 ,e�/S'O ice: w•r_ta._✓� /'� 7v 1eE� A� �. d r C'KCHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK jUly 2 5 1993 Weather Temp. Chili Factor Visibility Wind Vol. Signed 0"'I UWs Cons. Luaifnisslu;, Report OF °F miles I knots, REMARKS CONTINUED: V fro Jr '• I ' T cAlm 90f do ma 4. L7l r — B ►.r &..%L #' w,11 ALI DESCRIPTION DAILY ACCUM. TOTAL CAMCO OTIS SCHLUMBERGER DRESSER -ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING j FRACMASTER B. J. HUGHES Roustabouts Diesel p Methanol Supervision Pre -Job Safety Meeting S AFE .23C D SX ,c. 10311 01 L16 ' r PUMP 40�0 6AR6e 61A.T r_. goo P,4V 3 ao DODO O(� TOTAL FIELD ESTIMATE 41 7619 00 Signed iJ �C—El v tu ARCO Alaska, Inc. JUN Z 5 1993 WELL SERVICE REPORT Subsidiary of Atlantic Richfield Company A-#aska Oil & Gas Cons. Cornmissiof, f 10 CST. `c -s r : .? 9 2 bio M rk6j 1311 CT[1 E KUPARUK PETROLEUM ENGINEERING /0A18 5-C &US. PurmPEb S/a /'ur»�,E� — �STAQT Q.(.1�. CF QAKER �ET �Ac��CE�C Tu 13"'vG EA)b ,Cc CATER . i4yb. �aSc'CA/AlEGT. c c /C 3000 C- c" m 6&7"c"S C Ai T c c'.s . 6UG d —7—EST. 424 )�iu/SNED kd. of eTb ecAiyec1cR /.151 T Piti y ttia ,C/&k 3 01'/ )Y X6, 01.SCvA/Ajzu a? -ESI "I eEmemr ,erfr4m u kuAl�yi�ti � TC.o� w/ �.,�� G.S Fis�A/ Ok E FLAPPER aACR AO-ESSuk VALVE /./G'/ YC •8,2 � aAkEk PACk Ee I& o6' A T. Tom. coo Ial-i' OPEN-si-yA13 S/TP-21's-C1* ' s7ART PUmniNO z/ESEL zcw"ti C7urd /.O ,6plr S'tL,f FACE .01 1305- c,, 'w,Tei4 Tc, cSE44,0Q'7Ek 6,1° CQACTAJ E /'c MPIA16 .DocvA) C U9, kX4 13a Q c S TA C 7 Pum PSN t3 6 aZ ° e,sEAec iA %E,E' & ujAj TBG. &? t I .4AjoV 4 US I A110 h/7'. C �qEe,e /3, �-oc * C 6c,31 60 AJ T J'11/ . 143C SET -Dc i c,'AJ C� 6 ! /b ' (--'7-In b S/d PU MPlAiC .DQW'A CTA T36ZC T To Tee Avb W6,E'k del -VA/ Jg01-F. /o?O 13b/s. leu w 4A1A1 c,`u.S' ZQ41141 1440 /Du MP1AJG f3pm zowAI 61. T x /sc, -4yAlulus T To .75' ,0m . I� CO (..S4;T�*r4! To ACCSFL To 0/SAACP "146JU e 67*U -s&eT Pocjq . PUM,J 1.3 QPM DQWAY (frU K ° biFsE� /5A1G` 0,y.SctRF,4C'6 +J%CTU . CoNT1AuuE .b SPXAel�tiG w/ D/ESE.L 3'7QA/s. 1616) S/D Pump 7Y,66h. Pum/'6b. 4sec uRcc we u— E 6- R T R.D. r .TAiFLATA,aiz AACkEQ 94,6 4646-E CAi E'L(',rneA 7-4. E// �G lc(.,,4 AART�A44V aSA/A•AREd Pkcr» WcAwAJ6 Ord. oSEuT p4eg&q 64c.,R is �RuDNO� LU,i2 /c'E11�'FSS. 114 /YIlkU OAMCC 4 L UA117 / 0dt5 AIH `Y Aso KT . /to 1AS1.00 OT. GSS, 3* IWw'd ,.�. QO Brolah To 68Al- WLAt -A., q eal D- iy�rn Jc A/e Ti: /it soot'sff Weather Tamp. Chill Factorf Visibility Wind Vol. Signed A wit 4 a n nr o .. ,I •' REMARKS CONTINUED: /o ll sr��r��rjrM- V-4.0 NOW A W.o i DESCRIPTION CAMCO WIL (, mjT OTIS SCHLUMBERGER DRESSER -ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel 135 Bbis• Methanol Supervision V F i-sp"C m NT PUMP Pre -Job Safety Meeting yes AFE In z aggj.,mg xwigj Ingeej7 cei. a10 ?uFcA 7A K �qc lo'e u TOTAL FIELD ESTIMATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMW..>ION APPLICATION FOR SUNDRY APPROVALS by 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X ARCO Alaska, Inc. Exploratory _ Stratigraphic _ RKQ 100 feet 3. Address 7. Unit or Property name P. O. Box 100360 Anchoracie, AK 99510 Service Ku aruk River Unit 4. Location of well at surface 8. Well number 208' FNL, 1104' FWL, Sec. 1, T11 N, R9E, UM 1 Y-29 9. Permit number At top of productive interval 312' FSL, 2366' FEL, Sec. 35, T12N, R9E, UM88-91 10. API number At effective depth 330' FSL, 2595 FEL, Sec. 35, T12N, R9E, UM5o.,029-21 852 11. Field/Pool Kuparuk River Field At total depth 344' FSL, 2547' FEL, Sec. 35, T12N, R9E, UM Ku aruk River Oil Pool 12. Present well condition summary Total Depth: measured 7708 feet Plugs (measured) None RE r E IV E true vertical 6415 feet Effective depth: measured 7468 feet Junk (measured) NoneJ�s `r ,�:M . true vertical 6220 feet Size Cemented Measured h True ic�epth Casing Length we s�'1G ofJ07 Structural Conductor 1 15' 1 6 " 181 SX AS 11 115' 1 1 5' Surface 4063' 9 5/8" 900 AS III & 4104' 3574' Intermediate 350 SX AS I Production 7516' 7" 250 SX Class G 7549' 6286' Liner Perforation depth: measured 7084'-7150'1 7272'-7279', 7284'-7299', 7311'-7354', 7392'-7405' true vertical 5912'-59641, 6062'-6068', 6072'-6084, 6094'-6129', 6159-6170' Tubing (size, grade, and measured depth) 4", 11#, J-55, Ccs 4019'; 3.5", 9.3#, J-55 (_@ 4019-6937' Packers and SSSV (type and measured depth) PKR: Baker "HB" @ 6863'; SSSV: AVA 4" Side Guard @ 1823' 13. Attachments Description summary of proposal _2L Detailed operation program _ BOP sketch _ Isolation of the "Cl" sand with a polyacrylamide gel squeeze. 14. Estimated date for commencing operation 15. Status of well classification as: February 1993 Oil -X comas Suspended 16. If proposal was verbally approved Name of approver Date approved Service 17. 1 hereby certify that the fore oing is true and correct to the best of my knowledge. -w. C� i Attachment 1 Profile Modification Kuparuk Well 1Y-29 ARCO Alaska requests approval to isolate the "C1" sands in Well 1Y-29 through the implementation of a polyacrylamide gel squeeze. This procedure calls for injection of 200 bbis of polyacrylamide gel by coiled tubing into the Kuparuk C1 interval, located between the depths of 7140' and 7151' MD-RKB. RR' E C E0 I V E 1E , Alas!(a oil e:: Gi..i(.� �va- }tt�. 2-�.eicho a-u. dt STATE OF ALASKA t ALASr,A OIL AND GAS CONSERVATION COMMIS, -.JN JN R I G 10 L. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown _ Stimulate Plugging Perforate _ Pull tubing Alter casing Repair well Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X ARCO I Exploratory ' RK13 feet 3. Address Stratigraphic 7. Unit or Property name P.O. Box 100360, Anchorage, AK 99510 Service Ku aruk River Unit 4. Location of well at surface 8. Well number 208' FNL, 1104' FWL, Sec. 1, T11 N, R9E, UM 1 Y-29 9. Permit number/approval number At top of productive interval 312' FSL, 2366' FEL, Sec. 35, T1 2N, R9E, UM 88-91 10. API number At effective depth 330' FSL, 2595' FEL, Sec. 35, T12N, R9E, UM - - 0-029-21852 11. Field/Pool At At total depth 344' FSL, 2547' FEL, Sec. 35 T1 2N, R9E, UM Ku aruk River Oil Pool 12. Present well condition summary Total Depth: measured 7708' feet Plugs (measured) true vertical 6415' feet. Effective depth: measured 7468' feet Junk (measured) true vertical 6220' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 16 " 181 Sx AS 11 1 1 5' 1 15' Surface 4069' 9 5/8" 900 Sx AS III & 4104' 3574' Intermediate 350 Sx Class C Production 7516' 7" 250 Sx Class G 7549' 628 6' Liner Perforation depth: measured 7084'-7150',7272'-7279',7284'-7299',731 1'-7354',7392'-7405' true vertical 5912'-5964',6062'-6068',6072'-6084',6094'-6129',6159'-6170' Tubing (size, grade, and measured depth) 4" 11.0# J55 Qu 40194, 3 1/2" 9.3# J55 @a 6937' EC -1 Packers and SSSV (type and measured depth) 3-1/2" Baker "HB" pkr. @ 6863 AVA SSSV @ 1823' 13. Stimulation or cement squeeze summary Attempt C sand cement squeeze on perforations at depths listed �t Q. Intervals treated (measured) GlIns. 9 A����� Oil & ��� ���� C Sand from 7084' to 7150' CIC�14C�� Treatment description including volumes used and final pressure Pumped 116 bbl. cement and 400 bbl. Biozan gel, FWHTP=1800 psi 14. Rearesentative Daily Average Production or Injection Data Oil -Bbl Gas -Md Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 2698 7249 6295 1020 327 Subsequent to operation 2841 6742 4635 1780 315 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Water Injector Daily Report of Well Operations Oil --X- Gas Suspended Service 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. �'. . W .�,,- 12— 1 Signed Title • eratlons Engineer Date Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE 7) *lr I N AKUL) AmKa, inc. 1W Subsidiary of Atlantic Richfield Compan%` WELL CONTRACTOR /� �g e a REMARKS �- w/'2 —. - ci__-,� SOT FIELD - DISTRICT - STATS , OPERATION AT REPORT TIME e - WtLL %*=KV1Uh Hh)JUK 1 DAYS DATE o A -Y e t�ce y eAle s �eyey �� e1/tea r-��s !26n y' 7 /oao'd ria a 1,300 ,210 1 Srt._ !� _ s L. il a4 w CA -,P b 6 0i0`� q66 - - C4 1^ .- YL 1 L"'[ . . „ .,,. A* . - - - •. - 9!!-p / /T 11 -?/J?A:w MA/ ii ) O_ �/ �� � d L 2 5! A 7.4067 '5-3- ,-SOT ss .LL -v 6 400 ❑ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. Chill Factor VisibilityWind Vol. Report I OF I °F miles knots Signed Alaska Oii "i, G33 REMARKS CONTINUED: /, 4/ -- - . 5-11 y o z a y, g� / a-., �4 DESCRIPTION DAILY ACCUM. TOTAL CAMCO OTIS SCHLUMBERGER DRESSER -ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING V FRACMASTER B. J. HUGHES Roustabouts ,• a 4c Diesel 4- uv K / Methanol lj p �S�pervts � 4 ' O G� Pre -Job Safety Meeting AFE TOTAL FIELD ESTIMATE Sign Subsidiary of Atlantic Richfield Company / BD� /� / �l� FIELD -DISTRICT -STATE, ' CONTRACTOR A� _ ^y C L� � � I n 11/c d 115-- I OPERATION AT REPORT TIME 0,5 e-10 REMARKS .. I=amr. vSMIA V Ivy FILM vn DAYS DATE 1 .4. f Z C`sd34 n C (? 11" le -,,,2 Se�,ucto- 7P G S 40' 4� _ T a ti 1..�, , . v7 %�.•, . ' C©i �1t iso a a zC 4 C c IZ- 100, S!1 w 77-1 / 'w Ott-) /'N /f r �-.7, A w t"I 111 . 9� Al� a? r 4e., S /// 7 Ta i & 7 i 196' n rA-i / ,',v 7-:� c/,g ' ) 5�L / / u d 4-0 7/ 0 S-' a . d // r,? v S �? �- a 6 T2s i S mak,%z ;2 -- J / P ' / S ix -v i 07 %,6 /'S tt) e '3/4 ti Ge- / • kc J gzd 113 to Y z >° 1;? 910��M &n z -Z /e Q., 7,P.3!2 . ZO' _ - I _ . ' © J 12 A7,v� ,+moi , a. / s C ss nnhe5vesrsn /J hw d& a _ b*/. e / 4 ❑ CHECK THIS BLOCK IF EdMMARY CONTINUED ON BACK Weather I Temp. Chili Factor Visibility Wind Vel. Sign Report 7 of I /r�� OF miles knots REMARKS CONTINUED: S,1111Lc� ) r I1tz fo /1y o to �?ndaT)e -,rat / a 1AX C WO �7'rl /J:: t S • Tt.I'I-(-CcBg/.�%Ni PA+a �'L �o ll93' C �f ��n 3,S3Pn� / 5: 3 - ?00 /J - (o r �,.•,,a R.•;� ra 2.0 3P*4t %5 � y �' C4 _ c / ` c- 1 � O / VlJ / 7o J i .4 %1 /A. 110 - .00. 1 C. S`2yZ� /O lO/S /S/G� t� eesye�'-s....� 0 Aa A2 jq e _ 2 DESCRIPTION DAILY ACCUM. TOTAL CAMCO OTIS SCHLUMBERGER DRESSER -ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel Methanol Supervision Pre -Job Safety Meeting AFE TOTAL FIELD ESTIMATE Signed STATE OF ALASKA A.1 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL 0 GAS 0 SUSPENDED Q ABANDONED SERVICE 2 Name of Operator ARCO Alaska, Inc 7 Permit Number 88-91 3 Address P.O. Box 100360, Anchorage, AK 99510-0360 8 API Number 50-029-21852 4 Location of well at surface ' OOF� 208' FNL, 1104' FWL, SEC 1, T11N, R9E UM OAS At Top Producing Interva-� } 312' FSL, 2366' F L, SEC 35, T12N, R9E UM ERl i -_ At Total Depth r > _a 344' FSL, 2547' , SEC 35, T12N, R9E UM 9 Unit or Lease Name KUPARUK RIVER UNIT 10 Well Number 1Y-29 11 Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL 5 Elevation in feet (indicate KB, DF, etc.) RKB 100' 6 Lease Designation and Serial No. 1 ADL: 25646 12 Date Spudded OCT 18 1988 13 Date T.D. Reached OCT 25 1988 14 Date Comp. , Susp. or Aband. 15 Water Depth, if offshore NA feet MSL 16 No. of Completions 1 17 Total Depth (MD+TVD) 7708' MD & 6415' TVD 18 Plug Back Depth (MD+TVD) 7468' MD & 6220' TVD 19 Directional Survey YES NO 20 Depth where SSSV set 1823' feet MD 21 Thickness of permafrost 1300' (approximate) 22 Type Electric or Other Logs Run DIL,SFL,GR,CAL,SP,FDC,CNL,CBL,GYRO 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" 181 SX AS II 9 5/8" 36# J-55 SURF 4104' 12-3/4" 900 SX AS III & 350 SX CLASS G 7" 26# J-55 SURF 7549' 8-1/2" 250 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 7272'-7279' MD, 2-5/8" W/ 4 SPF 6062'- 6067' TVD 7284'-7299' MD, 2-5/8" W/ 4 SPF 6071'- 6083' TVD 7311'-7354' MD, 2-5/8" W/ 4 SPF 6093'- 6127' TVD 7392'-7405' MD, 2-5/8" W/ 4 SPF 6158'- 6168' TVD 7083'-7149' MD, 2-1/8" W/ 12 SPF 5911'- 5964' TVD 25 TUBING RECORD SIZE DEPTH SET MD PACKER SET MD 4"/3-1/2", J-55 6937' 6863' 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 7272'- 7405' 14,000 Ibs 16/20 CARBOLITE 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR TEST PERIOD *- OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS -OIL RATIO Flow Tubing Press. Casing Pressure CALCULATED 24-HOUR RATE �► OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY -API (corr) 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 5bbmit in duplicate ' 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. NA TOP KUPARUK C 7083' 5911' BOTTOM KUPARUK C 7153' 5967' TOP KUPARUK A 7265' 6056' BOTTOM KUPARUK A 7407' 6170' Y 31. LIST OF ATTACHMENTS 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title AREA DRILLING 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 A D D E N D U M WELL: 1Y-29 1/24/89. RU DA, PU 2-5/8" Slim Kone BH perf gun. RIH, att to perf 7392'-7405'; gun misfire, POOH. RIH, perf 4 SPF, 180° phasing 7334'-7354'. Flow well f/3 min. RIH, perf @ 4 SPF, 180° phasing f/7392'-7405'. Flow well f/3 min, POOH. RIH, perf @ 4 SPF, 1800 f/7311'-7334'. Flow well f/3 min. RIH, perf 4 SPF, 180° phasing f/7284'-7299'. Flow well f/3 min. One misfire. RIH, perf @ 4 SPF, 7272'-7279'. Flow well f/3 min. One misfire. RD DA. 4/10/89 Frac Kuparuk "A" sand perfs 7272'-7279', 7284'-7299', 7311-7354', 7392'-7405' in nine stages per procedure dated 2/10/89 as follows: Stage 1: Pm 150 bbls gelled diesel ±252# silica flour @ 25 P BPM, 4167P si 0j�?�! Stage 2: 180 bbls gelled diesel 1302# of silica flour @ 25 BPM, r& SiSSC� 2125 psi tage 3: 5 bbls gelled diesel w/2 ppg, 16/20 Carbolite @ 25 ;1 �s�®C�,� BPM, 4064 psi :.�.` Stage 4: 13 bbls gelled diesel w/4 ppg, 16/20 Carbolite @ 25 BPM, 3966 psi Stage 5: 19 bbls gelled diesel w/6 ppg, 16/20 Carbolite @ 25 BPM, 3488 psi Stage 6: 25 bbls gelled diesel w/8 ppg, 16/20 Carbolite @ 25 BPM, 3844 psi Stage 7: 36 bbls gelled diesel w/10 ppg, 16/20 Carbolite @ 25 BPM, 3844 psi Stage 8: 46 bbls gelled diesel w/12 ppg, 16/20 Carbolite @ 25 BPM, 6237 psi Stage 9: 3 bbls gelled diesel flush @ 25 BPM, 6237 psi Sanded out w/10 ppg slurry @ top of perfs. Fluid to Recover: 427.5 bbls Sand in Zone: ±42 bbls slurry & 14,000# Sand in Csg: ±82 bbls slurry and 22,500# Avg Pressure: 4200 psi 6/30/89 RU Atlas, perf 7116'-7149' (Rn #1 and #3; Rn #2 did not fire). Perf 7083'-7116' (Rn #4 and #5). All @ 60° phasing. RD Drillin c� pervisor Date Schlumberger SUBwSURFACE DIRECTIONAL SURVEY gGjUIDANCE CONTINUOUS [TfOOL lo IlZr00 -Jaska Qit Gas Cons. Comnih, ' Anchorage - Company ARCO ALASKA, INC. Well Name 1Y-29 (208' FNL,1104' FWL,SEC l,T1lN,R9E,UM) Field/Location KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 73056 Logged BY: SCHWARTZ Gate 6-NOV-88 Computed ft. KRUWELL 4 MMM M %46 M SCHLUMFERGER GCT 'DIRECTIONAL SURVEY CUSTOMER LISTING FOR, ARCO ALASKA, INC. IY-29 SCUP A RUK NORTH SLOPE,ALASKA SURVEY DATE: 06-NOV-88 ENGINEER: SCHWARTZ METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 88 D=G 29 MIN WEST J R COMPUTAT19N DATE: 13 -OEC -88 PAGE I ARCO ALASKA INC. DATE 13F StJRVFY: 06-NOV-88 1y-29 KELLY BUSHING ELEVATION: 100.00 FT KUPARUK NORTH SLOPEtALASKA ENGINEER: SCHWARTZ INTERPOLATED VALUES FOP EVEN 100 FEET OF MEASURED DEPTH T R U SUB -SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HO RIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH 3EPTH DEG` MIN DEG MIN FEET DEG/100 FEET FEET FEET DEG MIN 0.00 0.00 -100.00 0 0 N 0 0 E 0.00 0.00 0.00 IN 0.00 EE- 0.00 N 0 0 E 100.00 100.00 0.00 0 17 S 84 5() W 0.24 0.28 0.015 s 0.24 W 0.24 S 78 46 W 200.00 200.00 100.00 0 22 S 79 14 W 0.33 0.19 0.21 S 0.84 W 0.87 S 76 7 W 300-00 300.00 200.00 0 24 N 35 55 W 1.52 0.17 0.23 S 1.52 W 1.54 S 81 25 W 400.00 399.99 299.99 0 35 N 14 53 W 2.35 0.42 0.13 S 2.36 W 2.36 S 86 53 W 500.00 499.98 399.98 1 1 S 88 27 W 3.76 0.34 0.17 S 3.77 W 3.77 S 87 23 W 600.00 599.96 499.96 1 11 N 37 14 W 5.69 0.52 0.10 s 5.69 W 5.69 S 89 0 W 700.00 699.94 599.94 1 23 S, 88 29 W 7.99 0.18 0.10 s 7.99 W 7.99 S 89 17 W 800.00 799-90 599.9a 1 41 N 88 34 W 10.65 0.4? 0.11 s 10.66 W 10.66 S 89 23 W 903.00 899.85 799.85 2 1 N 88 34 W 13.833 0.76 0.03 S 13-84 W 13.84 S 89 52 W 1000-00 999.75 399.75 3 35 N 83 6 W 18.37 2.68 0.26 N 18.37 W 18.37 N 89 12 W 1100,00 1099.29 999.28 7 9 N 74 7 W 27-54 3.20 2.37 N 27.43 W 27.59 N 85 4 W 1200.00 1198-01 1098.01 11 32 N 74 43 W 42.76 5.85 6.86 1-1 42.59 W 43.14 N 80 51 W 1300.00 1234.93 1194.99 15 32 N 77 25 W 66.50 1.99 12.45 N 66.20 W 67-36 N 79 20 W 1400.00 1390.74 1290.74 18 9 N 77 26 W 94.80 2.38 18.69 N 94.34 W 96.13 N 73 47 W 1500.00 1434.51 1384.51 2" 45 N 78 47 W 128.82 5.09 25.95 N 1.28:18 W 130.79 N 78 33 W 1600.00 1575.50 1475.50 25 50 N 79 32 W 169.76 3.44 33-52 N 168.93 W 172-23 N 78 46 W 1700.00 1664.41 1564.41 27 47 N 79 11 W 214.95 0.93 41.83 N 213.93 W 217.99 N 78 56 W 1800.00 1752.90 1652.90 27 48 N 78 3 W 260.82 0.37 51.12 N 259.56 W ?64.95 N 78 51 W 1900.00 1841-34 1741.34 27 46 N 77 4 W 306.65 0.58 61.11 N 305.15 W 311.21 N 78 40 W 2000.00 1929.91 1329.51 29 45 N 75 9 W 352.79 5.01 721.17 N 351.01 W -158.35 N 78 22 W 2100.00 2014.93 1914.93 31 49 N 76 20 W 403.61 0.51 34.33 N 401.r, -) , W 410.29 N 79 7 W 2200.00 2099-86 1999.96 11 46 N 75 46 W 455.15 0.43 97.13 N 452.74 W 463.05 N 77 53 W 2300.00 2184.93 2034.93 32 15 N 75 14 W 506.37 2.37 110.33 N 503.64 W 515-59 N 77 38 W 2400.00 2267.10 21E7.10 38 12 N 77 9 W 561.84 7.05 124-21 N 558.76 W 572.40 N 77 28 W 2500.00 2343.54 2243-54 40 45 N 783 53 W 1525-27 1.39 137.34 N 621.P7 W 636.86 N 77 32 W 2600.00 2419.03 2319.03 40 4 5 Al 79 23 W 590.04 0.95 149.39 N 636.34 4 702.41 N 77 43 W 2700.00 2495.13 2395.13 40 13 N 79 14 W 754.08 0.46 161.46 N 750-09 W 767-27 N 77 51 W 2800.00 2571.77 2471.77 39 29 m 79 9 w 317.47 1.40 173.47 N 813.18 W 831.43 N 77 57 W 2900.00 2649-75 2549.76 38 10 N 78 53 W 879.22 0.56 195.35 N 874.64 W 894.06 N 78 2 W 3000.00 2728.71 2628.71 37 30 N 78 34 W 939.70 0.67 197.33 N 934.82 W 955.42 N 73 4 W 3100.00 2808.26 2708.26 37 19 N 7.9 26 W 999.:35 0.76 209-51 N 994-18 W 1016.01 N 79 5 W 3200.00 2886.66 2786.66 40 20 N 90 57 W 1060.60 4.41 221.03 N 1055.14 W 1078.04 N 73 10 W 3300.00 2961.74 2861.74 41 31 N 12 6 W 1126.23 0.36 230.24 N 1120.55 W 1143.96 M 78 23 W 3400.00 3036.69 2936.69 41 21 N 31 39 W 1191.98 0.24 239.60 N 1186.07 W 1210.03 N 78 34 W 3500.00 3111.73 3011.78 41 21 N 81 26 W 1257.53 0.27 249.31 N 1251.40 W 1275-99 N 78 43 W 3600-00 3186.90 3086.30 41 8 N 131 7 W 1323.03 0.58 259.29 N 1316.65 W 1341.94 N 73 51 W 3700.00 3262.40 3162.40 40 46 N 80 41 W 1388-01 0.50 269.74 N 1381.39 W 1407.47 N 78 57 W 3800.00 3338.42 3238.42 40 11 N qO 34 W 1452.37 0.81 280-38 N 1445.48 W 1472.42 N 79 1 W 3900.00 3415.21 3315.21 39 31 N 80 39 W 1515-81 0.57 290.79 N 1508-67 W 1536.44 N 79 ,5 W COMPUTATION DATE: 13 -DEC -88 ARCO ALASKA, INC. IY-29 KUPARUK NORTH SLOPEtALASKA DATE 9F SURVEY: KELLY BUSHING ELEVATION: PAGE 17- 06-NOV-88 100.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED D; -::PTH TRUE SU3-SEA COURSF VERTICAL DOGLEG RECTANGULAR Cl -ORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG. 14IN DEG MTN FEET DEG/100i=EFT FEET FEET DEG MIN 4000.00 3492.70 3392.702 38 42 N 90 40 4 1578.43 1-16 301.04 N 1571.04 W 1599.63 N 79 9 W 4100.00 3571.44 3471.44 37 24 N 11 6 W 1639.52 1.52 310.93 N 1631.39 W 1661-25 N 79 12 W 4200.00 3651.19 3551.19 37 8 N 81 47 W 1699.41 0.27 319.80 N 1691.57 W 1721.53 N 79 17 W 4300.00 4400.00 .3730.91 3810-65 3630.91 3710.65 37 37 6 11 N N 92 92 6 29 W W 1759.39 1819.37 0.2f) 0.35 328.26 336.33 N N 1751.35 1811.13 W W 1781.85 1842-10 N N 79 79 23 28 W W 4500-00 3890.29 3790.29 37 10 N 82 37 W 1979.53 0.14 344.15 N 1871.11 W '1902.49 N 79 34 W 4600.00 3970.10 3170.10 3651 N 92 50 W 1939.47 0.48 351.82 N 1930.87 W 1962.66 N 79 40 W 4700.00 4050-24 3950.24 36 42 N '33 17 W 1999-01 0.22 359.0? IN 1990.24 W 2022.37 N 79 46 W 4800.00 4130.30 4030.30 37 19 N 83 11 W 205,8.70 1.96 365.96 N 2049.76 W 2082-18 N 79 52 W 4900.00 4208.56 4108.56 39 27 N 82 19 W 2120.61 0.88 373.87 N 2111.49 W 2144.33 N 79 57 W 5000.00 4285.54 4185.54 39 41 N 82 27 W 2184.07 0.14 382.35 N 2174.75 W 2208.11 N 80 1 5 W W 5100.00 4362-54 4262.54 39 36 N 92 36 W 2247.53 0.15 390-64 N 2238.02 W 2271.85 N 80 5200.00 4439.62 4339.62 39 28 N 82 40 W 2310.91 0.36 398.80 N 2301.20 W 2335.50 N 80 10 W 5300.00 4516.92 4416.92 39 18 N 82 44 W 2374.02 0.10 406.84 N 2364.12 W 2398.87 N 80 14 W 5400.00 4594.39 4494.39 39 6 N 82 48 W 2436.95 0.20 414.81 N 2426.86 W 2462.05 N 80 18 W 5500.00 4672.10 4572.10 38 53 N 82 58 W 2499.57 0.19 422-60 N 2489-30 W 2524-92 N 80 21 W 5600.00 4750.02 4650.02 3844 N 83 5 W 2561-98 0.20 430.21 N 2551-53 W 2537.55 N 80 25 W 5700.00 4828.03 4729.03 38 47 N 83 9 W 2624.27 0.24 437.70 N 2613.64 W "650.04 N 80 29 W 5800.00 4905.94 4305.94 38 53 N 83 17 W 2686.69 0.32 445.11 14 2675.89 W 2712.65 N 80 33 W 5900.00 4983.65 4883.65 39 5 N 83 20 W 2749.38 0.19 452.42 N 2738.41 W 2775-53 N 80 37 W 6000-00 5061.15 4961.15 39 14 N 13 21 W 2312-31 0.16 459.74 y 2801.17 W 2838.64 N 80 40 W 6100.00 5138.66 5038.66 39 6 N 83 33 W 2875.25 0.44 466.97 N 2863.94 W 2901.76 N 80 44 W 6200.00 5216-27 5116.27 39 11 N 83 58 W 2938.11 0.27 473.80 N 2926.64 W 2964.74 N 80 48 W 6300.00 5293.73 5193.73 39 6 N 34 15 W 3001.15 0.44 430.26 N 2989.54 W 3027.86 N 90 52 W 6400-00 5371.57 5271.57 IS 42 N 94 19 W 3063-77 0.26 486.52 N 3052.00 W 3090.54 N 80 56 W 6500.00 5449-66 5349.66 38 37 N 94 34 W 3126.08 0.35 492.58 N 3114.18 W 3152-90 N St 0 W 6600.00 5527.96 5427.96 38 13 N 84 53 W 3188.15 0.59 498-30 N 3176.12 W 3214.97 N 81 5 W 6700.00 5606.82 5506-82 37 47 N 35 26 W 3249.54 0.43 503.50 N 3237.39 W 3276.31 M 81 9 W 6800.00 5685-96 5585.96 37 29 N 95 5.1 W 3310-58 0.57 508.09 N 3298.34 W 3337.24 N 81 14 W 6900.00 5765.47 9665.47 37 23 N 95 53 W 3371-17 0.38 512.38 N, 3358-84 W 3397.69 N 81 19 W 7000.00 5844.86 5744.86 37 21 N 95 54 W 3431.92 0.39 516-69 N 34-19-49 W 3458-31 N 81 24 W 7100.00 5924.38 5824-38 37 17 N 95 5.9 W 3492.49 0.23 521.04 N 3479.97 W 3518.76 N 81 29 W 7200.00 6003.90 5903.90 37 16 N 85 59 W 3553-08 0.65 525.22 N 3540.47 W 3579.21 N 81 33 W 7300.00 6083.93 5983.93 36 29 N 35 27 W 3612-95 0.21 529-67 N 3600-24 W 3639.00 N al 37 W 7400.00 6164.47 6064.47 35 31 N 94 31 W 3672.13 3.57 534.63 N 3659.31 W 3698.16 N 81 41 W 7500-00 6245.86 6145.36 35 31 N 84 24 W 3730.09 0.00 540.26 N 3717.15 W 3756.20 N 81 43 W 7600.00 6327.24 6227.24 35 31 N 84 24 W 3788.05 0.00 545.92 N 3774.97 W 3814.25 N 81 46 W 7700.00 6408.63 6308.63 35 71 N 14 24 W 3846.00 0.00 551-59 N 3832-80 W 3872-29 N 81 48 W 7708.00 6415.14 6315.14 35 31 N A4 24 W 3850.64 0.00 552.05 N 3837.43 W 3876.93 N 81 48 W COMPUTATION DATE: 13 -DEC -88 ARCO ALASKA, INC. IY-29 KUPARUK NORTH SLOPEtALASKA PAGE 3 DATE OF SURVEY: 06-NOV-88 KELLY 3USHrNG ELEVATION: 100.00 FT ENGINEER: SCHWARTZ IR INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB -SEA COURSE VERTICAL DOGLEG RECTANGULAR COORCINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH 14IN DEG MTN FEET DEIJ/100 FEET FEET FEET DEG MIN 0.00 0.00 -100.00 .0 0 N 0 0 F 0.00 0.00 0.00 N 0.00 E 0.00 N 0 0 E 1000.00 999.75 399.75 3`35 N 33 6 w 18.37 2.69 0.26 N 18.37 W 18.37 N 89 12 W 2000.00 1929-51 1829.51 29 45 N 76 1 W 352.79 5.01 72-17 N 351.01 W 358.35 N 78 22 W 3000.00 2728-71 2628.71 37 30 N 78 34 W 939.70 0.67 197.33 N 934:PZ W 955.42 N 78 4 W 4000.00 3492.70 3392.70 38 42 N 90 40 W 1578.43 1.16 301.04 N 1571.04 W 1599-63 N 79 9 W 5000.00 4285.54 4185.54 39 41 N 32 27 W 2184.07 0.14 382.35 N 2174.75 W 7208.11 N 80 1 W 6000.00 5061.15 4961.15 39 14 N 83 21 W 2312.31 0.16 459.74 N 2801.17 W 2838.64 N 80 40 W 7000.00 5844-86 5744.82 37 21 N 85 54 W 3431-92 0.39 516.69 N 3419-49 W 3458.31 N 81 24 W 7708.00 6415.14 6315:1 35 31 N 84 24 W 3350.64 0.00 552.05 N 3837.43 W 3876-93 N 81 48 W IR rl v C9MPUTATION DATE: 13 -DEC -98 PAGE 4 ARCO ALASKA 9 INC. DATj OF SURVEY: 06-NOV-88 1y-29 KELLY BUSHING ELEVATION: 100.00 FT KUPARUK NORTH SLOPE#ALASKA ENGINEER: SCHWARTZ INTERPOLATED VALUFS POR EVEN 100 FEET OF SUB -SEA OEOTI TRUE SUB -SEA C 0 U R S F VERTICAL DOGLEG RACTANGULAR COn-701NATFS HORIZ. DE 0 A RTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH.EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH BEG MIN DFG MTN FEET 3ES/100 FEET FEET FEET DEG MIN 0.00 0.00 -100.00 0 0 N 0 1 F 0.00 0.00 0.00 IN 0.00 E 0.00 N 0 0 E 100.00 100.00 0.00 0 17 S 94 50 W 0.24 0.28 0.05 s 0.24 'A 0.24 S 78 46 W 200.00 200.00 100.00 0 22 S 79 14 W 0.83 0.19 0.21 S 0.84 W 0.87 S 76 7 W 300.00 300-00 200.00 0 24 N 85 5-1) w 1.52 0.17 0.23 S 1.52 W 1.54 S 81 25 W 400.01 400.00 300.00 0 35 N 84 53 W 2.35 0.42 0.13 S 2.36 W 2.36 S 86 53 W 500-02 500.00 400.00 1 1 S 88 27 W 3.76 0.34 0.17 s 3.77 14 3.77 S 87 23 W 600.04 600-00 500.00 1 11 N 97 14 W 5.69 0.52 0.10 s 5.69 W 5.69 S 89 0 W 700.06 700.00 600 0 1 23 S 98 28 W 7.99 0-13 0.10 S e.00 w 8.00 S 89 17 W 800.10 800.00 700.00 1 41 N 88 34 W 10.66 0.4? 0.11 s 10-66 W 10.66 S 89 23 W 900.15 900.00 800.00 2 1 N 88 34 W 13-84 0.76 0.03 S 13.84 W 13.84 S 89 52 W 1000.25 1000-00 900.00 3 35 N 83 4 W 19.39 2.69 0.26 IN 18.39 W 18.39 N 89 11 W 1100.72 1100-00 1000-00 7 10 N 74 5 W 27.152 3.21 2.3`3 N 27-57 W 27-67 N 85 2 W 1202.03 1200.00 1100.00 11 39 N 74 49 W 43.15 5.95 6.97 N 42.98 W 43.54 N 80 47 W 1305.20 1300.00 1200.00 15 38 N 77 27 W 67-37 1.99 12.75 14 67.56 W 68.75 N 79 18 W 1409.78 1400.00 1300.00 19 31 N 77 29 W 97.37 2.97 19.37 N 97.40 W 39.30 N 78 45 W 1516.90 1500.00 1400.00 23 28 N 79 8 W 135.49 3-66 27-22 N 1 X4.82 W 137-54 N 78 35 W 1627.30 1600.00 1500.00 26 40 N 79 31 W 181-63 3.69 35.71 N 130.75 W 184.25 N 73 49 W 1740.22 1700.00 1600.00 27 45 N 78 36 W 233-42 0.61 45.46 N 232.30 W 236.71 N 73 55 W 1853.27 1800-00 1700.00 27 49 N 77 36 W 285.27 0.50 56-34 N 293.88 W 289.42 N 78 46 W 1966.32 1900-00 1900.00 28 24 N 76 14 W 336.93 2.83 68.22 N 335.24 W 342.12 N 78 29 W 2082.43 2000.00 1900.00 31 42 N 76 23 W 394-56 0.74 82.21 N 392.53 W 401.05 N 78 10 W 2200.16 2100.00 2000.00 31 46 N 75 46 W 455-23 0.43 97.15 N 452.82 W 463.13 N 77 53 W 2317.84 2200-00 2100.00 32 50 N 75 19 W 515.66 3.90 112.77 N 512.87 W 525.12 N 77 35 W 2442.74 2300.00 2200.00 40 1 N 78 5 W 588.65 1.87 129.96 N 585.43 W 599-68 N 77 29 W 2574.81 2400.00 2300.00 40 57 N 79 28 W 673.74 0.55 146.37 N 670.11 W 685.91 N 77 40 W 2706.37 2500.00 2400.00 40 11 N 79 14 W 758.14 0.45 162.23 N 754.12 W 771.38 N 77 51 W 2836.46 2600.00 2500.00 38 57 N 79 5 W 840.24 1.74 177-82 N 835.84 W 854-55 N 77 59 W 2963.74 2700.00 2600.00 37 45 N 79 41 W 917.138 0.78 192.93 N 913.11 W 933.21 N 79 4 W 3089-63 2800.00 2700-00 37 17 N78 23 W 993-18 0.49 208.24 N 988.04 W 1009.74 N 73 5 W 3217.66 2900.00 2100.00 40 47 m 81 24 W 1072.08 3.16 222.73 N 1066.59 W 1089.59 N 78 12 W 3351.09 3000.00 2900.00 41 26 N 91 52 W 1159-87 0.44 234.96 N 1154.03 W 1177-75 N 79 29 W 3484.31 3100.00 3000.00 41 21 N 81 29 W 1247.25 0.20 247.78 N 1241.15 W 1265.64 N 73 42 W 3617.40 3200.00 3100.00 41 4 N 30 55 W 1334.38 0.52 261.07 N 1327.96 W 1353.33 N 78 52 W 3749.56 3300.00 3200.00 40 32 N 80 34 W 1420.01 0.50 275.01 N 1413.•'_5 W 1439.76 N 79 59 W 3880.28 3400.00 3300.00 39 38 N 90 40 W 1503.37 0.60 238.76 N 1496-28 W 1523.89 N 74 4 W 4009-32 3500.00 3400.00 38 36 N 80 40 W 1584-18 1.17 301.98 N 1576.77 W 1605.42 N 79 9 W 4135.84 3600-00 3500.00 37 6 N 81 20, W 1561.00 0.87 314.22 N 1653.29 W 1682.89 N 79 14 W 4261.24 3700.00 3600.00 37 8 N 81 58 W 1736.15 0.19 325-01 N 1728-18 W 1758.48 N 79 20 W 4386.63 3800.00 3700.00 37 9 M 92 26 W 1811-33 0.33 335.27 N 1803.13 W 1834.03 N 79 28 W 4512-19 3900-00 3800.00 37 9 N 82 37 W 1386.86 0.23 345.09 N 1878.42 W 1909.85 N 79 35 W v COIMPUTATIIN DATE: 1.3-9EC-88 PAGE 5 ARCO ALASKA, INC. DATE OF SURVEY: 06-NOV-A3 1Y-29 KELLY BUSHING ELEVATION: 100.00 FT KUPARUK NORTH SLOPE,ALASKA FNGINEE2: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 !FEET OF SU8-SEA DEPTH TRUE SUB -SEA COURSE VERTICAL 00GLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH FAST/'WEST DIST. AZIMUTH DEPTH DEPTH DEPTH 09(; AIN DEG MIN FEET DEG/100 FEET FEET FEET DEG MIN 4637.33 4000.00 3900.00 k w �44 N 83 1 W 1961.72 0.35 354.57 4 1953.05 W 1984.98 N 79 42 W 4762.08 4100.00 4000.00 1 N 83 20 W 2035.99 0.63 363.31 N 2027.12 "W 2059.42 N 79 50 W 4888.91 4200.00 4100.00 319'17 N 82 22 W 2113.50 1.44 372.92 N 2104.51 W 42137.29 N 79 57 W 5018.79 4300.00 4200.04 39 39 N 82 29 W 2196.01 0.18 383.92 Al 2186.65 W 2220.10 N 80 2 W 5143.61 4400.00 4300.00 39 34 N 82 38 W 227€?.36 0.05 394.61 N 2268.75 +W 2302.81 N 80 7 W 5278.13 4500.00 4400.00,`39 19 N 82 43 W 2360.24 0.2+0 405.09 N 2350.38 W ?385.04 N 80 13 W 5407.23 4600.00 4500.00 39 5 N 82 48 W 2441.48 0.20 415.38 N 2431.38 W 2466.60 N 80 13 W 5.535.83 4700.00 4600.DQ 38 50 N 93 1 W 2521.95 0.13 425.34 N 2511.62 xW 2547.38 N 80 23 W 5664.05 4800,00 4700.00 38 44 N 83 7 W 2601.35 0.30 435.01 N 2591.29 W 2627.54 N 80 28 W 5792.38 4900.00 4800.00 38 52 N 83 16 W 2681.93 0.23 444.55 N 2671.14 W 2707.88 N 80 33 W 5921.07 5000.00 4900.00 39 7 N 83 21 'W 2762.61 0.25 453.95 N 2751.60 W 2788-79 N 80 37 W 6050.14 5100.00 5000.00 39 11 N 93 24 W 2843.98 0.15 463.39 N 2832.65 W 2870.34 N 80 42 W 6179.02 5200.00 5100.00 39 9 N 83 54 W 2924.91 0.27 472.40 N 2913.47 W 2951.52 N 80 47 W 6308.08 5300.00 520+0.00 39 4 N 84 15 W 300.5.24 0.49 480.77 N 2994.61 W 3032.96 N 80 52 W 6436.40 5400.00 5300.00 38 - 39 N g4 23 W 3386.44 0.13 488.75 N 3074.63 W 3113,24 N 80 58 W 6564.36 5500.00 5400.00 38 23 N 84 46 W 3166.09 0.47 496.31 N 3154.10 W 3192.91 N 81 3 W 6691.37 5600.00 5500.00 37 48 N 85 22 W 3244.26 0.40 503.07 N 3232.142 W 3271.04 N 81 9 W 6817.66 5700.00 5600.00 '37 2 5 N 85 53 W 3321.30 0.43 50$.86 N 3309.04 W 3347.93 N 81 15 W 6943.51 5800.00 5700.00 37 28 N 35 55 W 3397.52 0.25 514.2.5 14 3385.24 W 3424.08 N 81 21 W 7069.34 5900.00 5800.00 37 19 N 95 52 W 3473.93 0.24 519.72 N 3461.44 W 3500.24 N 81 27 W 7195.10 6000.04 5900.00 37 13 N ?6 0 w 3550.11 0.51 525.01 N 3537.50 W 3576.25 N 81 33 W 7319.98 6100.00 6000.00 36 28 N 3r� 23 W 3624.81 0.10 530.62 N 3612.08 W 3650.85 N 81 38 W 7708.00 6415.14 6315.14 35 31 N 34 24 W 3850.64 0.00 552.05 N 3837.43 W 3876.93 N 81 48 W R v--1 COMPUTATION DATE: 13 -DEC -38 PAGE 6 ARCO ALASKA, INC. DATE OF SURVEY: 06-NOV-89 1Y-29 KELLY SUSHING ELEVATION: 100.00 FT KUPARUK NORTH SLOPEPALASKA ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR CHOSEN HOR17"ONS SURFACE LOCATION AT 0 RIGIN= 208 FNL9 1104 FWLt SEC. It TllN9R9EjUM MARKER MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KS FROM K8 SUS -SEA NCRTH/SCUTH EAST/WEST TOP KUPARUK C 7083.00 5910.86 5810.86 520.31 N 3469.69 W BASE KUPARUK C 7153.00 5966.55 5856.55 523.26 N 3511.99 W TOP KUPARUK A 7265.00 6055.79 5955.79 529.05 N 3579.50 W BASE KUPARUK A 7407.00 6170.12 6070.12 535.00 N 3663.42 W LAST GCT READIN!,7 7417.45 6179.67 6078.67 535.58 N 3669.41 W PBTD 7468-00 6-119.131 6119-81 539.44 N 3698.64 W TD 7708-00 6415.14 6315.14 552.05 N 3837.43 W R ARCD ALASKA, INC. 1Y-29 KUPARUK NORTH SLDPE,ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST GCT READING PBTD TD COMPUTATION DATE: 13 -DEC -88 PAGE 7 DATE OF SURVEY: 06-NOV-88 KELLY 3USHING ELFVATIGN: 100.00 FT ENGINEER: SCHWARTZ #-.1-1 STRATIGRAPHIC SUMMARY MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 7708.00 6415.14 6315.14 SURFACE LOCATION AT ORIGIN= 203 FNL, 1104 FWL, SEC. 19 T12N9 R9E,UM MEASURED DEPTH TVD R-CTANGUL:AR COORDINATES BELOW KE FROM KB SUB -SEA NORTI/SOUTH EAST/WEST 7083.00 5910.36 5810.85 520.31 N 3469.69 W 7153.00 5966.55 5866.55 523.26 N 3511.99 W 7265.00 6055.79 5955.79 528.05 N 3579.50 W 7407.00 6170.12 6070.12 535.00 N 3663.42 W 7417.45 6178.67 6078.67 535.58 N 3669.41 W 7468..00 6219.31 6119.81 533.44 N 3698.64 W 7708.00 6415.14 6315.14 552.05 N 3337.43 W FINAL WELL LOCATION AT TD: TRUE SUB -SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 7708.00 6415.14 6315.14 OR HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 3876.93 N 81 48 W r SCHLUMBERGER DIRECTIONAL SURVEY COMPANY ARCO ALASKA, INC. WELL 1Y-29 FIELD KUPARUK COUNTRY USA RUN 1 DATE LOGGED 06 - NOV - 88 REFERENCE 73056 r f WELL: 1Y-29 #(208' FNL, 1104' FWL, SEC 1, T11N, R9E, UM) WPTM 40nn REF 73OSS ••• •1• • •1.1• 0 -1000 �•• -3000 SOUTH -4000 -6000 NEST SCALE = 1/1000 IN/FT HORIZONTAL PROJECTION -4000 -3000 -2000 -1000 0 1000 2000 3000 EAST Y WELL: lY-29 ~(208' FNL, 1104' FWL, SEC l, TllN, RB[, UM) '-- — ' s�. LAI. w VERTICAL PROJECTION �uuu _1000 00m slow 272. m � En N. PROJECTION ON VERTICAL PLANE 272. - 92. SCALED IN VERTICAL DEPTHS HORIZ SCALE = 1/1000 IN/FT R � o � � litt 00m slow 272. m � En N. PROJECTION ON VERTICAL PLANE 272. - 92. SCALED IN VERTICAL DEPTHS HORIZ SCALE = 1/1000 IN/FT R � o � � WELL LOG INVENTORY WELL NAME K[ A I Y- J cl PAGE 1 of LOG LOG COUNT DATE REC RUN# CDM (mudlog) DIL/SFL IVU 7 (dual induction log) —�— CNFD�Na 7 (compensated neutron density)5 (compensated neutron formation/ Litho -density) CFD ( compensated formation density) - BHC/SL (borehole compensated sonic) LSS : (long spaced sonic) SSS - (short spaced sonic) CYB (cyberlook) GCT 0� _ (groscopic survey) DIPMETER SAMPLES: Re yes yes no Date Received: f Comments: r STATE OF ALASKA9_,,, AI—k—A'A OIL AND GAS CONSERVATION COMMIS... �,)N �. REPORT OF SUNDRY WELL OPERATIONS' 1. Operations performed: Operation shutdown Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Pull tubing _ Other Complete 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska Inc. Development ,. Exploratory Stratigraphic _ _ RKB 1 feet 3. Address 7. Unit or Property name P.O. Box 100360, Anchorage, AK 99510-0360 Service Kuparuk River Unit 4. Location of well at surface 8. Well number 208' FNL, 1104' FWL, Sec. 1, T11N, R9E, UM 1Y-29 9. Permit number/approval number At top of productive interval 312' FSL, 2366' FEL, Sec. 35, T12N, R9E, UM 88-91/8-791K - 10. API number At effective depth 330' FSL, 2595' FEL, Sec. 35, T12N, R9E, UM 50— 029-21852 11. Field/Pool At total depth 344' FSL, 2547' FWL, Sec. 35, T12N, R9E, UM Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured 77081MD feet Plugs(measured) None true vertical 64151TVD feet Effective depth: measured 7468' MD feet Junk (measured) None true vertical feet 6220'TVD Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 16" 181 sx AS 11 115' MD 115' TVD Surface 4069' 9-5/8" 900 sx AS III & 41041MD 35741TVD Intermediate 350 sx Class G Production 7516' 7" 250 sx Class G 75491MD 62861TVD Liner Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) f, 411/3-1/2112 J-552 tbg w/tail @ 6937' Packers and SSSV (type and measured depth) .�� `' , "` r ., BOT 'HB' Pkr @ 6863' & AVA SSSV @ 1823' Al 13. Stimulation or cement squeeze summary ` Olige cot���f, N/A �nchQrago Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data N/A Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run � Gyro Daily Report of Well Operations X Oil _X- Gas _ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. �a - y>. , -- Signed Title Area Drilling Engineer Date IoZ g Form 10-404 Rev 06/15/88 SW03/079 0* Completion Well History SUBMIT IN DUPLICATE 6?1 ARCO Oil and Gas Company „ Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District County, parish or borough State ARCO ALASKA INC. NORTH SLOPE AK Field Lease or Unit Wetl no. KUPARUK ADL: 25646 1Y-29 Auth. or W.O. no. Title AK3331 COMPLETE APT 50—O29-21 A52 Operator ARCO W.I. ARCO 56.0000 Spudded or W.O. begun Date Hour Prior status if a W.O. ACCEPT 11/23/88 2330 HRS Date and depth Complete record for each day reported as of 8:00 a.m. NORDIC 1 11/24/88 ( 1 ) LOAD PIPE SHED 711@ 7549' MW:11.2 NACL TD: 7549 MIRU, ACCEPT RIG AT 2330 ON 11/23/88, ND TREE, NU BOPE, TEST PB: 7468 TO 3000 PSI, LOAD PIPE SHED SUPV:TA DAILY:$17,008 CUM:$935,170 ETD:$935,170 EFC:$1,471,000 11/25/88 ( 1 ) DISPLACE W/ DIESEL 711@ 7549' MW: 0.0 DIESEL TD: 7549 RIH W/ COMPLETION, LAND TBG HGR, TEST TO 5000 PSI, SET PKR, PB: 7468 TEST TBG TO 2500, TEST SSSV, SHEAR PBR, RELAND, SHEAR SOS, SUPV:TA TEST ANNULUS TO 2500 PSI F/30MIN, SET BPV, ND ROPE, NU TREE, TEST TO 5000 PSI, DISPLACE W/ DIESEL (AVA SSSV @ 1823', BOT 'HB' PKR @ 6863', TT @ 6937'.) DAILY:$228,516 CUM:$1,163,686 ETD:$1,163,686 EFC:$1,471,000 Jilin _walaska Gas C®ns..00MrjjS 1— Anchors e Signat/ Dae 1� c jtZ /�� /K X TitleA�A L 7 For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Number all dally well history forms consecutively Page no. as they are prepared for each well. AR3B-459-1-D ARCO Oil and Gas Company Ji I Daily Well History— Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District county or Parish state ARCO ALASKA INC. NORTH SLOPE AK Field KUPARUK tease or A&: 25646 1Y-29 well no. Auth. or W.O. A3331 Title COMPLETE API: 50-029-21852 Operator Date A.R.Co.�.0000 Producing Interval Total number of wells (active or inactive) on this ARCO Production Oil on test Gas per day cost center prior to plugging and abandonment of this well Spudded or wkc8ly rl CC 11 Date 11/23/88 Hour 2330 HRS T77a W.O. Date and depth as of 8:00 a.m. GOR Complete record for each day reported NORDIC 1 Allowable 11/26/88 ( 1 ) RIG RELEASED 7"@ 7549' MW: 0.0 DIESEL TD: 7549 DISPLACE W/ DIESEL, SICP & TP ZERO, TEST ORIFICE, RIG PB: 7468 RELEASED 0730 11/25/88 SUPV:TA DAILY:$1,725 CUM:$1,165,411 ETD:$1,165,411 EFC:$1,471,000 til.& Gas cons. comnllo, r�Fy iAnCil��'�QP Old TD New TD PB Depth Released rig Date Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) 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 corrected Allowable Effective date i ne aoove is correuT Signatyyg I Date ITitle For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Number all daily well history forms consecutively Page no. as they are prepared for each well. AR3B-459-3-C Division of AllanticRlchfieldCompany STATE OF ALASKA AL, oKA OIL AND GAS CONSERVATION COMMI��iON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation shutdown _ Re-enter suspended well — Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance — Perforate _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development feet ARCO Alaska- Inc- Exploratory _ Stratigraphic _ � 3. Address 7. Unit or Property name P. 0. Box 100360 Anchorage, AK 99510 0360 Service_ Ku aruk River Unit 4. Location of well at surface 8. Well number 1Y-29 208' FNL, 1104' FWL, Sec.1, T11N, R9E, UM At top of productive interval 9. Permit number 120' FNL, 2230' FEL, Sec.2, T11N, R9E, UM (Approx) -Pli 10. API number At effective depth 237' FSL, 2617' FEL, Sec.35, T12N, R9E, UM (Approx) 50 029-21852 11. Field/Pool At total depth 226' FSL, 2513' FEL, Sec.35, T12N, R9E, UM (Approx) Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured 7 7 0 8' M D feet Plugs (measured) None true vertical 60 7 4 'TVD feet Effective depth: measured 7 4 6 8 M D feet Junk (measured) None true vertical 6217 ' TVD feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 16" 181 sx AS I 1 115'MD 1151TVD Surface 4069' 9-5/8" 900 sx AS I I I & 4104 MD 3577' TVD I ntermediate 350 s x Class G Production 7516' 7" 250 sx Class G 7549'MD 62821TVD Liner Perforation depth: measured RECEP%11 None true vertical None DEC 19 19$3 Alaska Uii & Cas Com-,... Commission Tubing (size, grade, and measured depth) . None Anchorage Packers and SSSV (type and measured depth) None 13. Attachments Description summary of proposal _ Detailed operations program _ BOP sketch _. Well History 14. Estimated date for commencing operation 15. Status of well classification as: January, 1989 Oil \V Gas _ Suspended _ 16. If proposal was verbally approved Name of approver Date approved ` Service 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title 1,211 y ge p.Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness (Dani) S A 4 / 0 2 3 Approval No. d ' Plug integrity _ BOP Test — Location clearance T 1� Mechanical Integrity Test _ Subsequent form required 10- iA 4diAL SIGNED Approved by order of the Commissioner BY LONNIE C. SMITH Commissioner Date 1o2.- 1-o Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE &t • ARCO Oil and Gas Company „ Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. ARCO Alaska, Inc. NORTH SLOPE 11 ir County, parish or borough State District KUPARUK ADL: 25646 Field Lease or Unit Well no. nx3311 DRILL Auth. or W.O. no. ARCO Operator SPUD Spudded or W.O. begun Date and depth as of 8:00 a.T0/18/88 SUPV:DL itle DOYON 14 API: 50-029-218 1 Prior status if a W.O. Complete record for each day reported L) FUNCTION TEST DIVERTER MW: 8.6 VTR- 97 L15) MOVE RIG FROM 1Y-30 TO 1Y-29. ACCEPT RIG @ 0000 HRS, 10-18-88, NU DIVERTER ASSY. PU BHA, CUT DRILL LINE, FINISH MU BHA. FUNCTION TEST DIVERTER, PREPARE TO SPUD. DAILY:$22,050 CUM:$22,050 ETD:$22,050 EFC:$1,471,000 10/19/88 ( ) TD: 29901( 275) SUPV:DL!` 10/20/88 TD: 4120'( 1 SUPV:EEV 10/21/88 TD: 4976' SUPV:EEV D %-4 �q � as conn. R�aska p�'1 A,�►��iorage DRILLING MW: 9.3 VIS: 58 SPUD WELL @ 0600 HRS, 10-18-88. DRILL AND SURVEY 115'-17911. TAKE SS SURVEY. DRILL AND SURVEY 1791'-29900. DAILY:$45,238 CUM:$67,288 ETD:$67,288 EFC:$1,471,000 ) 9-5/8"@ 4104' MW: 9.8 VIS: 78 .30) DRILL AND SURVEY 2990'-4120'. CIRC BOTTOMS UP AND MAKE SHORT TRIP TO 800'. HOLE TIGHT 1150'-9501. CIRC AND COND WELL, DROP SURVEY AND TOH. LD BHA. RU CASING TOOLS. WORK ON PIPE SKATE. RUN 68 JOINTS 9-5/8, 360, J-55, CASING. SET DOWN AT 2690'. PU CIRCULATING HEAD AND WASH THROUGH BRIDGE. CONTINUE RUNNING CASING. DAILY:$124,181 CUM:$191,469 ETD:$191,469 EFC:$1,471,000 DRILLING 9-5/8"@ 4104' " MW: 8.8 VIS: 30 56) FINISH RUNNING SURFACE CASING 106 JTS 9-5/8", 36#, J-55, BUTT. SHOE @ 4104', COLLAR @ 4022'. RU DOWELL AND CIRC AND CONDITION WELL AND CEMENT W/ 80 BBL WATER, 900 SX AS III AND 350 SX CLASS G. DISPLACED W/ 311 BBLS WATER. HAD FULL RETURNS ENTIRE JOB AND 11.4 CEMENT TO SURFACE LAST 10 BBLS OF DISP. BUMPED PLUG TO 2000 PSI, OK. FLOATS HELD OK. CIP 1100 HRS 10/20/88. ND DIVERTER NU STARTING HEAD AND BOP. TEST BOP TO 3000 PSI, OK. PU BHA AND TRIP IN HOLE. TAG FC AND DRILL CEMENT TO 4084'. TEST CASING TO 2000 PSI, OK. ONTINUE DRILL OUT TO 41301. DISPLACE WATER WITH POLYMER "IMISs)07D AND TEST SHOE TO 12.5 EMW, NO LEAKOFF. DRILL AND SURVEY 41301-49761. DAILY:$100,854 CUM:$292,323 ETD:$292,323 EFC:$1,471,000 10/22/88 ( 5 TD: 71201( 21 4) SUPV:EEV 10/23/88 ( 6 TD: 7448'( 3 8) SUPV:EEV The above is correct For form preparation and distribution, see Procedures Manual, Section 10, DRILLING 9-5/8"@ 4104' MW:10.8 VIS: 50 DRILL AND SURVEY 49761-71201. DAILY:$76,305 CUM:$368,628 ETD:$368,628 EFC:$1,471,000 DRILLING 9-5/84 4104' MW:11.2 VIS: 62 DRILL 7120'-7141'. CIRC AND COND MUD. PULLED 35 STANDS, HOLE STOPPED TAKING CORRECT FLUID. TIH, CIRC BOTTOMS UP, GAS CUT. RAISED MUD WEIGHT TO 11.1. TOH AND LD TURBINE, MWD, PDC BIT. TIH TO SHOE AND CUT DRILL LINE. FINISH TIH. REAM 60' TO BOTTOM. DRILL 71411-74481. DAILY:$56,189 CUM:$424,817 ETD:$424,817 EFC:$1,471,000 i ARCO Oil and Gas Company Daily Well History—Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District County or Parish state ARCO Alaska, Inc. NORTH SLOPE AK Field Lease or Unit Well no. KUPARUK 1Y-29 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. DOYON 14 10/24/88 TD: 7658'( SUPV:EEV 10/25/88 TD: 7708'( SUPV:EEV 10/26/88 TD: 7708' SUPV:EEV 7) LOGGING 9-5/811@ 4104' MW:11.2 VIS: 55 210) DRILL AND SURVEY 74481-7658'. MAKE SHORT TRIP TO SHOE. CIRC AND COND WELL. MUD APPEARS CO2 CONTAMINATED. MAKE 10 STAND SHORT TRIP AND CIRC BOTTOMS UP. NO PROBLEMS. DROP SURVEY AND TOH FOR LOGS. STAND BACK BHA. NO PICTURE ON SURVEY. RU SCHLUMBERGER. RUN 1 DIL/SFL/GR/FDC/CNL/CAL TD TO TOP OF KUPARUK. DAILY:$65,541 CUM:$490,358 ETD:$490,358 EFC:$1,471,000 8) LOGGING RUN 4 9-5/811@ 4104' MW:11.2 VIS: 57 50) LOG RUN 2 ML/GR TD TO TOP OF KUPARUK, POH, RD SOS. MU BHA AND TIH TO SHOE, CIRC BOTTOMS UP AND FINISH IN HOLE. REAM 30' TO BOTTOM. DRILL 76581-77081. SPOT PILL AND TOH. RU SOS LOG RUN 3 FMS/GR TD TO TOP OF KUPARUK AND RIH W/ RUN 4 RFT/GR. DAILY:$43,094 CUM:$533,452 ETD:$533,452 EFC:$1,471,000 9) RUNNING 7" CASING 711@ 7549' MW:11.2 VIS: 62 0) FINISH LOG RUN 4, RFT/GR. MADE 18 TOOL SETS. D SOS. TIH, CIRC AND CONDITION WELL, SPOT PILL. POH LDDP. RU CASING EQUIPMENT. RUN 7" CASING. DAILY:$298,607 CUM:$832,059 ETD:$832,059 EFC:$1,471,000 RCI�L DEC 19 1988 Ajoka Uii & Gas gone. Commission Anchorage The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 ARCO Oil and Gas Company Ai Daily Well History—Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test Is not required upon completion, report completion and representative test data in blocks provided. The "Final Report' form may be used for reporting the entire operation if space is available. Accounting cost center code District County oc�' sh_ SLOPE Stat ARCO Alaska, Inc. N TTHH Field Lease or25646 1Y-29 well no. KUPARUK Auth. or W.O. A3331 Title DRILL API: 50-029-21852 Operator A.R.Co. 19-6. 0000 otal number of wells (active or inactive) on this Producing Interval ARCO Test time cost center prior to plugging and Oil on test Gas per day abandonment of this well Spudded or WSQPheaun tau Date 10/18/88 Hour 0600 HRS 7�us If a W.O. Date and depth Complete recprd_far jach4day reported as of 8:00 a.m. LJ(Jl�IV 1 10/27/88 ( 1 ) RIG RELEASED 711@ 7549' MW:11.2 NACL TD: 7708 FINISH RUNNING 192 JTS 7" 26# J-55 BUTT CASING. SHOE @ PB: 7968 7549', COLLAR @ 7468'. CIRC 2 CASING VOLUMES. CEMENT AS SUPV:BRB FOLLOWS: TEST LINES 4000 PSI, PUMP 10 BBLS CW100, 20 BBLS 12.2 PPG SPACER 3000, 250 SX CLASS G W/ ADDITIVES. DISPLACED W/ 11.2 BRINE. BUMP PLUG W/ 3500 PSI, OK. FLOATS HELD OK. CIP 0930 10-26-88 RAISE STACK AND SET SLIPS, BLOW BRINE FROM CASING AND CUT OFF 7". INSTALL PACKOFF AND NU TREE. ATTEMPT TEST, LEAKING PACKOFF. ND TREE AND CHANGE PACKOFF. TEST TO 3000 PSI, OK. INJECT 75 BBLS DIESEL IN ANNULUS AND RELEASE RIG @ 1730 HRS 10-26-88. DAILY:$86,103 CUM:$918,162 ETD:$918,162 EFC:$1,471,000 R I Of DEC 19 1988 Alaska Oil & Cas Cora. Commission Anchorage Old TD New TD PB Depth Released rig Date Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) 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 corrected Allowable Effective date e above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Alaska, Inc. Date: November 28, 1988 Transmittal #: 7358 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. 1Y-30 Cement Evaluation Log 1 1-06-88 8103-9468 1 Y-32 Cement Evaluation Log 11-07-88 6710-6716 1 Y-29 Cement Evaluation Log 11-06-88 6380-7460 Receipt Acknowledged: NSK Drilling 3 ----------- - Jr`J0,-ate:------------ State of Alaska(+sepia) ARCO Alaska, Inc. Date: November 28, 1988 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO -1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal M 7354 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1 Y-25 LIS Open Hole Tape 1 1-1 1-88 #72953 1Y-29 LIS Open Hole Tape 1 1-1 1-88 #72983 1Y-30 LIS Open Hole Tape 1 1-1 1-88 #72973 1 Y-32 LIS Open Hole Tape 1 1 -1 1-88 #72953 Receipt Acknowledged: State of Alaska R- dRCoka Oil & Gas Coas.. ------------------------`--� A�Ga� : ------------ a e: ARCO Alaska, Inc. Date: November 4, 1988 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO -1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #: 7341 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1Y-29 Formation Microscanner 10-25-88 6800-7705 1Y-29 Repeat Formation Tester 10-25-88 7088-7640 1Y-29 2" & 5" Raw FDC 10-24-88 4400-7622 1Y-29 2" Dual Induction 10-24-88 1000-7648 1Y-29 5" Dual Induction 10-24-88 1000-7648 1Y-29 Cyberlook 10-24-88 7000-7600 1Y-29 2" & 5" Porosity FDC 10-24-88 4400-7622 1Y-29 5" & 10" Microlog - GR 10-24-88 6800-7652 Receipt Acknowledged: 9 01 NSK Drilling VJD 'T ii } t ------------------ alOt11'--------- F ++CE - 7 � �k'�91�4 State of Alaska(+sepia) Franzen D&M L. Johnston(vendor package) -BVI EMORAN DV M State of Alaska A ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Lonnie C SmithDATE: November 4, 1988 Commissioner FILE NO: D.A,DA.136 TELEPHONE NO: THRU: Michael T Minder SUBJECT: BOP Test Sr Petroleum Engineer AAI KRU 1Y-29 Permit No. 88-91 Kuparuk Rv Field FROM: Doug Amg;:��� Petroleum Inspector Thursday, October 20, 1985: I traveled this date from AAT PBU to .AAI KRU Y - a to witness the BOP test at Doyon Rig No: 14. The testing commenced at 5:30 p.m. and was concluded at 7:00 p.m. There was one failure which was repaired and retested on 10/21/88. I filled out an AOCCC BOP inspection report which is attached. In summary, I witnessed the BOP test at AAI KRU 1Y-29 well on Ryon Rig No 14. Attachment 02-001A (Rev. 8/85) Ow 1M+ 5'84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report 4 V ti.o 2� Nla�rk u_gem W45 QJa-\N Distribution orig. – AO&GCC cc – Operator cc – Supervisor Inspector Date I_ ZO, lot slb Inspector O Well r Z Operator _A&I16& Representative Well -' Permit` t - Location: Sec�yTRM L4. M Casing Set @-- ft. Drilling Contractor bw Kk -*4 Ri # l 4. Representative ivy` �G �� Location, General Well Sign t ACCUMULATOR SYSTEM General Housekeeping kf: Rig r Full Charge Pressure C> + psig Reserve Pit Pressure After Closure 14- pn psig riud Svstems Visual Audio Pump incr. clos. pres. 200 psig___,___ min gra sec. Trip Tank V/' Full Charge .Pressure Attained: min '? sec. Gauge 1 N,, Z_ -Z 6� -Z.00 psig • �" -75, law Monitor ++ I 1% 46 -- -- Controls: Master Gas Detectors �,/� Remote i-/ Blinds switch cover %S Kelly and Floor Safety Valves BODE Stack Test Pressure Upper Kelly --L -lytest Pressure , -3 000 Annular Preventer Doo Lower Kelly_.�6,)�Test Pressure Pipe Rams �!v L L'� Z Ball Types! Nest Pressure Blind Rams t tj Inside BOP _��est Pressure Choke Line Valves Z h Choke Manifolds _'Test Pressure H.C.R. Valve %.Y '► No. Valves Kill Line Valves Z No. flanges Check ValveAdjustable Chokes --- — • - 11Hydrauicallyoperated choke Test Results: Failures *est Time �� � I Y ' Repair or Replacement of failed equipment to be made within days and Inspector/ Commission office notified, d l l V ti.o 2� Nla�rk u_gem W45 QJa-\N Distribution orig. – AO&GCC cc – Operator cc – Supervisor Inspector M EMORA,1 Du M State of Alaska 'ALASKA OIL AND -GAS CONSERVATION COMISSION TO: Lonnie C Smithilf-114 DATE: October 21, 1988 Conmis-sioner FILE NO: D.BDF.133 THRU: Michael T Minder 10"01 Sr Petroleum Engineer FROM: Bobby D Fos ter fl-', I Petroleum Inspe t6r TELEPHONE NO: SUBJECT Diverter Test AAI KRU IY-29 Permit #88-91 Kuparuk Rv Field Tuesday, October 18, 1988: 1 inspected the diverter system on AAI's IY-29 this date, anou d it to be in compliance with AOGCC regulations. I did request the ARCO rep to tie the lines down which he did. In summary, I inspected the diverter system on 1Y-29. 02-001A (Rev. 8/85) STATE OF ALASKA ALr•,oKA OIL AND GAS CONSERVATION COMMI,,,,iON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon — Suspend _ Operation shutdown _ Re-enter suspended well Alter casing _ Repair well Plugging _ Time extension _ Stimulate _ Change approved program Pull tubing _ Variance _ Perforate _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development �i feet Exploratory _ Stratigraphic — RKB 102 3. Address 7. Unit or Property name P. 0. Box 100360 Anchorage, AK 99510 0360 Service_ Ku aruk River Unit 4. Location of well at surface 8. Well number 1Y-29 208' FNL� 1104' FWL, Sec.1, T11N, R9E, UM 9. Permit number At top of productive interval 200' FSL, 2350' FEL, Sec.35, T12N, R9E, UMRR-91 10. API number At effective depth 50— 029-21852 11. Field/Pool At total depth 241' FSL, 2581' FWL, Sec.35, T12N, R9E, UM Kuparuk River Oil Pool 12. Present well condition summary Wel l haso f s p u d d e as of 10-14-88. meet Total depth: measured Plugsgmeasured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor R Surface .:. .S' Intermediate Production a OSS, GOl:SStC1"t Liner V Perforation depth: measured This sundry request is for a change in bottomhol e location for the subject well. This new BHL is true vertical 502' northwest of that previously permitted. The change was approved by Mike Minder to Mike Winfree Tubing (size, grade, and measured depth) on 10/14/88. Packers and SSSV (type and measured depth) / y� 13. Attachments Description summary of proposal _ Detailed operations program _ BOP sketch _ &VIS ..b �/ ,6G771�OZ_ GoTs 14. Estimated date for commencing operation 15. Status of well classification as: October 17 1988 Oil Gas Suspended 16. If proposal was verbally approved — _ Mike Minder to M. B. Winfree 10/14/88 Name of approver Date approved ' Service 17. 1 h eb4certify hat th foregoing is true and correct to the best of my knowledge. Signed Title Date V FOR COIRM1,95110N USE ONLY -l-W, Conditions of approval: Notify Commission so representative may witness (T WM) S A 4 / 0 08 Approval No. _ 7 Plug integrity _ BOP Test _ Location clearance _ Mechanical Integrity Test _ Subsequent form required 10- Approved COPY ORI` Pot Returned SIGNED BY �Q `99 Approved by order of the Commissioner LONNIE C. SMITH Commissioner Date �d ' r_ �5- 60 Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE 2000 Z 1000 0 0 0 c = 0 1000 HORIZONTAL PROJECTION SCALE 1 IN. = 1000 FEET ARCO ALASKA. Inc. Pad 1Y, Well Not 29 Revised Proposal Kuparuk Field. North Slope. Alaska U W, 9 WEST -EAST 5000 4000 3000 2000 1000 TARGET LOCATION% 200' F9L. 2350' FEL SEC. 35. T12N. R9E 7 �... TARGET r 4 = TVD -5964' TWaT 145 DEP•34T8 NORTH 408 WEST 3454 V,, v� TD LOCATION% SEC . 35 . T 12N ., RW N 83 DEG 16 M I N W 3478' CTO TARGET) 0 1000 SURFACE LOCATION% 208' FNL. 1104' FWL SEC. I. T11N. R9E ARCO ALASKA. Inc. Pad 1Y. Well Not 29 Revised Proposal Kuparuk Field. North Slope. Alaska 21 1tLi 1�Li 1 0 � RKB ELEVATION% 102- 1000 KOP TVD=1000 TMD=1000 DEP=O 3 9 B/ PERMAFROST TVD=1342 TMD=1344 DEP=31 15 BUILD 3 DEG 21 PER 100 FT 2000 27 33 39 EOC TVD=2203 TMD=2302 DEP=427 T/ UGNU SNDS TVD=2302 TMD=2429 DEP=507 3000 T/ W SAK SNDS TVD=2942 TMD=3253 DEP=1026 K-12 TVD=3362 TMD=3794 DEP=1367 9 5/8" CSG PT \ TVD=3562 TMD=4051 DEP=1529 4000 5000 K-5 TVD=4952 TMD=5841 DEP=2657 AVERAGE ANGLE 39 DEG 3 MIN T/ ZONE D TVD=5952 TMD=7129 DEP=3468 6000 TARGET TVD=5964 TMD=7145 DEP=3478 T/ ZONE A TVD=6119 TMD=7344 DEP=3604 B/ KUP SNDS TVD=6242 TMD=7503 DEP=3704 TO (LOG PT) TVD -6397 TMD -7703 DEP=3830 7000 0 1000 2000 3000 4000 VERTICAL SECTION m 50 [�7 50 150 200 250 300 800 850 900 950 1000 1050 1100 1150 1200 1250 1300 800 850 900 950 1000 1050 1100 1150 1200 1250 1300 100 50 0 50 I 150 200 250 300 ARCO Alaska, Inc. Bost Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 2?6 1215 October 4, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT: Conductor As -Built Location Plat - 1Y Pad (Wells 25, 26, 29, 309 32) Dear Mr. Chatterton: Enclosed is an as -built location plat for the subject wells. any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG: hf Enclosure GRU13/1.1 ARCO Alaska. Inc. is 3 Subsidiary of A.tlanticRichfiel.Cornoanv If you have t.. U v t C? Uti1fJ u,a .Oil Gas Cons, vur M Z O� 2 O (ot NTS ALL WELLS LOCATED IN SECTION T. 11 N., R. 9 E., UMI AT MERIDIAN. PROTRACTED SECTION CORNER 35 36 21 I I. COORDINATES ARE A.S.P. ZONE 4. 2. ALL DISTANCES SHOWN ARE TRUE. 4. REFERENCE FIELD BOOK: L-88-341 pgs.76-78 AND L-88-35, pgs. 35,38-39. 5 O.G. ELEVATIONS FROM CED- 7Y00-3001 , rev.7. 6. HORIZONTAL POSITION BASED ON 1-Y CONTROL MONUMENTS PER LHO and Associates. Well I Na , , ASPs , Y X LATITUDE LONGITUDE Dist F.N.L. Dist. FWL. O.G. Elev. Pad Elev. 25 5,974,755.59 530,951 .49 700 '20'31.515" 149044'55.725" 568' 1282' 60.9 66.1' 26 5,974,75 5.59 530,891.45 700 20'31.517 " 149044'57.479" 5 68' 1222' 60.6' 66.0' 29 5,975,115.51 530,771 .76 70020'35.062-" 149045'00.933" 208 1 104' 59.2' 65.2' 30 5,975, 1 15 .51 530j831.66 70020'35.060" 149°4459.183" 208' 1164 59.4' 65.4' 32 57975, 1 15 .38 530,951.51 70020'35.054" 149°4455.681 208' 1284' 59.6' 65.5' I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 8/23/88. `` ' "�'1 O {�']� {'';1�. .J♦iiiiiSiiJ�..:tii: Of A4. Oq 00 '* 49th ARCO Alaska, Inc. 0 do �/ CRAIG L. SAVAGE �� I]• I -Y �+ %0 4538-5 i�,# WELL CONDUCTOR AS - B U I LT lf Amm & IWOOMU ENWEM • RWERs • SUWEX>Ts Di by.' M.0'D. Ct ey.' A.J.R. SAI. I all I Rer.li By Dote Deserlptiof Date.' 8-23-88 1 DwOP Na.'NSK6.125. d 6 August 18, 1988 Telecopy No. (907) 2"76-7542 i B Kewin Regional Drilling Engineer ARCO Alaska, Inc P 0 Box 100360 Anchorage, AK 99510-0360 Rei Kuparuk River Unit 1Y-29 ARCO Alaska, Inc Permit # 88-91 Surf Loc 208'FNL, 1104'FWL, Sec. 1, T11N, R9E, LM Btmhole Loc 1171M. 23471FEL, Sec. Z, T11N, R9E, M-1 Dear Mr ewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additlonal permits required by law from other govern- mental agencies prior to commencing operations at the well site. 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. Ve; truly yoUrs'... C V Chat tei`_f Chairman Alaska Oil and Gas Conservation Commission j 0 Enclosure c: Department of Fish & Game, Habitat Section - w/o encl Department of Environmental Conservation - W/o encl STATE OF ALASKA ALASKA C+.— AND GAS CONSERVATION CO,._rvIISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of work Drill ® Redrill ❑ 1b. Type of well. Exploratory ❑ Stratigraphic Test ❑ Development Oil 71 Re -Entry ❑ Deepen ❑ Service ❑ Developement Gas ❑ Single Zone K Multiple Zone O 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 1021, PAD 671GLfeet Kuparuk River Field Kuparuk River 0 i 1 Po 3. Address 6. Property Designation P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25646 ALK 2577 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 208'FNL,1104'FWL,Sec.1,TllN,R9E,UM (approx) Kuparuk River Unit Statewide At top of productive interval (@ target) Number 8. Well number 120'FNL,2230'FEL,Sec.2,TllN,R9E,UM 1Y-29 #8088-26-27 At total deppth Amount 9. Approximate spud date 117'FNL,2347'FEL,Sec.2,T11N,R9E,UM 09/21/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line DS 1Y-13, 1Y-14 74791MD 117' @ TD feet 30' surface feet 2560 64041TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 1 000 feet Maximum hole angle 3(o° Maximum surface 2108 psig At total depth (TVD) 3323 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 35' 35' 1151 115' ±200 # cf 12 - - 6. 0 # J-55 BTC 3940' 35' 35' 39751 3562' 900 sx AS III & IIV-LHW 350 sx Class 8-1/2" 7" 26.0# J-55 BTC 7445' 34' 34' 1 74791 6404' 100 sx 50/50 Poz Lea F-ERW I I 1 1 200 sx Class G tail 19. To be completed for Redrill, Re-entry, and Deepen Operations. To of G 500' above Ku�aruk Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee 9 Property plat 1� BOP Sketch K Diverter Sketch X Drilling program Drilling fluid program X Time vs depth plot ❑ Refraction analysis ❑ Seabed report ❑ 20 AAC 25.050 requirements X 21. 1 hereby certi hat the fore oin is true and correct to the best of my knowledge Signed Title Date Commission Use Only TEM PD3 0147 Permit Number API number Approval date See cover letter 8 .,cif 50-0?_y ,4 /L'-5-,2 08/18/88 1 for other requirements Conditions of approval Samples required ❑ Yes X No Mud log required ❑ Yes K No Hydrogen sulfide measures ❑ Yes �6 No Directional survey required X Yes ❑ No Required working pressur for B 2M• 3M; ❑ 5M; ❑ 10M; ❑ 15M Other: by order of Approved byCommissioner the commission Date0110FI-A0 Form 10-401 Rev. 2-1-85 f Submit in friplicate ARCO ALASKA. In** Pad 1Y. Well Not 29 Proposed Kuparuk Field. North Slope. Alaska ERLTMHN I!�ISC..HR,TI�TENEN 0 -a RKB ELEVATIONS =* 1000 KOP TVD=1000.TMD=1000 DEP=0 3 9 B/ PERMAFROST TVD=1342 TMD=1344 DEP=31 1s BUILD 3 DEC 21 PER 100 FT 2000 271 33 EOC TVD=2117 TMD=2193 DEP=361 T/ UGNU SNDS TVD=2302 TMD=2421 DEP=494 �at 1 i 7000 T/ W SAK SNDS TVD=2942 TMD=3210 DEP=956 K-12 TVD=3362 TMD=3728 DEP=1258 9 5/8" CSG PT TVD=3562 TMD=3975 DEP=1403 K-5 TVD=4952 TMD=5688 DEP=2405 AVERAGE ANGLE 35 DEG 48 MIN 0 1000 2000 VERTICAL SECTION T/ ZONE D TVD=5952 TMD=6921 DEP=3126 T/ ZONE C TVD=5964 TMD=6936 DEP=3135 _.,T/ ZONE A TVD=6119 TMD=7127 DEP=3246 TARGET TVD=6242 TMD=7279 DEP=3335 TD (LOG PT) TVD=6404 TMD=7479 DEP=3452 3000 4000 TARGET LOCATION% 120' FNL. 22301 FEL SEC. 2. T11N. R9E TD LOCATION= 117' FNL. 2347' FEL SEC. 2. T11N. R9E HORIZONTAL PROJECTION SCALE 1 IN. 1000 FEET ARCO ALASKA. Inc. Ped 1Y• Well Not 29 Proposed Kuperuk Field. North Slope, Alaska E. H11 !N, NOVA _-! TE►S4EN WEST—EAST 5000 4000 3000 2000 1000 0 1000 z 1000 0 0 c X 0 TARGET TVD -6242 TMD=7279 DEP-3335 NORTH r88 1000 WEST 3334 N 88 DEG 29 MIN W 3335' (TO TARGET) SURFACE LOCATION% 208' FNL. 1104' FWL SEC. 1. T11N. ROE 100 50 50 .100. 150 _200 . 250.. 300 850 900 950 1000 1050 1100 1150 1200 1250 1300 135C 850 900 950 1000 1050 1100 1150 1200 1250 1300 135( GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4) Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) Drill 8-1/2" hole to logging point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparu k sands. 10) Run and cement 7" casing:. Pressure test to 3500 psig. 11) Downsqueeze Arctic pack -and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in workover rig. NU BOPE. 16) PU 7 casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. DEGASSER MUD CLEANER SHALE STIR STIR STIR SHAKERS L��_ y 4 H 41 MUD CENTRIFUGH CLEANER LWK4/sh TYPICAL MUD SYSTEM SCHEMATIC DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up Weight Up to TD Density 9.6-9.8 8.7-9.2 11.4 PV 15-30 5-15 11-16 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-50 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 6 pH 9-10 9.5-10.5 9.0-10.5 Solids 10± 4-7 12-15 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak -off of 13.5 ppg EMW and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 438' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non -hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. TEM6/ih KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC DESCRIPTION 6"CONDUCTOR 'MC SLIP-ON WELD STARTING HEAD 'MC DIVERTER ASSEMBLY WITH TWO 2-1/16" 000 PSI BALL VALVES 0" 2000 PSI DRILLING SPOOL W/10" OUTLETS 0" HCR BALL VALVES W/10" DIVERTER LINES, SINGLE VALVE OPENS AUTOMATICALLY UPON ,LOSURE OF ANNULAR PREVENTER. VALVES CAN BE IEMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 0"2000 PSI ANNULAR PREVENTER ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE & OPERATION N INITIAL INSTALLATION, CLOSE PREVENTER AND FY THAT VALVE OPENS PROPERLY. 3E ANNULAR PREVENTER AND BLOW AIR THROUGH RTER LINES EVERY 12 HOURS. 3E ANNULAR PREVENTER IN THE EVENT THAT AN JX OF WELLBORE FLUIDS OR GAS IS DETECTED. N APPROPRIATE VALVE TO ACHIEVE DOWNWIND RSION. NOT SHUT IN WELL JG 4/26/88 DIAGRAM #1 13-5/8" 5000 PSI RSRRA MY STACK 1. 16" - 2000 PSI TANKCO STARTING HEAD 2. ll* - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOa. 4. 13-5/8" - 5000 PSI PIPE RANG 5. 13-5/8" - 5000 PSI DRILLING SPOOL W 04OKE AND '7 KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/PIPE RANG ON TCP, BLIND RAMS ON BOTTOM 7. 13-5/8" - 5000 PSI AML LAR ACCLUXATOR CAPACITY TEST I. CHECK AND FILL AATCR RESERVOIR TO PROPER LEVEL WITH HYDRALLIC FLUIQ 2. ASSURE THAT ACCUMJLATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOYINSTREAM OF THE REGULATOR. 3. OBSERVE TINE. THEN CLOSE ALL UNITS SINOJLTANEOUSLY AM TSME WIRPIOFTER ALL UNIARECLOSED WIT CHARGING PUNFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOVER LIMIT IS 45 SECONDS CLOSING TINE AND 1200 PSI REWAINTNG PRESSURE. 5 13-5/8" BOP STACK TEST 4 I. FILL BLP STACK AND CHOKE MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL LOCK DOWN SCREWS IN WELLHEAD ARE FULLY RETRACTED. SEAT TEST PLUG IN WELLHEAD WITH RUNNING JT AND RUN IN LOCKDOWN SCREWS. 3. CLOSE W4ULAR PREVENTER APD MANUAL. KILL AND CHOKE LINE VALVES ADJACENT TO BOP STACK. ALL OTHER VALVES AND CHOKES SHOULD BE 0121M 3 4. PRESSURE UP TO 250 PSI APD HOLD FOR 10 MIN. IN- CREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MIN. BLEED PRESSURE TO 0 PSI. 5. OPEN *"JLAR PREVENTER AND MVAA- KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOICE L I PES. 6. TEST TO 250 PSI AND 30100 PSI AS IN STEP 4. 7. CONTINUE TESTING ALL VALVES. LINE -S. AND G-IOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. M NaT M fig TEST ANN Qjaz T 2 NOT A FULL CLOSING POSITIVE- SFAJ 04OKFFUYCTIUN 8. TEST Q -EKES THAT LX) NUT FULLY- CLOSE.Y OPEN TOP PIPE RAMS APD CLOSE BOTTOM PIPE RANG. TEST BOTTOM PIPE RAMS TO 250 PSI AND 3000 PSI. 9. OPEN BOTTOM PIPE RAMS. BACK OUT RUNNING JT AND PULL OUT OF HOLE. 10. CLOSE BLIND RANG AND TEST TO 250 PSI AND 3000 PSI. 11. OPEN BLIND RAMS AND RETRIEVE TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF NON-FREEZING FLUID SET ALL VALVES IN DRILLING POSITION. 12. TEST STANDPIPE VALVES. KELLY. KELLY COCKS. DRILL PIPE SAFETY VALVE, APD INSIDE BOP TO 250 PSI AND 3000 PSI. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIM AND SEND TO DRILLING SUPERVISOR. 14. PERFCRM CONPLETE BCPE TEST AFTER NIPPLING UP AND WEEKLY THEREAFTER FUVCTICNALLY OPERATE BOPE DAILY. CHECK LIST FOR NEW WELL ITEM APPROVE _DATE (1) Fee (2) Loc _Z 8 (2 thru 8) (5) BOPE` (23 thru 28) (6) OTHER 88 (29 thru 31) (6) Add: Geolo En inee in : WWB LCS BEW BEW MTM RAD rev: 07/22/88 #; nii PERMITS Company Lease & Well No. , YES NO REMARKS 1. Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ OR 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen -day wait ...................... 9. Does operator have a bond in force .................................. 10. Is a conservation order needed ...................................... / 11. Is administrative approval needed ................................... 12. Is the lease number appropriate ..................................... 13. Does the well have a unique name and number ......................... 14. Is conductor string provided ........................................ .PC 15. Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... 16. Is enough cement used to circulate on conductor and surface ......... � 17. Will cement tie in surface and intermediate or production strings ... 18. Will cement cover all known productive horizons , 19. Will all casing give adequate safety in collapse, tension and burst.. 20. Is this well to be kicked off from an existing wellbore ..........000 21. Is old wellbore abandonment procedure included on 10-403 ............ 22. Is adequate wellbore separation proposed ................... ;........ . See 23. Is a diverter system required ....................................... 4q 24. Is the drilling fluid program schematic and list of equipment adequate -;t-f- 25. ;t-L25. Are necessary diagrams and descriptions of diverter and BOPE attached. 4&r VARiA cc Rc"9 = r -IS 26. Does BOPE have sufficient pressure rating - Test to 3 O oo psig i4t 27, Does the choke manifold comply w/API RP -53 (May 84) .................. 28. Is the presence of H 2 S gas probable ................................. .Af For exploratory and Stratigraphic wells:''/f' 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ......... 31. If an offshore loc., are survey results of seabed conditions pr ented 32. Additional requirements ............................................. 44-t Additional Remarks: POOL (8) (3) Admin a (9 thru 13) 1Y- /�� � ,�' _ �o� ' 3d (10 and 13) (4) Casg '0V� 8--6- (14 thru 22) (5) BOPE` (23 thru 28) (6) OTHER 88 (29 thru 31) (6) Add: Geolo En inee in : WWB LCS BEW BEW MTM RAD rev: 07/22/88 #; nii PERMITS Company Lease & Well No. , YES NO REMARKS 1. Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ OR 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen -day wait ...................... 9. Does operator have a bond in force .................................. 10. Is a conservation order needed ...................................... / 11. Is administrative approval needed ................................... 12. Is the lease number appropriate ..................................... 13. Does the well have a unique name and number ......................... 14. Is conductor string provided ........................................ .PC 15. Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... 16. Is enough cement used to circulate on conductor and surface ......... � 17. Will cement tie in surface and intermediate or production strings ... 18. Will cement cover all known productive horizons , 19. Will all casing give adequate safety in collapse, tension and burst.. 20. Is this well to be kicked off from an existing wellbore ..........000 21. Is old wellbore abandonment procedure included on 10-403 ............ 22. Is adequate wellbore separation proposed ................... ;........ . See 23. Is a diverter system required ....................................... 4q 24. Is the drilling fluid program schematic and list of equipment adequate -;t-f- 25. ;t-L25. Are necessary diagrams and descriptions of diverter and BOPE attached. 4&r VARiA cc Rc"9 = r -IS 26. Does BOPE have sufficient pressure rating - Test to 3 O oo psig i4t 27, Does the choke manifold comply w/API RP -53 (May 84) .................. 28. Is the presence of H 2 S gas probable ................................. .Af For exploratory and Stratigraphic wells:''/f' 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ......... 31. If an offshore loc., are survey results of seabed conditions pr ented 32. Additional requirements ............................................. 44-t Additional Remarks: d H O En H c b n H M M Z POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE 1Y- /�� � ,�' _ �o� ' 3d 49016(z� PC v -I WL- 8g© d H O En H c b n H M M Z 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. ALASKA COMPUTING CE��TER Cii L Ci MEi E R G F: R A Vj E I Y 2 9 .s,r A T F A L A8 K B 0 p 0 11 G, H N U.) R TH, St0 P E,� 018F )-029"21852-00 A p I W U " R 5( R E F F, R F N, C F' ",' 0 72983 PAGE: 1 6F'RV1,(7ti ' AMF: clp I C l N 1'1 1 C REEL t4AMF: 72983 COMmV.I T I,,TS T11,PFi SERVICE NAMF ED IT DATF R 111/10 [3RTc 1:N F l,TC TAPE~ NA14E729 33 CO TTNOATI*T':iN 1 PRFIP� QiJS TAPE C 0 IV M F _ `r **}ry*,A*� F��'TI',�F"�. HF".ADF'R ****t} $!'!�a�' SERVICE a r� VERS WIN I A 0 2 DATF;`. /11./1.0 M A X ;.� C SIZE f Q3 t 0 9 6 FTLE 'HYPELAST FlbE KATf"ARLIK I `1. 29 v AR: 15(1-029-2185; ,y���y��.}��y��,�yy Tar�y��yr �y T`_"..{yy"�"!^��.,yy'{{4��"...T��"aa����.^'q�,"'',t1r"'7�}�r '1"'TyT yT� r��.�yT¢yT�Ty �7y". y�y �Ty �yTT��}�,/��. ��T'yR"'.4�r"�yT�."yTµ �Tr.?y'�r �y�yTy'v7�y'.y�r'yT Tr T�a�y'yI4�'w*T���yT�.Ty�, Tjr 'yT "yR"•T. •Tr���y y���Tr� ]T�•r'�R."T'PT"T'�"T*�T*�*TTT'����"f^"T "f" �T�. '�'"TT"!"'!�"T TT^!"��7'�T ���i7^T�T'i'TTT'1'�T'i"TTTT�'!°T'���T�T'A"T•T T'T �T"T'F^��r 'v.ELb SERVICES F"TFfL�iA U K STATE, �LASKA RANGE* * 9E E 'v A T .1.. LOG2" �' R ` E`t • 3'r{' •shy. qy •i T„ ,qt f/ 1 � E: g 4, �}i }� qy..w jp+E �' '1% j}'�3 [p�q� �(y' ry,{ (yY� 'per}+ dye °•t . '. a r"t iy,�f ,.Z CY a.M %f !, T l„; .R K H `!.� i.^ 2 ,, A fi 1,..G Y yA� IS Tape 'Veritication Jisttnei PAGE: chluirtleraer Alaska E LF, V I Cl f; 6 Ktlto 101, Gl,: 67, PATE Rllf.11, T D D R I Ij L, 765P CASTNC 1: !i 8 it 36. 1,±"; n 41 0 4 !)HULLER/ 4102, LOGGER BTT SIZE 1: 1/2" C,) 7658* TYPF P'tTTID IN HOMF,* ',, K T, G H T E, P () L Y IVE R DENSITY, 1.1 ,2 VISCOSTIY: 52, i) f", :*TjOss 0 " 308 MUD PFSI,5TlVlTY; 2t,63 73, FILTRATE RESISTIVT't.'Y: 2,82 74, WID CAKF RESI,STI�TTY: 2 . 32 0 740 TLIF CTRCUL�ATTO,� E ' 0 D k, 0 23 : 0 0 10-24 TIMF LOGGER U 03:35 10-24 MAXIMI,Jf,� Twl-MP 13 8 o, DISTRICTOO PRIM. H 0 fol' t'3 A Y LOG(',4lf,JG ENGIN4'ER: 0 A R N F R WTTNESS: F f, E T r Hi"', R / V A UG H N TOt','.')U NUMRFRSO 5TS EC 1131 DTC 417 p(ill"; Hs 508 CNC A 1238 S ��j GC ic t 1, 1 f) t*,.;'L IAF B C 1. ,312 1 FM, B 17, 14 4 8 FTELD RENIARKS: 1 1/2" STAf,-,`UOF*FS ArX, 2* 1140t&F'I,N[)FR OS ON TOOL 6TRING MiATRIX OFMSTTY 2 6S Gtl/C3 kbUlD DE,41SITY - 1,00 GM/C.It E R CfAPT Rl X 8 A N w3f. C CORRECTION = CALIPER, YOUR TODAY �I'AiS S N, T T h T W T L b I A MS Dv WARNFRo N SCHbU ERGER qp 0 9 * 0 s o 0 000400000090WE 'll'l-4V,;.F Yf')U FOP IJAIN('A p-, 72963 V)P/Afl'A.* R., 81AF',,t5 T!,11S DAPA HVI �-O' DFF)TH SilTF TED - OVEkLAYS FULD PRINTS * 4 * * * * * # 4 * * * * * * 4 4 * * * * * * * * * * * * # S Tare Verif Ication, L-1-stinq 16:08 PAGE: 3 chlurrif",erger A.Iaska Cornoutinq Cen-ter TABLE TYPE : CONS T U I V A L U DEFT C H '(-0,16EPGER L!(.IGS TNrLUDEX, WITH THT.S F11AE (Ff)IT,001): FITIF EDI T0002 FUP 1,211 iSAtfiR1,VU; FDC./CNL DATA> I y - 29 Well Name NATI Nation STAT SPHFRICALUY eQCUSED T. (9DIU) FIRST TG. IjAST READING' '7680'9 TO 4078' SFC T Fc .)kf.1Vr1014 0ENSITY COM-P�,.�NSATFQ LOG (,FUQ FIRST TO LAST READIING: 7660"-6ROof 47000-4400" V L 208' FNL & 11,0.4f FWL LOG ( CN11 N(' �" T FIRST V)LAS T READING: 7;8"j't-680(), 4'70()-4400, A M M ' 4 1(AY UN CASING (vCHT�) API Serial Number FIRST TO LA431T 1'1�J"AV-U-1(-'-'*' 417b' TO 1, 0 0 0 'P TABLE TYPE : CONS T U I V A L U DEFT C ARCA ALASKA# INC* Company Name Ff! KUPAROK Field Name w N. I y - 29 Well Name NATI Nation STAT ALASKA State or Province C011 N NORTH 8V,)PFi County SFC T I Section T (I W, V 11.114 T 0 w n 5 h i P RANX 9 E Rane V L 208' FNL & 11,0.4f FWL Fieyd Location N(' �" T 0 W A R iNy 'F,;';P,, Engineerfs Name 384 Service Order Number APIN 50-029-21852-00 API Serial Number MAM +,111 IAM M► MRf MAe MMI AA AIA MW MM AAM ,. «. MAM MM MMl *M -, .111 MM MA MM MIM IAM oRM MMA MM MIM WIl RM w +IAA Ale MM rs Aw NM M� ,-A Mw eR .� MFM M- � IAII ,- MM •• MM .� .... Aw M1M MMI MA MAM MR +AM MAM MMM MMI MAl ,111 �w MkM t1A 1. «111 A11 MIM IAM +IIA WN .. MMe MA MA1 MMA M• MM1 .. MM M11 wA M1l MMI «� �+ •IR NA11 � A MM 1111 MAM AMA M� MIA TABLE TYPE : CURV DFFI w W meow w oftwMIN MNI w aM w t Mw MIR Mw 4M w M MM MA full NR MIM «lI WM "M MM M Mw M w NEL NA14E DEPTH CHAM4. TFMS Tension SFLIJ SFU Unaverajo-d JUM U -medium Resisti,vity I U 1) TI.,-Cfeep Resistivity S P krioontan'eous Potent . J. a I GP Cmm a Ray TENS Tensfor- VIP�11, Density Porosity F) P H F; Delta r�io R1.40B lulk Density C A J., T tali P e r T5 Tape verif I c a ti or) Ll vs t 1. 10 -WV -1988 16:08 PAGE: L ct)i,umberger tkiaska CoTpultjr)o center D EF T Wft"m"W WWW "M$W" MWM40 MOW W W M M A wwwrIMR M W wW M MWW (21 'IR Gamma Ra N P H T WE0 , 'RONF,140-131TY TNRA CALIBRATED VIERNAU RATTO RTNR RAW THERMAL Ne,11TRON, R4TTO RCFT RCPT RCNT R CM T CFTC CFTC. CNITC CNTC (7R Gamma Rav TFNS Tension i5p Gamma r. ay, TENS Tension r,R Gamma Ray CALI Caliper mm" WNMS m W" m "W" ""m " "m www M" ft. MIM wAMI m" w go to ""mm won" M mm m "W w DATA FOPTIAT SPr`,C1F1("ATTtN RE.CQRj) 'IMI MIME MII RIA w AMI MMR A MM MRI M!II AAA IMR MIM T Y P Ell R EPP ir (IDE VALUE 1 66 0 2 66 0 73 1 k,!4 4 66 5 6 6-, 6 7 65 68 Qo5 F I 10 68 13 6 6 14 65 FT 6 (1 66 SET TYPEIMIMP CRAN 4: !IAM RAM AIR MR AIM NIR 'ARI IAM w AAR IRA RR A IIA1 MR A RIM aMA AMI Mk SRA AYAA IIM! NAME SI ERV UNIT SI ERl! VICE I APNMI I APIL P I FILE NWAB i';Ll - SIIA ZE REPR PROCESS fy 01. R '11) E R IIIA 0 G Y P F C h A S S M Q, f) N M B S APi' p F.L, P1, 1`4 CODE (HEX +MAA Rr AMR ARM IIA IAM MIMI MN AAM AMM IMA IRA w NR ARI w N1R +IAA HIAA HAMA AMM Aw AMI a IMA MR Ar w AIR NAN aNR IIA NRR MAR IIR 1118 MAI ARM AMR NMI RIM AIA wI NMA NRR *A IAM /MR Mw MMM AMR +k11 Ir MIAI Mw TMI IMII MIMI AIIR AA RIM IMI IIIA AIM RA RAA +AIR AAA INlI NIA AR +AMM AM11 AIfM �wIM +MR rR RR IRA IRR ARI IDFPT FT 548384 00 000 00 1 1 4 68 0000000000 TENS 0114 LP54,�384 H h k 0 0 f) 0 1 1 4 61.4 0000000000 I L 0 M 54 3 P 4 0 000 0 4 68 0 0 0 0 0 0 I IL} D I T.j I�,i 54R364 0 000 f,)0 t 4 68 0000000000 11,; 0 Dlf1 n 11; 11N`4( 546394 00 0 0 00 0 1 4 68 0000000000 is 'rare verl fication IAstln(i TENSOTL 1, ci 0 0Q0 0 S F L 13 * ()ICS 2 054 (- lv830 Tlo,V*l)lL PAGEt chlurnk)pr(.jer -13,711, AlaSKa COmputinq Center. 1660,000 PIPS 1',o FOC 2 3*330 OW) FDc 0 p R H 0 B 9 F D C :2*265 CAL, I FDC 8,0031 GR 0 Foc 9"90000 NPHT CNL : man" TNRAoCNL "a* RTNR*CNL A 1� - SF V NIT SEP JCF: API API J� P I I" F F v 114 � M I F, R R CES -999*250 r) *999:2150 ORDER I'Mi "J."VITIE ("L,ASS ml-' D ray. mB SA MP FLEM DEPT* CODF HEX) 4344*000 SFLU 9 0 1 b 2,0226 ow so .Msmp me* 4 68 00OU000000 sp 1), 1 L, V 5 4. R 3 8 -4000 4344oOOO lmi 1 0 Fpc 00 OkHrIoFDC 0:015 1 1 CA,LI'FDC 9078 4 GPqFDC R D T I, A P T 54 f; 394 60 X00 cl, 0 1 1 1 4 68 0000000000 MNS FPC UR—, 50384 0 sl0 * "999 250 FNs:MJA T N 439 20000 L 1�0 563 4 6B 0000000000 UPHT FDC P U 54,P- 3 R 4 tj0 X00 00 S F 1, U . D T L 2*326 ILMO011 29414 4 68 0000000000 R H 0 FDC G/C3 548384 (111 0 000 li 0 0 1 1 20447 4 be 0000000000 RHOP FUC G/C3 5004 tetttett0 -, rl oo oo RCFTOCNL I 1 1 4 68 0000000000 C A t, I FDC I N X4 S 3 8 4 00 CRCHb -999.250 T EN, S m 1.- 14 39200()00 . 4 68 0000000000 cl p F 0 C ('w A P .1 . 14 384 0 ("1 0 0 0 Q I 1 1 4 68 0000000000 N P H T C NIT PO 5 4 8 3 JR 4 J Q 0 0 C. 1 1 l 4 68 0000000000 TV,RA -i CNL 54R3R4 00 no() 00 4 68 0000000000 RTNR CNL 54�,384 oO -0 00 u I 1 t 4 68 0000000000 RCFT CNL CPS 54?3R4 000 ,1)0 0 4 68 0000000000 RCNT CNL CPS 54F�384 Oo 000 00 011 I 1 1 4 68 0000000000 CFTC M CPS S4?384 010 000 00 01 1 1 1 4 68 0000000000 CMTC CNL CI'S 548384 (W(' 00 4 68 0000000000 CP CNL GAPI 548384 00 0()(.) t"No k) I 1 1 4 68 0000000000 TENS CHL li R 5 4 �i 3 8 4 00 0()() r)0 4 68 0000000000 GR CHL GAPI 549384 Cho loo 00 0 1 1 1 4 68 0000000000 TFNS MLL I r B 54P,394 () 0 (.psi 0 0 () () 1 1 1 4 68 0000000000 CSP M L L GA P 1 5 4 iR 3 8 4 OCA 0 () 0 Q) 110 1 4 68 0000000000 CA LT Ml -s li I M 5 4 1118 4 r;+(Ol 00 0 4 68 000000000( ww .... m w w w " w "" DATA OFPT 7 6 79- 0o TENSOTL 1, ci 0 0Q0 0 S F L 13 * ()ICS 2 054 1.L M I L lv830 Tlo,V*l)lL -13,711, (;R*UTL 9 000 S F C T EN D 1660,000 PIPS 1',o FOC 2 3*330 OW) FDc 0 p R H 0 B 9 F D C :2*265 CAL, I FDC 8,0031 GR 0 Foc 9"90000 NPHT CNL : 40 122 TNRAoCNL 3,326 RTNR*CNL 3'586 0 PCFT*CrjL 507*367 tv Rct"T C tj 1,8449350 CFTCoCNL 571*390 CNTCoCNL 1865 554 NL 999000 TF'NS:CHL w999,250 GR9CHL -999*250 TENSoMLL *999:2150 rip * ^fljb -999.250 CA L I M L. b -999.250 DEPT* 7 T E b 5 D I J�� 4344*000 SFLU 9 0 1 b 2,0226 10,10 IL 29242 2,189 spoOlL -8 773 GRqOIL 910438 TENS*FDC 4344oOOO lmi 1 0 Fpc 14.746 OkHrIoFDC 0:015 Pl H C, 13 . F V, C 20407 CA,LI'FDC 9078 4 GPqFDC 91.438 NPHIOCNII 47 Rd'o 0 11 TNRAvCNL 3:860 RTNR'CN`L 9 4922 kCFT*c�'41'.4 448,653 RCNToCNL 1769.913 mccii,4t, 520 673 CNTC CNL 19369913 c IN, li 191 4 3 8 TENSoCHL - 999.250 GH L R v C * "999 250 FNs:MJA T N 439 20000 L 1�0 563 c A tj I Vf I t 6 9 * 9 5 2 D F P T 4, 7 1,) 0 0 0 0 T K" N S 1) 1 t., 4368*OUO S F 1, U . D T L 2*326 ILMO011 29414 1 L El o V) I b 2.359 SPoDli, -11.727 GR -V D I L 92.125 T K fib So F D C 43680000 PPHT FDC 12,329 1:) foi (i , F L) C 6,014 RHCb,FDC 20447 CA L, T 9 Ff) C 9,o4l4 Gp : FV(" ()2*125 J�-j H 1 *CNL 43*894 'CNF� A , C N L, 3*612 RTNROCNIj 3o932 RCFTOCNL 496,541S RVOT c i 1922,980 CFTCoCNL 561.,w210 CNl'CqCNL 197 29398 rll�, T. r f I 1j. 1p 92,125 !p W N S CH 11 "999*25o CRCHb -999.250 T EN, S m 1.- 14 39200()00 . JS Tape Veriticotfon I.,isting PAGE: C .1 -, r �chjumberqer Ala',SKA 01MU'Utinrl Certc DFPTt 7 �4 (-) o , 0 5,263 . T 'C', f,I S, 1) 11, SP* TL 42C,4. 000 S K, U I L GPI*OIL 77* 375 I T, 14 o V I L TF'NS*FDC 50800 42049000 DPHT FDC v I. GR FIX 101. 8 710 77.375 r,Rpn,FDC I lipHIOCNI, 2 31 349 PHOBoFDC TNPA4,Cr,,,'L 'ec"u-s 2*471 2 882 CAL14FDC PTNR*CNL 99148 3, 02 PCFT*��,jf,, 0 732,589 77,375 R C, t�� r, 1. 1 CN 6 sqc�H.b Z-1 163 2 3 3 -999 250 CFT r %. G��VCHL 8 51.: 179 —999*250 CNTCoCNL TENSoMLL 23709193 38000000 Gp 0 �Ibfl 88 , 313 CALI . MIA, 9: 328 DFPT o 11jr,41DIL 7 3 o o (a 84440 T F N'So 0 1 L, 4 3 G 4 v 0 0 F L J o D I b 10,p 176 78o188 ILM *DIL TENS*FDC 8*534 43049000 DPH1*FDC GRoFDC 15.21 .7 78.198 E)RHO.FDC �tjpHjoc�,J, 01030 3192212 RHQR-*F��DC TNRAoCNL 2099 20864 CALI*FDC RTNP CNL 900 3 301 9 RCFTvCML GR.C'NI, 840,605 7P.IP8 RCNT,CNL TFNS*CHU 2404 195 W999:250 C�Tclocmb GROCHL 881*429 409999250 CNTC:CNL TEN'SoMLiL 2480*619 3684*000 CR. 8 0 0 C A L I L L 9 * 25 0 VFPT, T 1, r� D.1. U 710 0 , (� 0 0 6. 4 (10 TE N', S v 11) 1 L Sp*1)11,j 41929000 -17.7bl 5 F L 1) . 0 1 L� GR,DIL 7 702 # 70*125 1 b Mo D I L, TE:.NSoFDC .* &89 4192oOOO L)PH, T FT)C GR. FI)c 16.293 70o125 R H 0 it' ppb D C C t, b 000iJ8 31.016 R 14 0 J-4 v F DC T N R A . C N L 2081 29898 CALI*FDC RTNN CWL 9*609 392 0 RCFT:C'N'i., R v ts 749.769 7(f,, 125 RcNtoc�,11.4 T K P )1 2263. 593 op 9 9 9 251 CFTCVCNL GR*CSL 82.8 967 009.4 9 : 25 0 9 CNTCvCNL TFNS*MLL 23699513 3730*000 Gp% '.11LL 7 6 6 2 5 c A. L I ti 9l q PFD T T L Do 1) f b 7 21 .504 111f. -I PY 3 1 4. 8 P Io LLA 4 1 C, 4, 0 0 0 w & 1 38 781 SFLU 1) T fj G. R T) I Ej 24*668 540 '719 ItMoDIL IT �N S FD C 2:2 9 519 4104000 I. PH T F D C GIR FIX 1 *474 549719 0 R H 'Dc 1"') H I m C N L "OoO12 34oO18 Rii F DC GHQi�i 4 �. CN L 2,626 3*170 CALI:FDC RTNR*CNL 10, 602 3*4 6 RCFToCN�L r .1 R . r N, ts 702.25S 54,719 C t'l'r C, W L Ir E4 N Is I, 229lo697 -999o250 CFTC: CN L, CRCHL 818*985 -999*250 CNTC*CNI, TENS o M b L 2482016 3710oOOO GR * MLL S4,281 C A LIr 0 M; L 1, 10o758 DFpT IR T. 1,10 0 D I b 7 'u 0 Q a 0 (j, 1,502 T E N 5 * D I T,, SP,OTL 406 0f,)0 "200500 SF'UQ * DIL GR01L1,084313 1 651 IL M o DIL T EN4 S * F 0 C 19537 40609000 1) p f-1 T 0 F 1). C G "IR FDC 21 340 1)8,313 D R F1 0' *F T C Ni p H I C N'L 09023 43061 RH 0 ti o FDC TN-R4,oCNL 2* 298 3o678 CALTvFDC RTNRoCNL 10013 39 8 RCFT*OCK-fi GR 0 CKU 414.65b I Q, se 31, 3 RCINIR fifa E, cfiL 1682o949 -099 250 CFTCICNL GR C l'i b 6 4 4v346 0"999*250 cp)TCCNL TENS,MLL 16469387 36900000 G R Mi b L 115.313 61-d * 71, Tito 1 17 OFPT *))TL 6 91 0 0 . I o 829 ',r )4 1115 , 0 1 L 8 P 0 DI L, 3994oO()O -2592 0 SFLU DU G R. j.') I Jj 2 394 114: 500 ILM•DIL TENS FUC 10096 3994tOOO t)Pfi T o FOC GRIFOC 16 o, 9 42 11,4o50,0 1) R h, 0 o F D C Upf I,CNL, 0 o 006 450005 RHOaoFOC TWRA*C,,NL 2 '370 3:748 CAbIOFDC RTNR*CNL 10 3 6 3 4096 R C F T (-, P 440,(ji4 11,4056-0 p (", N' T . C N Lk TEfl-SoCHt-4 1716'v497 -999.250 C. F T C �,, c il 1 GROCHL 490oO73 -9990250 CNTCOCNL TENS'MIL 17 7 Ow, 26 1 36540000 C� R il U 11 1, 16 o 375 A I.. l. L b 1 6 () 9 DEPT 68 10 () t,* 2,319 11 El. N 8 . 0 1 L, 387^' 4 o 0 o SFU I Q I (1 GR*01L 39714 241,*375 11, M 01L, TENSoFDC 2*442 3874oOOO D P 11. F 1) C C,RoFDC 21v438 241,375 j)p h F, r WpH1*_L 0 01 13 44.919 R H 0 B t F D C V`+ACN"1j 2*296 3 697 CAL1oFDC RTNR;CNL 9066 39946 RCFT.COL (I R 0 C!v t: (i 2 4 3 It 241.L.375 RCtil ToCNL� T E !,4 1859o266 -99q.250 CI4TCoCWU Gk,,CHL 507*344 -999:250 CNTCOCNL TENS,MLL 1848o289 35140000 IS Ta e Verification fjistirici l0-'NQ'V-19A8 16:0�i PAGE ow chlumpercer 41aska Coorlutinn Certer Gl p b Ll 272.250 CA L I b 3m D FP T 6(009000 TEN 6, f) I L 3 -9 4 0 0917 0 0 S FL fo 0 1) 1 JJ 4.134 1 LM * DIL 30593 ILD:1)11' 3.676 spoon -3Oo266 GRrDlL 165o625 TENS9FDC w999#250 DPHTOFDC -999.250 DRPO FDC 91 -999,250 RHO�iqFDC -999.250 CALI*FDC w999#250 GR,FDr -999,250 llipHlOICINLI -9990250 TNR 4vCNL -999.250 RTNR*CNL -999.250 RCFTvCt,lL -999.250 -999 250 CFTC*CNL -999:250 CNTC*CNL w999250 GR,Cif lL -999.250 '"LAC6socHi-4 -999:250 CRgCHb -999o250 TENS *MLL w9999250 GR 0, MLL -999,250 C A L. T p.�' L 1.1 -999,250 r,,FPT,, 6 ti () 0 TE, r� 3 0 D 16 3 9 2 01. 0 o 0 S FL U o D I L 2,*824 1 L'm 9 1) 1 L 2s716 ILf),wDTL 2,752 sp.nlL -'250734 112 438 TENS F0(" w999 250 I)PHIPFIDC -999.2sO ORHO.FF)c -Q99*2bO RHO89FDC -999 250 CALT.FDC 09999250 GROFric "999.250 -§99.25o TNRAOCNL RTNR.CNL w999.250 RCFT CNIL -999.250 RMIT Ciii'l-, -9990'250 CF'T("OCNL :999'256 999:250 CNTC CNL -0999.2go '60'al -999,250 TENS CHI, "999.250 GRopCHT.4 "9999250 TENS MLL w999#2 0 CR I., , T", 'I R 1p -999, 250 C All 1 12 L 1, -999.250 DEPT 9 65000 5 ()m 0 0 T 1P ks" D 11-1 3 A 3 0 * 0 () 0 SFLO 114 2*465 XMoDIL L 3*364 TLDqDlL 30410 Sl):Y-JL "26.813 GkvDIL 109*375 TENS*FDC "999#250 DPHT' -999.250 1) li 14 o , F D c -999,250 R H (,° b o F 1) C -999*250 CALI*FDC "999.250 :F'D(,'* GRFT)c "990.250 p P, IV T Cl L -999,2�O TNRA Oct -411 -999,250 RTNR#CNL w999#250 RCFTOC�vq' -999*250 f�cf%��"r.CN(j "999*250 rFj' C,Cf4jj -999.250 CNTC*CNL "999 250 C" P. c t�LL� t; "999999,250 CHL "999999,250 (;R*CHL -9990250 TENS.MLL *999 250 GR �A -.250 (7, 1, 1 LT Lf A -t2so D F P 6 4 0 l" E 1, 1 3974 000 s F T" 9 J) I b 49255 ILM DI 3o426 ILD . DIL 3,434 Sp 011, " '0279734 G R 9 D I li 112o250 t E t"41 S F D C w999.250 L)PHT o FDC -999 , 250 DR H � -) w999.250 R H () Bw Ff.) C IM999o250 CALItFDC m999#250 C�ipoFf)('* -999,250 ripHj:CNl-"� -999,250 TNR.A*CNL -4999 250 RTNRoCNL -0999.250 R.CF'T9Cl'iL -999,250 RCN'TCT)L -999 250 CFT(A" CNIj -999:250 CNTCoCfJL w999*250 R CN'L -999,025,1) TENSOCHL "999:250 GROCHL "999*250 TFNSoMT)lj 0999.250 y*.. R# A, 1, L "9999250 c A w999.250 DEPT 6300*000 T E FllS , D 1, 11 -17900000 5FLU v OTL 2,550 1 L Mq 1) 1 L 2o354 1-; 1) It, 21392 s p * !) I f.', -21098'4- GR*0IL 115750 TENS*FDC W999.250 r)PH,IoFr'C "99920 DRHOVIX "999.250 RHOvFDC -999:250 CALloFDC -0999,1.21 0 C,R,FPC Not .11902150 N P H I : c 1J. "9990250 TNIRA CNL -999.250 R'TN'RoCNL *9999210 RCFT*CNL -999.250 RCNT.CML "999 250 CFTC:CNL -999.250 CNTC*CNL 'W999.2 0 G'scNJ.f -999.250 *A 1ESOCH14 -999:250 GRvCHL "9999250 TFNS*MLL w9990210 cl A° fli -999.250 C A p{" I M L L) D F-" P T 2 0 0 Ir �'. N s ill 1. L 3630oOOD SF L U'o f) -I L 3 541 ILM * Di 3*330 I LP . Dl L 3.324 s p 1 tj -36#000 G- R. DIL 1260063 TENSOFUC w999#250 DPHI. it FDC 4994t250 1) R Yt cl F D c -999.250 R H ()81 F"D c -999.250 C A L T 0 F"n -m999.250 G.p 0 FT)c -' 991250 N11) fil I c N, -999,250 Tl RA v C"M b -999 250 RTNR*CNL "9990250 RC,FTscm� -999,250 R(,t-JTjXNlJ 111", N. -999.250 CFTCoCNL -999:250 CNTC.CNL "9990250 G c lk". 1, -999.2 fl�' Is 4 r fli li -999.250 CR.0 Uto -999.250 TFXSfMLL °i9(C GR Pll L -999#250 CA J..,s I �A L Lf "999.250 DEPT 0:10 0 0 0 T F "I s 'D� 11,1 3 fj 3 0 9 0, () 0 S Fl -o t I D 1, L 4,585 1 M 0.01 L 40163 T L P, f) T tj 4 0 P4 p r" 1 f.- 3 3 0 3 i G R D'I L 12 7 ;. 18 8 T K N8 * FDC -*999.250 D P H T FCU C 9 9 2 5 p -999 , 250 R H B F. D C -999*250 �ATIJ*FDC "999.250 CR, FDC 4 t o' c 4w c )99 2t�o 0 T NkA oCNL "999.250 lk OCNI, RT R "999,250 R c F 1. 9 99* 25 0 (7 C Ll 9 9, 9 . 2 5 0 CVTC lw 114 b -999,� 250 ClmTcqCNL "999*250 , i: j ? * f") A JS Tare Verification tdstini ,�PAGE: ,chlumberger Alaska Cort,;.)utir),a Center NIL -999.250 T ig; -999,250 G, p i1.1 —999,250 'cFN%S , Mbli w999.250 m t t, wo 9 9 2 5 CA!,Tv Jk -999o2sO C)EPT 6 Q 0 0 0 T F. f, S 1-.! .3644 600 F, 1,.k, j D 11 tj lo4b7 I L M . 1) 1 L 29026 T Ljrl 0 1 1� 2 o o 7 Q. 5P 1) T L -2o 234 G 0 T L 142*125 TENS * FDC o999.250 r',PHT,Ff.)C -999.25 r, i� 14 (1 F (--,, r, 99 250 i)\iiOBOFoc -999o250 CAL I*FDC w999*250 GR FDC 0 -999.250 1 C N b *.,� -9999250 TNRAjCr-l.L '"999.250 RTNR CNL m999#250 RCFToCNL -999.250 R(:tz�.CNtj -999 250 CFI�C.C'tlf, -999:250 CNlt'qCNL 09990250 GR . CN L -990 * 29; 0 TU *.(7f4t - J-1 "999 250 CH I clib -999,250 "999,250 CIP 0 MLL -999.250! C A 1, t I q, tv T. t, —999o250 U; F P T 1p 5900,000 TFbS 0 DT 1,, 0 1 3634 00 .0 SFLODT 14 1 966 0 ILMo DIL 20182 ILP VDIL 2.o1.94 sPor,"ll"I GRODU 99*938 TENS FDC "999450 DPHTvFDC -999025o r)RH()sFDC .;23,250 990250 RHOBJDC -999o250 CALI FDC 09990250 r,R,Fjjlc -999.2S0 1,,,,PPToCNL -999o250 TNRAvCML -999 250 RTPCNL,o999#250 RCFToCNTI -999o250 R. CNI, c -999,250 CFTC. CN L, -999.250 CHTC.CNL Gpocivii -999,250 rp , -999 250 G�RVCHL -999v250 TENSom-LL :9999250 999v250 GR , Mbtt -999.250 C A fj,l * �, tj L "9199:250 DFPT# 5 �4 0 () 0 T KW S o D I L, 3674 , 000 S F L T'Jo D I L 1,948 IL . D IL 2olSO 2*195 sp*011L -249500 GkvDIL 99oOOO TENSFDC w999.2 0 1) PHToF'DC - 9 9 9 o 2 5 (y i, FDC R H 999o250 RHO13ofDC 250 CALI FDC m999#290 GP F.Dr 999*250 NpHl*cNL -999.250 V`R,�Ocrllb -999.250 RTNR*CNL *999#250 RCFT CNL, -0,99,250 PCOTOM . 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C 11 L -999 250 RTNRoCNL w999,250 R C F T 4, C PJ L "999. 250 L **L;940250 CFTC,CfJL -9,49:250 CNTC.CNL w999'250 Is Tape yerif Ication ustirl(i PAGE: 13 ch1timberger Alaska Cowt uuin,,; ("enter G p Cl ,11,, t, -9914.425t.> 2 1 10 , o �,i o cR Cpqj 32o1,88 TFKSoPLL w999.250 L, -999,250 -4 L I 1 ! tj -999.250 DFPTo 2600,R(10 Tr"" N,`3 1-11 T L, -999.250 5 F L, d D I L -999,250 ILM.DIL w9999250 1 IjPp 1) 1 L, on 9 9 9 , 7- 5 0 Sr., F) I L - q 119. 250 GRv L-) I L -999 250 TENSeFDC m999.250 DPH19FDC -Q99.250 OR H, F F) C "999,2SO R, H o s 0 F r) c -999.250 CALI*FDC w999,250 C,R*FCjC -999.250rr,-.�i -999.250 TNRAOCNL -999,250 RTNR,CNL "999,250 RCMICNiL -999.250 NcN,,r.c)Ni! -999,250 CFTC.CNL -9990250 CNTCOCNL, w999.250 r o C N L -999.250 T �-', N s p 1-1 112, 110 0 (;R, CHL 20*000 TENSOMLL w999250 GRshLTj -999,250 CAII L L, -999 250 0 [)EPT v 2 50 0 . 0 0 Q T Fll',F S L�l I Tj -999,250 S F Lt Up 1.) 1 L -999.250 1 rdtt 0 D I L W999.250 ILT),v[)TL -999.25() splPill -999.2SO Gizol)IL, "999.250 TENIS.FDC "999.250 VpHTvFDC 409Q9,P250 DRf40,,FDc -999.250 RHOBoFOC -999.250 CALI. FDC' w999.250 GQ F,r)c -999.250 tJlOhl.CNb -999.250 TNRAOCNb -999.250 RTNR.CNL 09990250 RCF�*061..i -999.250 RC!,vrcNb "9019.250 CFTCvCNL, -999 250 CNTCqCk'L **999.250 G,P C'e-IL -999,250 TENSOCHij 2074,00o clk1. cHIJ, 32:375 TFNS.MLL w999.250 G P c 5 0 I y,; CAL 1, -999.250 DEPT. 2400, 11)00 TENSODIL -999925() SFLU'DIL -999.250 ILMqDIL w999.250 ILDODOL -999,0250 spy)lb "999,250 GRVII)lb -999,250 TFNS,FDC "999;250 V P H T o F 1) C "9999250 D R HiO F x)C 999q250 RHOBJOC -999;250 �ALIJDC w999w250 GP*Ff)c -999IR2,50 i:p v HI c1l', 1L -9990250 TNRAgCNL "949 250 -41,250 RTNR.CNL w999,250 RCFTOCVL w999.250 I R C- N T c "i b 9 9 9 , 2 5 0 CFTC. C14L .99 CNTC CNL *0999 250 G R, 0 c I-, "999,2so T E N S C H L 20QOqOOO GR* 42" 0719 TENSvMLL o999:250 C ,jp*MLL "999,250 C A L 1 ?4 Is L, "999,250 DFpT* 2300�,000 T V!N 3,0 D. T. Lf "999.250 S FL U L) I L "999,250 ILMODI o999,250 I L P 0 fn 1, -999.25() 11-S P 0 1 Ll -, 0 - no �49 1 - 9,250 Gp 0 r),TL w999 2.50 0 TENS FDC 0 -0999, so DPHT*FI)C -9999,250 f)RHQmFDC w999,250 Rpogf)Foc -999o250 CALI.FDC 09990150 GR 0 FDC -999.250 P H I c flli LJ -999 2CO 02,50 T N R A 0 C"N L -999.250 RTNR*CNLj 0999,250 RCFTOCNL "999.250 RCNT:CNL -§§§,* CFTC*CNL -999.250 CNTCoCNL 0999 2,50 ri R c NI L w999,250 V F IN s c H It", 19959000 GR I CH14 35o281 TENSoMLL W*999: 250 GR: MU -999,250 C A L I MtA 14 99 t 250 V F 1:0 T 0 2200*000 TENSOPIL "999o250 S F L, U,� U I L m999.250 ILMoDIL *999.250 1, w9999250 USPODIIJ w999o250 Gpol)IL -999.250 TENS.FDC vo999,*250 DPHIvFDC -999,250 ORHOOFF)c -W),250 Rfi0f�oFDC ft999.250 CALIoF'DC *999#250 Gp 0 FUT -999.250 , p H 1 9 C'N', L, -9'99-250 Ir KI R A t c 114 tj -999.250 R TN R , CN L "999#250 PCFIT-,Oc�At, -999,250 RCNT*r-NTi 1"999o250 CFTCO'CNL -999.250 CNTC.CNL o999*250 G, R C N b -999 2501 T E H L 9 0 GR,r-HL 440563 TENSoMLL *999.250 (Mv MLL -999:250 i.<. 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D I L -9Lj9, 250 -s F 1) U 1 0 1.14 GR*91L -999 250 -999-:250 1 L D I L TENS., FDC 409990 50 W999.iso VPHI , F,Dc rt'RoFDC Im 999*250 -99940250 -999.250 -999.250 RHO;4j,-;�Dc TNPk@C,`JL "9999250 -999 250 CALIeFDC RTNR'CNL "999#250 R C F 1'. C N'L r3p,CNI, W99 9 j 2 -N � i w 999 25z) R C b, T CIN b rEt�-SCHI-o -9919,250 15(45.000 CFTCvCNL GRaCHL m999 250 489969 CNTC: CNL TENSoMlob :999.250 999 250 GR to o' Lb 00969:�, - c A I. 1 0 '-ALL -9's9.250 0999:250 DEPT TLD,:rjIL 12 0 0 -999.250 T E, N S , T.) 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Thi S ts () P E County s , ECT I FORATIOINI 1.s[,--JJ81TY COMPEINSATED LOG ( F'DH) P A N G FIRST "101 LAST READING: 767to"TO 6800f C0t4PFN,5ATk",r, NFU'J'RON L(IG Sofl 548384 FTR.S.1` tri"! LAST R})ADI f,4 706f To 68000 TABLE TYPE : CONS 'r WNJ V Al; U DEFT 011 ARCO ALASKAO INC o Company Name F' sKUPAROK Field Name W V, I y - 29 Well Name NATT, Nation STAT ALASi�A State or Province C'01.1h N 0 R. Thi S ts () P E County s , ECT I Section TOV! 11& Township P A N G 9F IR a, n e F11 2080 FNL & 11,040 FWlj Fie?d Location F 1'l C7 1 D , W A k Nl F R Engineer0s Name Sofl 548384 Service Order Number IS Tane verification i,istirq 10-Nbv-1488 16:08 &,luirherger Alaska Conc.pwtino Cpnter PAGE 00 17 tj T V A L L)EF1 50-029-21952-0() API Serial Number 11M AIM IMM MM iIM7I MIM 7qM Mw MMI MMI !IM mm IIM MM MMM w"M A"" ' "Rim" OR " M "on" TAB ,F TYPE : CUkV DEFT DEPT DEPT14 CHANNEL NAM -F TFNS Tension VPHI Density Porosity DPHO Delta rho R 14 ().p Billic Depsity NFDC Near FIX Count Rate FFDC Far FDC Cot -lilt Rate CA111 Caliner CF Gamma Ray TVRA CALTBRATED THERMAL NFUTROO kATI,C) RTNP RAW TYIERMAL NEUTRON PkTIO R.CFT RCFT RCNT RCP T CFTC CFTC C NT r CNTC GR G atri r[l a R a V ** VATA FOR14AT SPFCIFTCATION RF(.'(,)Rf) #* SET TYPE 64EB X7M AMM IMII MM MM. RN 971k 71M MMF tIM7 41M MRI' IAM VIII MMI 71111 77M IIM IAI MIA MMI � IMM MAI �' � � 7� IAM' IMM T y P -E RFP -R COT"'K MM1 MM � M11 i!M 171M #! MAR MM >a1M AMM MI IMA IMM 1171 IIM MRM MM MM MMI 71MI IIM AM MM RI�I N4 MRA RAI A�9t 6 6 �afMy}M 2 6 6 73 6 4 6 6 5 66 h 73 7 65 Via,6 8 00o 66 12 68 13 66 16 66 66 IS lape Verif Icatiort I,Jstino 18800000 DPHIWFDH 110951 UV 10-i�-1988 16:08 RHOB * FDH 2*453 PAGE„ is chluipterger FFIDC 0 FDH Alaska Computina 9,w 14 1 Center NPHIOCNH �99944 TNRAOCNH 39320 RTNRoCNH 3*582 HC:` F T,, c §N H. 552.218 R C, N, T 0 c N H *4 ,SET TYPE - CHAN CNTC*CNH 20299106 GFOCK,H M No m w m w " w 4w we 4332oOOO w SRA M 4w 40 Op 14o998 DRHDvFDH 0*007 R IP" IT SEP CE AP1 API API API I bE C,,R, 0 F014 6 1 ZE, 43*157 RO ESS 3*626 Iii 30591 fl, R D K R # LOG TYPE CtjASS CF-TC.CNH f4UMB SV,-lP Ef,-IEill GR,r-Ntq CODF (HFX NDA IRM NM IRD wD ,... ,AAA Iw w MRA. RpR IRR w � ,aA Mll w w tlw ., Aw MD MR .. w w MR wR M. 1MM w. M A+IR • wII w Mw AAD N ., w Mw w wR w RAIZ Mr w+ Rw w w ww RRR ANR w ,., Rw •M RNR AMr w RRR w :AAM aMD w w 7w fAD lA ARM +1N1 NMD w MAR ANM IMA Alw RIM I)EPT DPfilwFDIJ ' FT 548 4 u 0 000 0 NFDc, Fl")H 2 F E'D C FT) H 46S*250 4 of 3 3oM 00(l00 0 00 TF NS FDH Lb 548384 00 090 00 f) 2 1 1 4 68 0000000000 DPHI FOH PH 54-8384 On 000 00 2 1 1 4 68 0000000000 VRNO FLM ("I/C3 50364 00 000 00 (i 2 1 1 4 68 0000000000 RPOS FVH G/C3 5483P4 oo RCFT CNH 9 00 0 2 1 1 4 68 0000000000 NFDr- FDD CPS 54P384 00 no U 2 1 1 4 68 0000000000 FFDC FOH CPS 54 9314 00 000 00 CAliToFDH 2 1 1 4 68 0000000000 CALT FDH IN 548384 00 0100 00 u 2 t 1 4 68 0000000000 GP FDH GAPI 549384 00 000 00 0 2 1 1 4 68 000OU00000 NIPHT chip Pl.) 54P384 l')() 000 00 2 1 1 4 68 0000000000 VIRA CNH 548384 00 000 no (4i 2 1 1 4 68 0000000000 RTNP CN14 548384 00 000 00 2 1 t 4 68 0000000000 RCFT CNH CPS 54H 394 000 00 u 2 1 4 68 0000000000 p("NT CN -11 CPS 50384 00 000 00 0 2 1 4 68 0000000000 CFTC C!,vii CPS 548384 00 000 00 2 1. 1 4 68 0000000000 QTC CNH CPS 5483P4 fsr 00,10 00 0 2 1 1 4 68 00000000OU GF CN4 GAPI 549384 00 000 00 2 1 1 4 68 0000000000 * * DATA vFpl, 0 7677o200 T ,INS F D H 18800000 DPHIWFDH 110951 RH 0 0 F 1) H (4 080 RHOB * FDH 2*453 Pli F D c F UH 1 . . 664 500 0 FFIDC 0 FDH 554*500 CALT*FDH 9,w 14 1 GpoFUH NPHIOCNH �99944 TNRAOCNH 39320 RTNRoCNH 3*582 HC:` F T,, c §N H. 552.218 R C, N, T 0 c N H 20U6043 c F, I, C 0 c c H 621#901 CNTC*CNH 20299106 GFOCK,H DEPTs 7600*000 TENSoFPH 4332oOOO DPHT.FDH 14o998 DRHDvFDH 0*007 R14OR*Fr)H 2t403 F Dc FD14 587 500 FFOCoFDH 524*000 CALloFOH 10,078 C,,R, 0 F014 9618,75 'N P H T C 43*157 TN'R A o C N 4 3*626 RTNKoCNH 30591 RCFTOCNM 3600680 RrNT*cNH 1775:080 CF-TC.CNH 516oO16 CNTC*CNH 1,8569126 GR,r-Ntq 96o975 DFPT* " 750V0000 Ts* N69F"J.)H 42249000 DPfilwFDIJ ' 9 207 DRHOvFDH 0*054 ]PHOR FL)H 2*498 *75f) NFDc, Fl")H 610 v 500 42.491 F E'D C FT) H 46S*250 CAbloFDH of 3 3oM ��:IrDH 95 twHjom,��i T�-!RA"CNH 3:539 RTNR CNH RCFT''I.i 451:30'7 1969,686 CF-TCvCN14 5639828 CNTC:CNH 1961v965 GptCNH 850,750 ).')EPT . 74 0 (1, ,()0 Q TKN3tFDfl 4144 # Ok) 0 [.-)PHI 0 pr"!i 12 111 f4 H (),j F. 1) 11 09028 R H () 4 j, F r) H, 2.4 -so ��O F, D c F 1) H 597,500 FF'DC o FOH 490 750 CALJvFDH 99219 C, R, 0 FD H R ?- 11 5 63 Illpfil C N H 3.3060 TNRAoC4H 3 022 RTNRoCNH 3#416 RCFT CNH 9 700 o3l R C K T . C t�l' 2286o468 CFTCvCN 82 30594 CNTC#CNH G R N, P k, 2 5 t) 3 VFPT, 73 0 0 Q 0 f TENS 42,12.000 DPHI o, FDH IS 697 DRHO FDH 00009 RHOBqFDH 2 341 f� F 1) c F D)*i 6150500 FFDC v FO -H 610 000 CAliToFDH 8s969 R . F t) H, 'rk�i 7 6 1, !'48 f"i P H I C 6i; H "T 299735 TNRA*CMH 2:760 k T N R s C N H 2 84 R r- F T 0 C 414. vi (ii.,) 5 R C 6,,� c ti" i 1 2802 1 259 CF71C.MH CNTCoCOH 2560:6355 Tave V e r i t ication '16:08 FILF NAME ED I T .002 PAGE: 19 chiumk,erger Alaska Computing Center DATF MAX REC STZE 1(")96 FILF TYPE 1, LAST FILE DFPT 7200*000 TENS* FVH 414 0, 000 P J,i I h'D H 16,101 T-) R H 0 9 F D H 00008 PHO P, FDiA 2 3 P i.- F c , F f s 596.500 F FD C FD li 549v000 CALIFDF- 99734 C3p, FDH 6 1 'o C 2996:40 TNRAoCNH 2,815 RTNR:CNH 2 744 RCS" T,*C�,H 881 ,405 KCNT*Ch: -09,754 2( CFTC.CNH 948*826 CNTC,CNH 2553:727 DEEP 7 1 0 1 0 r E f"ll 5 . P" T.) 40 90 , 0 Go DPHI.FDH 1.4, 191 DRH0,FDH mm0,049 RH0PqF(lfq 2,416 wF1')'CjFL>i 470*o00 FFD C.FDH 442 250 CAL19FDD 100906 G P o F I) H. 1),438 1 C 33 3 TN'K A q C 3 181 RTNRtCNH 39477 R C F Tj C koi 657o284 R c �Jl Ir : c i,4 234b,594 C F'I'Co C !H 759,889 CNTCoCNH 2329oO28 G p , C N li 6 (), 4 3 8 DEPTO 7000,000 TFWSqFMH 4020,0yQ DPH14FD4 150822 URHOeFDH 0v064 RHOPIFOH 2*389 NFI , )C,FDH 674v000 FFDCoFDH 6239000 CALI FUH l0o414 GR FDH 101 500 N'phlcNH 47 163 TN R A 9 C, 3087.,3 RTNR:CNH 3o853 RCFT4,civv 456:462 R C N5, T , 0 8 5 4 CFTC $ cry ii 4560472 CNTCvCNH 17009125 GR c �114 H. lol os()() DFPT, 6 9 r? kl),O 0 o 0 T 0� A, S 0 F Df'i 3974,000 DPH I v FON 10 * 66 8 DRHO 9 F -DH 00053 PHOSOFDH 2*474 619.500 FFDc FDH 492#000 CALIoFDH 109445 GR,oFr)H 10�j938 -11� PH Im c N 420063 T Nl� R A : C W H 3:596 RTNROCNH 39789 IR C FT C ",I h 461*735 �R, C, Tocr,,�.H 1724*600 CFTCoCNjH 500,4430 CNTCgCNH 18069332 G p c N, .10 2 9 3 R V E P T 8 T K, A 5 0 F F" H 3864 0 Q 0 DPHlvFDH 2,09585 OKHO 0 FDH 000A7 RH6�: P,I)li 2010 "4 F D C * F D H 0 .41,5 0 C FFVCqF0H 674 500 CALl*FDH 9s8 3 G R 0 F, DH 2 4 3 * 2 5 U 0 1 C lv'ii 4 1 408 TNRAgCNH 3:515 RTNR*CNH 4*000 RCFToc,r" 459*083 ii c f. -i T r H�- 83 1 0,237 CFTCoCNH 539*524 CNI'CoCNH 1893*197 GR,WCNH 0 2430251. DEPTO 6797o899 TFN5qF0-H 3860*OUO t)PHl*FDH 19*892 ORHOOFDH ovols PHQR,FDH,. 24322 NqlDrl*FDH 636o5OO FFDC*F0H 657,500 CALI*FDH 9,0961 GPvFr'H 2230250 NPHTOCN�.f 43*406 TNR)'ikwCNH 30630 RTNRgCNH 3.799 RCFTOCNH 438,535 RCNT*CNR 1705w863 CFTC*C'NH 521*905 CNTCoCNH 18779943 c1p. 0 Civ H 25(l 2 23 0 , li EN'll 0 F T") A T A , FILF NAME ED I T .002 SFRVICE Fi4lc VERSION 0OIA02 DATF MAX REC STZE 1(")96 FILF TYPE 1, LAST FILE IS TaPe Verification T,istino 1 0-N I,) V- 988 1 6 (18 PAGE: 20 chiumter(ier AlaSKa Comol,)tin(j Center FTLF N'AME q1 ED I f 1003 SERVIrE : FT4 T VE4SION : OotAO2 PATE : R c /11/1.G MAX REC SITZE 14.)Q6 FILF TYPE b i) T..AST E' 11,,E THIS DATA HAS NOT 8FEN DEPTH SHIFTED M. OVERLAYS FIELD PRINTS SCHb(1M8EKGER LUGS TNCtUOED 'VJTH THIS FRILE FTUE NAME' = EDIT,,003 = <1.*211 SAMPLE ATE> DATA AVATLABLE: 76700 TO 67980 is TABLE TYPE 0 CONS T i, I fll V A UJ DEF1 ---------- cvi ARCO ALASKA, INCe Company Name FN K U P A F' Tj K Field Name W!�' I Y - 29 Well NaMe NIATI Nation STAT ALASKA State or Province colj!! NORTH SLOPE County S F C T I Section TOWN 1114 Township RAMC~ 9E Range F1.1 26 0 FNL & I T04'" F'4- I.; Field Lo5ation ENGI 0 WARt'E-k 5a83b4 Engineer s Name SON Service Order Number API N 50-029"21852-00 API Serial Number TS Tape verif icaticn Listirri 10-1' (JV -198 1.6-08 P A G K. 21 chlofphercier. Alaska r-ornputin Center TABLE '1'Y PF; ; CURV DFIFi WWWWW www" M"M WW"W" MOW MM"WMM "W Wft " M W m WWWW M"W W""MWWMW W MWW DFPT DEPTH CHAL NAKE V, I N v fiicro-inve'rse k4e's'istivity Oicro-Normal, Resistivity mWW"mwWwmft" mm ""mm""m "m I DATA FORMAT SPECIFICATION PF"C(,')RD DATA 7668o333 L t"Ov I , "'ZOR 'I,b t, I A.; 1,601 M, 0, . 0 m Io926 HTKK * MLL w999,250 SET TYPE, 64EB TYPE RE PR CODE V A L Lt F 1 66 66 3 73 16 4. 66 1. 73 7 b5 65 FT 6 6; 6 12 6F, 13 6 6 tt 14 65 is 66 6 1.6 SET TYPE CHAN "A M" ME 6" R" V" "(J "N T" " S F "R ( I C F: APT API 4PI API FILE NOV15 NUM6 SIZE REPR PROCESS 0- F'V FS F? # IJ)(3 TYPE CLASS MOD NUMB SAS P FLEM c 0.1) E 0JEX) 41w IM11 VFPT F,T 54�Npr8erMA 3► 8wll 4w or) 000 *NN M 11X1 4X1+ Mer PM 3 QA 9IN MXR 1X11 Illt MTNV mjjL 04114M 548384 00 tic) 0 () 0 00 1 0 3 1 1 1 4 4 68 68 000000000IM 0 0000000000 mFnp ALL ("jH104 548384 00 000 00 0 3 1 4 68 00 00000000 HTt-N MLL LR 5411184 t:` 0 3 1 4 6P 0000000000 DATA 7668o333 L t"Ov I , "'ZOR 'I,b t, I A.; 1,601 M, 0, . 0 m Io926 HTKK * MLL w999,250 IS Tape Verif icatlon Ustirlo TRAILER. #*** lib -()a : E'D 11, go,03 PAGE*', 22 chlorrh.ercier y,lasKa Cofputi q Center 0OIA02 DATF # 808/1 PAX REC SIZE 7 6 0 0 1961/10 2,o4l Pl U R 2.594 HTE 10159500 JrM 2,336 fl, r 20105 'N * M Ti h 11' F. 7070250 7 4 0 0 , � 1, 1 u 9 OR p "14b 50430 HTKNvMbL 6849500 1") F p T 7 3 I N. v 11 L 0 3 1 L L 6,008 li T E N o, P, L li 618,750 V FpT I 2 0 00 7 0 0 v I 1 . ol—U X0117 my'OROALL 6,625 HTENOMLL 639*250 DFPT 710C, 0 C A, I V ; J., L 3,326 - N1 H ri P, * M li L 50215 HTFN*MLL 6789000 DFPTq 7000,C)OO lo426 MNQRvMLL 10040 HTENoMLL 6839189 DFPT, 69060000 1 V' t, 2,203 P't N 0 P , M L IU I p 6 18 f I T EN, w Yl L L 6379500 T)FPT 68009000 11,4 `4 (1 2v336 WN 0 R o q- L; b 29213 HTENsMLL 6199000 VETT 67 96 , 55.1#F 1 IV V T " I , Wl 6 MHOROMLL 19654 141 T P- fuo M b[! w999.250 ** ENO OF DATA ** **** FILE TRAILER. #*** FTLF NAME : E'D 11, go,03 SFRVICE ! FLTc VERSION 0OIA02 DATF # 808/1 PAX REC SIZE 1961/10 FTLF TYPE Lo LAST FlF TAPF TRATLFP' SERVICE NAMF E01T DATE 88/11/10 p I G I IN ii I c TAPS" NAME 72983 CONTI N UATIOV 0' PRE.VIOUS TAPE rOmMENT SERVICE 'JANIF ED I I [)ATF 0 Rj. G I N F, 11 T C RFEL NAME r 72983 CONTINUAT, PPION EIVIOU'S RFFU COMMENT LF, T A p K,r Al -'J "i KU'PARUK I Y-29, AP 'l #50-029-21852
