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183-104
KƌŝŐŝŶĂƚĞĚ͗ ĞůŝǀĞƌĞĚƚŽ͗ϭϭͲ&ĞďͲϮϲ,ĂůůŝďƵƌƚŽŶ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵ͘tŝƌĞůŝŶĞΘWĞƌĨŽƌĂƚŝŶŐ ƚƚŶ͗͘EĂƚƵƌĂůZĞƐŽƵƌĐĞdĞĐŚŶŝĐŝĂŶƚƚŶ͗&ĂŶŶLJ,ĂƌŽƵŶ ϯϯϯtĞƐƚϳƚŚǀĞŶƵĞ͕^ƵŝƚĞϭϬϬϲϵϬϬƌĐƚŝĐůǀĚ͘ ŶĐŚŽƌĂŐĞ͕ůĂƐŬĂϵϵϱϬϭŶĐŚŽƌĂŐĞ͕ůĂƐŬĂϵϵϱϭϴKĨĨŝĐĞ͗ϵϬϳͲϮϳϱͲϮϲϬϱ&Z^ͺEΛŚĂůůŝďƵƌƚŽŶ͘ĐŽŵdŚĞƚĞĐŚŶŝĐĂůĚĂƚĂůŝƐƚĞĚďĞůŽǁŝƐďĞŝŶŐƐƵďŵŝƚƚĞĚŚĞƌĞǁŝƚŚ͘WůĞĂƐĞĂĚĚƌĞƐƐĂŶLJƉƌŽďůĞŵƐŽƌĐŽŶĐĞƌŶƐƚŽƚŚĞĂƚƚĞŶƚŝŽŶŽĨƚŚĞƐĞŶĚĞƌĂďŽǀĞt >>ED W/η ^ Zs/ KZ Zη &/ >ED :KdzW ddzW >K''/E'd WZ/Ed^η /'/d>η ^ dηϭ ϭͲϮϬ ϱϬͲϬϮϵͲϮϮϭϭϮͲϬϬ ϵϭϬϱϵϳϯϰϯ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮͲ&ĞďͲϮϲ Ϭ ϭϮ ϭͲϭϰϱ ϱϬͲϬϮϵͲϮϯϱϮϲͲϬϬ ϵϭϬϱϵϲϳϵϭ <ƵƉĂƌƵŬZŝǀĞƌ DƵůƚŝ&ŝŶŐĞƌĂůŝƉĞƌ&ŝĞůĚΘWƌŽĐĞƐƐĞĚ ϳͲ&ĞďͲϮϲ Ϭ ϭϯ ϭ&ͲϬϵ ϱϬͲϬϮϵͲϮϬϵϴϯͲϬϬ ϵϭϬϱϯϵϯϭϮ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮϲͲ:ĂŶͲϮϲ Ϭ ϭϰ ϭ,ͲϭϬϭ ϱϬͲϬϮϵͲϮϯϱϴϱͲϬϬ ϵϭϬϱϯϵϰϯϭ <ƵƉĂƌƵŬZŝǀĞƌ DƵůƚŝ&ŝŶŐĞƌĂůŝƉĞƌ&ŝĞůĚΘWƌŽĐĞƐƐĞĚ ϭϴͲ:ĂŶͲϮϲ Ϭ ϭϱ ϮͲϭϰ ϱϬͲϭϬϯͲϮϬϬϰϬͲϬϬ ϵϭϬϱϵϳϯϰϮ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϳͲ&ĞďͲϮϲ Ϭ ϭϲ ϯ^ͲϲϮϰ ϱϬͲϭϬϯͲϮϬϴϲϴͲϬϬ ϵϭϬϱϯϵϭϴϰ <ƵƉĂƌƵŬZŝǀĞƌ WůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂů ϮϯͲ:ĂŶͲϮϲ Ϭ ϭϳ ϯ^ͲϲϮϰ ϱϬͲϭϬϯͲϮϬϴϲϴͲϬϬ ϵϭϬϱϯϵϭϴϰ <ƵƉĂƌƵŬZŝǀĞƌ WůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂů ϮϰͲ:ĂŶͲϮϲ Ϭ ϭϴ ϯ^ͲϲϮϰ ϱϬͲϭϬϯͲϮϬϴϲϴͲϬϬ ϵϭϬϱϯϵϭϴϰ <ƵƉĂƌƵŬZŝǀĞƌ dƵďŝŶŐWƵŶĐŚZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂů ϮϱͲ:ĂŶͲϮϲ Ϭ ϭϵϭϬW> ^ <EKt> ' Z /Wdz^/'E/E'EZ dhZE/E'KWzK&d, dZE^D/dd>> dd ZdKd, dd Ed/KEK&͗&ĂŶŶLJ,ĂƌŽƵŶ͕,ĂůůŝďƵƌƚŽŶtŝƌĞůŝŶĞΘWĞƌĨŽƌĂƚŝŶŐ͕ϲϵϬϬƌĐƚŝĐůǀĚ͕͘ŶĐŚŽƌĂŐĞ͕<ϵϵϱϭϴ&Z^ͺEΛŚĂůůŝďƵƌƚŽŶ͘ĐŽŵĂƚĞ͗^ŝŐŶĞĚ͗dƌĂŶƐŵŝƚƚĂůĂƚĞ͗190-162214-138183-104217-138185-145223-104T41362T41363T41364T41365T41366T41367T41367T41367214 138183-104217 138ϯϭ&ͲϬϵϱϬͲϬϮϵͲϮϬϵϴϯͲϬϬ ϵϭϬϱϯϵϯϭϮ<ƵƉĂƌƵŬZŝǀĞƌWĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂůϮϲͲ:ĂŶͲϮϲϬϭGavin GluyasDigitally signed by Gavin Gluyas Date: 2026.02.11 13:44:36 -09'00' ORIGINATED TRANSMITTAL DATE: 8/26/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5019 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 5019 1F-09 50029209830000 Production Profile (PPROF) 24-Aug-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 tom.osterkamp@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 183-104 T39487 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.26 10:36:06 -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 tom.osterkamp@conocophillips.com • dc6 - 024 21'&2 WELL LOG TRANSMITTAL# DATA LOGGED Z /5/201G M.K.BENDER To: Alaska Oil and Gas Conservation Comm. June 10, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JUN 2 8 2016 AOGCC RE: Leak Detect Log with ACX: 1F-09 Run Date: 7/8/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1F-09 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-20983-00 Leak Detect Log with ACX (Processed Log) 1 Color Log 50-029-20983-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. SCANNED DEC o 92016 Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: QD✓Qighov __,,�_ jy TE OF ALASKA KRU 1F-09 Al <A OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations Fracture Stimulate 1 Pull Tubing l7, Operations Shutdown IT Performed: Suspend IT Perforate IT Other Stimulate IT Alter Casing IT Change Approved Program IT Plug for Redrill I- Perforate New Pool E. Repair Well F Re-enter Susp Well r I- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory 183-104 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-20983-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25652 KRU 1 F-09 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 7600 feet Plugs(measured) 7247 true vertical 6327 feet Junk(measured) None Effective Depth measured 7462 feet Packer(measured) 6863,7012,7229 true vertical 6203 feet (true vertical) 5668,5801,5995 Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 16 107 107 0 0 SURFACE 2309 9 5/8 2341 2147 0 0 PRODUCTION 7512 7 7544 6277 0 0 Perforation depth: Measured depth: 7144-7172,7276-7289,7304-7351,7305-7331,7337-7341,7347-7352 True Vertical Depth: 5919-5944,6037-6049,6062-6104,6063-6087,6092-6095,6101-6105 RECEIVED DEC 3 1 2015 Tubing(size,grade,MD,and TVD) 3.5, L-80,7253,6017 ] A Packers&SSSV(type,MD,and TVD) PACKER-FHL PACKER,4762(60K SHEAR RING)@ 6863 MD and 5668 ND O v C PACKER-OTIS RRH PACKER @ 7012 MD and 5801 ND OTIS WD PACKER@7229 MD and 5995 ND SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: s titel /:\P" 13 5 20 1 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut in Subsequent to operation waiting fac hookup 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: �'`'''! Daily Report of Well Operations Exploratory I Development F Service Stratigraphic T Copies of Logs and Surveys Run r- 16.Well Status after work: Oil 1 Gas 1 WDSPL Printed and Electronic Fracture Stimulation Data T GSTOR r WINJ IT WAG IT GINJ I- SUSP SPLUG 1- 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: N/A Contact Danny Kane(aa265-6048 Email Danny.Kanet7a cop.com Printed Name Danny Kane Title Sr.Wells Engineer Signature ...„// .je".........„ Phone:265-6048 Date 11/3i / I s Form 10-404 Revised 5/2015 �T6 ������� Submit Original Only '4 7471 KUP PAD 1 F-09 CanocoPhillips 'a Well Attribute Max Angle TD Alaskia.io . 1 Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Corwcatompa 500292098300 KUPARUK RIVER UNIT PROD 47.13 3,600.00 7,600.0 • ... Comment H2S(ppm) Date Annotation End Date KB-Grd(tt) Rig Release Date 1F09.12/29/201511,44;17 AM SSSV:NONE 20 11/8/2014 Last WO: 12/1/2015 33.21 9/1/1983 :.:.Vernral suhn6attninciva9.. Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,374.0 7/15/2014 Rev Reason:WORKOVER,GLV C/O lehallf 12/16/2015 HANGER,21.0 ('i';1 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.060 32.0 107.0 107.0 63.00 H-40 WELDED .,, Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 32.0 2,341.0 2,146.6 40.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread _^..ti CONDUCTOR,32.0-107.0- PRODUCTION 7 6.276 32.0 7,544.0 6276.6 26.00 J-55 BTC Tubing Strings H 11 Tubing DescriptionMa...ID(in) Top(ftKB) Depth(ft.. Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection Tubing RWO 2015 1 String 31/21 2.9921 21.01Set 6, 940.01 5,736.31 9.301 L- 80 'Top 8rd Mod SURFACE;32 0-2,341.0- 1 Completion Details -1t Nominal ID Top(ftKB) I Top(ND)(ftKB) Top Incl C) Item Des Com (in) GAS LIFT;2,840.9 �- 21.0 I 21.0 0.08 HANGER FMC Tubing Hanger,TC-1A-EN,6"x 3-1/2"EUE 8rd Box 2.992 x Box,3"ISA BPVG is Ilt 6,831.9 5,641.0 28.67 LOCATOR Locator Sub,GBH-22(bottom of locator spaced out 7') 2.990 Ilk mIA 6,832.9 5,641.8 28.66 SEAL ASSY Seal Assembly,80-40(total seal assembly length= 2.990 GAS LIFT;4,479.3 21.68') 6,839.9 5,648.0 28.60 PBR PBR,80-40, 4.000 6,863.0 5,668.3 28.40 PACKER FHL Packer,47B2(60K shear ring) 2.930 GAS LIFT;5,582.1 - 6,914.3 5,713.5 27.87 NIPPLE Nipple,2.813"DS,SN: 2 2.813 6,931.7 5,728.9 27.62 SWEDGE Poor Boy Overshot with 7.96'swallow(spaced out 1') 3.600 Tubing Description 'String Ma...'ID(in) 1 Top(ftKB) Set Depth(ft..]Set Depth(ND)I...'Wtib/ft) 'Grade I Top Connection Original Tubing 31/2 2.992 6,933.1 7,2532 6,016.9 9.30 J-55 EUEBrd GAS LIFT,6,305.1 ` Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl c) Item Des Com (in) 6,985.8 5,777.0 26.84 SBR OTIS SBR 2.813 GAS LIFT;6,774.9 '!!` 7,012.1 5,800.5 26.46 PACKER OTIS RRH PACKER 2.970 7,121.3 5,898.7 25.88 BLAST BLAST RINGS 2.992 RINGS 7,150.5 5,924.9 26.10 BLAST BLAST RINGS 2.992 LOCATOR,6,831.9 RINGS SEAL ASSY,6,832.9 7,227.6 5,994.0 26.53 SEAL ASSY OTIS LOCATOR SEAL ASSEMBLY 3.000 PBR,6,839.9 7,229.0 5,995.3 26.53 PACKER OTIS WD PACKER 4.000 PACKER,8,863.0 7,232.7 5,998.6 26.54 MILL EXT MILL OUT EXTENSION 2.992 7,247.3 6,011.7 26.56 NIPPLE OTIS XN NIPPLE NO GO(Set 2.81"PXN Plug 9-25-14) 2.750 NIPPLE,6,914.3 7,252.2 6,016.1 26.57 SOS BROWN SHEAR OUT SUB,ELMD TTL @7251'during 3.015 PPROF on 5/30/2008 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) CUT TUBING,6,934.0 6,934.0 5,730.9 27.59 CUT TUBING CHEM CUT 6934'(STRINGSHOT 6926'-6937') 11/13/2015 2.910 SWEDGE,6,931.6 it 7,247.3 6,011.7 26.56 PLUG '2.81"PXN PLUG 9/25/2014 0.000 GAS LIFT,6,949.1 Perforations&Slots 111 Shot SBR;6,985.0 4 Dens PACKER 7,012.1 Top(TVD) Btm(ND) (shoal Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com la 7,144.0 7,172.0 5,919.1 5,944.3 C-4,UNIT B, 10/15/1983 12.0 IPERF DA 5"csg gun;120 deg. PRODUCTION;7,048.0 '. 1F-09 Phasing II 7,276.0 7,289.0 6,037.3 6,049.0 A-4,1F-09 11/30/1983 4.0 IPERF Dresser thru tbg;0 deg. PRODUCTION;7,114.1 Ph BLAST RINGS;7,121.3 - _ 7,304.0 7,351.0 6,062.4 6,104.3 A-4,1F-09 6/16/1984 4.0 RPERF RigidJet;90 deg'V'Phase IPERF;7,144.0-7,172.0L� BLAST RINGS;7,150.5 7,305.0 7,331.0 6,063.3 6,086.5 A-4,1F-09 11/30/1983 4.0 IPERF Dresser thru tbg;0 deg. Ph II 7,337.0 7,341.0 6,091.8 6,095.4 A-4,1F-09 11/30/1983 4.0 IPERF Dresser thru tbg;0 deg. PRODUCTION;7,190.8 i if Ph SEAL ASSY;7,227.6 --- 7,347.0 7,352.0 6,100.8 6,105.2 A-4,1F-09 11/30/1983 4.0 IPERF Dresser thru tbg;0 deg. Ph it PACKER;7,229.0 Mandrel Inserts MILL EXT;7,232.7 11 :.. St atii IN Top(ND) Valve Latch Port Size TRO Run NIPPLE;7247.3.E / - N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com PLUG;7,2429 i 1' 2,840.9 2,508.1 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,262.0 12/5/2015 2 4,479.3 3,697.0 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,247.0 12/5/2015 XO THREADS;7,250.2 .11 3 5,582.1 4,595.7 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,240.0 12/5/2015 SOS;7,252.2 4 6,305.1 5,190.1 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,230.0 12/5/2015 5 6,774.9 5,591.1 Camco MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 12/5/2015 IPERF;7,276.0-7,289.0- 6 6,949.1 5,744.3 OTIS WBD 1 GAS LIFT OPEN 0.000 0.0 11/12/2015 7 7,048.0 5,832.7 OTIS WBD 1 PROD HFCV BEK 0.000 0.0 9/27/2014 ...-- IPERF,7,306.0-7,331.0 8 7,114.1 5,892.3 OTIS WBD 1 PROD HFCV BEK 0.000 0.0 9/26/2014 RPERF;7,304.0.7,351.0 -_. 9 7,190.8 5,961.1 OTIS WBD 1 PROD HFCV BEK 0.000 0.0 9/26/2014 IPERF;7,337.0-7,341.0 Notes:General&Safety End Date Annotation IPERF;7,347.0-7,352.0 9/1012010 NOTE View Schematic w/Alaska Schematic9.0 PRODUCTION;32.0-7,544.0--.. • • : r Daily Operations Summary 0a Wiiiiiiiilig 1F-09 conoaptviiips Rig: NABORS 9ES Job: RECOMPLETION Daily Operations Start Date Last 24hr Sum 11/26/2015 Pull the pits away from the sub and stag on the pad.Pull the sub off well 1F-01A, move the sub down the pad past 1 F-09,and stage next to the opposite well houses. Pick up herculite and rig mats from around the 1F-01A. Clean up around the well. Set rig mats around well 1F-09 and lay out herculite. Hang tree in the cellar. Stage test spool, new HCR kill,and DSA in the cellar behind the well. Spot the sub over well 1 F-09, install mats under the sub,and set the sub down. 11/27/2015 Spot the pits to the sub,spot the cuttings box,and set up berming. Finish rig acceptance checklist and accept rig Nabors 9ES at 05:30 hours. Load the pits with 10.9 ppg NaCI/NaBr brine. RU lubricator, PT to 3000 psi(good test), pull BPV, and RD lubricator. RU circulating equipment for well kill operation. Test hard line with water to the kill tank to 3000 psi(good test). RU circulating equipment and kill the well with 10.9 ppg NaCI/NaBr brine pumping 276 bbl down the tubing taking returns out the IA to the kill tank. Observe the well for flow for 30 minutes and the well is static. Install 3"ISA BPV with dry rod. ND the tree,NU 13-5/8"x 11"adapter flange to test spool,and NU test spool to the BOP stack. NU new HCR kill. NU DSA,NU the BOP stack,install the mouse hole,install the riser,and air up the air boot. 11/28/2015 Conduct initial BOPE test to 250/3000 psi: test 2-7/8"x 5"VBR's(upper pipe rams and lower pipe rams)with 3-1/2"test joint;test annular to 250/3000 with 3-1/2"test joints;conducted CPAI Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Matthew Herrera via email on 11/27/15 at 11:17 hours. RU to pull 3-1/2"completion. Pull blanking plug and attempt to pull BPV but were unable to get retrieving tool to engage properly. Pump 10 bbls to clear any obstruction in the BPV. Monitor the well for 15 minutes and the well is out of balance. Circulate 60 bbl,observe the well for flow for 15 minutes and the well is static. Attempt to pull BPV but still unable to get retrieving tool to engage properly. The decision was made to pull the tubing hanger with BPV still installed. MU landing joint to the tubing hanger and MU TD. BOLDS and unseat tubing hanger at 110K. Pull hanger to the rig floor and lay down tubing hanger. RU to circulate and circulate bottoms up. Observe the well for flow for 15 minutes;the well is static. POOH laying down 3-1/2"tubing spooling control line to the SCSSSV. Lay down SCSSSV. Recovered 37 of 38 stainless steel bands.RD SLB control line spooling unit. Continue to POOH laying down 3-1/2"tubing removing GLM's. Strap,tally,and removing tubing from pipe shed. 11/29/2015 Continue to POOH laying down 3-1/2"tubing removing GLM's to 2364'. PU, MU,and RIH with the storm packer. Set the storm packer at 97',PT to 1500 psi for 10 minutes(good test),and DDT for 15 minutes(good test). Bleed off the pressure on the OA to 0 psi. ND the BOP stack,ND the DSA,and ND the tubing head. NU new tubing and NU DSA. PT the tubing head void to 3000 psi for 15 minutes(good test). NU the BOP stack, install the test plug,and PT the break to 250/3000 psi(good test). Pull the tree test plug and install the wear ring. PU, MU,and RIH storm packer retrieving head. Release the storm packer,and lay down the storm packer. Continue to POOH laying down 3-1/2"tubing removing GLM's to surface. Cut joint length= 12.45'. Pull the wear ring. PU,MU,and RIH with 3-1/2"stack packer gas lift completion. 11/30/2015 Continue to RIH with 3-1/2"stacked packer gas lift completion to tag on top of tubing stub at 6933"RKB. SO,observe overshot pins shear(12K down),SO,and observe 5'of swallow after pins sheared. Spot the corrosion inhibited brine pill around the packer/PBR assembly. Drop the ball& rod and pressure up to 3000 psi to set the FHL packer.Bleed tubing pressure to 1500 psi and PT the IA to 2500 psi for 10 minutes(good test). PU to shear the seal assembly out of PBR,SO,locate out,and mark the pipe for space out(no pups needed for space out). MU the tubing hanger and landing joint. Reverse circulate 186 bbls of 10.9 ppg corrosion inhibited brine down annulus. Land the tubing hanger and RILDS. PT the tubing to 3000 psi for 15 minutes(good test),bleed the tubing to 1500 psi,and PT the IA to 2500 psi for 30 minutes(good test). Bleed the IA to 0 psi, bleed the tubing to 0 psi,and quickly ramp up the pressure to shear the SOV(sheared at 2200 psi). Install 3"ISA BPV with dry rod. ND the BOP stack, NU the tubing head adaptor, PT the void to 250/5000 psi(good test),and NU the 3-1/8"tree. Pull the BPV and install the tree test plug with dry rod. RU tree testing equipment and fill the tree with diesel. 12/1/2015 PT the tree to 250/5000 psi(good test). Pull tree test plug with dry rod. RU Little Red Service and pump 75 bbls of diesel down the IA taking return up the tubing to the kill tank. RD LRS. Place the tubing and IA in communication allowing the well to u-tube and equalize. Final well pressures: Tubing=0 psi, IA pressure=0 psi,and OA=34 psi. Install 3"ISA BPV with dry rod. Install FMC manifold,secure well,and secure cellar. Release the rig at 06:00 hours. Page 1/1 Report Printed: 12/29/2015 • • R11rilli • Operations Summary (with Timelog Depths) _M &wens 1F-09 ConoCOPhiilips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/26/2015 11/26/2015 0.50 MIRU MOVE MOB P Pull the pits away from the sub and 0.0 0.0 20:00 20:30 stag on the pad. 11/26/2015 11/26/2015 0.50 MIRU MOVE MOB P Pull the sub off well 1F-01A,move the 0.0 0.0 20:30 21:00 sub down the pad past 1F-09,and stage next to the opposite well houses. 11/26/2015 11/26/2015 1.50 MIRU MOVE RURD P Pick up herculite and rig mats from 0.0 0.0 21:00 22:30 around the 1F-01A. Clean up around the well. Set rig mats around well 1F- 09 and lay out herculite. Hang tree in the cellar. Stage test spool,new HCR kill,and DSA in the cellar behind the well. 11/26/2015 11/26/2015 1.00 MIRU MOVE MOB P Spot the sub over well 1F-09,install 0.0 0.0 22:30 23:30 mats under the sub,and set the sub down. 11/26/2015 11/27/2015 0.50 MIRU MOVE SFTY P PJSM for spotting the pits. 0.0 0.0 23:30 00:00 11/27/2015 11/27/2015 1.00 MIRU MOVE MOB P Spot the pits to the sub,install mats 0.0 0.0 00:00 01:00 under the pits,lay out herculite,and set the pits down. 11/27/2015 11/27/2015 4.50 MIRU MOVE RURD P RU berming around the cellar and pits. 0.0 0.0 01:00 05:30 RU interconnect. Spot cuttings box and RU berming around cuttings box. Install handrails and traction mats. Spot the kill tank, RU hardline to the kill tank,and install ground strap. Finish rig acceptance checklist and accept rig Nabors 9ES at 05:30 hours. 11/27/2015 11/27/2015 0.50 MIRU WELCTL RURD P Start loading the pits with 10.9 ppg 0.0 0.0 05:30 06:00 NaCI/NaBr brine. Load lubricator into the pipe shed and bring to the rig floor. 11/27/2015 11/27/2015 0.50 MIRU WELCTL SFTY P Safety meeting on PU and testing 0.0 0.0 06:00 06:30 lubricator to pull BPV. 11/27/2015 11/27/2015 2.25 MIRU WELCTL MPSP P Open SSV and close master. Make 0.0 0.0 06:30 08:45 up lubricator and pressure test to 3000 psi(good test). Pull 3"ISA BPV and shut SSV. R/D lubricator. Initial well pressures:Tubing= 1200 psi, IA= 900 psi,and OA=0 psi. 11/27/2015 11/27/2015 1.75 MIRU WELCTL RURD P RU circulating equipment to circulate 0.0 0.0 08:45 10:30 down tubing taking returns up the IA to the kill tank. Test lines to 3000 psi. Leak in pump room-repaired same. Bleed IA to the kill tank. Bleed tubing to the kill tank. Shut in the well. Blow down lines and line up to pump. 11/27/2015 11/27/2015 1.50 MIRU WELCTL KLWL P PJSM. SITP=60 psi and SICP=180 0.0 0.0 10:30 12:00 psi. Kill the well with 10.9 ppg NaCI/NaBr brine pumping 276 bbl down the tubing taking returns out the IA to the kill tank at 3 BPM=230 psi hold 100 psi back pressure at the choke. 298 bbls returned to the kill tank. SITP=100 psi and SICP= 100 psi. Page 1/8 Report Printed: 3/15/2016 • 0 ,., Drilling g Operations Summary (with Timelog Depths) fr. &Wells 1F-09 CanocoPhitlips i. Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/27/2015 11/27/2015 1.00 MIRU WELCTL OWFF P Monitor the well for 30 minutes. SITP 0.0 0.0 12:00 13:00 =0 psi and SICP=50 psi. Blow down hardline to the kill tank. Open the tubing and IA up to the atmosphere and the well is static. Observe the well for flow for 30 minutes and the well is static. 11/27/2015 11/27/2015 0.50 MIRU WELCTL RURD P Blow down all circulating lines and RD 0.0 0.0 13:00 13:30 circulating equipment. 11/27/2015 11/27/2015 0.25 MIRU WHDBOP MPSP P Install 3"ISA BPV with dry rod. 0.0 0.0 13:30 13:45 11/27/2015 11/27/2015 1.75 MIRU WHDBOP NUND P Bleed off pressure from the control 0.0 0.0 13:45 15:30 line and void. ND the tree and remove from the cellar. Obtain RKB's. 11/27/2015 11/27/2015 5.50 MIRU WHDBOP NUND P NU 13-5/8"x 11"adapter flange to test 0.0 0.0 15:30 21:00 spool and NU test spool to the BOP stack. NU new HCR kill. 11/27/2015 11/27/2015 1.50 MIRU WHDBOP NUND P Due to the 7-1/16"3000 psi tubing 0.0 0.0 21:00 22:30 head the 1-3/8"bolts from the 7-1/16" x 11"DSA were removed and 1-3/8"x 1-1/8"bolts were installed into the DSA. Install R45 x R46 API ring onto tubing head to go from the 3000 psi tubing head to the 5000 psi DSA.. NU the DSA to the tubing head. 11/27/2015 11/28/2015 1.50 MIRU WHDBOP NUND P NU the BOP stack. Install the mouse 0.0 0.0 22:30 00:00 hole,install the riser,and air up the air boot. 11/28/2015 11/28/2015 1.00 MIRU WHDBOP RURD P RU BOPE testing equipment. Fill 0.0 0.0 00:00 01:00 BOP stack and choke manifold with freshwater. Purge lines. Page 2/8 Report Printed: 3/15/2016 i i Operations Summary (with Timelog Depths) &W 1F-09 conocoPhitliprs Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/28/2015 11/28/2015 6.50 MIRU WHDBOP BOPE P Conduct initial BOPE test to 250/3000 0.0 0.0 01:00 07:30 psi: test 2-7/8"x 5"VBR's(upper pipe rams and lower pipe rams)with 3-1/2" test joint;test annular to 250/3000 with 3-1/2"test joints;conducted CPAI Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Matthew Herrera via email on 11/27/15 at 11:17 hours. Tests: 1) Blinds, Kill Demco,Chokes 1,2,3, &16(Passed) 2) Chokes 4,5,&6(Passed) 3) Chokes 7,8,&9(Passed). 4) Manual Choke,Hydraulic Choke (Passed) 5) Chokes 10&11 (Passed) 6) Chokes 12, 13,&14(Passed) 7) Annular with 3-1/2"test joint,3-1/2" EUE TIW,4"HT-40 TIW, HCR Kill, Choke 15(Passed) 8) Upper Pipe Rams with 3-1/2"test joint,4"HT-40 TIW,HCR Choke (Failed low pressure test-greased HCR Choke;Passed) 9) Upper Pipe Rams with 3-1/2"test joint, Upper IBOP(hydraulic),Manual Choke(Passed) 10)Lower IBOP(manual),Lower Pipe Rams with 3-1/2"test joint(Passed) 11)Blinds, HCR Kill,Outer Test Spool (Passed) 12)Blinds, HCR Kill, Inner Test Spool (Passed) Conduct CPAI Koomey Draw Down Test: Starting Accumulator Pressure=2950 psi Accumulator Pressure After Closer= 1600 psi Pressure Gain of 200 psi=34 seconds Full System=158 Seconds Average N2(6 Bottles)= 1992 psi 11/28/2015 11/28/2015 2.00 MIRU WHDBOP RURD P Blown down all lines,drain the BOP 0.0 0.0 07:30 09:30 stack, RD BOPE testing equipment, put all the chokes in the correct line up. Clean and clear the floor. 11/28/2015 11/28/2015 1.00 MIRU WHDBOP OTHR P Bring Weatherford tubing tong and 0.0 0.0 09:30 10:30 SLB control line spooling unit to the rig floor. RU Wetherford tubing tongs and SLB control line spooling unit. 11/28/2015 11/28/2015 0.75 MIRU WHDBOP MPSP P MU blanking plug retrieving tool,pull 0.0 0.0 10:30 11:15 the blanking plug,and lay down blanking plug and retrieving tool. 11/28/2015 11/28/2015 0.75 MIRU WHDBOP WAIT T Wait for FMC rep to go to the obtain 0.0 0.0 11:15 12:00 BPV pulling tool. Page 3/8 Report Printed: 3/15/2016 • • Operations Summary (with Timelog Depths) Drilling' 1 F-09 ConocoPhiilip5 Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 11/28/2015 11/28/2015 0.50 MIRU WHDBOP MPSP T Attempt to pull BPV but were unable 0.0 0.0 12:00 12:30 to get retrieving tool to engage properly. 11/28/2015 11/28/2015 1.25 MIRU WHDBOP CIRC T MU landing joint to the tubing hanger 0.0 0.0 12:30 13:45 and MU the TD. Blow air through the kill line out to the kill tank to verify it is clear. Pump 10 bbls at 1 BPM= 122 psi to clear any obstruction in the BPV. Blow down the TD and kill line to the kill tank. Pull the landing joint and drain the stack. 11/28/2015 11/28/2015 0.25 MIRU WHDBOP OWFF T Monitor the well for 15 minutes and 0.0 0.0 13:45 14:00 the well is out of balance. 11/28/2015 11/28/2015 0.50 MIRU WHDBOP RURD T RU to circulate through the secondary 0.0 0.0 14:00 14:30 choke and choke manifold. Install landing joint and MU TD. 11/28/2015 11/28/2015 0.75 MIRU WHDBOP CIRC T Circulate 60 bbl at 1.5 BPM=240 psi. 0.0 0.0 14:30 15:15 Blow down the TD,pull the landing joint,and blow down the secondary kill/choke manifold. 11/28/2015 11/28/2015 0.25 MIRU WHDBOP OWFF T Observe the well for flow for 15 0.0 0.0 15:15 15:30 minutes;the well is static. 11/28/2015 11/28/2015 0.50 MIRU WHDBOP MPSP T Attempt to pull BPV but still unable to 0.0 0.0 15:30 16:00 get retrieving tool to engage properly. The decision was made to pull the tubing hanger with BPV still installed. 11/28/2015 11/28/2015 1.00 COMPZN RPCOMP PULL P MU landing joint to the tubing hanger 6,934.0 6,903.0 16:00 17:00 and MU TD. BOLDS and unseat tubing hanger at 110K. Pull hanger to the rig floor(PU=93K and SO=70K). Lay down landing joint and lay down tubing hanger. 11/28/2015 11/28/2015 1.00 COMPZN RPCOMP CIRC P MU crossover to the tubing and MU 6,903.0 6,903.0 17:00 18:00 TD. Circulate bottoms up at 9 BPM= 1648 psi. Blow down the top drive. 11/28/2015 11/28/2015 0.25 COMPZN RPCOMP OWFF P Observe the well for flow for 15 6,903.0 6,903.0 18:00 18:15 minutes;the well is static. 11/28/2015 11/28/2015 2.75 COMPZN RPCOMP PULL P POOH laying down 3-1/2"tubing 6,903.0 4,982.0 18:15 21:00 spooling control line to the SCSSSV. Lay down SCSSSV. Recovered 37 of 38 stainless steel bands. 11/28/2015 11/28/2015 0.50 COMPZN RPCOMP RURD P RD SLB control line spooling unit. 4,982.0 4,982.0 21:00 21:30 11/28/2015 11/29/2015 2.50 COMPZN RPCOMP PULL P Continue to POOH laying down 3-1/2" 4,982.0 3,097.0 21:30 00:00 tubing removing GLM's. Strap,tally, and removing tubing from pipe shed. 11/29/2015 11/29/2015 1.25 COMPZN RPCOMP PULL P Continue to POOH laying down 3-1/2" 3,097.0 2,364.0 00:00 01:15 tubing removing GLM's to 2364'. Strap,tally,and removing tubing from pipe shed. Page 4/8 Report Printed: 3/15/2016 • Operations Summary (with Timelog Depths) &Wells 1 F-09 ConocoPhiifips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/29/2015 11/29/2015 1.75 COMPZN WELLPR MPSP P Change elevators to 4"DP. PU and 2,364.0 0.0 01:15 03:00 MU storm packer. RIH with storm packer and set at 97'. Release from the storm packer,stand back DP,and lay down twin thread safety joint. Close the blinds, PT the storm packer to 1500 psi for 10 minutes(good test), and DDT for 15 minutes(good test). 11/29/2015 11/29/2015 2.00 COMPZN WELLPR RURD P Drain the BOP stack and blown down 0.0 0.0 03:00 05:00 lines. Bleed off the pressure on the OA to 0 psi. 11/29/2015 11/29/2015 1.00 COMPZN WELLPR NUND P Pull the mouse hole and pull the riser. 0.0 0.0 05:00 06:00 ND the BOP stack and set back on the stump. 11/29/2015 11/29/2015 3.50 COMPZN WELLPR NUND P ND DSA and ND tubing head. 0.0 0.0 06:00 09:30 Replace 1-1/8"x 1-3/8"bolts with 1- 3/8"bolts in the DSA. Prep the wellhead for the new tubing head. 11/29/2015 11/29/2015 1.50 COMPZN WELLPR NUND P NU new tubing and NU DSA 0.0 0.0 09:30 11:00 11/29/2015 11/29/2015 0.25 COMPZN WELLPR PRTS P PT the tubing head void to 3000 psi 0.0 0.0 11:00 11:15 for 15 minutes(good test) 11/29/2015 11/29/2015 2.25 COMPZN WELLPR NUND P NU IA valve to the new tubing head 0.0 0.0 11:15 13:30 and NU the BOP stack. Install mouse hole,install turnbuckles,install riser, and air up the air boot on the riser. 11/29/2015 11/29/2015 1.50 COMPZN WELLPR BOPE P PJSM. Install the test plug and fill the 0.0 0.0 13:30 15:00 BOP stack with fresh water. PT the break to 250/3000 psi(good test). Drain the BOP stack,pull the test plug,and blow down all testing equipment. 11/29/2015 11/29/2015 1.00 COMPZN WELLPR RURD P PU wear ring running tool with a joint 0.0 0.0 15:00 16:00 of DP. Install the wear ring,RILDS, and lay down wear ring running tool. 11/29/2015 11/29/2015 1.00 COMPZN WELLPR MPSP P PU and MU storm packer retrieving 0.0 2,364.0 16:00 17:00 head. RIH,engage storm packer, equalize storm packer(no pressure under the storm packer),release the storm packer,monitor the well for 5 minutes,POOH laying down DP,and lay down the storm packer. 11/29/2015 11/29/2015 4.50 COMPZN RPCOMP PULL P Continue to POOH laying down 3-1/2" 2,364.0 0.0 17:00 21:30 tubing removing GLM's to surface. Strap,tally,and removing tubing from pipe shed. Cut joint length=12.45'. Clean and clear the floor. 11/29/2015 11/29/2015 0.50 COMPZN RPCOMP SVRG P Service the top drive. 0.0 0.0 21:30 22:00 11/29/2015 11/29/2015 0.25 COMPZN RPCOMP SFTY P PJSM for running 3-1/2"completion. 0.0 0.0 22:00 22:15 11/29/2015 11/29/2015 0.25 COMPZN RPCOMP RURD P PU a joint of DP, PU wear ring pulling 0.0 0.0 22:15 22:30 tool,pull the wear ring,lay down the wear ring pulling tool,and lay down the joint of DP. Page 5/8 Report Printed: 3/15/2016 • ,., ari111-19 Operations Summary (with Timelog Depths) &Welt 1 F-09 ConocoP'hi hps Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/29/2015 11/30/2015 1.50 COMPZN RPCOMP PUTB P PU and MU poor boy overshot,nipple 0.0 688.0 22:30 00:00 assembly,joint of 3-1/2"tubing, FHL/PBR assembly, 1 joint of 3-1/2" tubing,and GLM with SOV. RIH with 3-1/2"stacked packer gas lift completion on 3-1/2"9.3#L-80 EUE 8rd Mod tubing to 688'at midnight. 11/30/2015 11/30/2015 4.00 COMPZN RPCOMP PUTB P Continue to RIH with 3-1/2"stacked 688.0 4,530.0 00:00 04:00 packer gas lift completion on 3-1/2" 9.3#L-80 EUE 8rd Mod tubing from 688'to 4530'RKB. 11/30/2015 11/30/2015 0.50 COMPZN RPCOMP RURD T The door latch on the Weatherford 4,530.0 4,530.0 04:00 04:30 tubing tongs was not working properly. RD the tubing tongs and RU the backup tubing tongs. 11/30/2015 11/30/2015 3.50 COMPZN RPCOMP PUTB P Continue to RIH with 3-1/2"stacked 4,530.0 6,931.0 04:30 08:00 packer gas lift completion on 3-1/2" 9.3#L-80 EUE 8rd Mod tubing from 4530'to 6931'RKB. 11/30/2015 11/30/2015 0.25 COMPZN RPCOMP HOSO P Tag up on top of tubing stub at 6933" 6,931.0 6,941.0 08:00 08:15 RKB. Slack off and observe overshot pins shear(12K down). Slack off and observe 5'of swallow after pins sheared. 11/30/2015 11/30/2015 0.50 COMPZN RPCOMP RURD P PU to 6930'(3'off the tubing stub). 6,941.0 6,930.0 08:15 08:45 RU circulating equipment. 11/30/2015 11/30/2015 0.50 COMPZN RPCOMP CRIH P Pump 10 bbls of 10.9 ppg corrosion 6,930.0 6,930.0 08:45 09:15 inhibited brine down the tubing and chase with 61 bbls of 10.9 ppg brine to spot the corrosion inhibited brine around the packer/PBR assembly at 3 BPM=361 psi. 11/30/2015 11/30/2015 0.50 COMPZN RPCOMP WAIT P Drop the ball&rod and allow time for 6,930.0 6,940.0 09:15 09:45 it to fall to seat. SO and place poor overshot 1'off tubing stub. 11/30/2015 11/30/2015 1.00 COMPZN RPCOMP PACK P Pump ball and rod down,pressure up 6,940.0 6,940.0 09:45 10:45 to 3000 psi,and hold for 5 minutes to set the FHL packer. Bleed tubing pressure to 1500 psi. Close upper pipe rams and PT the IA to 2500 psi for 10 minutes(good test). 11/30/2015 11/30/2015 0.25 COMPZN RPCOMP PRTS P Bleed tubing pressure to 1500 psi. 6,940.0 6,940.0 10:45 11:00 Close upper pipe rams and PT the IA to 2500 psi for 10 minutes(good test). Bleed the IA to 0 psi. 11/30/2015 11/30/2015 0.50 COMPZN RPCOMP HOSO P PU to shear the seal assembly out of 6,940.0 6,836.0 11:00 11:30 PBR with 115K(25K over string weight)while holding 1700 psi on tubing(PU=88K and SO=70K). SO, locate out,and mark the pipe for space out(no pups needed for space out). 11/30/2015 11/30/2015 0.50 COMPZN RPCOMP RURD P Blow down circulating equipment and 6,836.0 6,836.0 11:30 12:00 RD circulating equipment. 11/30/2015 11/30/2015 0.50 COMPZN RPCOMP THGR P MU the tubing hanger and landing 6,836.0 6,839.0 12:00 12:30 joint. 11/30/2015 11/30/2015 0.50 COMPZN RPCOMP RURD P RU circulating equipment to reverse 6,839.0 6,839.0 12:30 13:00 circulate for corrosion inhibitor. Page 6/8 Report Printed: 3/15/2016 • • = Drilling Operations Summary (with Timelog Depths) w={ &We11t 1F-09 ConocoPhitips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/30/2015 11/30/2015 1.50 COMPZN RPCOMP CRIH P Reverse circulate 186 bbls of 10.9 ppg 6,839.0 6,839.0 13:00 14:30 corrosion inhibited brine down annulus taking return up the tubing at 3 BPM= 414 psi and chase with 10 bbls brine to clear lines. 11/30/2015 11/30/2015 0.75 COMPZN RPCOMP THGR P Land the tubing hanger and RILDS. 6,839.0 6,860.0 14:30 15:15 11/30/2015 11/30/2015 0.75 COMPZN RPCOMP RURD P Blow down and RD all circulating 0.0 0.0 15:15 16:00 equipment. Lay down the landing joint. 11/30/2015 11/30/2015 2.00 COMPZN RPCOMP PRTS P Close the blind rams. PT the tubing to 0.0 0.0 16:00 18:00 3000 psi for 15 minutes(good test), bleed the tubing to 1500 psi,and PT the IA to 2500 psi for 30 minutes (good test). Bleed the IA to 0 psi, bleed the tubing to 0 psi,and quickly ramp up the pressure to shear the SOV(sheared at 2200 psi). 11/30/2015 11/30/2015 0.75 COMPZN RPCOMP RURD P Blow down all the lines and drain the 0.0 0.0 18:00 18:45 BOP stack. 11/30/2015 11/30/2015 0.25 COMPZN WHDBOP MPSP P Install 3"ISA BPV with dry rod. 0.0 0.0 18:45 19:00 11/30/2015 11/30/2015 2.00 COMPZN WHDBOP NUND P Pull mouse hole and pull the riser. ND 0.0 0.0 19:00 21:00 the BOP stack,ND DSA,set BOP stack back on the stump,and secure to the stump. SimOps: Weld crack in hub on wheel #7. 11/30/2015 11/30/2015 0.75 COMPZN WHDBOP NUND P NU the tubing head adapter. 0.0 0.0 21:00 21:45 11/30/2015 11/30/2015 0.25 COMPZN WHDBOP PRTS P PT the void to 250/5000 psi(good 0.0 0.0 21:45 22:00 test). 11/30/2015 11/30/2015 1.00 COMPZN WHDBOP NUND P NU the 3-1/8"tree. 0.0 0.0 22:00 23:00 11/30/2015 11/30/2015 0.50 COMPZN WHDBOP MPSP P Pull the BPV and install the tree test 0.0 0.0 23:00 23:30 plug with dry rod. 11/30/2015 12/1/2015 0.50 COMPZN WHDBOP OTHR P RU tree testing equipment and fill the 0.0 0.0 23:30 00:00 tree with diesel. 12/1/2015 12/1/2015 0.50 COMPZN WHDBOP PRTS P PT the tree to 250/5000 psi(good 0.0 0.0 00:00 00:30 test). 12/1/2015 12/1/2015 0.25 COMPZN WHDBOP OTHR P RD tree test equipment. 0.0 0.0 00:30 00:45 12/1/2015 12/1/2015 0.25 COMPZN WHDBOP MPSP P Pull tree test plug with dry rod. 0.0 0.0 00:45 01:00 12/1/2015 12/1/2015 0.50 COMPZN WHDBOP FRZP P RU Little Red Service and lines in the 0.0 0.0 01:00 01:30 cellar to freeze protect the well with diesel. 12/1/2015 12/1/2015 1.25 COMPZN WHDBOP FRZP P PJSM. PT LRS line to 3500 psi(good 0.0 0.0 01:30 02:45 test). Pump 75 bbls of diesel down the IA taking return up the tubing to the kill tank at 2 BPM(ICP=800 psi and FCP=1250 psi). 12/1/2015 12/1/2015 1.25 COMPZN WHDBOP FRZP P RD LRS. Place the tubing and IA in 0.0 0.0 02:45 04:00 communication allowing the well to u- tube and equalize.Final well pressures: Tubing=0 psi, IA pressure=0 psi,and OA=34 psi. 12/1/2015 12/1/2015 0.25 COMPZN WHDBOP FRZP P Blow down all lines and RD circulating 0.0 0.0 04:00 04:15 lines. Page 7/8 Report Printed: 3/15/2016 • Drilling Operations Summary (with Timelog Depths) &wells 1F-09 ConocoPhillips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/1/2015 12/1/2015 0.25 COMPZN WHDBOP MPSP P Install 3"ISA BPV with dry rod. 0.0 0.0 04:15 04:30 12/1/2015 12/1/2015 1.50 DEMOB MOVE RURD P RD cellar lines,and RD annulus valve, 0.0 0.0 04:30 06:00 Install FMC manifold,secure well,and secure cellar. Release the rig at 06:00 hours. Page 8/8 Report Printed: 3/15/2016 AWTE OF ALASKA KRU 1F-09 KA OIL AND GAS CONSERVATION COMIItION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon fl Plug Perforations E Fracture Stimulate r Pull Tubing E Operations Shutdown Performed: Suspend Perforate IT Other Stimulate I' Alter Casing F Change Approved Program Plug for Red rill I, Perforate New Pool IT Repair Well IF Re-enter Susp Well Other:Resin Packer F. 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory IT 183-104 3.Address: 6.API Number: Stratigraphic Service P. O. Box 100360,Anchorage,Alaska 99510 50-029-20983-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25652 KRU 1F-09 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 7600 feet Plugs(measured) 7035, 7247 true vertical 6327 feet Junk(measured) None Effective Depth measured 7462 feet Packer(measured) 6863, 7229 true vertical 6203 feet (true vertical) 5668, 5995 Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 16 107 107 0 0 SURFACE 2309 9.625 2341 2147 0 0 PRODUCTION 7512 7 7544 6277 0 0 0 0 0 0 0 0 SCANNED MAR 0 2 ZU16 0 0 0 Perforation depth: Measured depth: 7144--7172,7276-7289, 7304-7351, 7305--7331, 7337-7341, 7347-740 ie•�v True Vertical Depth: 5919-5944,6037-6049,6062-6104,6092-6095,6101-6105 1 DEC6 ' Tubing(size,grade,MD,and TVD) 3.5,J-55, 7253=MD, 6017=TVD ,i CC Packers&SSSV(type,MD,and TVD) PACKER-Otis RRH@7012 MD and 5800 TVD, PACKER-Otis WD @ 7229=MD, 5995=TVD TRDP-CAMCO TRDP-1A @ 1911 MD and 1814 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation waiting fac hookup 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory Development F Service Stratigraphic IT Copies of Logs and Surveys Run 16.Well Status after work: Oil 17 Gas r WDSPL I— Printed and Electronic Fracture Stimulation Data GSTOR WINJ r WAG GINJ IT SUSP IT SPLUG F- 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: 315-501 Contact John Peircec 265-6471 Email John.W.PeirceCa�conocophillips.com Printed Name John W. Peirce Title Sr. Wells Engineer Signature 724.Z.r� Phone:265-6471 Date 12! AL/�o'I S- ---� -� 1/71- t /4./l6 Form 10-404 Revised 5/2015L. „ DEC 2120 5 Submit Original Only 4//iii RBDMS g • • Nor'- COnOCOPIIIIIIPSWell History 1F-09 :500292098300 : 12/16/2015 Date Event 9/23/2015 PULLED DV&SET CV(5/16" CHOKE) @ 6949' RKB; PULLED CATCHER @ 7031' RKB; DUMP BAIL SILICA SAND FROM 7035''7031' RKB. IN PROGRESS. 9/24/2015 DUMP BAIL SILICA SAND FROM 7031''7001' RKB. IN PROGRESS. 9/25/2015 DUMP BAIL SILICA SAND FROM 7001'^'6986' RKB. READY FOR COIL. 10/18/2015 (PRE-RWO) FUNCTION T AND IC LDS OK,T POT PASSED,T PPPOT PASSED, IC POT PASSED, IC 10/26/2015 After numerous job delays,was finally able to successfully pump about .35 bbls of 10.5 ppg 10/27/2015 REPLACED 1" CV @ 6949' RKB WI 1" DV. DHD UP NEXT AFTER ALLOWING RESIN TO CURE FOR 7 DAYS PRIOR TO MIT-T/MIT-IA, IN PROGRESS. 11/4/2015 (AC EVAL) MITT PASSED TO 2500 PSI,T DDT FOR BUR, MITIA PASSED TO 2500 PSI, IA DDT FAILED. 11/12/2015 FUNCTION TEST TRDP-1A TR-SSSV,VALVE APPEARS STUCK OPEN AND NON-FUNCTIONING PULLED STA.#5 BK-DUMMY @ 6,949' RKB LRS PUMPED 50 BBLS INHIBITED SEAWATER, 70 BBLS DIESEL DOWN TBG, U-TUBE FOR FREEZE PROTECT. FIRED 10'STRING SHOT OVER INTERVAL FROM 6,926'TO 6,937' RKB. IN PROGRESS. 11/13/2015 CUT TBG W/CHEM CUTTER @ 6,934' RKB SET 2.85" ISOLATION SLEEVE IN TR-SSSV @ 1,911' RKB. READY FOR BPV.JOB COMPLETE. 12/5/2015 SET BAITED PIT ON BALL'N ROD @ 6914' RKB. PULLED SOV&SET OV @ 6774' RKB. PULLED DVs @ 6305', 5582',4487', 2841' RKB&SET GLVs. IN PROGRESS. 12/6/2015 PULLED BALL'N ROD & RHC PLUG BODY @ 6914' RKB. SET DV @ 6949' RKB. MITT TO 2500 PSI ( PASS) BAILED FILL& METAL DEBRIS @ 6960'SLM. IN PROGRESS. 12/8/2015 BAILED FILL FROM 6964'^'6976' SLM. IN PROGRESS. 12/9/2015 BAILED FILL FROM 6975'^'6981' SLM. IN PROGRESS. 12/10/2015 BAILED FILL FROM 6982'^'6990' SLM. IN PROGRESS. 12/11/2015 BAIL FILL FROM 6990' ^'7004'SLM. IN PROGRESS. 12/12/2015 BAILED FILL FROM 7004'^'7009'SLM. ATTEMPT EQ WRP. IN PROGRESS. 12/13/2015 BAIL FILL& PULLED WRP @ 7035' RKB; MEASURE BHP @ 7150' RKB(3295 PSI).JOB COMPLETE. KUP PROD • 1F-09 Con©coPhdtips a Well Attributes Max Angle&MD TD Alaska,Inc, : Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) c.«r+xo')lui8ps 500292098300 KUPARUK RIVER UNIT I PROD 47.13 3,600.00 7,600.0 ... Comment 8125(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1F-09,411 6/201 5 8:11;16 AM SSSV:TRDP 75 12/13/2013 Last WO: 33.21 9/1/1983 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date casing 1,00Last Tag.SLM 7,374.0 7/15/2014 Rev Reason:GLV C/O hipshkf 4/16/2015 HANGER;210 i'.:tiii asing rings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread ut.Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread uuauaunuuamu �! �� ” CONDUCTOR 16 15.060 32.0 107.0 107.0 63.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 32.0 2,341.0 2,146.6 40.00 J-55 BTC • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6276 32.0 7,544.0 6,276.6 26.00 J-55 BTC n -A ,CONDUCTOR;32.0-107.0• Tubing Strings if 1 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/tt) Grade Top Connection TUBING 3 1/2 2.992 21.0 7,2532 6,017.0 9.30 J-55 EUE8rd SAFETY VLV;1,911.1 ;3° Completion Details ILSE Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Corn (in) GAS LIFT;1,980.6 21.0 21.0 0.08 HANGER FMC TUBING HANGER 3.500 1,911.1 1,813.5 37.99 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE 2.813 6,985.8 5,777,0 26.84 SBR OTIS SBR 2.813 7,012.1 5,800.5 26.46 PACKER OTIS RRH PACKER 2.970 7,121.3 5,898.7 25.88 BLAST RINGS BLAST RING(2) 2.867 SURFACE;32.0-2,341.0 7,227.6 5,994.0 26.53 SEAL ASSY OTIS LOCATOR SEAL ASSEMBLY 3.000 GAS LIFT;4,002.5 7,229.0 5,995.3 26.53 PACKER OTIS WD PACKER 4.000 7,232.8 5,998.7 26.54 MILL EXT MILL OUT EXTENSION 2.992 GAS LIFT;5,565.6 lin 7,232.8 6,011.7 26.56 NIPPLE OTIS XN NIPPLE NO GO(Set 2.81"PXN Plug 9-25-14) 2.750 7,252.3 6,016.1 26,57 SOS BROWN SHEAR OUT SUB,ELMD TTL @7251'during 3.015 GAS LIFT;6,282.8 PPROF on 5/30/2008 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;6,949.0 Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) 47,031.0 5,817.5 26.19 CATCHER 2.80"CATCHER(OAL-48") 1/19/2015 SBR;6,985.8 7,035.0 5,821.1 26.13 PLUG 2.78"WEATHERFORD WRP 2/11/2015 0.000 PACKER;7,0121 7,247.3 6,011.7 26.56 PLUG 2.81"PXN PLUG 9/25/2014 0.000 Perforations&Slots Shot CATCHER;7,031.0 kl�li Dens PLUG;7,036.0 iTop(TVD) Btm(ND) (shotstt l � Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,144.0 7,172.0 5,919.1 5,944.3 C-4,UNIT B, 10/15/1983 12.0 IPERF DA 5"csg gun;120 deg. 1F-09 Phasing PRODUCTION;7,047.9 - 7,276.0 7,289.0 6,037.3 6,049.0 A-4,1F-09 11/30/1983 4.0 IPERF Dresser thru tbg;0 deg. alPh PRODUCTION;7,114.1 - 7,304.0 7,351.0 6,062.4 6,104.3 A-4,1F-09 6/16/1984 4.0 RPERF RigidJet;90 deg'V'Phase 7,305.0 7,331.0 6,063.3 6,086.5 A-4,1F-09 11/30/1983 4.0 IPERF Dresser thru tbg;0 deg. IPERF;7,144.0-7,172.0- Ph 7,337.0 7,341.0 6,091.8 6,095.4 A-4,1F-09 11/30/1983 4.0 IPERF Dresser thru tbg;0 deg. Ph ll 7,347.0 7,352.0 6,100.8 6,105.2 A-4,1F-09 11/30/1983 4.0 (PERF Dresser thru tbg;O deg. PRODUCTION;7,190.8 I Ph Mandrel Inserts SEAL ASSY;7,227.6 = St a __- h on Top(ND) Valve Latch Port Size TRO Run NTop(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com PACKER;7,229.0 6- l/ 1,980.6 1,868.1 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 4/13/2015 2 4,082.5 3,369.9 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 4/13/2015 MILL EXT;7,232.8 � 'f�# 3 5,565.8 4,582.4 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 4/13/2015 4 4 6,282.8 5,171.4 OTIS WBD 1 GAS LIFT DMY INT 0.000 0.0 4/13/2015 NIPPLE; 5 5,744.3 OTIS WBD 1 GAS MY BK 0.000 0.0 3/12/2015 LUG7,2423'., 7 6,949.0047.1 5,8922 OTIS WBD 1 PROD HFCV DFCV BEK 0.000 0.0 9/26/2014 PLUG;7,247.3 6 7,047.9 5,832.6 OTIS WBD 1 PROD HFCV BEK 0.000 0.0 9/27/2014 8 7,190.8 5,961.1 OTIS WBD 1 PROD HFCV BEK 0.000 0.0 9/26/2014 Notes:General&Safety Vi End Date Annotation SOS.7,252.3 9/10/2010 NOTE:View Schematic w/Alaska Schematic9.0 IPERF;7,276.0.7,289.0 • IPERF;7,305.0-7,331.0-..-- . RPERF;7,304.0-7,351.0 IPERF;7,337.07,341.0-- IPERF;7,347.07,352.0 PRODUCTION;32.0-7,544.0-• tiOF Thr �wI�j�4. THE STATE Alaska Oil and Gas N��►��� ofAT ASKA Conservation Commission z _ __ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 � ���1NNMain: 907.279.1433 ALAS ,1�l) Fax: 907 276.7542 www aogcc.alaska.gov John Peirce Sr. Wells Engineer E 8 3 .- f 0 ConocoPhillips Alaska, Inc. V P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1F-09 Sundry Number: 315-5 01 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 7°7q€4/ Cathy . Foerster Chair DATED this Zity of August, 2015 RBDM " SEP 0 4 2015 Encl. STATE OF ALASKA 1 I ,KA OIL AND GAS CONSERVATION COMh„..)SION • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Flug Perforations r Fracture Stimulate r Pull Tubing rOperations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing FrChange Approved Program r Rug for Redrill r Perforate New Pool r Repair Well IV Re-enter Susp Well r Other. Resin Packer Fii• 2.Operator Name: 4.Current Well Class: 5 Permit to Drill Number: ConocoPhillips Alaska, Inc. - Exploratory r Development r. 183-104 • 3 Address. Stratigraphicr Service r 6.API Number P.O. Box 100360,Anchorage,Alaska 99510 50-029-20983-00 • 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 pi I KRU 1 F-09- 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25652 . Kuparuk River Field/Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft). Total Depth TVD(ft). Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 7600 • 6327• 7462'. 6203'• 7035',7247' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 16 107' 107' SURFACE 2309 9.625 2341' 2147' R E C E V E D PRODUCTION 7512 7 7544' 6277' G ?Oh ( C Au.AOGCC Perforation Depth MD(17144-7172,7276-7289, Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft). 7304-7351,7337-7341,7347-7352 ' 5919-5944,6037-6049,6062-6104,6092-6095,6101-6105 3.5 J-55 7253 Packers and SSSV Type. Packers and SSSV MD(ft)and TVD(ft) PACKER-OTIS RRH PACKER ' MD=7012 TVD=5801 PACKER-OTIS WD PACKER • MD=7229 TVD=5995 SAFETY VLV-CAMCO TRDP-1A SAFETY VALVE 4 MD=1911 TVD=1814 12.Attachments Description Surrmary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development rJ r Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work. 9/1/2015 OIL F. VVINJ r WDSPL r Suspended r 16.Verbal Approval: Date' GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Email: John.W.Peirce@conocophillips.com Printed Name John Peirce Title. Sr. Wells Engineer SignatureC4 tf •. — Phone:265-6471 Date g 1171 S .� I Commission Use Only Sundry Number. Conditions of approval: Notify Commission so that a representative may witness S l -50k Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: /.0 — 4 Q 4 APPROVED BY Approved by: "€1.0"E"'•--- COMMISSIONER THE COMMISSION Date: 8-2_ -1,5J ✓"�L $ Approved a�pllc i lon is yaltd for 11month 011/5 the date ofi approval �� R G NAL 1 mit uaAd Form 10-403 Revised /20 �g� � RBD' I . inb .�iciie4 2015 I. KUP PROD 1F-09 ConocoPhillips I Well Attributes Max Angle&MD TD • Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl)) MD(MB) Act Btm(ftKB) L-k.nTs 500292098300 KUPARUK RIVER UNIT PROD 47.13 3,600.00 7,600.0 .-. �. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 1F-09,4/16/20158:11.16 AM SSSV:TRDP 75 12/13/2013 Last WO: 33.21 9/1/1983 Vertical schemalc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Casing 1;0.0 - Last Tag:SLM 7,374.0 7/15/2014 Rev Reason.GLV C/O hipshkf 4/16/2015 ...._... m HANGER,21.0 •�_M, Casing Strings Casing Description OD(in) 10(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread „ '' . I , �r Casing Description141• SOD(in) ID(in) TopftKB Set Depth 8KB Set Depth(ftKB) p ( ) p (ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.060 32.0 107.0 107.0 63.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(EKE) Set Depth(ND)...WtlLen(1...Grade Top Thread I SURFACE 95/8 8.835 32.0 2,341.0 2,146.6 40.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 32.0 7,544.0 6,276.6 26.00 J-55 BTC is-A-0 CONDUCTOR;32.0/azo• + Tubing Strings �� Tubing Description String Ma...ID(in) Top(RKB) Set Depth(ft..Set Depth(ND)(...Wt Ob/ft) Grade Top Connection TUBING 3 1/2 2.992 21.0 7,253 2 6.017.0 9.30 3-55 EUE8rd SAFETY VLV;1,911.1 NMI Completion Details Nominal ID = o Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Com (In) GAS LIFT:1980.6 I� 21.0 21.0 0.08 HANGER FMC TUBING HANGER 3.500 1,911.1 1,813.5 37.99 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE 2.813 6,985.8 5,777.0 26.84 SBR OTIS SBR 2.813 7,012.1 5,800.5 26.46 PACKER OTIS RRH PACKER 2.970 7,121.3 5,898.7 25.88 BLAST RINGS BLAST RING(2) 2.867 SURFACE;32.0-2,341.0-A 7,227.6 5,994.0 26.53 SEAL ASSY OTIS LOCATOR SEAL ASSEMBLY 3.000 GAS LIFT;4,082.5 7,229.0- 5,995.3 26.53 PACKER OTIS WD PACKER 4.000 7,232.8 5,998.7 26.54 MILL EXT MILL OUT EXTENSION 2.992 GAS LIFT;5,565.8 7,247.3 6,011.7 26.56 NIPPLE OTIS XN NIPPLE NO GO(Set 2.81"PXN Plug 9-25-14) 2.750 7,252.3 6,016.1 26.57 SOS BROWN SHEAR OUT SUB,ELMD TTL @7251'during 3.015 GAS LIFT;6,282.8PPROF on 5/302008 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;6.949.0 - Top(TVD) Top Incl Top(ftKB) (ftKB) (") Des Com Run Date ID(in) illi 7,031.0' 5,817.5 26.19 CATCHER 2.80"CATCHER(OAL-48') 1/19/2015 SBR;6,985.6 titin 7,035.0 5,821.1 26.13 PLUG 2.78"WEATHERFORD WRP 2/11/2015 0.000 PACKER;7,012.1 7,247.3 6,011.7 26.56 PLUG 2.81"PXN PLUG 9/25/2014 0.000 Perforations&Slots CATCHER;7,031.0 �Ir. I Shot ns PLUG;7.035.0- �� Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date U Type Com 7,144.0 7,172.0 5,919.1 5,944.3 C-4,UNIT B, 10/15)1983 12.0 IPERF DA 5"csg gun;120 deg. 1F-09 Phasing PRODUCTION;7,047.9 t - 7,276.0 7,289.0 6,037.3 6,049.0 A-4,1F-09 11/30/1983 4.0 IPERF Dresser thru tbg;O deg. Ph PRODUCTION;7,114.1 MI - 7,304.0 7,351.0 6,062.4 6,104.3 A-4,1F-09 6/16/1984 4.0 RPERF RigidJet;90 deg'V'Phase _ 7,305.0 7,331.0 6,063.3 6,086.5 A-4,1F-09 11/30/1983 4.0 IPERF Dresser thru tbg;0 deg. IPERF;7.144.0.7,172.0- Ph 7,337.0 7,341.0 6,091.8 6,095.4 A-4,1F-09 11/30/1983 ' 4.0 IPERF Dresser thru tbg;0 deg. Ph 7,347.0 7,352.0 6,100.8 6,105.2 A-4,1F-09 11/30/1983 4.0 IPERF Dresser thru tbg;0 deg. PRODUCTION;7,190.8 117- Ph Mandrel Inserts SEAL ASSY;7,227.6 St ati Iii on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (8K8) Make _ Model OD(in) Sew Type Type (in) (psi) Run Date Corn PACKER;7,229.0 '_ t' 1,980.6 1,868.1 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 4/13/2015 MILL E%7;7,232.8 r 2 4,082.5 3,369.9 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 4/13/2015 _ 3 5,565.8 4,582.4 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 4/13/2015 4 6,282.8 5,171.4 OTIS WBD 1 GAS LIFT DMY INT 0.000 0.0 4/13/2015 5 5,744.3 OTIS WBD 1 GAS DMY BK 0.000 0.0 3/12/2015 NIPPLE;7,247.3 1/; 7 6, 4.0 5,892.2 OTIS WBD 1 PROD HFCV BEK 0.000 0.0 9/26/2014 PLUG;7,247.3 6 7,047.9 5,832.6 OTIS WBD 1 PROD HFCV BEK 0.000 0.0 9/27/2014 8 7,190.8 5,961.1 OTIS WBD 1 PROD HFCV BEK 0.000 0.0 9/26/2014 Notes:General&Safety End Date Annotation SOS;7.252.3 9/10/2010 NOTE:View Schematic w/Alaska Schematic9.0 IPERF;7.2760.7.289.0 IPERF;7,306.0-7,331.0L_ RPERF;7,304.0-7351.0 IPERF;7,337.0-7,341.0 IPERF;7,347.0.7,352.0- 1 PRODUCTION,32.0.7,544.0 1F-09 Resin Repair of Leaky Packer 1F-09 is a Kuparuk A and C Sand producer with 3.5", J-55 tubing that was originally completed in 1983. 1F-09 was a CTD candidate in late 2014, but it developed annular communications in late 2014, and has been LTSI since 2014 for annular communication diagnostics. On 2/11/15 a wireline retrievable Plug was set at 7035' RKB, and then a CMIT to 2500 psi passed. 1F-09 was circulated out on 2/12/15 with Seawater & Diesel through open GLM #5 at 6949' RKB, and then a 2/13/15 T x IA DDT failed. On 3/12/15, a DV was set at 6949' to dummy off tubing and a MITT to 2500 psi passed. DDT-T's also passed, but IA-DDT's failed (LLR -0.13 gpm at 0 psi on IA). On 7/8/15, an acoustic leak detect log was run and a sonic anomaly was seen at the Packer at 7012' RKB indicating that a 1-way' Packer leak was causing failing IA-DDT's. It is proposed that Resin will be placed on top of the leaky Packer to seal the leak. Resin jobs have sealed off similar leaks in other Kuparuk wells. Procedure Slickline: 1) RIH & pull the DV at 6949' RKB. On 2/11/15, a Catcher Sub was left set on WRP at 7035'RKB. 2) RIH & set a fully open orifice HFCV in GLM #5 at 6949' RKB. 3) Pull the Catcher Sub at 7031' RKB. 4) Make dump bailer runs to bail in a sand plug on top of the WRP at 7035' RKB. Final acceptable TOS should be in the 6985 - 6995' RKB range. The objective of the long sand plug (minimum 40' OAL) is to ensure that Resin can't contact the WRP at 7035' RKB. This will require 2 SL days. Tag final TOS to verify that it's in the acceptable target window. Coil Tubing: 5) MIRU CTU. Stab CT on well. Displace all cold Diesel FP from CT with 1 CT volume (-40 bbls) of warm 140°F Diesel to the nozzle at -2 bpm while taking displaced Diesel from CT to tanks. With CT loaded with warm Diesel, open the Tbg x CT annulus to tanks and open the swab to RIH with large port nozzle. Continue circulating -250 bbls of warm Diesel down CT to 1 bpm until reaching 2000' RKB to start warming up the wellbore while displacing cooler wellbore fluid out to tanks. Once CT is below 2000' RKB, start circulating to 2 bpm while RIH. Slow rate and then stop all circulating as nozzle approaches 6900 RKB. RIH to tag TOS at -6990' RKB, flag pipe, and then PU to park nozzle at 6900' RKB. Resume circulating warm Diesel to 2 bpm until 250 bbls of warm 140°F Diesel has been circulated to continue warming the well to suitable temperature for Resin placement. A minimum 50°F temperature must be maintained at all points in the CT to ensure maintaining good Resin integrity as it is pumped into the well. With 250 bbls warm Diesel away, SI Tbg x CT, and open the IA to tanks. Pump a 1 or 2 bbls of warm Diesel down CT to 0.5 bpm while taking returns from IA to tanks to verify that the HFCV is open and unobstructed. Start mixing Resin after this verification is complete. SI the IA, and open Tbg x CT annulus to tanks, and continuing pumping the following schedule down CT: a) 30 bbls of 140°F Diesel down CT at 2.0 bpm. The 30 bbl volume pumped ensures that the well stays warm for Resin pumping while a Resin batch is being prepared (-20 minutes to mix), followed by b) 10 bbls of (140°F target) Lead Corrosion Inhibited Water (CIW) Spacer down CT at 2.0 bpm (to avoid a Diesel interface with Resin to maintain good Resin integrity), followed by c) 1.5 bbls of warm 10.5 ppg activated Resin at 1.5 - 2.0 bpm while monitoring bbls pumped accurately as possible to enable measuring when Resin arrives at nozzle. Continue pumping, d) 10 bbls of (140°F target) Tail Corrosion Inhibited Water Spacer at 1.5 - 2.0 bpm, followed by e) 10 bbls of 140°F Diesel down CT down CT at 1.5 - 2.0 bpm, followed by f) 10 bbls warm 50 / 50 mix of Resin Solvent / Freshwater down CT at 1.5 - 2.0 bpm, followed by g) XX bbls warm 140°F Diesel Displacement to fill up remaining CT volume. When Resin gets 1 bbl from the nozzle, drop warm Diesel pump rate to 0.3 bpm and RIH -75' from 6900' to 6975' RKB, to just above TOS. As Resin begins exiting nozzle falling onto TOS at -6990' RKB, POOH from 6975' to 6949' RKB at -35 fpm as the first 0.35 bbl of Resin is spotted into the 41' of tubing 'dead leg' between TOS to GLM #5, then park nozzle at 6949', then SI Tbg x CT and open IA to tanks to pump the last 1.15 bbls of Resin from CT at 0.3 bpm to spot Resin to IA through CV at 6949' RKB. SI the IA as soon as all Resin has exited the CT. SI IA and open Tbg x CT annulus to tanks, and then pump 1 more barrel of warm Diesel down CT to ensure that all Resin has exited the CT. POOH with nozzle to safety at 6449' RKB (-500' above Resin) while replacing voidage 1:1 with 140°F Diesel pumped down CT. When the nozzle is parked at 6449' RKB, SD all pumping for 30 minutes to let the 10.5 ppg Resin swap down the IA onto the Packer. As the 1.15 bbls of dense Resin swaps down the IA, it will displace out lower density fluid above the Packer to Resin fill IA from the top of the leaky Packer at 7012' RKB to near the base of GLM #5 at 6956' RKB. This IA volume is -1.15 bbls. With Resin stacked on the Packer to no higher than base of GLM #5 we may enable preservation of future functionality of GLM #5 after the Resin placement. After 30 minutes waiting on Resin swap, verify Tbg x CT annulus is open to tanks, then resume pumping warm Diesel down CT at 1.5 bpm while RIH to park nozzle at GLM #5 at 6949' RKB as 50/50 Solvent mix begins to exit nozzle. Reciprocate nozzle across HFCV, then RIH to jet down to TOS at -6990' RKB to contaminate all Resin in tubing dead leg, then PU to wash the remaining solvent over HFCV at 6949' to clear the pocket area of Resin. The solvent mix contaminates and prevents Resin curing in the tubing and clears Resin from CT. With the nozzle parked at 6949' RKB, continue pumping warm Diesel at 1.5 bpm while taking returns from the Tbg x CT annulus to displace all contaminated Resin and solvent mix from the tubing until clean Diesel is seen at surface. This should require < 60 bbls of Diesel pumping. 2 With clean Diesel returns observed at surface to tanks, SI the Tbg x CT annulus and open the IA to tanks. Continue pumping another 5 bbls of warm Diesel down CT at 0.5 bpm through the HFCV to the IA, then SD pumping and -close the IA. This Diesel pumping flushes the HFCV clear of contaminated Resin and verifies good circulation remains through the HFCV. Open the Tbg x CT. POOH with CT while replacing voidage with Diesel. Put tubing & IA in communication at surface to U-tube and equalize tubing & IA FP. RD CTU. q Slickline: 6) On the morning after CT Resin pumping, RU SL & pump 10 bbls Diesel down tubing at 1 bpm while taking returns from IA to verify good circulation exists through the CV. By design, a 7 day Resin set time has delayed Resin curing. Make run 1 to brush GLM #5 pocket at 6949' RKB to remove any remaining residual Resin around the HFCV. Make run 2 to set Catcher Sub on Plug at 6990' RKB. Make run 3 to pull HFCV from GLM #5 pocket at 6949' RKB. Make run 4 to set DV in GLM #5 pocket at 6949' RKB. Do not perform any MIT's or IA DDT's after a successful DV set. Pressure tests should wait for at least 1 week to prevent possible induced micro-annuli creation through the IA Resin Plug placement before Resin has had enough time to fully cure. Make run 5 to pull Cather Sub. RD SL. DHD: 7) If the DV was set (step 6) and the Resin has had at least 7 days to fully cure, perform an MIT-T to 2500 psi, MITIA to 2500 psi, and an IA-DDT. If all pressure tests pass, proceed to step 8. Coil Tubing: 8) RIH with jet swirl nozzle jet out sand plug to WRP at 7035' RKB. POOH & RD CTU. Leave the WRP set at 7035' RKB to keep the well secured. Review and verify the status of 1F-09 wellhead and tree equipment with regard to maintenance and/or equipment replacement that may still be pending before performing WRP removal. 3 Irt ect Well History File' e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original filei may be scanned during a special rescan activity or are viewable by direct inspection of the file. J _~.~- _/~_ ~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [3 Maps: [] Grayscale items: [3 Other, No/Type [3 Other items scanne hie by large scanner [] Poor Quality Originals: .... OVERSIZED (Non-Scannable) [] Other: NOTES: '[3 : Logs of various Rinds [] Other BY: ~BREN VINCENT SHERYL MARIA LOWELL DATE'.~-/ /SI Project Proofing -. BY: BEVERLY BREN VINCEN~ARIA LOWELl_ D ATE :~'"~_ /S/ Scanning Preparation .,~._.~ x 30 : ~() + ~-~.~ = TOTAL PAGES <~(~ Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: X YES NO BY: ~BREN VINCENT SHERYL MARIA LOWELL Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY: BEVERLY BREN VINCEN MARIA LOWELL DATE RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ~SI General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3NOTScanned.wpd i ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Jan 2, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~~~ SAN ~ 2009 Dear Mr. Maunder: C RECEIVED JAN 0 7 2009 Alaska Oil ~ Gas Cons. Commission Anchorage Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter 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. Similarly, It was noticed In August 2007 that 5 wells on DS 1 C had similar cement and sealant treatments. These wells were inadvertently omitted from the 10-404 submitted at that time for other work being performed. These wells are included here. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, \. Perry K1 ' _ ConocoPhillips Well Integrity Supervisor • . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1F-09 #I83-104 11" na 11" na 1.70 12/7/2008 1 F-14 183-146 18" na 18" na 2.00 12/7/2008 1 F-17 196-047 8" na 8" na 1.70 12/7/2008 1 F-19 196-052 8" na 8" na 1.70 12/7/2008 1 F-20 196-053 6" na 6" na 1.00 12/7/2008 1C-111 201-128 5' 9" 0.50 18" 8/27/2007 21.00 8/29/2007 1 C-13 198-011 32' 10" 4.00 18" 8/27/2007 17.00 8/29/2007 1 C-14 206-001 14' 6" 2.00 18" 8/27/2007 9.00 8/29/2007 1 C-21 205-034 38' 10" 4.00 18" 8/27/2007 8.60 8/29/2007 1 C-23 199-034 10' 10" 1.50 18" 8/27/2007 23.00 8/29/2007 ~ ~. 06/10/08 NO. 4741 ~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~~N~~ JUN ~. ~ 2D0~ Well Job # Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 2W-13 11970689 GLS/PROD PROFILE - 05/27/08 1 1 3J-17 11970690 GLS/PROD PROFILE /~ - C~ 05/28/08 1 1 2M-08 11996642 PROD PROFILE/DEFT / / ~ l/ 06/03/08 1 1 16-10 11994672 PROD PROFILE/DEFT ._ G 05/31/08 1 1 1 A-20 11994673 PROD PROFILE/DEFT - / 06/01/08 1 1 1G-13 11994674 PROD PROFILE/DEFT 3 ~ ~(0~/5/~ 06/02/08 1 1 1A-03 11994673 PRODPROFILE/DEFT - /(®s./~s.~ 06/04/08 1 1 2W-17 11996644 PROD PROFILE/DEFT .-I ~ ®~G/ 06/05/08 1 1 iC-125 11994677 INJECTION PROFILE T y`!(®~(0 06/05/08 1 1 iC-127 11994675 INJECTION PROFILE _ L `(®L® ~ 06/03/08 1 1 iF-09 11994671 PROD PROFILElDEFT -/ /~~~ 05/30/08 1 1 iC-27 11994679 SBHP SURVEY `~ ,~1./ 06/07/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Scblullbepger 1 it! Œ~· / / ~------ 12/19/06 NO. 4077 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth vc' '\~~Þf' ~J ·:;:JiJ '~:J';.-' ~---,-~.;.,.' , M~¡Çompany: Alaska Oil & Gas Cons Comm l.UU5 Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 /153 --/éLj Field: Kuparuk Well Job# Date BL Color CD Log Description 1 R-03A (REDO) 11483497 INJECTION PROFILE 11/30/06 1 1 B-09 11483500 INJECTION PROFILE 12/03/06 1 3S-26 11538769 INJECTION PROFILE 12/10/06 1 1 F-04 11538770 INJECTION PROFILE 12/11/06 1 3S-08B 11538771 PRODUCTION PROFILE 12/12/06 1 3H-10B 11534187 PRODUCTION PROFILE 12108/06 1 1J-136 11534188 USIT 12/10/06 1 2M-12 11534189 PRODUCTION PROFILE 12/11/06 1 1F-10 11534192 INJECTION PROFILE 12/12/06 1 1 Y -27 N/A PRODUCTION PROFILE 12/14/06 1 2Z-20 N/A SBHP SURVEY 12/15/06 1 1 H-21 11551832 SBHP SURVEY 12/16/06 1 1 F-05 N/A INJECTION PROFILE 12/13/06 1 1F-09 11548550 PRODUCTION PROFILE 12/14/06 1 3S-03 11551831 PRODUCTION PROFILE 12/15/06 1 3J-18 11548550 PRODUCTION PROFILE 12/16/06 1 1H-14 11551835 SBHP SURVEY 12/18/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate __ Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 630' FNL, 484' FEL, Sec. 19, T11N, R10E, UM At top of productive interval 1132' FSL, 1208' FEL, Sec. 19, T11N, R10E, UM At effective depth 993' FSL, 1250' FEL, Sec. 19, T11N, R10E, UM At total depth 933' FSL, 1266' FEL, Sec. 19, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 109 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 F-09 9. Permit number/approval number 83-104 10. APl number 50-029-20983-00 11. Field/Pool Kuparuk River Field/Oil Pool 7600 feet Plugs (measured) None 6326 feet Effective depth: measured 7462 feet Junk (measured) None true vertical 6203 feet Casing Length Size Cemented Measured depth Structural Conductor 80' I 6" 175 Sx CS II 1 07' Surface 2 3 0 5' 9 - 5 / 8" 1000 Sx AS III & 2 3 41 ' Intermediate 250 Sx AS I Production 7511' 7" 675 Sx Class G 7544' Liner Perforation depth: measured 71 44'-7172',7276'-7289',7304'-7351 ' true vertical 591 9'-5944',6032'-6041',6054'-6100' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 7253' Packers and SSSV (type and measured depth) Pkrs: Otis RRH @ 7012' & Otis WD @ 7229'; SSSV: Camco TRDP-1A @ 1911' 13. Stimulation or cement squeeze summary True vertical depth 107' 2146' 6276' RECEIVED NOV 24 199 ' &G~ .... ^---"' Alaska Oil ~,~. 14. Refracture "A" sands on 6/19/97. Anchoragl~ Intervals treated (measured) ORIGINAL 7276'-7289',7304'-7351' Treatment description including volumes used and final pressure Pumped 198.6 M lbs 20/40, 12/18, & 10/14 ceramic proppant into formation, fp was 5800 psi. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3 9 8 178 187 1072 204 Subsequent to operation 6 2 6 770 403 1083 167 15. Attachments Copies of Logs and Surveys run__ Daily Report of Well Operations X 16. status of well classification as: Oil X Gas Suspended Service 17. I hereby,~ae~fy that the foregoing is true and correct to the best of my knowledge. Signed ~Z'"'J~_~ Title Wells Superintendent Form 1~4~~06~15/~ - SUBMIT IN DUPLICATE '-ARco Alaska, Inc. KUPARUK RIVER UNIT ~4~, WELL SERVICE REPORT ~ K 1 ( 1 F- 0 9 (W 4-6)) WELL JOB SCOPE JOB NUMBER 1 F-09 FRAC, FRAC SUPPORT 061 3972023.2 DATE DAILY WORK UNIT NUMBER 06/19/97 REFRACTURE "A" SANDS DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 (~) Yes O NoI (~ Yes O No DS-GALLEGOS BLACK__ ^,,Yoos ^oouMcos ESTIMATE KD1895 23ODS 10FL $1 40,909 $140,909 Initial Tb_q Press Final Tbq Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 928 PSI 3000 PSII 700 PSI 500 PSII 0 PSI 250 PSI DALLY SUMMARY I PUMPED "A" SAND FRAC. SCREENED OUT W/54.4 OF 61 BBLS WATER FLUSH PUMPED. INJECTED 198,581 LBS OF PROP IN I FORMATION W/11.7 PPA OF 10/14 @ PERFS. MAX PRESSURE 5800 PSI & FG @ .86 TIME LOG ENTRY 14:00 17:00 17:30 18:15 19:15 MIRU DS FRAC CREW, APC VAC TRUCK & LRS. HOLD SAFETY MEETING (14 ON LOCATION). PT BACKSIDE LINES TO 3000 PSI. SET TREESAVER & PT HI PRESSURE LINES TO 7800 PSI. ALL LOOKS GOOD. PUMP BREAKDOWN W/50# XL F/15 TO 28 BPM. MAX PRESSURE 5800 PSI & ENDING PRESSURE 3474 PSI. PUMPED TOTAL 432 BBLS. ISIP 2450 PSI IFG=.84). STAND BY & MONITOR PRESSURE F/CLOSURE (2220'PSI). PUMP DATAFRAC W/50# XL F/5 TO 15 BPM. MAX PRESSURE 3500 PSI & ENDING PRESSURE 3464 PSI. PUMPED TOTAL OF 126 BBLS. ISIP 2517 PSI (FG=.86). STAND BY & MONITOR PRESSURE F/CLOSURE. CALLED CLOSURE @ 14 MINUTES. ADJUSTED PAD TO 145 BBLS (ORIGINAL DESIGN @ 175 BBLS). PUMP FRAC W/50# XL F/5 TO 15 BPM. BEGAN TO PRESSURE UP DURING 10 PPA FLAT STAGE. BEGIN TO CUT ACTIVATOR. SCREENED OUT W/54.4 BBLS OF 61 BBL WATER FLUSH PUMPED. ISIP 3300 PSI. PUMPED TOTAL 1164 BBLS. PUMPED TOTAL OF 200,307 LBS PROP (16,684 LBS OF 20/40, 177,022 LBS OF 12/18 & 6601 LBS OF 10/14). INJECTED 198,581 LBS OF PROP IN FORMATION W/11.7 PPA OF 10/14 @ PERFS. LEFT 1726 LBS OF PROP IN WELLBORE. 21:00 BEGIN RD. DEPRESSURED IA TO 500 PSI & RD LRS. 22:00 23:00 REMOVE TREESAVER (ALL CUPS RETRIEVED). CONTINUE RD. RD COMPLETE. OFF LOCATION & WELL SECURED. TURN OVER TO PRODUCTION AWAITING CTU CLEAN OUT. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $8,300.00 $8,300.00 ARCO $250.00 $250.00 DOWE LL $126,859.00 $126,859.00 LR-FLE RED $5,500.00 $5,500.00 TOTAL FIELD ESTIMATE $140,909.00 $140,909.00 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Ui I61i AL August 12, 1991 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate is a Report of Sundry Well Operations for the well listed below. WELL ACTION 1 F-09 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer CC: M. E. Eck ATO 1176 S. M. Renke ATO 1126 KOE1.4-9 w/o attachments RECEIVED AUG 1 ,5 1991 Alaska 011 & Gas Cons. 6ommissien Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company AR3B-6003-C STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5, Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 630' FNL, 484' FEL, Sec. 19, T11N, R10E, UM At top of productive interval 4148' FNL, 1208' FEL, Sec. 19, T11N, R10E, UM At effective depth 4310' FNL, 1250' FEL, Sec. 19, T11N, R10E, UM At total depth 4347' FNL, 1260' FEL, Sec. 19, T11N, R10E, UM 6. Datum elevation (DF or KB) 109' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1F-09 9. Permit number/approval number 83-104 10, APl number 50-029-20983 11. Field/Pool Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor I 0 7' Surface 2 3 41 ' Intermediate Production 7 5 4 4' Liner Perforation depth: measured 7347-7352' true vertical 7 6 0 0 feet 6326' feet 7 4 6 2' feet 6203 feet Size Cemented Plugs (measured) None RECEIVED AUG 1,5 1991 Junk (measured) Norle Alaska.0il a Gas Cons. C0mmissi~ Anc. hor. age. Measured depth True vemca~ oeptl3 I 6" 175 Sx CS II 107' MD 107' TVD 9-5/8" 1000 Sx ASII 2341' MD 2146 TVD 7" 675 Sx Class G & 7544' MD 6276' TVD 150 Sx AS I 6100'-6103' , 6091-6099' , 6061'-6086' , 6037-6048 , 5919-5944 Tubing (size, grade, and measured depth) 3-1/2" J-55 BTC W/Tail @ 7253' MD Packers and SSSV (type and measured depth) OTIS WD pkr @ 7229'; OTIS RRH pkr @ 7012'; Camco TRDP-1A SSSV @ 1911' MD 13. Stimulation or cement squeeze summary Refracture 'A' Sand Intervals treated (measured) 'A' Sand from 7276' to 7352' MD RKB Treatment description including volumes used and final pressure 14. , 7337'-7341' , 7305'-7331' , 7276-7289' , 7144-7172' MD TVD Refracture 'A' Sand with 95M lbs. 12/18 Carbolite proppant and gelled water, FWHTP=4741 psi Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 900 / 470 40 900 150 1 770 / 1 070 I I 0 1 400 1 55 16. Status of well classification as: Water Injector Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned~{~ /~' ~ Title Sr. Operations Engineer Form 10-404 Rev 09/12/90 Date 8/8/91 SUBMIT IN DUPLICATE -~RCO Alaska, Inc~ Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT WELL REMARKS !o3o AU (~ 1 § t991 Alaska 0il & Gas Cons. 6ommissien Anchorage [--} CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK We'ther Temp' I Chill F'ct t Vl'lblllty IWindV'l'Report 'For, --F mil. . ARCOAlaska, Inc-~ Subsidiary of Atlantic Richfield Company WELL IPBDT {FIELD- DISTRICT- STATE CO~ITRACTOR //~,, ' IOPERATION AT REPORT TIME WELL SERVICE REPORT REMARKS 0700 ~ 7..5"'o HECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Temp. Chill Factor I Visibility Wind Vel. °F *FI miles Weather. Report REMARKS CONTINUED: . DESCRIPTION DAILY ACCUM. TOTAL CAMCO SCHLUMBERGER · . DRESSER-ATLAS HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel I/,(::> ~,L Methanol Supervision 5"-~ (..~ Pre-Job Safety Meeting AFE .... TOTAL FIELD ESTIMATE '7_. I/~'~ I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown __ Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 630' FNL, 484' FEL, Sec. 19, T11N, R10E, UM At top of productive interval 4148' FNL, 1208' FEL, Sec. 19, TllN, R10E, UM At effective depth 4310' FNL, 1250' FEL, Sec. 19, T11N, R10E, UM At total depth 4347' FNL, 1260' FEL, Sec. 19, T11N, R10E, UM 12. Present well condition summary Total Depth: measured 7 6 0 0' feet true vertical 6 3 2 6' feet Plugs (measured) None 6. Datum elevation (DF or KB) RKB 115 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1F-09 9. Permit number/approval number 83-104/8-761 10. APl number 50-029-20983 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7462' feet true vertical 6203' feet Junk (measured) None Casing Length Structural Conductor 107' Surface 2 3 4 1 ' Intermediate Production 7 5 4 4' Liner Perforation depth: measured 7347'-7351 ', true vertical 6100'-6103', Size Cemented 16" 175 SxAS II 9-5/8" 1000 Sx ASIII & 250 Sx ASI 7" 675 Sx Class "G" & 250 Sx Permafrost C Measured depth 107' MD 2341' MD 7544' M D 7337'-7341', 7305'-7331', 7276'-7289', 6091'-6099', 6061'-6086', 6037'-6048', True vertical depth 1 O7' TVD 2146' TVD 6276' TVD 71 44'-71 72' MD 5919'-5944' TVD Tubing (size, grade, and measured depth) 3 1/2" J-55 BTC w/tail @ 7253' MD Packers and SSSV (type and measured depth) Otis WD pkr @ 7229'; Otis RRH pkr @ 7012'; Camco TRDP-1A SSSV @ 1911' MD 13. Stimulation or cement squeeze summary Refer to Well Service Report Intervals treated (measured) Refer to Well Service Report Treatment description including volumes used and final pressure Refer to Well Service Report 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 248 172 180 1130 175 Subsequent to operation 655 523 670 1130 150 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~Y~~,~-~ Title Sr. Operations Engineer Signed i 0,0~.404~e¢ Fo rm 06/15/88 Date SUBMIT IN DUPLICATE STATE OF AI_ASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown m Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 630' FNL, 484' FEL, Sec. 19, T11N, R10E, UM At top of productive interval 4148' FNL, 1208' FEL, Sec. 19, T11N, R10E, UM At effective depth 4310' FNL, 1250' FEL, Sec. 19, T11N, R10E, UM At total depth 4347' FNL, 1260' FEL, Sec. 19, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 7 6 0 0' feet Plugs (measured) 6326' feet None 6. Datum elevation (DF or KB) RKB 115 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1 F-0~ 9. Permit number/approval number #83-104/8-1 81 10. APl number 50-029-20983 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7462' feet Junk (measured) true vertical 6203' feet None Casing Length Size Cemented Measured depth Structural Conductor 107' 1 6" 175 Sx AS II 107' MD Surface 2341' 9-5/8" 1000 Sx ASIII 2341' MD Intermediate & 250 Sx ASI Production 7544' 7" 675 Sx Class "G" & 7544' MD Liner 250 Sx Permafrost C Perforation depth: measured 7347'-7351', 7337'-7341', 7305'-7331', 7276'-7289', 7144'-71 72' true vertical 6100'-6103', 6091 '-6099', 6061 '-6086', 6037'-6048', 5919'-5944' Tubing (size, grade, and measured depth) 3 1/2" J-55 BTC w/tail @ 7253' MD Packers and SSSV (type and measured depth) Otis WD pkr @ 7229'; Otis RRH pkr @ 7012'; Camco TRDP-1A SSSV @.1911' MD 13. Stimulation or cement squeeze summary ! Refer to Well Service Report ~. r Intervals treated (measured) ~ ~: Refer to Well Service Report Treatment description including volumes used and final pressure Refer to Well Service Report True vertical depth 107' TVD 2146' TVD 6276' TVD MD TVD 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1 3 4 5 700 180 850 150 Subsequent to operation 850 600 180 850 150 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Form 10-404 I:~'ev 06/15/88 Title Sr. Operations Engineer Date 9/18/88 SUBMIT IN DUPLICATE ARCO Alaska, In/-' <> S<~3s=ctiary of Atlantic Richfield Company 2~TRACTOR REMARKS~, S.-_ ~ PPm WELL SERVICE REPORT IFIEJ_[;) - DISTRICT- STATE DA;rE OPERATION AT REPORT TII IE I"'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK We'ther ITemP'Report °F Chill Fact [ Visibility IWindV'l'°r~F mile. ARCO Alaska, Inc Post Office box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 4, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action Anticipated Start Date 1 F- 01 Acidize October, 1988 1 F- 0 3 Acidize October, 1988 1 F-09 ~ Acidize October, 1988 2X-01 Fracture October, 1988 2 T- 0 7 Fracture October, 1988 1 G- 1 0 Acidize September, 1988 If you have any questions, please call me at 265-6840. Sincerely, G. B. Smallwood Senior Operations Engineer GBS:kjr Attachments cc: J. Gruber M. L. Hagood S. P. Twiggs KeEl .4-9 ATe 1478 ATe 1120 ATe 1130 ARCO Alaska, inc. is a Subsidiary o! AtlanlicRichlieldCompany' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate .zX__.. Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 630' FNL, 484' FEL, Sec. 19, T11N, R10E, UM At top of productive interval 4148' FNL, 1208' FEL, Sec. 19, T11N, R10E, UM At effective depth 4310' FNL, 1250' FEL, Sec. 19, T11N, R10E, UM At total depth 4347' FNL, 1260' FEL, Sec. 19, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 7600' MD 6326' TVD 6. Datum elevation (DF or KI~) RKB 1 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1F-0~) 9. Permit number 83-104 10. APl number 50-029-20983 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool feet Plugs (measured) feet NOlle Effective depth: measured 7462' MD true vertical 6203' TVD feet Junk (measured) feet NOne Casing Length Size Structural Conductor 107' I 6" Surface 2 3 41' 9 - 5 / 8" Intermediate Production 7544' 7" Liner Cemented 175 Sx CS II 1000 Sx ASII & 250 Sx ASI 675 Sx Class G & 150 Sx AS1 Measured depth 107' MD 2341' MD 7544' MD True vertical depth 107' TVD 2146' TVD 6276' TVD Perforation depth: measured 7374'-7351', 7337'-7341', true vertical 6100'-6103', 6091'-6099', Tubing (size, grade, and measured depth 3 1/2", J-55 BTC w/tail @ 7253' MD 7305'-7331' 6061 '-6086', 7276'-7289', 6037'-6048', 7144'-7172' MD 5919'-5944' TVD 13. Packers and SSSV (type and measured depth) OTIS WD pkr @ 7229'; OTIS RRH pkr @ 7012'; Camco TRDP-1A SSSV @ 1911' MD Attachments Description summary of proposal Acidize "C" Sands 14. Estimated date for commencing operation October. 1988 16. If proposal was verbally approved Name of approver 17. Signed Date approved Detailed operation program _ 15. Status of well classification as: Oil _~ Gas_ Service BOP sketch I hereby certify that the foregoing is true and correct to the best of my knowledge. .,/~ L;~,~ //~ ~/~~:4,O,)¢'~ Title Sr. Operations Engineer FOR COMMISSION USE ONLY SUSlSended -- ., Date 9/1 8/88 Conditions of approval: Notify Commission so representative may witness IApproval No.__ Plug integrity __ BOP Test _ Location clearance__ ~_~, I ~-"~---' 7~ / Mechanical Integrity Test_ Subsequent form require.~p~-l~,;,_,?~_TOopy Returned Approved by the order of the Commissioner ORIGINAL SIGNED BY Commissioner/'~)-'//~'~ Date //0 '- 7-'~:~O~ Form 10-403 Rev 06/15/88 LONNIE C. SMITH SUBMIT IN TRIPLICATE Well 1F-09 C Sand Acid Treatment General Description Well 1F-09 is currently a combined A and C Sand oil producer. Proposed downhole stimulation work will reduce near wellbore damage to increase well productivity. The proposed work will utilize a pump truck and surface lines to displace the acid across the C Sand perforations, The surface lines will be pressure tested to 4000 psi against the 5000 psi tree valves. Static bottomhole pressures from a wellhead pressure and fluid level indicate BHP of 2600 psig in the A Sand and 3500 psig in the C Sand. Procedure 10. 11. 12. 13. 14. 15. 1. MIRU Slickline. Pressure test lubricator. 2. RIH with blanking plug. Set in NOGO at 7247 FT MD-RKB. 3, POOH and RDMO Slickline. Open well to production, 4. Allow stabilization and obtain C Sand only test. 5. MIRU Transports and Pumps. Pressure test equipment. 6. Titrate 12% HCL(10% < HCL<14% Acceptable) 7. Begin treatment and pump above parting pressure(10-15 BPM). A. Pump 5 barrels musol. B. Pump 75 barrels HCL acid with additives. 8. Displace with 150 BBLS diesel at 10 BPM. 9, Immediately return well to production. Begin gaslift immediately. A. Attempt to flow well at reduced rates to allow fines removal. RDMO Transports and Pumps. Flow at reduced rates prior to fully opening choke. Obtain a C Sand only test. MIRU Slickline, Pressure test lubricator. RIH and pull blanking plug in NOGO at 7247 FT MD-RKB. POOH and RDMO. Open well to production. Allow stabilization and obtain NC test. ~---- STATE OF ALASKA ALAS, . OIL AND GAS CONSERVATION COMI,,.._,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate/~ Pull tubing [] Amend order [] Perforate [-] Other [] 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360. Anchorage: AK 99510 4. Location of well at surface 630' .FNL, 4.84' FEL. Sec 19 T11N, R10E UM At top of proaucuve interval ' ' ' 4148' FNL, 1208' FEL, Sec.19, T11N, R10E, UM At effective depth 4310' FNL, 1250' FEL, Sec.19, TllN, R10E, UM At total depth 4347' FNL: 1260' FEL; S~_c.19.. TllN: R1OF= IIM 5. Datum elevation (DF or KB) RKB 109 6. Unit or Property name Kunaruk Rivc_r Unit , 7. Well number ]F-9 8. Permit number Permit #83-104 9. APl number 50-- 029-20983 10. Pool K~,nar~k R~v~r r)il p_nnl feet 11. Present well condition summary Total depth: measured 7600' MD true vertical 6326' TVD feet feet Effective depth: measured 7462' ND feet true vertical feet 6203' TVB Casing Length Size xxx~'m~,~kxx xx Conductor 107' 16" Surface 2341' 9-5/8" x x x ;kr'xt~ ~q~,~ Rte Production 7544 ' 7" xxx JSCZxxxx Plugs (measured)None Junk (measured) None Cemented Measured depth 175 SX CSII 107' MD 1000 SX ASIII & 2341' MD 250 SX ASI 675 SX Class G 7544' MD Perforation depth: measured 7347'-7351', 7337 7276'-7289', 7144 true vertica16100'-6103', 6091 6037'-6048', 5919 ~bing(size, grade and measured depth) 3½" J-55 BTC w/tail @ 7253' MD '-7341' 7305'-7331' MD '-7172' MD '-6099' 6061'-6086' TVD "5944' TVD ~ue Vertical depth 107' TVD 2146' TVB 6276' TVD Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .,,~~ /~~/~-'t~ Title Sr. Operations Engineer Commission Use Only Date3/7/88 Conditions of approval Approved by Form 10-403 Rev 12-1-85 Notify commission so representative may witness Approval No. ~;) / [] Plug integrity [] BOP Test [] Location clearance -"/ & - ) Approved Copy ,~ ~ ORIGINAL SIGNED BY Returned,~'//~Y order of t, ONNIE C. SMIT, Commissioner the commission Datec:~ '~/~--- ~? , ~ Submit in triplicat~ 14. If proposal was verbally approved Name of approver Packers and SSSV (type and measured depth) ..... ,,.., r, ...... i', ...... i'~' '~,' 0TT-q ~ll n~g ra 777q'_~ (1TT~q ppl-I nL, n ca ?n19 · r'AMr'n TPnD_IA qq~u ca 1G7t .... Mrt '~", ...... 12.Attachmen'ts Description summary of proposal [] Detailed operahons program [] BOP CR~lcl~ ~ Pump 1235 gallons MUSOL Diesel 13. Estimated date for commencing operation March, 1988 Well 1 F-09 General Description Well 1F-09 is currently a combined A and C Sand oil producer. Proposed downhole stimulation work will reduce near wellbore damage to increase well productivity. The proposed work will utilize a pump truck and surface lines to displace the musol diesel across the C Sand perforations. The surface lines will be pressure tested to 4000 psi against the 5000 psi tree valves. Static bottomhole pressures from a wellhead pressure and fluid level indicate BHP of 2500 psig in the A Sand and 3200 psig in the C Sand. Procedure 1. MIRU pump truck and transports, Pressure test equipment, 2. Pump 1235 gallons musol diesel and displace with 63 barrels diesel, Surface injection pressure should remain below 3500 psi. 3. Allow to soak for 1 hour. 4, RDMO pump truck and transports, ARCO Alaska lnG, is a subsidiary of Atlantic Richfield Company AR3B-6001-A ARCO Alaska, In Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: November 5, 1987 Transmittal # 7006 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one sig9ed copy of this transmittal. Kuparuk Well Pressure Report(Camco) Kuparuk Well Pressure Report(Camco) Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report(Otis) Sperry-Sun Pressure Build Up Test 'A' Sand Static BHP Survey PBU Well Test Interpretation Plots 'A' Sand Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report)Otis) KOE Buildup Analysis- KOE Falloff Analysis KOE Falloff Analysis KOE Falloff Analysis KOE Falloff Analysis KOE Falloff Analysis KOE Buildup Analysis KOE Falloff Analysis KOE Falloff Analysis KOE Buildup Analysis KOE Falloff Analysis Kuparuk Well Pressure Report 6-10-87 6-13-87 6-14-87 6-17-87 6-18-87 6-14-87 6-11-87 6-10-87 6-17-87 6-12-87 6-9-87 7-8-87 Static 7-7-87 'C' Sand 8-5-87 Static 8-3/5-87 PBU 8-22-87 7-19-87 AK-MS-70043 7-14/17-87 100591H 7-15/19-87 6-10-87 Static 7-28-87 Static 'C' Sand 'C' Sand Both Sands Both Sands Both Sands Both Sands ~C' Sand Both Sands Both Sands 'C' Sand Both Sands 11-3-87 Static 'A' Sand Receipt Acknowledged: DISTRIBUTION: \ ./ .. ,,.u_; ..' _ ~. ~ .la~a 0Il a uas (;0ns. Commission Anchorage D&M State of Alaska BPAE Chevron Mobil SAPC Unocal ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompan¥ ARCO Alaska, inc. Post Offic~"~x 360 Anchorage, ,.daska 99510 Telephone 907 277 5637 Date: 2/05/85 Transmittal No: 4824 RETIYR2q TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P~O. Box 100360 ~Anchorage, AK 99510 !~n~tted herewith are the following items. and return one signed copy of this transmittal. Please acknowledge receipt PBU SURVEYS & SEQUENCE OF EVENTS --2X-7/ 8/16/84 -~--2Z-6/ 9/03/84 2X-6/ 8/16/84 ---- 2X-C/ 8/16/84 ~--2X-1F'" 8/16,19 --2V-5;/ 8/16,19 '~2V-2/ 9/07/84 - - 2F-9/' 8/28/84 / --2F-8',,i; 10/08/84 --2F-7/ 10/07/84 ~2B-l~/ 9/03/84 ~-2C-5 / 8/17/84 ~-~ 1Y-!3/ 8/16/84 ~lY-9/ 9/07/84 ~lY-5z 9/14/84 1Y-5~ 9/06/84 ~lG-6~ '8/25/84 ~lH-4~ 9/04/84 ~1F-12¥ 9/09/84 ~-lF-9/ 8/17,18/84 <-lF-8z. 8/16,17/84 ~-lE-8~~ 10/12/84 ~-lD-5/ 10/07/84 ~lA-4~ 9/02/84 ---1A-3Z 9/02/84 Gearhart Otis Gearhart Camco /84 Camco /84 Dresser "HP 232" Otis Otis Camco Otis Otis Otis Dresser "PIP 233" Camco Camco Otis Otis Otis Otis Camco Camco Otis Camco Otis Otis Receipt Acknowledged: 9/06/84 "SBHP" 9/05/84 "Static BHP" 8/17/84 "PBU"" 8/16/84 "PBU" 10/13/84 "SBHP" "E Line" 10/07/84 "Pressure Falloff" B. Currier Drilling DISTRIBUTION W. Pasher State of AK BPA.E Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D&M NSK Ops. J. Rathmell Well Files ARCO Alaska, inc. Post Offic ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 RETURN TO: ' ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box.100360 ~~r~ns~chorage, AK 99510 itted herewith are the following items. and return one signed copy of this transmittal. -PBu su v zs : -- ': Camco 1G-10 12/05/84 " 1F-9 .12/04/84 " 1F-8 11/27, 28/84 " 1H-4 11/25/84' Date: 12/20/84 Transmittal No: 4926 Please acknowledge receipt /cat Receipt Acknowledged: B. Currier BPAE Chevron D&M D~illing Geology Mobil NSK Ops. DISTRIBUTION Date: .... W. Pasher G. Phillips Phillips Oil J. Rathmell State of AK Sohio Union Well Files ARCO Alaska. Inc. i,: ! subsidiary of AtienhcFicl~fieldCompany ARCO Alaska, ~-.' O!i;:~_ ~cx 36,2: Ancho:ag(;. Alaska 995~0 ~.cie?hone 907 277 5637 Date: 9/04/84 Transmittal No: 4712 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 ra. nsmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. PRESSURE ANALYSIS/PBU SURVEYS & 1E-12~ PBU "BOMB'! 8/17/84 1E-15~.'' S'~i~'i~'-~'B'HP 8/05/84 1F-2 u~. SIBHP 6/04/84 1F-3~' .,~B~ 4/30/84 1F-4'~ SIBHP 6/04/84 1F-5 ~' ./i[~B~2> 5/08/84 1F-6- SIBHP 6/05/84 iF-? ~ SIBHP 12/19/83 1F-7-~ SIBHP 6/05/84 1F-7~ SIBHP 4/30/84 1F-9~ GAS LIFT SURVEY 4/29/84 [~-9~ .... ~'~RAWDOWNSAND 12/26/83 1F-10 --f~0/DRAWDO~N~ 12/20/83 1F-10.-~'" DRAW-DOWN 12/21/83 1F-11-- fp~_.i> 12/23/83 1F-11 ~-' PBUTDRAWDOWN 1F- 12 .... ~BU / DRAWD OWNcA 1F-12~ (PBU ."A" SAND_J5 1F-12 -~ PBU/PDD 1F-12 -~ PBU/PDD "A" 1F-13~ ~p~u "A" SAND 1F-13-~/ S IBHP-NEW_I[" C" 1F_16~/ [~U-,,A~-q, Receipt Acknowledged: 12/24/83 3/09/84 7/03/84 3/10/84 3/09/84 5/03/84 1/26/84 5/04/84 SEQUENCE OF EVENTS 1F-16~/ 1F-16 -- /cat B. Adams F.G. Baker D&M Drilling P. Baxter Geology BPAE Mobil DISTRIBUTION LOGS & PBU~"A" SAND ~/04/84 ; ; PBU & L ~ ' / . ./ Date: " :"' : ~'~4-~ ~.~. Pasher C. R, Smith G. Phillips State-' of Alaska Phillips Oil Sohio J.J. Rathmell Union R & D Well Files Chevron KSK Operations ARCo Alaska,/nc Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 27'6 1215 June 29, 1984 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission 300! POrcupine Drive Anchorage, AN 99501 Dear Mr. Chatterton. Attached in dupl/Cate are SUbsequent notices fo/iowin9 we/Is at the KUparuk River Field: Wel I .... Ac t i on IF-/ 1F-3 Fracture 1F-$ Fracture 1F-9 Fracture 1F-9 Perforate Fracture 1F-1 0 Per rOtate 1 F- 1 0 Fracture 1F-1 1 Per rotate 1F-13 Per rotate 1 F- 1# Perforate 1 F- 14 Fracture 1 F- 15 Per fora te 1 F- 1,5 Fracture 1F-16 ~0-7 Perforate 1C-10 Choke Perforate 10-10 Fracture 10- 12 Per fora te lO- ! 2 Fracture on the Date Performed 6/10/84 6111184 6/12/84 6/16/84 6/19/84 611q/84 6/18/84 6/19/84 6119/84 6/22/84 6/23/84 6/17/84 6121184 6/19/84 $14184 i 5129/84 ~'\ L .. v ~ 5130/84 5129184 ,.i~iL(~i~ 5131/84 " Alusk~ Oil & Eas Cons, ARCO Alaska, /nc. is a Subsidiary ol AtianticRichlieldCornPany "-'- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CL/MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCAT I ON' 629 ' T11N, R10E, UM FNL, 484' FEL, Sec. 19, BOTTOM HOLE LOCATION: SEC. 19, T11N, .5. Elevation in feet (indicate KB, DF, etc.) 109' (RKB) Pad 80' 12. 4471' FNL, 1176' FEL, 6. Lease Designation and Serial No. 7. Permit No. 83-104 8. APl Number 5o- 029-20983 9. Unit or Lease Name KiJPARIIK IR IVFR UN !T 10. Well Number 1F-9 11. Field and Pool R10E, UM KUPARUK RIVER F! ELD / KUPARUK RIVER OIL ADL :2.~t~.~? ALK _?578 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations L--) Altering Casing [] Stimulate [] Abandon [] Stimulation I~ Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On June 19, 1984, the "A" sands of Kuparuk well 1F-9 were hydraulically fractured and propped to improve production. treatment consisted of 279 BBLS of gelled diesel as pad and fluid and 23,900 LBS of 12/20 sand as proppant. The carrying Prior to pumping, equipment and lines were tested to 5000 psi. sand was tagged with R.A. tracer to aid determination of job performance. The RECEIVED JUL 0 3 19114 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certif~~t to Signed The space below for Commission use the best of my knowledge. KU PARU K Title OPERAT IONS COORD I NATOR 6~28~84 Conditions of Approval, if any: A Approved by By Order of COMMISSIONER the Commission Date ......... Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 29, 1984 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached in duplicate are subsequent notices on the following wells at the Kuparuk River Field: Well Action Date Performed 1F-1 Fracture 6/1 0/84 1F-3 Fracture 6/11 / 84 1F-5 Fracture 6/12/84 1 F-9 Perforate 6 ! 16 / 84 1 F-9 Fracture 6 / 19 / 84 1F-1 0 Perforate 6 / 14 / 84 1F-1 0 Fracture 6/1 8/84 1F-11 Perforate 6 / 19/84 1F-1 3 Perforate 6/19/84 1F-1 4 Perforate 6 / 22 / 84 1F-1 4 Fracture 6/23 / 84 1F-15 Perforate 6 / 17 / 84 1F-15 Fracture 6/21/84 1F-16 Perforate 6 ! 19 / 84 1G-7 Choke 5 / 4/84 1G-1 0 Perforate 5 / 29/84 1G-1 0 Fracture 5 / 30 / 84 1G-12 Perforate 5 ! 29/84 1G-12 Fracture 5 / 31 / 84 ARCO Alaska. Inc. is a Subsidiary of AilanticRichfieldCompany STATE OF ALASKA '~-' ALASKA O~L AND GAS CONSERVATION CO~MISSION SUNDRY NOTICES AND REPORTS ON WELLS V 1. DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2. Name of Operator ARCO ALASKA, INC, 3. Address P. O. BOX 360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION, 629' T11N, R10E, UM FNL, 484' FEL, Sec. 19, BOTTOM HOLE LOCATION. 4471' FNL, SEC. 19 T11N R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 109' 1176' FEL, 12. ( RKB ) 7. Permit No. 83-104 8. APl Number s0- 029-20983 9. Unit or Lease Name KUPARUK RIVER UN I T 10. Well Number 1F-9 11. Field and Pool KUPARUK RIVER FIELD I 6. Lease Designation and Serial No. KUPARUK RIVER O I L Pad 80' ADL 25652, ALK 2578 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~ Altering Casing [] Stim u late [] Abandon [] Stim u lat ion [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On June 16, 1984, the "A" sands of Kuparuk well 1F-9 were re-perforated to enhance stimulation. After testing the lubricator to 3000 psi, the well was shot with a wireline conveyed gun. The well was re-perforated to provide improved perf orientation for the upcoming fracture treatment. Interval (MD). 7304' - 7351' (2 SPF) RECEIVED J U L 0 31984 Alaska 0il & Gas Cons. Commissior Anchorage 14. I hereby certify that~tl2e f.oregoing is ~ru~ and correct to the best of my knowledge. KU PARU K Signed /'~'('~~_~-~ TiceOPERATI ONS COORD I NATOR The space below for Commission use 6/28/84 Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date. Form 10403 R~.v_ 7-1 Submit "Intentions'; in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In Post Office ~°x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 13, 1984 Mr. C. V. Chatterton Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached are notices of intention to fracture 1F-9 and 1F-10. Kuparuk wells If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) U N ]984 was Cons. Commission Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA .-~ ALAS, ..'OIL AND GAS CONSERVATION ~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA_ INC. 3. Address P; O: BOX .g60. ANCHORAGE, AIARKA _9 _9.~10 4. Location of Well SURFACE LOCATION' 629' FNL, 484' FEL, Sec, 19 T11N, RIOE, UM BOTTOM HOLE LOCATION- 4471' FNL, 1176' FEL, SEC. 19, T11N, R10E, UM 7. Permit No. 83-104 8. APl Number 50- O2q-?OqR~ 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1F-9 11. Field and Pool KUPARUK RIVER FI ELD 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KUPARUK R ! VER O I L 109' (RKB) Pad 80' I ADL 25652, ALK 2578 POOL 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ' [] Alter Casing [] Perforations [] Altering Casing Stimulate ~] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" sand in Kuparuk well 1F-9 be hydraulically fractured and propped to improve production. The treatment uses gel l ed diesel as the pad and carrying fluid and 12/20 sand as the proppant. Lines and equipment wi ! I be pressure tested to 5000 psi prior to starting the job. R.A. tagging of the proppant and pre/post frac production logs are included in the treatment program. Fluid' Diesel 375 BBL Proppant: 12/20 sand 24,000 LB ANTICIPATED START DATE- June 14, 1984 RECEIVED JUN 1 3 ]984 Alaska Oil & ISas 0ohs. 0ommissJon Anch0rag0 14. I hereby c~rtify that the foregoing is true and correct to the best of my knowledge. Signed ~(~__j~ ,f~ ~ TitleKg PARUK The space below for Commission use OlJl-~ I- i ON$ Date 6/13/84 Conditions of Approval, if any: Approved by Approved CoPy Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Ir' Post Office clox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 12, 1984 Mr. C. V. Chatterton Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear ~r. Chatterton' Attached are notices of intention to re-perforate wells 1F-9 and 1F-10. Kuoaruk If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator ~,.4LL / kmc Attachment (in Triplicate) RECEIVED JUN 1 3 i9B4 Alaska 0i~ & Gas Cons. Gomrniss! Anchor2ge ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ,~--, STATE OF ALASKA ALASK. OIL AND GAS CONSERVATION'---~"MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER i-1 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-1r) 4 3. Address 8. APl Number P. O. BOX 360, ANCHOPd~,C;E, ALASKA 99510 50- 029-20983 9. Unit or Lease Name FNL, 484' FEL, Sec. 19, KUPARtJK RIVER UNIT 4. Location of Well SURFACE LOCATION' 629' T11N, R10E, UM BOTTOM HOLE LOCATION' 4471 ' FNL, 1176' FEL, SEC. 19, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 109' (RKB) Pad 80' 6. Lease Designation and Serial No. ADL 25652, ALK 2578 10. Well Number 1F-9 11. Field and Pool KUPARUK RIVER FI Et.r) KUPARtJK RIVER OIL POOL 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate E~ Alter Casing [] Perforations [] Altering Casing [] Stimulate- [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] [] Other [] Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" sand be re-perforated Procedures call for the well to be shot with a under a lubricator. PROPOSED INTERVAL (MD): 7304 - 7351' (2SPF) in Kuparuk well 1F-9. wireline conveyed gun ANTICIPATED START DATE' June 13, 1984 RECEIVED JUN 1 319 4 14. The space below for Commission use AlasKa U,i ~ (;::S Cons. Commission An::h:)rafie that th~ for~oin~ is tr~~rrect to th~ b~st of mv knowledge. K u PARU K Title Date OPE~TiONS COORD i NATOR 6/1~/84 Conditions of Approval, if any: tRIGIN,~L $1GIi[,2 BT L0~NIE C, S~]f.~ By Order of Approved by COMMISSIONER the Commission ,~.pprovod Copy .Returned .... Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In Post Office clox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Apri I 16 , 1984 ~4r. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached in duplicate are subsequent notices on the following wells at the Kuparuk River Field- Well Action Date Performed 1F-9 Acidize "A" Sands 3-15-84 1F-13 Acidize "C" Sands 3-25-84 1G-11 Perforate "A" Sands 3-29-84 1Y-16 Acidize "C" Sands 3-27-84 2X-8 Fracture "C" Sands 3-20-84 If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Ooerations Coordinator MLL/kmc Attachment (Duplicate) RECE iVED APR 1 ? 't984 0il & Gas Cons. 0ommission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATEOFALASKA ~--~ ALAS.~'~}I L AND GAS CONSERVATION 'MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL'S3 OTHER [] 2. N~,r~i~6OpAr~/~S ~&,' ~NC. 7. P§r~it I~1o0/4 8. APl Number 3. ACC.~eSSO. BOX 360, ANCHORAGE, ALASKA 9951 0 50- 02 9 - 2 0983 9. Unit or Lease Name 484' Sec. KtJPARUK RIVER IJNIT 4. Location of Well SURFACE LOCATION. 629' FNL', FEL, 19, T11N, R10E, UM BOTTOM HOLE LOCATION' 4471 ' FNL, 1176' FEL, SEC. 19, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 109' (RI(B) Pad 80' 6. Lease Designation and Serial No. ADL 25652, ALK 2578 10. Well Number 1F-9 11. Field and Pool KUPARUK RIVER F! ELD KUPARUK RIVER OIL POOL 12. (Submit in Triplicate) Perforate .".-d Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On 3-15-84 the "A" sands in Kuparuk well 1F-9 were acidized to improve production. The treatment 'consisted of 1470 gallons of 12% HCL/3% HF acid. A pre and post-flush of 1596 gallons of 12% FE acid was used to control reaction by-products. The job was pumped by coil tubing unit and displaced with nitrogen to aid well cleanup. Post treatment rate: 50 BOPD. 14: I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~,/-~¢-~2//~ TitleKUPARUK OPERATIONS COORD i NATOR The space below for Commission use 4/13/84 Date Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date ................ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate , ~ ::D './ Ei4GI EERING },UP~.,U,, N TO: TRAUSMiTTAL FROM: D. Fay Allison Transmitted herewith are the following: WELL NAME' see below PLEASE NOTE'~]~- BLUELINE~~) SEPIA, F - FILM, T - TAPE, PC - PHOTOCOPY Well Descript ion Date Run /! , .. P,~PT ACKNOWLEDGED: ~/PLEASE RETURN RECEIPT TO ARCO ALAS.,A, ATTN- D. FAY ALLISON-- ATO/11]~Oil& · P. O. BOX 100360 ~-, ...... ,~ ANCHORAGE, AK. 995].0 ARCO Alaska, Inc.:~ Post Office b,.,x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 1, 1984 Mr. C. V. Chatterton Cha i rman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Commission Dear Mr. Chatterton' Attached is a Sundry Notice of intention to stimulate Kuparuk well 1F-9 using an acid treatment. If you have any questions, please call me at 263-4527. Charles K. House Kuparuk Operations Coordinator CKH/kmc Attachment (In Triplicate) Alaska 0il & Gas Cons. [;ornmissior~ ~n~hora§e ARCO Alaska, !r~c. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~% ALASKA ~_ ,L AND GAS CONSERVATION Ct iMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL)CZ] OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, ];NC. 83-104 3. Address 8. APl Number P, O. BOX 360, ANCHORAGE, ALASKA 99510 50_029-20983 9. Unit or Lease Name 484' FEL, Sec. 19, KUPARUK RIVER UNIT 4. Location of Well SURFACE LOCATION. 629' FNL, TllN, R10E, UM BOTTOM HOLE LOCATION' 4471' FNL, 1176' FEL, SEC. 19, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 109' (RKB) Pad 80' I ADL 25652, ALK 2578 12. 10. Well Number 1F-9 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data . NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [~ Abandon [] Stim u lation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The "A" sand will be acidized using a 12%/3% HC1/HF "mud acid". HC1 pre and post flush will be used to control fluosilicate by-products. A coil tubing unit will be used to inject treatment. Nitrogen will be used to assist well cleanup. An reaction the acid Fluid Requirements' 12%/3% HCl/HF 1470 gals 12% HC1 1596 gals Nitrogen 2000 gals Diesel 2520 gals Expected Start Date' February 8, 1984 Subsequent Work Reported No.l?qO mt,,d The space below for Commission use Conditions of Approval, if any: Approved by the best of my knowledge. Title · KUD^~..v OPERATIONS COORDINATOR ~,.pproved C~py ~eturned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc.~~J''''' Post Offic~e~B,... 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 17, 1984 Chat Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Chat' Attached in duplicate are subsequent notices on the following wells at the Kuparuk River Field' Well Action Date Performed 1F-9 1Y-11 1Y-14 SWPT SWPT 2X-1 2X-2 2X-3 2X-5 2X-6 2X-7 Perforation 11/30/83 Stimulation 11/14/83 Production/Injectivity Test 5/24/83 Mud acid wash 11/22/83 Water Injection see attached Perforation 12/9/83 Perforation 12/10/83 Perforation 12/11/83 Perforation 12/12/83 Perforation 12/13/83 Perforation 12/14/83 If you have any questions, please call me at 263-4527. Charles K. House Kuparuk Operations Coordinator CKH/kmc Attachment (Duplicate) RECEIVED JAN 1 81984 Alaska 0il & Gas Cons. ~ommJs$i0r~ Anchorage ARCO Alaska. Inc. is a subsidiary of AtlanticRichfieldCornpany STATE OF ALASKA ALASKA UIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS OTHER [] 1. DRILLING WELL [] COMPLETED WELL 2. Name of OPerator 7. Permit No. ARCO ALASKA, INC. 83-104 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 50- 029-20983 4. Location of Well SURFACE LOCATION' 629' FNL, 484' FEL, Sec, 19, T11N, R10E, UN BOTTOM HOLE LOCATION' 4471' FNL, 1176' FEL, SEC. 19, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) ! 6. Lease Designation and Serial No. 10q' (RKB) Pad 80' ! ADL 25652. ALK 2578 12. 9. Unit or Lease Name KUPARUK RTVER UNIT RIVER FIELD RIVER OIL 10. Well Number 1F-9 11. Field and Pool KUPARUK KUPARUK POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair~Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) )~ Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). "A" Sand was perforated on 11-30-83 7337 - 7341' 7347 - 7342' 7305 - 7331' 7420 - 7430' 7276 - 7289' at the following intervals' ~JAN i 8 1984 A~,-'~'~ Oil a Gas CoilS. Comr~i~io,q 14. I hereby ce~ng ~~o the best of my knowledge. Signed Title KUPARUK The space below for Commission use OPERAT ! ONS COORD I NATOR Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7~1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KUPARUK ENG I NEER 1 FIG TO: William VanAlen ~4: D.W. Bose/Shelby J. Matthews Transmitted herewith are the following' pLEASE F, DTE: ~- BLUELINE, O SEPIA, F '- FII_M, T - TAPE, PC - R-OlqCEDPY S.30.¢3 /~1 ARCD ALASKA, ! IxC:. AT'R'I: SHEI RY J. I~,~T'I'HI~,S - ATO/1115-B P. O. BOX 100360 AI'~,,~E, AK. 99510 ( ARCO Alaska, Inc. Post Office Bux 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 14, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1F-9 Dear Mr. Chatterton' Enclosed are the well completion report and gyroscopic survey for the subject well. If you have any questions, please call me at 263 -4944. Sincerely, Gruber Associate Engineer JG' tw GRU5/L35 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany -"-- STATE OF ALASKA *,--., (~ ~ ·ALASKA_ ,'L AND GAS CONSERVATION C'~ iMISSION WELL COMPLETION OR RECOMPLETION' REPORT AND LOG 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .-? 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-104 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20983 4. Location of well at surface 9. Unit or Lease Name 630' FNL, 484' FEL, Sec.19,-T11N, R10E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 4148' FNL, 1208' FEL, Sec. 19, TllN, R10E, UM 1F-9 At Total Depth 11. Field and Pool 4347' FNL, 1260' FEL, Sec. 19, TllN, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 109' RKBI ADL 25652 AKL 2578 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore i16. No. of Completions 08/23/83 08/29/83 10/16/83J N/A feet MS LJ 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7600'MD,6326'TVD 7462' ,6203'TVD YES L-X1 NO []I 1911 feet MD 1450' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/FDC/CNL/Cal/GR, GR/CBL/VDL/CCL, 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 107' 24" 175 sx CS 'Il 9-5/8" 40.0# J-55 Surf 2341' 12-1/4" 1000 sx AS Ill & 250 sx AS I 7" 26.0# J-55 Surf 7544' 8-1/2" 675 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, sizeand number) SIZE DEPTH SET (MD) , PACKER SET (MD) 7172' - 7164' 3-1/2" 7253' ' 7012' and 7229' 7164' - 7144' w/12 spf (See Compl.Summary) 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.} I Date of Test Hours Tested IPRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD FioTM Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 Submit in duplicate Rev. 7-1-80 GRUS/WC04 CONTINUED ON REVERSE SIDE "~ ' -~ GEOLOGIC MARKERS ' '" ..... ~ -' _ - ...~'-'.:,':'. :' .; : .:' i~:: 'F(~RMATiONTESTS ' , . .. .- NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR,and time of each phase. Top Upper' Sand 7143 ' 5918 ' Base Upper Sand 7172' 5944' N/A Top Lower Sand 7262' 6024' Base Lower Sand 7392' 6140' 31. LIST OF ATTACHMENTS Drilling Histor),~ Completion Summary, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title.-.~.re~ Dri~!!ng Engr. Date · / / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production-from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". 1F-9 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 2115 hrs, 08/23/83. Drld 12-1/4" hole to 2399'. Ran 60 jts 9-5/8" 40# J-55 HFERW BTC csg w/shoe @ 2341'. Cmtd 9-5/8" csg w/lO00 sx AS III & 250 sx AS I. Bumped plug w/1500 psi - floats held - ok. ND 20" Hydril & diverter. Performed top job w/122 sx AS I. NU FMC wellhead. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 7600' TD on 08/29/83. Ran logs DIL/SFL/FDC/CNL/GR/CAL f/7581' to 2341'. Reamed hole to bottom. CBU. Ran 189 jts 7" 26# J-55 HFERW csg w/shoe @ 7544'. Cmtd 7" csg w/675 sx Class "G" cmt. ND BOP. NU FMC packoff & tbg spool & tstd to 3000 psi - ok. Displ 110' in 7" csg of brine and left hole void of fluid. NU master valve. Secured well & released rig @ 1915 hrs, 09/01/83. HILL/DH47 10/17/83 1F-9 COMPLETION SUMMARY RU Dresser-Atlas. Ran GR/CBL/VDL/CCL to 7443'; good bond. Ran Gyro. RD Dresser-Atlas. Secured well. Accepted rig @ 0200 hrs, 10/13/83. ND tree. NU BOPE & tstd to 3000 psi - ok. Perf'd 7172' - 7164' & 7164' - 7144' w/12 spf. RIH w/WD pkr & set @ 7229'. Ran 3-1/2" completion assy w/tail @ 7253' & SSSV @ 1911'. Sting into WD pkr @ 7229' Pulled pkr locator sub 1' above WD pkr & spaced out. Installed BPV. ND ~OPE. NU tree. Pulled BPV. Tstd tree to 3000 psi - ok. Disp well w/30 bbls diesel followed by Kuparuk crude oil. Dropped ball & set RRH pkr @ 7012'. Closed SSSV. Set BPV. Secured well & released rig @ 1630 hrs, 10/16/83. GRU5/CSO2'tw r . ".,,/:'.'~ ':;:', ~,~ ,5: '/.';~:::~'~';;::~::;~:;;~"i~:"'-:?::''' <':; '~ '~' ;;~;::'" "~'.;Z~:~;~:~::;~:~:~;;~:::~;i:~;:~ x~:.~:~:~:~:~::.~:~:~;~:~:~:~:~:~:~;~..~:~:~;~:~:~;~:~;~:~:;~::~:~;~=~:~:~;~;~:~:~;?.~:;:~:?~;:~;~:~:~:~:~:?.::::::~:~ '" :,' ,~ :' ,. '.; :' :,:...:~ ~:..:~::~:;..~d;::~x::~:;:;::::::::x~:..:::=:::::~:~:~:~;;~:.:::;..~::~::.x~.~x<:.x~:-:~.~...~x~`*~.~:~::~..~.:.x.:.~`i ,, ~ · KUPARUK OCTOBER 3, 1983 JOB NUMBER AK-BO-30102 ALASKA :~.., ,,., ,: ,.,, .,:,.,.~ :i'i:i;;~;:;i:?,:;:.::';;:,;,i,ii:;,?:';': 'i:'.: .,+;: · MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEPTH DEG MIN DEGREES DEG/1OO NORTH/SOUTH EAST/WEST SECTION ~. ': ':' : , . : I'' ::: :: ::~::'O.. : ::~::'~:: ~ :~'.~ :.:.~ ::: ~ :~:: ?: :'::: :?':'::~?~:~:~' ~::: : :.: ::::::::::::::::::::::::::::::::::::::::: ': ~ ~ ~ : '.~:. :::::::::::::::::::::::::::::::::::: ': :~::'?:a :': :::::::::::::::::::::::::::::::::: ~ ~. :: ~: ;: "::::r':: :~ ~'. :. ~.~::; ':. ~:~ :: ~ ;~:~: ~: ~:~;~': : ; :'~:; ; ~ :1 ~::: : : ':6:;'~;~'~: :?':' 5 ~?:':' :::~:: :;: :::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::: : :: ; :' : C, . C~ 900 2'~.~? l'~O.~ 0 33 N 52.10 E 0.33 O.SS N i.75 E -0.7S 400 S~,~ 2~0.~ 0 3& N 3~.~ E 0.14 I.OS N 2.4~ E -1.S& .: 'BO0 899.59 7~0.59 6 0 S 15.60 W 3.15 7.39 S 2.94 E 6.64 1000 998.63 889.63 9 44 'S 21. 0 W 3.81 20.33 S 1.50 W 20.21 :~:i:';:::::: ::::::::::::.::::':. ?:.::.: .::, J ,~ ===================================================================== :::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~::::::~ ~.:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ¥:¥::~: ~:: S :k c¥.:_:::::::,_:_,:,~.~. = :: :~_~ 1500 1470.7t 1361.71 28 13 S 5.60 W 4.47 175.11 S 31.~3 W 177.~4 1600 1557.49 1448.49 31 20 S 7.50 W 3.25 224.'44 S 37.64 W 227.3~ ,. ::. :: ... '.: '.' ".: :.:' ..,: :::.:-':,,...' ..', '~:.,'.'.:: :.:.:~:..:~::.?';L..::.: :' :: ;::.:.:'.i:' ..'>~:: :. :.: <..:;::.:...:~x.~.;:.x~:x.~:~:,;:,x:::A:::.:::<~:, :.:..':'~;:'.:::,.~ ~..: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: '.. ::.... :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: . ,.:~.x;;::: x.:;~>:~(:p,:;x> ~ :;x:::...x..:. :..<..., :.. ~: ..:.~. :. :::::::::::::::::::::::::::::::::::::::::::::: .:: ::,.:,..,:.x. :. ::. ,' · . · :. . ::. · '.' ..::;;:....;.:.:..:.:2':::.'....: ..: :'.: .. :~,~ ======================================================================================== .~'~ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :~ ~ ~:: :.~::.j~::~::;~7~.:::~:~::;;.::::.~:::::::i:;::~:::.~:~::::::~.:::L.:~;~:?::.~.~:~::::`~.~.:::..::: ~.~ ============================================================== '~::..::.: ':::: ..:.:....:: ~ ~_~ .: ~ '.~_ ~ 2100 1760.~5 1851.~5 3~ 22 S ~.60 W 0.84 515.18 S 84.06 W 521.4~ 2200 2038.16 1~2~.16 39 32 S ~.50 W 0.18 ' 577.84 S ~4.60 W 584.'~8 :: ~ .: _ :. ,~ · ======================================================================================== ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~::~:::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::: x?.::::::;?; ~_~ ~: :; :~ ~.. ; . 2700 2408.25 22'~'~. 25 44 52 S 12-.~ 0 W O. 45 ~07.75 S 156.62 W ~20.60 ; 2800 2479.07 2370.07 44 57 S 12.60 W O. 36 976.72 S 171 . 72 W 9~91 . 20 . , '"' ' · ' · ........ ' ':": ' · · ".": ': ~, :'"":'",'.~":'~"':'~':' .'+'. ':'. +:~+:~::~:'.:.:'~: ',," · ':::,',.:.' : :..:::,~;~;~.~ :.:~.:.:.'¥~:~'~ .~ · ~::~,~:i::~:~, .~.~ !~.~:~. ~~ ~~. ~8~::~: ~ .~:~ ~ ~ ~ ~ ~ ~ '~ ~ ~ ~ ~ ' ~ ' ' "'~' '" ' · , . · · ..., .~:. ~.. :..,?~x.:,:~,......::.::~x.:...:>:,::,:. ,.... ~ ,,., .,.: ....... :., ,:~.~.:..:~:~/~.:~.:~.:;~',:.x:: ~< ........ >+~.+~<,:...p....~,~ ....... ' ....... ~.. ..... ~..'.., ..~..~...,:~:~.+....,.x..>~.~,~,.~.,..~.>,L+ ,,. ~:~j~,~' ~.A~:::...~'.~ .................. '.'"'.""'": .......... :,.:.,.x...:..:.:.:,: .:,,:,:::.:. :.:::. :,:.,..:::,..:.:.~x;:.. ~,:,'.' ".;'....,.:.' .:.' .. :". :. : '~: .. ',,. I<UF'ARUK ALASKA MEASURED DEPTH i ~0~: 0 :, ::3300 3400 OCTOBER 3, 1~83 dOB NUMBER AK-BO-30102 KELLY BUSHING ELEV. = 109.00 FT. ""~ '~ " ' ' ::: '" ':: ': ' U .. ::;,x .. ,..,., ':. ,,<,,,; VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH .DEPTH ~EG MIN DEGREES D8G/IO0 NORTH/SOUTH EAST/WEST SECTION ' ~ . . ~:7~:.~ !l~a,O0 2827.36 2718.36 46 21 S !7.39 W 1.14 1323.54 S 262.80 W 1349.32 2896.20 2787.20 46 38 S 18.69 W 0.98 1392.50 S 285.27 W 1421.42 ': ::: '~:' .::':':" : ~ :) ::'"::" "::: "" +'~ ......... ::: :::'.:::~ "'.;:'~ ':: ....... ::::::::::::::::::::::::: ...... ::':::::?'": ......... ':"~~:~::~:'~:.~:!:;~::~:::'" ~:'.:'.:: .... ::::::::::::::::::::::::::: '~. :::.:.:::::.~, ~ :::~.': :.:::::.. .............. · ...... ' . :: . :'' ::: :' c: :: · : :.:~70:0 ~:.::.~::~?:::~¢:::~:::~:~:.:~: ~ j~ :~ ::~:?.: :::~::~.::::::::~.::::~,.~:::=:~ :':~::~ ::::::::::::::::::::::::::::::::: ...... ' ::::': . .' ::::. ',.::: ~::::~::~:::~:::.~:~=' .... ~" ..: "": "' :'.- ~ ============================================= ........ ........ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::e ...... ·. :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::s:. :t: i: _ 3~00 3237.11 3128.11 46 53 S 23.60 W 1.02 1736.13 S 40~.~ W 1783.27 4000 3307.32 31~8.32 43 53 S 21.~ W 3.30 1801.81 S 437.43 W 1853.17 ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ............ ........ ::::::::::::::::::::::::::::::::::::::::::::::: ....... ,.., =. :.:,,.~=. ~. . ~ ... ... ~ ................. ~ ....... :- ....... :~ ~.,~ :: .:.,,. ............. ~ . .:~:; ~:, ;~::~i:,:;:..~: :; ' ,:~::t: _~ ":: ;:::m ..... ~ ::::::::::::::::::::::::::::::::::::~'::'-:~:~:::::: ' .~:::::::::::::::::::::::::::::::~ :,::.i:~!:.;:..,.~. )i::..~'., ' :.~.~:~ ~' :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::x ~m ..... ~::::::::::::::::::::::::::::::::::::::::::::::~ ~'7 :~ ~'::: j:::..~ a. -]~: ~============================================= ~ ..~ ~'~ ~ .x'i:i'_' '~ ~.~ :.~:. ~' '~:: .. iL-.::..: ..... ~ '~7 ..... ~m ~ 4~5u L<507,02 33~8.02 ' 33 34 S 5, 10 W 2,77 1~4&, 18 S 474,55 W 2002,08 .) 4300 354~. 57 343~. 57 34 1 S 4.80 W O, ~4 1~73.8'~ S 47&. ~5 W 202'3, 70 '-'.-'---'-'--'--' ....... ' ..... · ..... ~ ~ ,~<":':<'": '-?'?:'?: :.: .:.: .>:.:.:~:>>x.:.'.:..: :. --' ' '::::'::: ::::::::::::::::::::::::::::::::::::::::::: ":~::' ~: ::.7:: ::;.:; ?:.:::: ~'..":':' .~.:~:::~.::8~:i:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .:.: ============================================= ~::[.i:..:~.' .: I l ': ::::. 8.i.. :.. ::: : ~ ~ ._ 4800 3~58.58 384~. 58 35 26 S 6.60 W O. 16 2258.56 S 505.70 W 2314.24 4900 403~. 82 3~30.82 35 53 S 6.8~ W O. 48 2316.46 S 512.55 W 2372.32 : .- : .-<~i~..._:::;::3::,::::,.:~' ::::::::::::::::::::::::::::::::::::::::::::::::::: ' ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ================================================================================ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::=========================== :~:::< :~ . ::~?:~:: ~ ~ ~.-.,::. · ,-, .. i 5400 4447.13 4338.13 35 2~ S .8,19 W 0.07 2603.76 S 551.95 W 2661.60 ~ 5500 4528.41 441~. 41 35 4~ S 8. SO W O. 33 2~ 1 . 40 S 560.41 W 271~. 75 '~,~ ............. ~...~, .............. ~~~~< .~.~ .,~, ........ ~.,,,n.~:. ?~ ~ ... ::~= ,~ ~ ~, ,~ , ~ ,~ =~ ~,~, ~ ,-,~ ......... , ,_ ......... · ~. '....'.. '.:::',,.:' .: - :, ....~ ~':':.. >..x ~.~:.:.~:=;;:::>::~.?.<,~,.:,:::~:.....~.,>,.....: '. ...... ::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ..... ~.....>,: .......... :.....:.~x.,:..x-.::,..~;x;<x~:~=~..~:~:,...~.,>..<.> .......... ~2~<:x.:::...:x~,x.x,?x:.: .:,.:.,>: :::: ........ ~¢....~.::¢.x<x>..,:.;::::......;..~:..:~,.,~::..::.: >: :x<...~...,.: ,..::::.:..~...,,.:..: ..,, :..:;7,:.. :, . . :, , : :.. .?,:.?.;:,:%,: ..,,:,,.;,:x.;::.:t:..~,:,:(,:,?=,~:¥::,::,t,::~,~.;~.?:.!.:.:.::'~,, ,:,,:::'::,;.:..:.:,?:.;:.:.:,'~.,:...~.~. :.:c. =,:.~:.;.4~., '".~:.:<:.?+:.~.x,:~.:.:..~.~:~:~::,~:~:,'.;,?;::~=:~::.>:,.~,:.:.::,:,t ?,'~,:o:,?,:,H.'~?,,:.:,.:?, t., ~,...~+,~.>.,~,.~.~...~.:'.~...,~.:::~;:,~,~:,:,:,:,x.:.~:.:.~.~.~ ...... ~.::..~..~...,~,,.%,:.., . ,,:,,:,::: ,.:,,::t%~;ut~::~ ~u.:.~tx~ ,:~:::::::~%: , ,,,..>..,,, · , ..... ,.. , . .,. :=:, '?:: '. .... ... := ~:~ ":?:::. ::: :' ~ ~::~::~,~::'.: :,~: ~":::::::':'::=.'~:~:'~ :' ::~:~ :::::~::~ ~ ',~:~ ~:~:~:.~'~:~ ='~: .:'.:~:~ ~::?~:?::::~:~:~;~:~:::~:~:::~:~::~=::~?::~;~¢;~:~:~,~ ~ ~ ~'~:~:~~~:~i?.:~::~:~:~:~:~::~::: ::~ ~:~:::~::~ ~::~: ::: ~:~: :~ '.~ ..: :.. ~.:,~=.~:':': ::x,':~=:::~=:.:.:''.. :.:' :=:':~'~'::.~.: ...... :.: ~'' ....... ~111 I , , :" ..' '. :: %,?,,' ':t ,s: >' :::::::::::::::::::::::::::::::::::: :::::~?,:~?~:;:':::::~::~:~:. ,~:~?.~;~:~?~::~?~:t'.:~;:: ~:~?~:.;;::~::;::~%:;~,~,,::::~:,?:?:.j:?.:~;~;:?::5:: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :%. ',,',5:::<.?::?:::'~:,~:::.,:::::::~:::,::::,::t,:5;~:::,':::',;:,':':~;:' ':::':;', '.'; : ':' ?'" ':' t:',' ":~"%' ":: ..... 0 0 0 KUF'ARLIK ALASKA · ,,,, ,-,., ,.,~, ,...,.,,',r ,-, , ,-,, , ,.,,, r::"'!: ~,?~''''''' ........................................................................................................... ~'~is~"'-":' ~;'~ci~i~"C~':~:'~U~w' OCTOBER 3, 1983 JOB NUMBER AK-BO-30IC)2 KELLY BUSHING ELEV. = 109,00 FT. ~vl~ JUB~ .................................. '"~?'""':::~:~'GR~ ~%''''':?' ................. ~"~UR'g~?':':~-'::''':::: .............................. i.,uu-L~- u ~u~H~ MEASURED VERT I CAL VERT I C:AL I NCL I NAT I ON D I RECT I ON SEVER I TY RECTANGLIL~R COORD I NATES VERT I C:AL DEF'TH DEPTH DEPTH DEO MIN DEGREES DEO/100 NORTH/SOUTH EAST/WEST SECTION &O00 4937.01 4828.01 34 5& S 10. 50 W O. 31 2945, &8 S &07.4& W 3007.65 ~.100 5019.14 4~10,14 34 37 S 10.80 W 0.3~ 3001,74 S &18.00 W 30~4.&8 &600 5439.22 5330.22 31 & S 10. 10 W 1.29 32&8.03 S &&8.49 W 3:335. &7 ~.700 5525.3~ 541~. 38 29 5~ S 11.30 W 1.31 3317. ~4 S ~77. ~1 W 3388.48 :~:~:~{~?: ~?,~:?,?~;~?:?-'"':?:' ~::~:~ ~ ~:':'"'"::::"::' "'.~ "i .?:: :::~:'': f';':'~: ~:~:: "":::~:':~ ? :~..~::::?:~::~::~ !": ~'"'" ~:': :'t~:~; :":'~?. ~'~ :::' ..~ ::.' ~ :.~:?.'.: · ::':' ,~ ' :': .' 7100 5878.92 5769.~2 25 43 S 14,~0 H 0.96 3500.12 S 719.22 W 3573.24 7200 5968.72 5859.72 2~ 28 . S 15. 0 ~ 0.77 3542.~6 S 730.43 W 3617.17 ' HORIZONTAL DISPLAC:EHENT = 3797.01 FEET AT 80UTH ~ DEO. 47 ~IN. WEST AT ~D = 7600 · - ....... · ......... .......... .,-->..., ............ < ................................... ~-~.-, .............. -.... >...,-< ...... >..,~.~........ .......... '...-, ....>.>.., ..,.,.',..A -.,~ ,.~>,-, .,,.-x...+ ....... x,..,..~ ....... :::~:.,~::. ~.,+>xx.>.~.,~.~.,.., ......... > ................. -~,...>.~>,.....~,,.> .......... ¢.. ............ <,.. .......................... · : , ' ..:]': .:': ~:: '~:."~;~:::; ..']~:~:~:~::~:~.~:]'~:~: ::~::~:~:'] :.:.::~:~:::~ ~:~]¥~F~ :~:~:~:~ ~ ::~:~;~;~:[~.~::~:~.::::~:~:~:~:~:.::::~::;::::~:;:~::~:~:.~:::::~.:~:..::~:~:.~:~:~:~:~:~:~::~:~:.::~::::~:~..~::~;.~::~:~::~:~::::::~::::::~::::::;~.::::~:~:::~:~:~:~:~.:~:~:~:~:~:::~.~;~:~:::~:~;~:~:~:]:~:~:~:~:::~:~:~:~:~::~:~:~:~:~:~:~:~;~:~:::~:..~.:.::.~.;.::~:~.~::~:::~::~.~::~:~::.:::.:.::..~ ':F:::~:::.:.:::.:': :.::: :.- :. ~, ~..' ....... : :' .~ ;::.:::::_'_.; :: :::::: .:: ::::': ~:;: ~74': :.~g:::~::::::::~ ::~'~:~ .~: ~::::::~:::::::::;::: :. :: ::::::::::::::::::::::::: ~: :~ ~L~: ~: :~ ~ ~: ~::::~:~:g?: ::::::::::::::::::::::: ~:~ ::::: :~:]:~;~;~:]~: ~ ~ :~::: ~::: ~ ~-~ ~, ~ ~ ~'~:;~: :~: :. ~:: :~: ~:~ ~:~.::~:: :~::.::: ~::~:~:::~:~.~ c~: .~9;:~:~ ~ ~ ~::~.~::~ ~:: ~::: ::::,:~::::::::::::::::: ~::::::: ::~::::;~::~ ~ ~. :::~:::~::: ~:::~ ~ ~: ::~::: :¥:~:~ :~: :~: :::~:~::~ :::~:::::~:~ :::~:~:~:~:':: '::: :::-:. :~::.~ ~. :~::?~:~:~:::~::::: ::..::. ::- :-::?:: :.':: ::~- ::::' :': :... © 0 © TRUE SUB-SEA TOTAL OCTOBER 3, 1983 JOB NUMBER AK-BO-30102 KELLY BUSHING ELEV. = 10~.00 FT. MEAE;U~ED VERT I CAL VERT I CAL RECTANGULAR COORI]! ! NATES ' MB-TVD VERT I CAL ' ': ' ' t. t~~ ~ ; "~' ~': ~ i~::: '~ i~::~':~ ~::~::~':!~i~! %:~ ::~:~ ~'~C: ~::' ~ ~ ~:: :i ~I, j: ~ ~ :~ ~ :~" :: ~ ~ j ~ ~ ~ :: :: ~: ~ ':~::Z: ~: ~ ~ ::Z:: ~ ~ ~ ': ~E~ :::, ~ ~:Z~ ~: ~: ~: ~ :~Z~ ~j ~ ~ ~ ~ ~: :: Z~: :: ~ ~ ~ '~ I'~ :' ~ ': Z '' Z ~:.~: ~;~ '.~: '.' ~ i "~ i ~I:~:~::!~ :: ~ ~: ~:~:~ ~:' :~: I: ~ ',~, ~ ~" ~2~':~:=:,I~ :i~:~':~::~ :: ~::~::21:~ ~:~ :I :,~ I' :: ~::'i~ ~:~j:__~ ~ ~ :7 ~ 'I ':': ~" ~: ~ :: ~: :I ': ::~:2~: ~ ~': ~ ~ I: ~ Z, ~ ~;~ '~: ~' ~ :: :'::'::':, ': ~ ~::~ ~:.':~ :.: ~::', ::~Z~ ~ ~::i:: '= ~" ~:::~:. ,~: ~: ~::':~':: ::~':~ :.~;::~;; ~ ~ ::~ :' ~: ~ ::~: ~ ~:: "~:':: I : :: 2000 1883.1~ 1774.19' . 453.21 S 73.47 W 116.81 115.44 3000 2620.04 2511.04 11!4.~~ S '..204.72 W 37~,9~ 263.15 .................................................................................................................... ~ ............... ~ ...... ~:~.,..:.:~ ........................................... .:~.~ ....... ~:::~ ~ ........ ~ :: ~:~: :~ ...... : .............. '"~ '::' ::' ~': :' "::' :':::::::::~:": ..... '~ ~":~:~:::' ~'~' ~:~"~"~::: '~": '~ ": '"'"'~:z~ '~:~" '~' ":~"~ .... :~ ~":';~ ~: ~ ':' :' '~" ':"~:':~:~:~ ~ ~ ~; ;:..::: ,. ... :: i i: :,:.:,,,.::::,, ,i.,. ::., , :.. ' , .' ',::~' ::,,:.:.,.:,::,,~ :.u.",,: 4'.":::: · ,.,.:..::, ': .,:,:~.-,4: .:::::,:,::,:,:,:,:,:.:,:,:~5,'.::.:, :,.<f ....<:;'::~:,::,::':::, .,:::,.,,.::::::::::~;~::::'::::~,::~,:~',: ~:,:"~,',:::~" ..:~::: .:::<,,: ,. ::.,:,..:.:."+:,,.,,, ~p,.':,,,:':i::.. ,:.:::~'?:::::::::~::..:::::::.::v..,::.~,.,.,:::, ,,:? .',:.:,,:,,,L.,~'::~::::::~, :::::::::::::::::::::::::::::::::::::::::::::::::::::::: 7600 6325.~0 62!6.90 37~,~6 S 775,5~ W 127~.10 , 63.18 0 0 0 ":':::':::~:': ::;:'"":~":'::'";::':: :::: : :':::::: :::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: " "::':' ' ':"~::..,:~...i! :::i:iii ~ i~ -"*"' :::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :~:::::-'::::::: f::~::::'::::: :' ::::::::::::::::::::::: ':: ::::'"::: I KUP~RLIK , OCTOBER a, l~8j dOB NUMBER AK-BO-3OlO2 . ALASKA . ' . ' ' KELLY BUSHINO ELEV. = 10'~.C~0 FT. ~: ~ :;~:.:: ~ ,~:L :~: ~:.: ~':? ?.::: :~ .'~:~::?':TL~.~:~:.:.::':::':~:.:~F~i~:,~::~::~ ~.~?::F:~::~'?:?:?~:~'.C:::: :V:~'~:?.~::~/.?::.~:::.::::~::~::~ :~ :::::::::::::::::::::::::: ~::::~ ?~::.'/?':'~.~7:~ ':.:: :.'...:.?.:~.;~'.~: ~?/:~:?.::.~::~(~::??.'.?::.~:':~::?:~:, ;::':'.::~::':::::~.~:(~:. ~: ': ; '. :: ': :~ ~:,~;~...:: ~.~/:~?~?~?~'.'.::::::.~ ~;::::'~::.~::~'.~/.~;,~;~;?:~[~?: ?:~::? '~'.~ ~:~¥:>:~: ~ : · ~: : ." I'RUE SUB-SEA TOTAL MEASURED VERT I CAL VERT I CAL RECTANGULAR COORD I NATES · MD-TVD VERT I CAL , ~ .... ,:. ,,.: ,,, :: . ,::.::::;,: :,.,: :: ,:.: ,::1: ..::: ~ .~:~::,:.~ ::.:,,:::1:::::::::~ :: : ' :...: ::: ... ~, /, :!: :'.,.~ /::: : :: : ' : : '.:: .', : : :: ~ :. ~ ': ': '. :: : ,':' :'., : :, , :~ :': ' ::.::' ,: :: ', , 209 209. O0 100. O0 O. 07 N I, 10 ~ O. O0 O. O0 309 30'~. O0 200. O0 O. 48 N 1,82 ~ O. 01 O. O0 ~::. ~ :'~':. .. :.. % .. ~,~' ~..:..~:~:~::~::~ ~i~:~:~:::'..~ ~.~:~:~.~j.:~::: ..~~!~::~ :~:~; .~:.r,j:f~ ~F~,::.:.::..:~:::::p.:~:::i:~:~:~i:::::::..~::~ ~....::: .::::: ..... ~:::'..:... ~ :::. ~:~ ~ ~ ~::) :?~;::: .~;:~;~:~::~::::: :, : ~..::~:~ ~::: :::::~::::~:::::: ::: : .' : : . ...... :'.:. :~:::~::~::: ::::::::::::::::::::: .:~:::::~: ::' '(:~,: . ' ::::~:.~::~:~':~:~:~s~:~,=i::~::~.:~::;:::~:~ ~: ~ ~ ~::,~i~::'.~i~:.~:~ ~ ~ ~,~:~:~,~:~:~.:~i;{~i~:~:~::~..~ ~::::~:~!..~ ~.~.~i~(~i~..~i~.~ ............................. . ....................................................................................................... 809 809. O0 700. O0 O. 34 S 4.58 E O. 12 O. 08 909 909. O0 800. O0 8.40 S 2.64 E O. 47 O. 36 ' (, / 14:30 1409.00 1300. O0 144.24 S 28.33 W 21 . 90 8. 75 ~ 1543 1~09, O0 1400.00 196.15 S 34.17 W 34 76 ' :~:::~:::"~i~:~ :~ :.~> :''~ .~:~::~:~:~:...::~ ~ ~. ::~:~.~:~::~:::::~:~:'::' .... ::~:::~:~:~::~9:~':' -~:::'" '"'~" '""~:::~'=..~ ...... :':~:~:..::s :: .-.::': :~::~':~:~:. ~ ............ '~' :'",~ '~ ~.....~..~:~.~.~..~F~.....~`~;~..;~1~.~.~.~`...~;~.~.~. ~ ~s ~ ......... ''? ~::: ::~:~:~'~::~:~!~:~:~ ~:~?~.' ~.~:~ ~:'~,~:~ ':~:~'.,:::~.~:~:~ ~: ~ :~:~::~:~::::?~'-~ :~:~ :~: ~ ~:~,~.~ ~ ~,~.:'.~::~:~!~ :~:~::s~:~:~ ~ .:~ ::~ ~::':~'~.~ ~' :.::"::::-~ ~.~.~::::~. ~:?:~.'~:~:~.~.7 ?:' ~'.'~ ..... 0 / KL F ARUK OCTOBER ALASKA TRUE SUB-~E~ TOTAL '~:' ' ,~" ::::::::::::::::::::::::::::::::: '~i.!?{jx::::::::: '::: :: :~.." ' :::: ':! : ':'::~ '.::: ':.: ':..:::::.¥ ::.:'::: .. ~:::'::L:::.: :::; ' ~'..'::'. :;':: ':.. :":~: : ,:,x,, . : .:~m:.....,..: ~:,i : ::::: : ; ::: ~,.::, , ,: :. :;:.': i : ] , :: : ;': ,'::' : :' : ', ,".:: ': ~1 . i~ , , -: ;,' ~. h ,,I .... 1~83 dOB NUMBER AK-BO-30102 KELLY BUSHING ELEV. = 10~.00 FT. :: % , ,~ ~: ~ : ' :~:~ ' ',,' .~'~ ..~' ' '~¥.F "',:5:: "~:~::~' ' . ,2, ~;~ '~:]: ,'~ ':.'::'?' ,'~'"L: '~:'::~']?""' ,' ~'" ~ ~'~ :',,?L~?::~5 2 ~:'/:~L'.: :.: ' ~ ' ~ ' MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES' MB-TVD VERTICAL · *.>o~ 2109 O0 2000.00 635.84 S 104 21 W 183.05 29 87 2423 2209. O0 2100. O0 720.20 ~ 118.26 W 214. ~4 31. ~ ............ · ~L~~~~C~ :3~E~c~ ,'-'~ ~.~ . ~t ~ m ....... ~, z~ ~ r,~ ' [~:~'::/?:?~::/~::':.. ~:,:.':?~ .... :.:.~?::;~': :.':. . . '~::': ........ :~?::[:,[~::~?~L.. : :'":::::.¥' '"'"]?~::~q~¢::~'~?:?..¥'',:,' "~ :::::::::::::::::::::::::::::::: ~ ' ':~:~:r '...'.~,~:~:;:~.;:::::.~,:,~,~;; ............ ~ ............. . .............. . ::. :::, :. .::. .... ...... :...::.:,::. ....... , . 3127 270~. O0 2600.00 ~ 203.27 S 227, 74 W 418.63 43.34 3273 280~, O0 2700.00 1305.17 S 257.04 W 464.3~ 4~. 7~ 4002 ~309. O0 3200. O0 1803, 27 8 ~8. O0 W ~.9~. ~0 4:3.44 4131 3409. O0 3300. O0 1880.94 S 464.05 W 722.73 29.44 ::.::4':' ::::' ":" ' ~': ": :':.'.:'..:' :'::::"."" .'?'::'? :'J~'" :'-' '"::~.:.:~:::::.:.::':::::>:::~--'"~'-:':'.'-" :::S:,'::.-..:~-':. "~::~::~:~k:::~:~::::~.x,x~' x.:::::f~k.. ::.::~...:":.' :..' .~.:.::':......::'.:':.~':~::.:~::::.~::.'>~'.-'.::..~'.~::':~g:~?~::Y:~:~:.:::'.'..::x:~c ~:'.'>'>::'.x.": '::' ::'.v~..'. ......::::~>~:..::::: ::?-::?: :':::J::'~>.+:+.......~.:*- ============================================================ :::':::':' ::..::::::.::::: ::::: ': ': ·: '" :: .'": ' :. ,.'>..'. :,,.,......+.., :.:2 :>:'-9 .' '. '- . .... ..... - ,,. ...... -..q~,;+>~.,~+~+:..::. .:. >:q.x.<;q~.~..,..~..,~...,~ ..~..:+. .. ...... >~ .:.:~.:+::..:~.,>:~,x...:.::5,':,. ~'~.>~.::~q .,~i~,.>,>.+.-. ~¢5~{~:' ~:~}bB~.x.~:.:.'.....:.'.,>.5~j>5:~::.+.:+:.:..v.'.~..>+~..,>.', >-... .'.'.. .~.>.h:~::.'q.~.-~..:..>4:.:,..-.'. ;+.>:.'.:,..::+:,..':,.: ':: <':.'..- :.....'. '- .q ...... ' - · .. , O : O I ,, :.; .., ,.. .. , ...... ...: ................................. ,,.:,..,~ ,.,,: ,,, : ,,..,:.., :.::: ....... : ,: :.., :~:::., :,:,:,:.,x.x:... x.:,:,, ,,., .. ....... . ..... ','.'.:...,,..~, ,. ¥,..,.t ....................... ~ ............................. ' ...... ,,;~ ,..:, :::: x,xxx., ~ KUPARUK 'OCTOBER 3, 1983 JOB NUMBER ALASKA :.:!::!.:::::,']:::~i!i:! :: :;" ' .. ': [ '[!:,.: ~::;~i~?::!~!:!:[!~::~:~:~:?~.~:!~:~.~::?:?.~!:~:~.~:7.~!:~:i:~:~!:~:~]:::~?!:{~:?~?t~;~?.!:'.':.:::h::!::.:i:!~.:.:? ' . ':? :~?:,: ~ :i :i~i,]~,, .[[: ':i',~[ ::~:: :..':: ~t~.:S~.~i :: ~S::'~::ZS S:' ~i~.~:~ '.~iC~i',~:~:::.?~.::~::Z:~::~ ........... TRUE SUB-SEA MEASURED VERT I CAL VERT I CAL .:: .y:?:~': f:. ', 4616 :: '880~, ~ 4861 4009. O0 3900. O0 4~85 410~. O0 4000.00 KELLY BUSHING ELEV. = 10:~.00 FT. TOTAL ~ECTANOULAR COORDINATES , MB-TVD VERTICAL 22m4. 2 s 5o .e7 w 2mms. em s 51e. 71 w 852. ~6 22.83 876.21 23.25 .... ~ ,-,-? .,,.-,-,,n ,-,,.-, ,, ~ r,,-, ,-,,-~ ~ ~=' ~ '='-~'"~ """' ' ~~!!~!~ ~ ~i~!~ ~ ~!~i~i~ ~li..[."~ ~ii i~/!~ii 1 i~i?~~:?. "~?¥:~??.?~::~?~!..- ...:?., '~: :~-'.... ::... ' ". "'r i:i:: '! · .~ ' [": i:'?:[ ~,' .... i!t: .....:..:.)ii:'' ~ '""'! ??!' 'f' "'xti:[ii[!!i:~i!h!ii!~ii:i!ii!!~iii' ': .......... K":~'::r:::?'"':",~ ~i!'.~:~:.':ii~;~?~l~F. ""'~~ ''''' :??'"" ::" :?": t 55~ 4609.00 4500.00 2718.34 8 569.18 W ~90,07 22.~8 5721 470~. O0 4600.00 2788.36 S 580.26 W 1012.64 22.57 : :,.::,..:.:.. :::,:: ~ ...:.?::. ~ :: .,..?:,:~:~.: .~.~..: ...:~:~:j.:~ ~.:~:,.. . .... : ......... ~.:.:~;~?~6~ ......... :..y;q::..-. ~ 6328 5209 . O0 5100. O0 6446 530~. O0 5200.00 0 0 © · I<LIPARLIK OCTOBER 3, 1983 .JOB NUMBER AK-BO-30102 ALASKA KELLY BUSHING ELEV, = 109.00 FT. TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES ' MD-TVD VERTICAL __J~IJ~F4~J~.~_ . J~,~U r~u ki,~O~lJ l~,i I~l i ~A~ ~l iE~,~ r,T~rrr,~Al~E .-.,q~~I~l 7133 5909. O0 5800. O0 3514.16 S 722.85 W 1224.39 7245 6009. O0 5900. O0 3562. £)5 S 735. ~1 W 1236. O0 ,.. .t ::...:.::, ... , :,. ,.:,.. :,:, :..,,., ~ . .::::,:,.:,.::t::?,, ...:.,..,.;~ :::::: ~.... .:..: ....... : ..... ~ ~.... ,...,.....,?~.,.~::,~ .,.::f~:~.. ,..,:.~, ....... )~.~.::5,...,,...,.,.,,,.~::~.,::::~x:,~;~,..~.:~]:~.,,.,t..,,~.~ ........ ,.:~,:::.:?:.._ ~/f:::E, _~.._:~j ,~.,~,R._~ ...... . ..... . ,:: .: :: ,:. '/ .' ~ ~:~.,:'.::,,'~:,~ ;,." ,. .4,,'; .:::~::H:~:. '. . : ,' , .¥~:~:::;;,:.f: ~::~j~ :' . ~. ~;,,:.: :' ,*: , ~:,~',,T::~::.::';~:::~tLt. "'~ ~:.' '~ ':~ ,'" :::::::::::::::::::::::::: ~" ' '.:: ~'" ~::.:::::L '. :. ',:' ~ :' .', ,': THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (~OM ~ADIU~ OF CURVATU~E~ POINTS : u,:,: :,:,:. ...:..,:..' ::.:: : .:: .,..... :.: :.::,::.u: ::::::::::::::::::::::::::::::: ,:.:.::.:.::.'.~:,:-:.:.:.:~-'..:':.::-:.:.:.' .:`::::::~:.:.'.::.:..::::.::.::.:::::~:.:.:.~g:~::::~.:x::..J.:.:::>.k~.::.....?~:¢:2[~?+:.::... .":,~:.~,.~,:+::.:.y:.'.'::'.:q~,'.'.:.>::,':'.'.','."'" .'..*',' .'.' 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'.2_ i: . ............. · Il'& F--L~ 7 % ,~r"'~l.. .I, 7 I ,I, .I, I~1 I'~.1, L.~r' I bLII'Ir~U I M I-.L Ul4 ,LIH I ~ KLIPARUI<. OCTOBER 3. 198:3 ,,,.lOB NUMBER AI<-BO-30102 ALASKA KELLY BUSHING ELEV. = 10'.~.00 FT. ~s~.~i~::~i~i~i[..i!i~i!~!~i~::i~iis.....~:~[~ii:,...:.i~::~i~:.`.~:~!~.~:~!~i¢[!!!~iil..!~J~i~:.~`~:~.~i::i~;:~.~!?i!i:ii:~.~!~::~:i~i.:i..~.:r!i..:ill;ii:}!~}~ 726,2 6024.20 591 ~5.20 3569.40 S 7392 ,6140.31 ,6,031 . 31 362~i. 96 S ', :., :~' .....:. :... · ,'..,:, . ...': : .,;, "::: ~:,: :::~ ::.:::I.,..,: ':..:.:'.:.:. ,.:.'.::.... :,.: ,.,:, ,. v. ::::::::::::::::::::::::: ....,:: ~,i: :: :::!1::.. !:...':,i:i::.. ::!::b :! ::: ::.:::~'.~:~]~ :::: :: ::~:~'~:~:::~:i~:~::. :::~ ,~:~:~ .:.:: ::....::'.'~:~:~ 737.57 W TOP LOWER SAND 752,,34 14 BASE LOWER SAND .,,;;:.:;;:;;,,:;::,,,;,;: x ;::::; :.: :;:,,;:;),, ;,.;:':,;x:.:,,,::',;:.',:~:::',.;Lc~, :;;;;~:;;;:: .: :: ::;;:::;:x~`:~::~;::~:;x;:::::;:~;;~:~:;?:;;~`~;~:::.4~;~;;.~.~:~::.~:~.~.~;~;.;.~:::~. . ,.;, : ~ ~,, :~::,'::;::, , , ..:.:,.mx:',:'.:m:,?,: ............................. " .................................... :' 0 I BH I 1 g~Hr ~ 1 g OUI'II'IH~ DER I gED USING D IL DEPTH~ ~ND SPERRY . , ................. ~ ~ ~,~~~ TOP UPPER SAND 7143., 5917.66 5808.'66 3518.19S 723.90W ) ',: ': , .... . ::' :' ,:x:; :::::::::,:::::: ":: ~ .... ::::::::::::::::::::::::::::::::::::::::::::::::::::::: :x::::, :.,'.':::::::::, :: , ,' ' ' ~ :: :: :: : .: :: ,.'::: ',:.:: :m.::: ::::::::::::::::::::: :::m:. ::::::,x:, :h: ..... :,:::::::.::::: · x,:,:: :~ ~ PBTD 7462 6202.77 6093.77 3656.59S 760.15W ~6.., 775.54W ~ TOTAL DEPTH DR I LLER 7600 6325.90 6216.90 3716. ~ c. ::::::: . 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Our Poss Gyroscopic Survey Job No. kK-BQ~301Q2 Well: ~1 F-09 (SEC 19 TllN R10E) Kuparuk Field North Slope, Alaska Survey Date: October 1, 1983 Operator: Samec Scale: 1" = 1000' TRUE NORTH $- ~1000.00 ~3000.00 Surface Location 630 FNL 484 FEL 0.00 ~ ~4000.00 H 0 R 1_1_1_f Z 0 N "l-.q L PROJECTIaN ~RCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. AK-BO-30102 Well: .~1 F-09 (SEC 19 TllN R10E) Kuparuk Field North Slope, Alaska Survey Date: October 1, 1983 Operator: Samec Scale: 1" = 1500 1500.00 3000.00 4500.00 6000.00 7500.00 3797.01' @ S 11° 15~0.00 47' W 90~0.00 VERT[CRL 75C0 I 4500, O0 ?BOJECT ~ ON Suggested form to be inserted in each "Active" well folder to d~,eck for timely compliance with our regulations. Operator, Wel~Na~ and Number Reports and Materials to be received by: /!--/~F- Date Required Date Received Remarks - Cc~pletion Report Yes /'/ '. We11 History -Yes //--, -.. Samples __- _ .- p~ .... · ,, Core Chips " .,"4'"/.~ ,.,,~/',~] .... '~ (J~A~. Core Description . / ~ /~-~ .... ~ x:-'.. U,"\ Registered Survey Plat ~/~-~.~ / ~ -' ~ '7~ ~.:~ d 4`./ Inclination Survey ~//) ~., , ~ - Directional Survey yc~~t //- Drill Stun Test Reports //,4/. ~.://?~ ---..,.--------~ /-'~ ,~" , · Prcddctidn Test Reports ~ ........ ~.~ ......... ~ ........... :5:.--?":'~'?~'~ - ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 4, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1F-9 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG' tw GRU5/L24 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~ ,LAND GAS CONSERVATION CE MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E3XX OTHER [] ~.Nameof Operator ARCO Alaska: Inc. 3. Address P, 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 629' FNL, 484' FEL, Sec.19, TllN, RIOE, UN 7. Permit No. 83-!04 8. APl Number 50- 029-20983 9. Unit or Lease Name Kuparuk River Unit 5. Elevation in feet (indicate KB, DF, etc.) 109' RKB I ' 6. Lease Designation and Serial No. ADL 25652 ALK 2578 10. Well Number 1F-9 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). RU Dresser - Atlas. Ran GR/CBL/VDL/CCL to 7443'; good bond. Ran Gyro. RD Dresser - Atlas. Secured well. Accepted rig @ 0200 hfs, 10/13/83. ND tree. NU BOPE & tstd to 3000 psi - ok. Perf'd 7172' - 7164' & 7164' 4 7144' w/12 spf. RIH w/WD pkr & set ~ 7229'. Ran 3-1/2" completion assy w/tail ~ 7253' & SSSV ~ 1911'. Stin~ into WD pkr ~ 7229'. Pulled pkr locator sub 1' above WD pkr & spaced out. Installed BPV. ND BOPE. NU tree. Pulled BPV. Tstd tree to 3000 psi - ok. Disp well w/30 bbls diesel followed by Kuparuk crude oil. Dropped ball & set RRH pkr ~ 7012'. Closed SSSV. Set BPV. Secured well & released rig @ 1630 hfs, 10/16/83. 14. I hereby certif,~that the foregoing is true and correct to the best of my knowledge. ///.//~.~~ Area Drilling Engineer Signed Title space bel/~Wf~C~o~ission use The ConditionsX)f Appro~, if any: Date By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRUS/SN03 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 November 4, 1983 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Commission Dear Mr Chatterton' Attached are notices of our intent to stimulate Kuparuk Unit Wells 1Y-11 and West Sak SWPT No.1, and perforate well 1F-9. If you have any questions, please call me at 263-4527. Charles K. House Kuparuk Operations Coordinator CKH/kmc Attachment (In Triplicate) ARCO Alaska. inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA UIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ID( 2. Name of Operator 7. Permit No. ARCO ALASKA, ]:NC. 83-104 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 50- 029-20983 4. Location of Well 9. Unit or Lease Name OTHER [] SURFACE LOCATION' 629' FNL, 484' FEL, T11N, R10E, UM BOTTOM HOLE LOCATION' 4471' FNL, 1176' Sec. 19, KUPARUK RIVER UNIT 10. Well Number 1F-9 FE L, 11. Field and Pool SEC. 19, TllN, 5. Elevation in feet (indicate KB, DF, etc.) 109' 12. R10E, UM KUPARUK RIVER FIELD I 6. Lease Designation and Serial No. KUPARUK R I VER O I L (RKB} Pad 80' ADL 25652; ALK 2578 POOl Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate j~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion,) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Ini MMS flAir tIAT~ hou the cle pre tial test data on 1F-9 indicates that the well flows approximately 4 CF of gas per day with very little oil. Due to the uncertainty of the Sand's capability to clean up; ARCO Alaska, Inc. proposes that the Sand be perforated, flowed, and production tested for at least 8 rs prior to installing dummies across the "C" Sand. This will allow "C" Sand gas to act as a lifting mechanism during the ~'A" Sand. anup. After the "C'' Sand is isolated, both a production test and a ssure transient test will be obtained on the "A" Sand. IIA~T Sand Perforations, 7275-7288' 7304-7330' 7336-7340' 7346-7351' Kuparuk Wel 1 1F-9, DIL Depths' Subseo/zent V/ork Reported on Fo'.~. No./~ 14. I hereby certify, that th~ foregoing is true and correct to the best of my knowledge. Signed ~ /~t~¢~--~--~ Title KUPARUK The space below for Commission use OPERAT ! ONS COORDINATOR Date Conditions of Approval, if any: Approved by IY HARleY W. I~U~LER Approved Copy Returnect By Order of COMMISSIONER the Commission Date Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 15, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton- Enclosed are the Nonthly State Reports for the following wells' 1G-10 1F-10 1G-11 1F-11 1G-12 1F-12 1F-9 1F-13 Thank you. Si ncerely, t Dril ling Engineer JBK/SHiO' sm Enclosures ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ' ' ~ .... STATE OF ALASKA 0 ALASKA, ~ AND GAS CONSERVATION CC ,VllSSION j~~ f4 NTHLY REPORT OF DRILLING AND WORKOVER OPERATIO 1. Drilling well J~]X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-104 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50-029-20983 9. Unit or Lease Name 629' FSL, 484' FEL, Sec. 19, T11N, RIOE, UM Kuparuk River Unit 4. Location of Well at surface 5. Elevation in feet (indicate KB, DF, etc.) PAD 80', 109' RKB 6. Lease Designation and Serial No. ADL 25652 ALK 2578 10. Well No. 1F-9 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of. September ,19. 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well (~ 2115 hfs, 08/23/83. Drld 12-1/4" hole to 2399'. 9-5/8" csg. Performed top job. Drld 8-1/2" hole to 7600' TD. & tstd 7" csg. Displ fluid in wellbore down to 110' f/surface. rig (~ 1915 hfs, 09/01/83. SEE DRILLING HISTORY Ran, cmtd, & tstd Ran logs. Ran, cmtd, Secured well & released 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8" 40# J-55 HRERW BTC csg w/shoe @ 2341 '. Cmtd w/1000 sx AS II I & 250 7" 26# J-55 HFERW BTC csg w/shoe ~ 7544, Cmtd w/675 sx Class "G" cmt. sx AS I. 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/FDC/CNL/CAL/GR f/7581 ' to 2341' 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. · TITLE Are~ Drilllnn Fpo~n~er DATE /(2 _ - Z. Oil and Gas~onserva~o~2~ Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-4'04 Submit in duplicate 1F-9 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 2115 hrs, 08/23/83. Drld 12-1/4" hole to 2399'. Ran 60 jts 9-5/8" 40# J-55 HFERW BTC csg w/shoe @ 2341'. Cmtd 9-5/8" csg w/lO00 sx AS III & 250 sx AS I. Bumped plug w/1500 psi - floats held - ok. ND 20" Hydril & diverter. Performed top job w/122 sx AS I. NU FMC wellhead. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 7600' TD on 08/29/83. Ran logs DIL/SFL/FDC/CNL/GR/CAL f/7581' to 2341'. Reamed hole to bottom. CBU. Ran 189 jts 7" 26# J-55 HFERW csg w/shoe @ 7544'. Cmtd 7" csg w/675 sx Class "G" cmt. ND BOP. NU FMC packoff & tbg spool & tstd to 3000 psi - ok. Displ 110' in 7" csg of brine and left hole void of fluid. NU master valve. Secured well & released rig @ 1915 hrs, 09/01/83. HILL/DH47 10/17/83 18 19 { -. PHASE II -AS .BUILT, WELLS 9 thru 16, DRI! .... 'SITE I-F CONDUCTORS AS BUILT LOCATIONS 17 WELL 9 ¥=5~958,895.613 Lat. ?0e 1~55.1255" ~20. X= 539,491 4.97 Long-149°4'O'48.661'' 6:50' F NL 484' FEL tNEEL lO Y = 5,958,95a*'679 Lot. 70° 17'55.7070" X = 539,480.848 L~g. 149°4~ 48.962" 570' FNL 494' FEL WELL I ! Y = 5,959,015.762 Lat. 70elT'56~SB7" X- '5'~9~470.2[4 Lmui. t49440'4~;2~ 5 11 ' FNL 504' FEL WELLI3 Y~"a, s59,140;04'/' Lat. 70017` 575120" X= 539,853596 L8~. 14 9440' ~8. 650." . 387' FNL 159' FE L _ WF.L. LI4 Y'- 5,959,081.057 -Let. TO° 17'56.93t2"' x= 53~,844.251 1.~,~.,149~1~'~" · 446' FN.L 129'FEL 'WELL 15 ' Y=5,959mOE[OOQ' Let.T0e 1:7'56.3498' · X: 539,854.796 Lon~. 14~'~4~58.05-" ' 505' FNL 119' FEL PHASE I WELLI6 Y: 5,95e,9~.89~ Lm.70orr'55.7677" x. 539,865.492 Lor.]. 149 040'$7.74 8" EXISTING 564' FNL I C9' FEL WELLS I thru 8 ..... · . ,T~?.....-.,...~e;~, [, NOTE, BASISPER I. HDOF ELEV.8~. ASSOC. IS TBM I--F MIDDLE. LOCATED IN' PROTRACTED SECTIONS lO1& ~,2~.~ 'r.: ..~ . TOWNSHIP Ii N.~ RANGE I0 E., UMIAT MER. S MIDDLE AND I-F SO~H S-~ ~ LHD and ASSOCIA~S 6 18 19 I HEREB~ CERTI FY THAT I AM PRO PERLY REGISTERED AND. LICENSED TO PRACTICE ~LAND SURVEYING IN THE STATE OF ALASKA~ AND THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT ALL 'DETAILS ARE CORRECT AS OF · AUG 5~!983 : ARCO Alaska, Inc. Kul~eru# Project North Slope Drilling DRILL SITE I-F AS BUILT CONDUCTOR LOCATIONS date: 8 --II -83 ,clle: I": 400' ~ .... ~. · P.I~ dwa_ ~.NSKg_I06 ~ d4 KqJP~K ENG ! NEERI blS TO: William VanA! en DATE: ~: D.W. Bose/Shelby J. IVlatthew~.. .. · ~' O/ TranSmitted herewith are the fol lowing- PLEASE I',DTE: BL- BLUELINE, S - sEPIA, F.- FILM,~, PC- [TDI'{:EOPY p,~~PT A..Q/,J'-IO,¥1 Fr~ED: E P.,EnJ~N RECEIPT TO- DATE: ,_., i:_, ~:~ ':'. ~.~.¢ g 4 . ~ ~~, !~. Alaska 0il & Gas Guns. Commission Anchorage 'A~: ~E~Y J. ~lg~ - A~/1115-B P. O. ~X 100360 ~~~E, ~. 99510 :FROM: MEMORANDUM State of Alaska ALASEiA OIL A~D ~AS CONSERVATIO~ COM~IISSIO~' Chai~k_/. /.,( / " FILE NO: ,.~~EPHONE NO: TO: DATE: _ TP...rU: L~nnie C. Smith Commissioner . · -Ben LeNorman SUBJECT: Petroleum Inspector August 29, 1983 108B :T1 Witness BOPE Test on ARCO ' s Kuparuk iF-9 Sec. 19, Tll~.',R10E,UM, Kuparuk River Unit. ~.e~...ne..sd. ay,~August _24, 198~: I departed my home at 3:15 pm for a 3:45 pm sho~ap and 4:45 pm departure via Alaska Airlines, Flight %341 for Deadhorse arriving at 7:10 pm. Weather: +37"F, over- cast, light wind. Thursday, AugUst 25, .... 1.98.3: Standing by at 1F-9. _F._r..~iday, Aug~ust 26,_. 198.3: BOPE tests began at 2..45 am and ~re completed at 3:45 am. BOPE inspection report is attached. I departed Deadhorse via Alaska Airlines, Flight #66 at 9:50 pm arriving in knchorage at 11:20 pm and at my home at 11:50 pm. In summarY, 1%~tnessed successful BOPE test on ARCO's Kuparuk 1F-9. Attachme_ nt I i 02-00IA(Rev. 10/79) 4/8]. -- STATE OF ALASKA ALASKA OIL & GAS flDNSERVATION COM~iLSSION B .0. P .E. Inspection Report Operator Representative Well yU~'~FZ//~ /_3~~' ~ Permit # Location: Sec /~ T//~R/~'M ~;~ " ~~asing Set @ ~ ~ 9&/ ft Drilling Contractor ~]w~/~f~ Rig #-/~/ Representative~~R -~ /~. ~ ~ O ~-~ Location, C~neral Well Sign_ Ceneral HoUSekeeping Reserve pit BOPE Stack Test Pressure ACCUMULATOR SYSTEM Full Charge Pressure Pressure After Closure Pump incr. clos. pres. 200 psig Ful 1 Charge Pressure Attained: psig psig Annular Preventer Pipe Rams ,~ Blind Rams Choke Line Valves-- H.C.R. Valve Kill Line Valves ~ Check Valve Ms c. rain ~ / sec. N2~ ~/~D ~/ ~A~0! .~ 9~o~ ~~0sig Controls: b~ster Remote ~/~_ Blinds switch cover/~,~_ Kelly and Floor Safety Valves Test Pressure Test Pressure_ Test Pressure Test Pressure Test Pressure Upper Kel 1y Lower Kelly Bal 1 Type Ins ide BOP Choke Manifold No. Valves __ No. flanges ~jUStable Chokes / Hydrauically operated choke Test Results: Failures, O Test Time,' / , .hrs Repair or Replacement of failed equipment to he made within Inspector/Ccmmission office notified. ~,~,~.~_~7-~. =~ ,-~7' ~ -' ~- ~., days and Distribution orig. '- AO&CCC cc - - Operator cc - Supervisor Inspector/~~/ ARCO Alaska, Inc.f ' Post Office b,.,x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 July 13, 1983 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1F-9 Dear Mr. Enclosed complete Since we earliest approval will be appreciated. questions, please call me at 263-4970. Chatterton' is a Sundry Notice for the subject well. We propose to this well with our workover rig. expect to start this work on October 1, 1983, your Sincerely, ~/__~__4,~Area Dri 11 i ng Engi n'eer JBK/GRU3L75-sm Enclosures If you have any ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ..}IL AND GAS CONSERVATION CvMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 4. Location of Well Surface: 629' FNL, 484' FEL, Sec. 19, TllN, RIOE, UN 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-104 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20983 5. Elevation in feet (indicate KB, DF, etc.) 109' RKB I 6. Lease Designation and Serial No. ADL 25652 ALK 2578 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1F-9 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [~]X Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other I~X Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to complete this well with the Westward Well Service Rig #1. The procedure will be as follows: 1) A mast truck will be utilized to run the CBL/VDL/GR and Gyro. 2) The rig will be moved on location; the BOPE will be nippled up and tested. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. 4) The well will be completed with 3-1/2", 9.2 #/ft, J-55, BTC tubing. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated start: October 1, 1983 Subsequent Work Beporte~L ' on Form No./~-z/~3 Dated/_/__[~__j.~ 14. I hereby certi~ that the foregoin~is true and correct to the best of my knowledge. Signed ~r /~ C ~'Y, Title Area Drilling Engineer The spac r Co ission use Conditio~m~ of Approval, if any: Date I)~IBINAL SIGNED ~)Y LON.~i[ C. S~I!TI~ Approved by. COMMISSIONER Approved Copy Returned By Order of the Commission Form 10403 Rev. 7-1-80 GRU3/SN42 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ~-. ALASK, JIL AND GAS CONSERVATION ~_ ~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER[~i3( 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-104 3. Address 8. APl Number P, 0, Box 100360, Anchorage, AK 99510 50- 029-20983 4. Location of Well Surface: 629' FNL, 484' FEL, Sec. 19, TllN, RIOE, UN 5. Elevationinfeet(indicate KB, DF, etc.) 109' RKB 12. 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1F-9 6. Lease Designation and Serial No. AD/ 25652 ALK 2578 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool Kuparuk River Field Kuparuk River 0i1 Poo] NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [~]X Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other E~X Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, inc., proposes to complete this well with the Westward Well Service Rig #1. The procedure will be as follows: 1) A mast truck will be utilized to run the CBL/VDL/GR and Gyro. 2) The rig will be moved on location; the BOPE will be nippled up and tested. 3) Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. ~ 4) The well will be completed with 3-1/2", 9.2 #/ft, J-55, BTC tubing. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon Conclusion of the job. Estimated start: October 1, 1983 14.1 hereby~ that the foregoing, is true and correct to the best of my knowledge. // Signed L /~(/), Title Area Drilling Engineer The spac r Co ission use Conditio)~ of Approval, if any: Date SI BY L0''~ ~,,IE 8. SAITIt By Order of Approved by ~O~MISSIONE~ lhe Commission Dale Form 10-403 Submit "Intentions" in Triplicate J'~iy 5, 1983 ~r. Jeffrey B Kewin Senio~ Dril ~ln~ Engineer ARCO A~.aska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Re: Kuparnk River Unit 1F-9 ARCO Alaska, Inc. Permit No. 83-104 Sur. Loc. 629'i~:~L. 484'FEL, Sec. 19, TllN, R10E, UM. Btmhole-Loc. 4471'~L, l!76'FEL, Sec. 19, Tllh', P. 10E, !?~. Dear Mr. Kewin: Enclosed is the approved application for perr,~it to drill the above referenced well. If coring is conducted, a one cubic inch chip fro~ each foot of recovered core is required. Sa~ples of well cuttings and a mud log are not required. A cont~.~uous directional survey is required am Per 20 AAC 25.050(b)(5). if available, a tape containing the digitized log information shall be submitted on all logs 'for copying except e×peri~ental logs, velocity surveys and dipmet~r surveys. ~ Many riVers in.Alaska and their drainage systems ~ave been classified as important for the spat~zaing or migration of anadromoum fish. Operations in these areas are subject to AS 16,05.870 and the regulation~ promulgated thereunder (Title 5, Alaska Ad~inistrative Code). Prior to commencin?~ operationm you may be contacted by the Habitat Coordinator's 0¢~= Department of Figh and Pollution of amy waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promul~ated thereunder (Title IS,.Ataska Administrative Code, 6~hapter 70) and by the Federal ?stet Pollution Control Act, as amended. Prior to co ~nv~encing operations you may be contacted by a representative of the Depar~z~ent of Environ~ental Conservatiop. To aid us in scheduling field wori~, please notify this office 24 hours prior to commencing installation of the blowout Mr. Jeffrey B. Kewin Kupa~uk River Unit 1F- 9 -2- July 5, 1983 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, k~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of-suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Verj_~truly yours, C, V. Cha-- t Chairman of Alaska Oil and Gas Conservation Commission be.. 6,H/A Enclosure ,cc'. Department of Fiah & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office Bux 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 28, 1983 Mr. C. V. Chatterton Commi ssi one r State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1F-9 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 1F-9, along with a $100 application fee. ° A diagram showing the proposed horizontal and vertical projections of the wellbore. ° A proximity plat. ° A proximity analysis. o A diagram and description of the surface hole diverter system. o Diagrams and description of the BOP equipment. Since we estimate spudding this well on July 7, 1983, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Si ncerely, /Area Drilling Engineer JBK/GRU3L56'sm Attachments RECEIVED Alaska Oil & Gas Cons..-,ommlsSlO, Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany STATE OF ALASKA '~'"' ALASKA u~L AND GAS CONSERVATION CO,v~MISSION PERMIT TO DRILL 20 AAC 25.O05 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC L_~ SINGLE ZONE ~( MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3' ¢.dd~.SSBox 100360, Anchorage, Alaska 99510 4. ~ooc~o~fof vv-e~fa~-- -- ~ ~ I 9. Unit or lease name At total depth % ¢~ ¢~?~ 11. Field anO pool 8~71' FNL, 1176' FEL, Sec. 19, ,11N, R10E, UN ~;~ / Kuparuk River Field ~~~t (indicate KB, DF etc.) I 6. Lease designation and serial no. '¢~& ~ Kuparuk R~ var 0~1 Pool RKB 109', PAD 80' J ADL 25652 ALK 2578 12. Bond information (see 20 AAC 25.025) Pederal Insurance CoBpany Type Sta~ewide Surety and/or number ¢8088-26-27 Amount $500~000 13. Distance and direction from nearest town 32 mi. NW of Deadhorse 16. Proposed depth(MD & TVD) 7808' MD, 6554' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 700 feet. 21 14. Distance to nearest property or lease line miles 4796' FSL (~ Surface feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 37 o (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program I15. Distance to nearest drilling or completed F-2 well 93' ~ 2096' ND feet 18. Approximate spud date 07/07/83 2328 psig@ 60°F Surface 2753 _psig@ 6129 ft. TD (TVD) SIZE ~ Hole Casing ~4" 16" ~ 2-1/4" 9-5/8" 8-1/2" 7" Weight 65.5# 40.0# 26# 22. Describe proposed program: CASING AND LINER Grade ;Coupling H-40 PEB J-55 BTC HF-ERW J-55 BTC Length 80' 2342' 7780~ SETTING DEPTH MD TOP TVD 29' I 29' 29' I 29' I I 28' I 28' I MD BOTTOM TVD 109'1 109' 2371'12200' 7808'16554' I I QUANTITY OF CEMENT (include stage data) ±200 cf 800 sx AS III & 250 sx AS I 433 sx Class "G" neat 377 sx Class "G" extended ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7808' MD (6554' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2328 psig. Pressure calculations are based on latest reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-55 buttress tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon comple- tion of the job. 1F-9 will be 93' away from 1F-2 @ 2096' MD. There are no closer wellbores anywhere downhole. Top of cement for the production string will be placed @ 2881'MD, approx 500'MD above the West Sak sands. -23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED The space b~' fo~/~'Co~¢ssio-'~us~'- Samples required I Mud log required I[]YES ~NO TITLE Area Dril ling Engineer DATE APPROVED BY ,COMMISSIONER DATE by order of the Commission 3u!y 5, 1983 CONDITIONS OF APPROVAL Directional Survey required APl number I--lYES ~-NO 0~LYES []NO 50-- O"L-~-'?'''0 ~(~3 Permit number Approval date ~ ~ ~' II Q..7,,,/-~5/.~ SEE COVER LETTER FOR OTHER REQUIREMENTS Form 10-401 Submit in triplicate ................. : ........... =__ ..... : ....... :_~_.:_: : _ ....... :..~: ..... ~ ........ :._: ........................ ,_._ :___ . ..... _ ................... :.:._ _~_~: .......... ~: !::-.-- : t .... j ' ~ : ' : : : : ' I i i ' , , i . ' I i ' I ' , · ' , ~ : r I : J, ' ~ ' · ~ , ~ ~ i i i I ' i ~ , , , ~, : , ~ J : .. , : ,...~ : ' , : J , . ; . ; : ~ : ; · , : . : ! : : : i ~ : ~ : I : : ~ ~ ~ : i i i ', ' : ~ : ~ / : : ~ , F: ~ I - ; ; ~ ~ : · : : ~ : :, t~ ; : j : : ' : ::; ', : i : ~: 8~;~ ;: ~: ' ~": i '~'~ .... '' ~'; · ~'':'' ' :- . : : ; : ; : · , : ; : ; : : : : i : : : , ; ; , : : : : : : , : : : : : ; : : i , : : ' ; : , ' ; : ' : : : : : : : ~ , : : ~ · : : : : : i ; : : , , : , : , : , , ANALYSIS OF 1F-9/1F-1 AND 1F-9/1F-2 WELLBORE CROSSINGS NOTE: Please refer to the attached proximity map. 1F-9/1F-1 The proposed well 1F-9 will cross well 1F-1 by a distance of 95' at a measured depth of 1570'. This distance was calculated using proposed well path data for 1F-9 and gyroscopic survey data for 1F-1. Well 1F-9 has an ellipse of uncertainty 30' across its major axis at its crossing depth of 1570' MD. Well 1F-1 will have an ellipse of uncertainty of 40' across its major axis at its crossing depth of 1630' MD. The areas of uncertainty for the two wells will therefore not intersect. ARCO Alaska, Inc.~ proposes the following procedures be used to drill 1F-9 safely past the aforementioned well crossing: 1. The 12-1/4" surface hole will be surveyed continuously, if calculations indicate that an intersection of 35' or less will occur between the two wellbores. The mud motor used to kick off with will be oriented approx. 200' MD above the crossing depth to impart a small angle (±3°) in the opposite direction. (The distance corresponds to an intersection of the areas of uncertainty.) 1F-9/1F-2 The proposed well 1F-9 will cross well 1F-2 by a distance of 93' at a measured deth of 2096'. This distance was calculated using proposed well path data for 1F-9 and gyroscopic survey data for 1F-2. Well 1F-9 has an ellipse of uncertainty 52' across its major axis at its crossing depth of 2096' MD. Well 1F-2 will have an ellipse of uncertainty of 37' across its major axis at its crossing depth of 2020' MD. The areas of uncertainty for the two wells will, therefore, not intersect. ARCO Alaska, Inc.~proposes the following procedures be used to drill 1F-9 safely past the aforementioned well crossing: 1. The 12-1/4" surface hole will be surveyed continuously, if calculations indicate that an intersection of 45' of less will occur between the two wellbores, a jetting assembly will be run approx. 300' MD above the crossing depth to impart a small angle (±3°) in the appropriate direction. (The distance corresponds to an intersection of the areas of uncertainty.) All other wellbore crossings shown on the proximity maps are in excess of 200' . GRU3/6:sm RECEIVED JUL Alaska Oil & Gas Cons. 6ommissiori Anchorage Surface Diverter S~s:em i · 2. 3. ¢. . . 16" - 2000 psi Tankco starting hea~. Tankco quick connect assy. 16" x 20" 2000 psi double studcled adapter. 20" 2000 psi drilling spool w/!O" side outlets. 10" ball valves, hydraulically actuated, w/lO" lines to reserve pit. Valves 1:o open automat'ical ly upon closure of annular preventer. 20" 2000 psi annular'preventer. 20" bell nipple. e Maintenance & Operation Upon initial installation close annular preventer and verify that ball valves have opened properly. Close annular preventer and blow air through diverter lines 'every 12 hours. Close annular preventer in the event~that gas or fluid flow to surface is detect,ct. If necessary, manually override and close ball valve to upwind diverter line. Do not s.hut., in w.el 1 under any ci rcumsta,nce.s. 16" Conductor .JUl_ "- i A'las~,~ Oi! &. Gas (~uns. ~Jommissio~ .<. F ANNULAR PREVENTER 9 Li BLIND RAMS -) .L PIPE RAMS 7 ) £. PIPE gq MS s C I CSG L O [AGRAM ..-'1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11' - 3000 psi x 13-5/8" - 5000 psi spaccr spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 13-5/8" - 5000 psi pipe rams 6. 13-5/8' - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8' - 5000 psi pipe rams B. 13-5/8' - 5000 psi blind rams -g. 13-5/8' - 5000 psi annular ACCUMULATOR CAPACITY TEST 1. CHECK ANO FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH XYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1S00 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER. ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONOS CLOSING TIME ANO 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL ~OP STACK AND' MANIFOLD WITH ARCTIC DIESEL. 2. .CXECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAO. 3. CLOSE ANNULAR PREVENTER AND CHOKES ANO BYPASS VALVES ON MANIFOLO. 4. TEST ALL COMPONENTS TO ZSO PSI AND HOLD FOR 10 MINUTES. " 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND XOLO FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAININ6 UNTESTED MANIFOLO VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. g. OPEN TOP SET OF PIPE RAMS ANO CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BOTTOM SET OF PIPE RA/~. BACK OFF RUNNING ,JOINT ANO PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLE£O TO ZERO PSI. 12. OPEN BLIND P, AP.S AND RECOVER TEST PLUG. I'kAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COC:KS AND INSIDE BOP TO 3000 PSZ WITH KOOMEY PUMP. 15. RECORD TEST INFORPLATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE 8OPE 0ALLY. m q IANNULAR PREVENTER ~," ) BLIND RAMS ' · PIPE z~S PIPE ~ 7 I! 10. 11. 14. D IAGRAN ~2 13-5/8" 5000 PSI RSRRA 80P STACK 1. 16" - 2000 psi Tanked starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 7-1/16" - 3000 psi tubing head 4. .7-1/16" - 3000 psi x Ii" - 3000 psi double studded adapter 5. i1' - 3000 psi x 13-5/8" - 5000 psi spacer spool 6. 13-5/8" - 5000 psi x 13-5/8" - SO00 psi drilling spool 7. 13-5/8' - 5000 psi pipe rams 8. 13-5/8' - 5000 psi drilling spool w/choke and kill lines 9. 13-5/8" - 5000 psi pipe rams 10. 13-5/8' - SO00 psi blind rams 11. 13-S/8' - SO00 psi annular ACCUMULATOR CAPACITY TEST 1. ~ECX AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REFRAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING P~ESSUREo 1}-5/8' BOP STACK TEST 1. FILL BOP STAC)~ AND HANIFOLD WITH ARCTI.C OIESEL. 3. CTIEC)C THAT ALL HOLD DOWN SCREWS ARE FULLY RE"TRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT 'AND SEAT IN WELl. HE. AD. RUN IN LOCX DOWN SCREWS IN 3. CLOSE ANNULAR PREVENTER AND._CHOKES AND BYPASS VALVES ON /~%NtFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. $. INCREA. SE PRESSURE TO 1800 PSI AND HOLE FOR I0 MINUTES. BLEED TO ZERO PSI. 6. · OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND MOLD' FOR 10 MINUTES. 8, CLOSE VALVES OIRECTLY UPSTREAM OF CHOKES. BLEED 0OWNSTREY~ PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTEO MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI 0OWNSTREAM. BLEED SYSTE)t TO ZERO PSI. OPEN TOP SET OF PIPE RAMS ANO CLOSE BOTTOM SET OF PIPE ~. INCRFJLSE PRESSURE TO 3000 PSI ANO HOLD FOR 10 MINUTES BLEED TO ZERO PSI. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING ,JOINT AND PULL OUT OF HOLE. CLOSE 8LIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AN0 RECOVER TEST PLUG. MAKE SURE MANIFOLD ANO LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. TEST KELLY C0CICS AND INSIOE 80P TO 3000 PSI '~ITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE 0OPE TEST ONCE A '~EE): AND TIONALLY OPERATE BOPE DAILY. CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee c~/~...,: ~ .... / / (,"2 thru 8) .(g thru 11) (4) .Casg ~/iT/ 7-4~-J~ (12 thru 20) (5) BO PE .M.,..I.,,, ....' '- (21 thru 24) (6) Add: Company 1. Is the permit fee attached .......... . . 2. Is well to be located in a del 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 .......... 6. Is well to be deviated and is well bore plat included ............. 7. Is operator the only affected party ......... ' ...................... 8. Can permit be approved before ten-day wait ........................ Lease & Well No. YES, NO , ~ · . , .. lC-, 0 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. D p h b d i f 9L~- .es o erator ave a on n orce .................................. , Is a conservation order needed ' ...e.e....eee.e...eeeeeee.ee..ee®eeeee , Is administrative approval needed ' .®..leee.eelelee.®eeee®ee..e..®ee®. Is conductor string provided . e...~, e........., e..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..... Will surface casing protect fresh water zones ..~~i.~.~.~.~. Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore .............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ....... , ................... Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ...,... Does BOPE have sufficient pressure rating - Test to ~~ psig .. ~-~T~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. 25. Additional requirements ............................................. REMARKS, Additional Remarks: Geology: Engineering: ~B4K --~ LCS --- BEW N~VA,~~ JKT~ HJH ~ ,,t? z ~ !; / rev: 12/06/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA 'NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. TAPE LIS TAPE VERIFICATION LISTING /P OlO,H02 VERIF'IC~TI(}N LISTI~,tG PAGE ~ REKL K~EADKD ** <RVICE NAMF CED '~A~E ~ 13o79q :)NTI~+U.aTION ~ ~ol ~EVIOUS REEL ~ TADE HEADER ** ,;~RVIC[C, NAM~T :EDIT 2IGI~~ :0000 9f;VlOUS TAPE ~ FII,E HWADER ** .'1[ l.~ E f',~ ~ '~"~ E :EDIT ,001 ~RVICE N A ~=~E : aXI~{]~ LEN(]T:~ : 1024 YI,E TYPE : REVIOUS F:ILE ~ * tNFrDRD~AT'[O~! RECf')DDS ** CONTE,¥TS N : 1F-.9 c~ : KIIPAR{IK r.~ W f,:: 1 1. N EOT: · RY: USA UNIT TYPE CaTE SIZE CODE 000 000 0!6 065 000 000 004 065 000 000 008 065 000 000 004 065 000 000 004 065 nO0 000 002 065 000 000 008 065 000 000 006 065 OOO 000 004 065 P OlO.H02 VERIFICATIO~I LISTING PAGE mPA~iY = ATLA,~TIC R IC.~FILbD COMPANY LI.., : 1 F'9 ELD = KUPA~OK ~t}NTY = ~ORTH S'I,~'~')P~ ....... BOROUGH ~$ING : 9,625" [a 2,343' "' !'PE FLI}ID :~ X,-C PObYB;iER 'SCOSITY = 35]0 S ,,lifo L{?]SS m 4, C3 ~'r~ I'.x SAIqDS,TO~tE BIT SiZE = 8 1/2" RM ~MC ~ AT BHT = 4,!20 ~ 64,0 DF = 4. 10 64,0 DF ,m~, 20 64'0 Dl~ m{ ,086 e 140,0 DF ~P oI0oH02 vK~IFI, C~TI~N t, ISTI~G PAGE IT~Y TYP~: SiZE ~PR CODE ENTRY ~ 'J 66 ~ ~ 7~ ~0 q 4 65 ,1 IN 0 ~ 66 0 ~TI..I~, ,. PECIFICAT [.,OC. KS E '[[) O~DER J I',OG TYPE CLASS I~OD NO, LEVEL EPR 0 0 I 68 0 1 68 0 I 68 0 1 0 I 68 0 1 68 0 1 68 0 1 68 0 I 68 0 I 68 0 I 68 0 I 68 0 1 68 ~ DA'fA ** ~PT 7595 5000 SFLtt 2 8809 Ib~ ~ -15!2187 GR q7i3125 NPHI :~0[! 2 0191 NCNL 1741 000,0 FCNI,, ~AT ] 7422 ~RA 4 1133 GR EPT 7400 0000 SFLU ~ -26,1094 GR ~('}B 2.~520 NCNL ~AT 3,5605 RNRA : 1387 IL~ 9 43?5 NPHI 1716.0000 FCNL 3.6660 GR 2,2988 IbD 47,$516 DRHO 423,0000 CALl 97.3125 2,0132 ILD 49.5117 DRHO 406,0000 CAb! 101,9375 2 7148 II, D 42:675~ DRHO 473.5000 CabI 99.4~75 2,~469 , 002 ~,5000 1,9502 0.0562 11,5703 2,5195 9,7656 010 HO2 VERIFICATION [.,ISrIN~, PAGE 4 ~PT 7~00.0000 MMLU ) ~.5~3594 GR ~[)M 2,4336 NCNb ~AT 3,1094 P,~RA CPT 7200,0000 8FLU 8906 GR 3984 NCNb ~AT 2, 344 GR ~33 NCNL 8086 RN:~A CPT 70.00,468000~. ~.F[,{!R ~ 36, ',{OB 2,36 2 NCNI, ~AT 3,6074 R. NRA ~[PT 6900 0000 SFL{! ~ "29 7i88 GR ~OB -999 2500 NCNI, ~AT '999 ~500 RNRA ~PT 6800.0000 SFL, U YOB -999,2500 NCNb ~T -999,2500 RNRA gPT 6700 0000 SFLU P -?.8,1562 GR HE)n -999,2500 NCNb ~AT -,999,2500 RNRA EPT 6600 0000 P -28,8906 ~OB -999,2500 NCNb RAT -999,25()0 RNR~ ~PT 6~00 0000 SFLI{ P - 3§:7188 GR HOB -999,2500 MCNL ~AT -999,2500 RN~A EPT 6400 0000 P -50,4063 GR NOB -999,2500 NCNL ~AT -999,~500 RNR.,~ ~PT 6~00 0000 SFLIJ P - 34~7500 14['3P. -999,250(3 ~A~~ -999,2500 4,613,3 IL~, N'PH 96,31.25 oooo ~6:3887 203:1 4 I445 ,0000 NPRI FCN '0000 169~ ,0977 GR 3 9883 IL~ NPHI -999 0 FCNL -999,2500 GR FCNL 7598 IBM - , .{500 FCNL -999,2500 GR. 6,1328 99,~500 GR 44805 1LM 159~3750 NPHI '999,2500 FCNL -999,2500 GR 4 6289 IL~ 155;7500 NPHi -999,2500 FCNL -999,2500 OR 150,8750 NPHI -999,2500 FCNI., -999,2500 GR 1,3291 IBM 147.6250 -909,2500 F' NL -999,~500 GR 42:58 3125 322 4~ 844 41I 000 1233750 4~'6 41.4:.~ ,O 142,0000 ., 2,6484 999~'25:00 '999,2500 2:54' 8750 " 2500 ' 99. 2500 186,5000 15 -099 ~ 5 88,3125 3 7207 -999i2500 -999 ~500 159,3750 3,2461 -999,2500 -999,2500 155,7500 ],1055 '999,2500 '999.2500 150.8750 1.3984 -999~ O0 147,6~50 I bD DRHC) CALI Z LD DRHD ILD Z DRHO CAL! IbD D.RHO CALl ILD DRHO DRHO RHO CALX ILL DRHO CALl I. LD DRHO CALX ILD DRHO CALl 4,3438 0,1006 8,5078 2,6250 '99'9~. 3828 .99!'8066 , :l ! 4! ,9 4 10, 063 3 4043 -999",2500 9,4219 3,0703 -999.2500 10.1562 ],9766 -99 ,2500 11,6016 1,4072 4219 ,r tP 0i. 0,[~02 VERIFIC~TIO~ LISTIMG PRG~ 6200 0000 SFLU -39 4375 GR -999 2500 NCNb -999 2500 ~nRa 610o,00o0 SFLU -46,156~ -999,2500 -999,2500 6000 0000 SFI.,U , -45,1562 GR -999,250(.) 5900 0000 S~I,U -45' ,6875 GR '999,2500 NCNb -999,~500 5 ~0o 0000 -45,46(~8 GR -999,2500 N CN !,,, -999,2500 RN~A 5700 000o SWl, ii -46,6563 GR -999,~5(')0 NCNI, -999.2500 RN~A 5600,0000 SFLU -45,q375 GR -999.2500 NCNL -999,~500 RMR..A 5500 OOO() -43i1562 GR -9~9 2500 NCNL -999 2500 5400,0o00 -60,9375 -999,2500 NCNb 5200,0000 SFLU 6~,9375 GR -999.2500 NCNI,,, -999,~500 ~R~ 5200 0000 $ wi.., ~t -999~ 2500 NCNb 154 7500 -999 2500 FCNb -999 ~500 2,1641 IL~ 101,6875 NPHI -999,~500 FCNI, "99:9,2500 GR 3,689:5 IbM R3,7500 NPHI -999,2500 FCN[,, -999,~500 GR 2,3281 IbM 103; 2500 -999,2500 FCNL -999~ 2500 97,7500 NPHI -999,~500 FCMI., -999,~500 G~ 01,56 9 : 7500 99 ; 2500 GR 3 1348 IbM -999,2500 FCN[ -9q9.~500 G~ 2,3965 IbM 104,1875 -999,2500 FCNL -999,2500 GR :4316 IbM 8 3750 NPHI -999,2500 FCMt, -999,2500 GR 2 6660 It.,~ 88:3125 NPN! -999 2500 FCNL -999:2500 GR 2,9453 I[,M ~9,0000 NP~I -999,2500 FCN!, 1 3408 -999 2500 -999 2500 154 7500 2 -999. -999 101 . 2,8613 999,~500 '9:~9, 500 83,7500 10~, O0 *999,2500 -999,~500 97,7500 999, -999,2500 84.7500 .~99,~500 ~99,~500 84,56~5 ~,4~6 -999,~500 -999,2500 ~04,~875 ~.5449 999,~500 :999,~500 87,]750 2,5742 -999,2500 -999.2500 88,~125 2,9883 '999,2500 '999,2500 ILD ORHO CALl ILD DRHO CAb! DRHO CALl CALl DRHO C~LI DRHO CALl DRHO CAL! DRHO Cab! zSp Dr~O C~LI ILO DRMO C~LI 1,2910 -99~,2500 , ,7t88 2,0898 -999;2500 10,6563 2,8t25 ~ 2So0 -99 ~6328 9,945] 2,:52~4 ~999,2500 9,8750 '99~, ~,0000 '999,2500 9,789~ ~,44~4 '999,2500 10,0~56 -999,~500 9,9~97 ~0,09~ -999,2500 ~0,09~ ~P OI0.H02 YF. RIFiCATION LISTING PAGE ~T ..999. 2500 NNRA !:PT 5100,0000 SFLU '::' -60.9687 GR qO~ -999,2500 NCNb ~AT -999.2500 {PT 5000. 0000 -~ -69,7500 GR ~OB -999.~500 NCNb =AT -999,2500 {PT 4900,0000 SFLU ~ -64,7500 GR ~f]B -999,2500 NCNb ~.AT -999.~500 EPT 4~00.0000 ~ 61, ]750 GR ~OB '999,250:0 NC:Nb RAT -999.2500 ~PT 4:100,0000 P 62,5938 qOH 999 ~ 2500 NCN [., RAT 999,~500 MPT 4600.0000 P -7~,9375 GR ~O}~ -999,2500 NCNb ~AT -999.~500 KPT 4500 0000 SWLU m -74.6B75 ~O~ -999,~500 RAT -999,2500 RNRA MPT 4400 0000 V -78:1875 MOB -999~ 2500 NCNb RAW -999 2500 RNR. A -83'9375 GR [1~ 2. 398~ NCNI., ~AT 3,4551 RNR'A OB 2.2539 NCNL RAT ~,611] RNRA 4~00,0000 ' ~5.4'~75 '099,2500 ~R 3438 8750 2500 2500 3320 9 ', 9375 '999, O0 3 79 '999 "999 ILM N:PHI FCNI.. GR IbM NPHI FCNL GR I. LM N:P:H I FC. NL FCNL 7383 I[,M 3125 NPHI 2500 FCNL 2500 GR 2,8945 IhlN ~02,7500 NPH! -999.2500 FCNL -999,2500 G~ 3,0020 1_~19. 5625 NPHI 9 ,2500 :999,2500 GR .91 , 25 NPH! -999,2500 FCNL -999,2500 GR 5 7070 IbM 99:8125 NPHI 18~1,0000 FCNL 4.0547 ~ 3,7695 I. LM 80,31~5 NPHI 1943,0000 FCNL 4,1523 GR 4,0{95 IL~ 77.1250 NPHI 89,0000 2, :0000 -999,2500 -999;:~500 105,4375 , 1289 · .99 :'2500 -999, 9:2, 3. 1465 '999, -999:, 75,6250 5,1797 '999; 2500 '999,~.500 2,9746 '999,2500 "999'~.500 102,7500 3,0938 '999,2500 '999,2500 II1,5625 3,i426 '999,2500 '999,2500 91,8125 5,0547 39,6484 49693.5000 ,8125 ],5977 41,2598 467,7500 80,3125 4.5820 40.9668 DRHO CALI ILD DRHO ILD DRHO CAb! .I [,D RHO 'ILD DRHO CALI DRHO ILO DRHO CALI ILD DRHO CAt, I DRHO CALl ILD DRHO CALI ILD DRHD 5566 250:0 9,8594 9844 o 06 5 9 999, 10,1172 93 2051 '999i2500 9922 6,5352 -999,2500 9,7969 3,0000 -999,2'500 10'9609 3,2266 -999,2500 11,5938 3,2988 -999,2500 11,1641 5,~281 O, 410 10,5469 3,6953 0,0575 12,7344 4,7813 0,0225 IP O10,H02 VERIFICATIOf~t I~ISTING PAGE 7 ,iI~B 2,21.4,8 NCNL ~.AT 3.6211: R~R~ ~iPT 4000 0000 SFLU -~ -45 3125 GR ~D~ 2 2227 NCnb ~T 342]8 PNR.~ !iPT ]900,0000 SFI,U 4[)R 2, 637 NCN[, "~OB 2,2402 CML ~AT 3, ]65;2 RNRA ~ "07 ,0000 ~ 08 2, '3125 .N C N I, VAT 3,3750 RNRA ~iPT ]6()00000 .SF L, IJ P - ~ 93125 G R HOB 22695 N C N, I.., ~T 3 50(~0 RSRA 0000 S FL U .5625 (;R 2090 NCt~ I., 3300.0000 SFI, I{ -~.0,6250 gR 3,621.1 RNR~ FP? 3100.0000 P -63 ,q 125 3,4102 RNRA ~_~ [" T 3000,0000 SFIJU 2084 ~000 FCNL 3:402 GR 5,:449~ 81,7500 2011,0000 35957 165 i 0000 m' 7910 NPH I FCN[, NPH! FCNI., I4 NPHI 2112, FCNL 3,8359 GR 7 1484 83 3-750 1900 0000 FCNL 4 0352 OR , 8828 It.~M 7 ,4375 NPH! 1886,0000 FCNI,, 3,7598 G~ 97188 735625 20600000 42070 NPHI FCNL 7.2305 ILM 62,906~ NPHI 20t2.0000 FCNI, 4,2305 GR 3 7813 NPHI 2268,0000 FCN[, 4.2333 GR 8.7969 666250 NPH! 1724:0000 FCNI., ].9570 GR 10.1484 Ib~ 67,7500 NPHI 2528,0000 FCNI, 3,8320 GR 13,3750 557,0000 77'1250 5 91,41 .0000 81 7500 5 40 436 77: 86,7813 6230 5 so o:oo 66,9375 7,9609 36,8'65~ 470,5000 83,3?50 67119 501~5000 70,4375 11,1094 4 ,5000 7],5625 8,1953 594 43, 000 480'~062 62, 18,0469 40,7227 535,0000 35.7813 44, 71 435.5000 66.6250 12.2578 ]7,4023 659,5000 67,7500 13,2422 CAbI DRHO CAbI DRHO DRHO RH0 DRH[) I bD DRHU CALI DRHO I bD DRH0 CA[,I ILD DRMO Cab ! IhD DRHO CALl I I.,D 13,7734 6,2500 , 0381 I ,8:2:03 6,4727 0,0342 12,4689 17,9062 1406 8,7656 , 0435 I ,0313 18,7813 ,0342 13,9922 ~ ~375 I , 454 13'1016 , 8 5781 0",0210 12,7109 19,8281 -0,0054 14,2656 10,~328 O, 347 I0.49~2 12,085q 0,0269 13,3125 12,757~ !P OlO,N02 VERIFICATIO~ bISTING PAGE : -75.~125 GR { 13 B 2. I 270 N C N b ~AT 3.4473 RN[~A 48.8750 NPHI 2456,0000 FCNL 3.7578 GR 9OO 000 ~ '7~' .]125 GR ~OB .1289 NCNL ~T ].5918 RNRA 13,9453 Ib~ 55:,~ 9375 1.8]:0000 88,48 0000 SFLU 2800. ~ ) '8~.5000 GR 4DB .0605 NCNL ~AT 3.6055 ~NRA 17.9844 IbM 37.1250 NPH.T 76. ~0 00o 3.7656 %~PT 2700.0o00 SFLIJ u -58.50:00 GR "~O~ 2.0977 NCNL ~A,T 4,0586 RNRA 7.37~5I 85,68 NPHi ! 691 0000 4 , ~PT 2600 0000 SFI.,U :' ..62,0000 , C ~ L 2,1211 N · 3. 8594 RNRA E [.:'T 2500,0000 SrLU ~ -78.7500 GR 13.4609 IbM 40.6875 NP:H! 184~,0000 .9199 9~PT 2400 0000 SFLU ~ -83:2500 G~ RAT 3.591~ RNRA 13.g750 II, M ]9, 375 NPHI 0000 FCNL 181 ~2852 GR .. 3 0000 SFI.,It F, PT 2 20, ... P "38,2500 GR HOB 2,0,{7 ! NCNL ~AT 4,2930 RNRA 2000 0000 ibm 41,1562 NPHi 1513,0()00 FCNL 4.5977 GR * F'IL~ TRAILER ** ILE NA~E :EDIT ,001 KRVICE NA~E ERSION # : aTE : ~XIMI!~ LENGT~ : 1,024 TLE ?YP~ ********** MOF 38.0859 653.:5000 48.8750 13 40 762 485 5000 55 9375 16,'1406 40 524 37 1.250 ,60~6 4~,:469 .:oooo 6875 9,0625 4 : 2'500 1975 13.9297 44'5801 469.2500 40.6875 1~.3594 38,18~6 42~,~000 39, 375 2000 0000 56:8848 329 0000 41:1562 DRHO CAb! ILD DRHO DRHO CA5 ! CAL. I DRHO ! bD DRHO ILD DRHO CAb! DRHO CAI,! -0,0029 13;2031 105, !5 I ]' ,445] 09,~984 , 127 16,6406 9,9844 12:8984 14,5391 ~470,5938 9,4878 ,0981 * TAPF TRATLER ** KRVICE ,N ~.~ g :Mt}IT rp 010,H02 VMRI, FICATION bIS?ING PAGE g ~A.E !NTINU~TION # TAPE I~M~;~TS ILIBP~RY T~PE "REEL TRAILER ** ~'RVICE. NAME ,'~DtT.. ~ ;TE 183/09/12 ~IGIN : CEL NAME t:130799 ]NTIMU~TIOM ~ ]M~ENTS ~LIBRARY TAPE ********** EOF
