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183-132
KƌŝŐŝŶĂƚĞĚ͗ ĞůŝǀĞƌĞĚƚŽ͗ϭϳͲĞĐͲϮϱ,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 ϭͲϭϰ ϱϬͲϬϮϵͲϮϮϵϱϬͲϬϬ ϵϭϬϱϬϴϬϭϭ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϭϭͲĞĐͲϮϱ Ϭ ϭϮ ϭͲϭϯϬ ϱϬͲϬϮϵͲϮϮϴϭϱͲϬϬ ϵϭϬϰϳϰϬϵϵ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮϳͲEŽǀͲϮϱ Ϭ ϭϯ ϭ ͲϬϯ ϱϬͲϬϮϵͲϮϬϰϳϳͲϬϬ ϵϭϬϰϯϮϬϱϱ <ƵƉĂƌƵŬZŝǀĞƌ DƵůƚŝ&ŝŶŐĞƌĂůŝƉĞƌ&ŝĞůĚΘWƌŽĐĞƐƐĞĚ ϮϭͲEŽǀͲϮϱ Ϭ ϭϰ ϭ ͲϬϯ ϱϬͲϬϮϵͲϮϬϰϳϳͲϬϬ ϵϭϬϰϯϮϬϱϱ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮϯͲEŽǀͲϮϱ Ϭ ϭϱ ϭ ͲϬϰ ϱϬͲϬϮϵͲϮϬϰϳϴͲϬϬ ϵϭϬϰϯϮϭϱϰ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϭϵͲEŽǀͲϮϱ Ϭ ϭϲ ϭ Ͳϭϴ ϱϬͲϬϮϵͲϮϬϵϬϰͲϬϬ ϵϭϬϰϳϰϮϯϯ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϵͲĞĐͲϮϱ Ϭ ϭϳ ϭ'ͲϭϮ ϱϬͲϬϮϵͲϮϭϬϬϵͲϬϬ ϵϭϬϱϬϴϬϮϯ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϭϱͲĞĐͲϮϱ Ϭ ϭϴ ϯͲϭϴ ϱϬͲϬϮϵͲϮϮϲϵϮͲϬϬ ϵϭϬϰϳϯϯϲϴ <ƵƉĂƌƵŬZŝǀĞƌ WůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮϵͲEŽǀͲϮϱ Ϭ ϭϵ ϯ<ͲϬϯ ϱϬͲϬϮϵͲϮϭϲϬϮͲϬϬ ϵϭϬϰϯϮϬϰϬ <ƵƉĂƌƵŬZŝǀĞƌ WůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϭϲͲEŽǀͲϮϱ Ϭ ϭϭϬ ϯ<ͲϯϮ ϱϬͲϬϮϵͲϮϮϳϲϯͲϬϬ ϵϭϬϰϳϰϯϬϭ <ƵƉĂƌƵŬZŝǀĞƌ >ĞĂŬĞƚĞĐƚ>ŽŐ &ŝĞůĚͲ&ŝŶĂů ϮͲĞĐͲϮϱ Ϭ ϭW> ^ <EKt> ' Z /Wdz^/'E/E'EZ dhZE/E'KWzK&d, dZE^D/dd>> dd ZdKd, dd Ed/KEK&͗&ĂŶŶLJ,ĂƌŽƵŶ͕,ĂůůŝďƵƌƚŽŶtŝƌĞůŝŶĞΘWĞƌĨŽƌĂƚŝŶŐ͕ϲϵϬϬƌĐƚŝĐůǀĚ͕͘ŶĐŚŽƌĂŐĞ͕<ϵϵϱϭϴ&Z^ͺEΛŚĂůůŝďƵƌƚŽŶ͘ĐŽŵĂƚĞ͗^ŝŐŶĞĚ͗dƌĂŶƐŵŝƚƚĂůĂƚĞ͗199-089197-183180-056180-057183-016183-132196-133186-103197-076T41200T41201T41202T41202T41203T41204T41205T41206T41207T41208Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.12.17 13:38:53 -09'00'183-132ϳϭ'ͲϭϮϱϬͲϬϮϵͲϮϭϬϬϵͲϬϬ ϵϭϬϱϬϴϬϮϯ<ƵƉĂƌƵŬZŝǀĞƌWĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂůϭϱͲĞĐͲϮϱϬϭ Originated: Delivered to:20-Nov-25Alaska Oil & Gas Conservation Commiss20Nov25-NRATTN: Meredith Guhl333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539Anchorage, AK 99518(907) 273-1700 main (907)273-4760 faxWELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTIONDATA TYPE DATE LOGGED2P-A 50-103-20475-01-00 204-009 Kuparuk River WL SCMT FINAL FIELD 6-Nov-252P-406 50-103-20484-00-00 204-022 Kuparuk River WL IBC-CBL FINAL FIELD 9-Nov-25CD4-209 50-103-20532-00-00 206-065 Colville River WL Patch Setting FINAL FIELD 11-Nov-251Y-22 50-029-22369-00-00 193-070 Kuparuk River WL LDL FINAL FIELD 14-Nov-251G-12 50-029-21009-00-00 183-132 Kuparuk River WL LDL FINAL FIELD 15-Nov-25Transmittal Receipt________________________________X__________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.Nraasch@slb.comSLB Auditor - TRANSMITTAL DATETRANSMITTAL #A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media.# Schlumberger-PrivateT41163T41164T41165T41166T411671G-12 50-029-21009-00-00183-132Kuparuk RiverWLLDLFINAL FIELD15-Nov-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.11.21 09:11:58 -09'00' STATE OF ALASKA APR 0 7 2015 Ali-‘,,KA OIL AND GAS CONSERVATION COMIv,,JSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1 Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate rOther p CTD Set-up Alter Casing r Pull Tubing Stimulate Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name. 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 183-132 3.Address. 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-029-21009-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25640 KRU 1G-12 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 9116 feet Plugs(measured) none true vertical 6836 feet Junk(measured) none Effective Depth measured 9014 feet Packer(measured) 8257, 8472, 8603 true vertical 6760 feet (true vertical) 6201,6362,6459 Casing Length Size MD TVD Burst Collapse CONDUCTOR 62 16 100 100 SURFACE 2513 10.75 2550 2302 PRODUCTION 9064 7 9096 6821 Perforation depth: Measured depth: 8385-8458, 8537-8589, 8812-8864 True Vertical Depth: 6297-6351,6410-6448,6612-6650 SCAMP . :9 Tubing(size,grade,MD,and ND) 5.5 x 3.5, H-40&L-80, 8796 MD,6600 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL RETRIEVABLE PACKER @ 8257 MD and 6201 TVD PACKER-BAKER FHL RETRIEVABLE PACKER @ 8472 MD and 6362 TVD PACKER-BAKER FB-1 PERMANENT PACKER @ 8603 MD AND 6459 TVD NO SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): NO STIMULATION OR CEMENT SQUEEZE DURING THIS OPERATION 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 shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16.Well Status after work: Oil p Gas r WDSPL r Daily Report of Well Operations =OK GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C O.Exempt 314-670 Contact Jonathan Coberly(a 265-1013 Email Jonathan.Coberlya.conocophillips.com Printed Name Jonathan Cobef ly Title Sr. Wells Engineer Signature /I �/ Phone:265-1013 Date Lii_G_Za/S iCk---- -- DD RBDMS lipR - 7 2015 iii- 4//c//5-- Form 10-404 Revised 10/2012 ��3/� Submit Original Only ICT IG it I NI/GFT KUP PROD 1G-12 onocoPillIprjf,1 -:: ' x- Well Attributes Max Angle&MD TD Alaska,Inc. '� Wellbore API/UWP Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(fIKB) conrxnRvnipt a 500292100900 KUPARUK RIVER UNIT PROD 54.10 3.500.00 9,116.0 ..- - Comment H25(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 1G-12,4/520159.56.35AM SSSV:NONE 90 12/16/2013 Last WO: 2/25/2015 40.99 10/2/1983 Venial schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date IiANceri(3i 3 Last Tag:SLM 8,850.0 3/28/2015 Rev Reason:PULL BALL,ROD&PLUG,TAG, hipshkf 4/5/2015 I I GLV C/O Lasing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15250 38.0 100.0 100.0 65.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread I`/ SURFACE 103/4 9.950 37.2 2,550.0 2,302.1 45.50 J-55 BTC Casing Description -OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 321 9,096.4 6,821.2 26.00 J-55 BTC Tubing Strings M/CONDUCTOR,380-100.0''II 'III Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING WO-Upper 3 12 2.992 31.2 8,610.0 6,463 8 9.30 L-80 EUE-Mod 1 Completion Details Nominal ID Top(ftKB) Top(TVD)((tKB) Top not I") Item Des Cons (in) SURFACE;37.2-2,550.0- 31.2 31.2 0.17 HANGER McEVOY TUBING HANGER 2.950 8,226.9 6,178.0 40.78 LOCATOR LOCATOR 2.990 GAS LIFT:2,842.6 ' _- 8,227.3 6,178.3 40.78 SEAL ASSY BAKER 80-40 PBR SEAL ASSEMBLY 2.990 illi 8,234.3 6,183.6 40.79 PBR BAKER 80-40 PBR 4.000 MI 8257.3 6,201.0- 40.83 PACKER BAKER FHL RETRIEVABLE PACKER 2.910 GAS LIFT;4,681.5 _ '.- 8,309. ' 6,240.7 41.02,NIPPLE i XNIPPLE 2.812 8,3822' 6,294.9 41.89 BLAST JOINT Blast Joint 3 1/2"EUE Mod XO Joint EUE Box x TCII Pin 2.992 MI GAS LIFT;5,973.7 - 8,402.9 6,310.3 42.10 BLAST JOINT Blast Joint 3 1/2"EUE Mod TCII Threads 2.992 8,472.1 6,361.7 42.01 PACKER BAKER FHL RETRIEVABLE PACKER 2.920 8,496.3 6,379.7 41.98 NIPPLE X NIPPLE 2.812 GAS LIFT;6,9221 8,533.6 6,407.3 42.24 BLAST JOINT BLAST JOINT XO JOINT(EUE BOX xTCll PIN) 2.992 8,553.3 6,421.9 42.35 BLAST JOINT BLAST JOINT TCII THREADS 2.992 8,602.8 6,458.5 42.60 LOCATOR 'LOCATOR 3.000 GAS LIFT;7,624.0 8,603.6 6,459.1 42.60 SEAL ASSY BAKER SEAL ASSEMBLY GBH-22,80-40 2.980 Tubing Description String Ma...ID(in) Top(ftKB) ret Depth(ft..'Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING WO-Lower 512 4.950 8,603.31 8,796.0 6,600.5 14.00 H-40 STC Completion Details GAS LIFT;8,170.2- biz Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inc)(^) Item Des Com (in) 8,603.3 6,458.8 4260 PACKER BAKER FE-1 PERMANENT PACKER 5.380 • 8,606.6 6,461.3 42.60 SBE 80-40 SEAL BORE EXTENSION 4.000 LOCATOR;8.226.9 SEAL HOST;8,227.2 R. 8,611.0 6,464.5 42.61 XO Reducing Crossover sub 4.75 Stub Acme x 3-12"EUE 2.950 PBR;8,234.3 8,625.9 6,475.4 42.61 NIPPLE X NIPPLE 2.812 PACKER;8,257.3 1144 8,668.3 6,506.7 42.63 XO Enlarging Baker Crossover 3 1/2"EUE Box x 5 1/2"STC Pin 4.500 (Ported) 8,669.1 6,507.3 42.63 WEAR SOCK WEARSOCK JOINT 4.950 8,795.5 6,600.2 42.75 BEVELED BEVELED SHOE 4.500 NIPPLE;8.309.8 SHOE Perforations&Slots Shot GAS LIFT;8,362.2 Dens Top(TVD) Btm(ND) (shots/( Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date 0 Type Com 8,385.0 8,458.0 6297.0 6,351.3 C-4,C-3,1G- 12/25/1983 12.0 (PERF 5"DA Perf Gun,120 deg BLAST JOINT;8.3822 - 12 pH IPERF;8,385.0-8,d58.0��- BLAST JOINT 0,402.9 _ 8,537.0 8,589.0 6,409.9 6,448.3 C-1,UNIT B, 12/25/1983 12.0 IPERF 5"DA Perf Gun,120 deg 1G-12 pH 33�11 3 8,812.0 8,830.0 6,612.3 6,625.5 A-5,A-4,10- 6/23/1984 4.0 APERF 2 1/8"RigidJet,90 deg. PACKER;8.472.1 12 pH NIPPLE;8,496.3 `a::.a, 8,830.0 8,850.0 6,625.5 6,640.2 A-4,1G-12 8/13/1993 4.0 APERF 2.5"Titan HC,180 deg pH;27 deg.CCW GAS LIFT;8,513.9 8,850.0 8,864.0 6,640.2 6,650.4 A-4,1G-12 6/23/1984 4.0 APERF 2 1/8"RigidJet,90 deg. pH _ _ Mandrel Inserts BLAST JOINT;8,533.6I St IPERF;8,537.0-8,589.0 g On BLAST JOINT;8,553.3~ N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (pal) Run Date Com -- -I. 2,8426 2,504.5 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,244.0 4/1/2015 i2 4,681.5 3,693.9 CAMCO MMG 1 12 GAS LIFT GLV RK 0.188 1,250.0 4/1/2015 I 3 5,973.7 4,588.9 CAMCO MMG 1 12 GAS LIFT GLV RK 0.188 1,251.0 3292015 LOCATOR 8.6028 4 6,922.2 5235.6 CAMCO MMG 112 GAS LIFT OV RK 0.250 0.0 3/29/2015 DCR1 PACKER;8,603.3, _ = 5 7,624.0 5,736.3 CAMCO MMG 112 GAS LIFT DMY RK 0.000 0.0 3/14/2015 SEAL ASSY;8,603.6- r 6 8,170.2 6,135.1 CAMCO MMG 112 GAS LIFT DMY RK 0.000 0.0 3/14/2015 SBE;8,606.6 � 7 8,362.2 6,280.0 CAMCO MMG 1 1/2 GAS LIFT CV RK 0.000 0.0 3/29/2015 =e'c 81 8,513.91 6,392.8ICAMCO IMMG I 11/21 GAS LIFT IDMY IRK 0.0001 0.0 3/14/2015 Notes:General&Safety NIPPLE;8,625.9 End Date Annotation ill 12/30/2003 NOTE:WAIVERED WELL: IA OA ANNULAR COMMUNICATION it a e 9/17/2010 NOTE:View Schematic w/Alaska Schematic9.0 WEAR SOCK 8,669.1 APERF;8,8120.8.826.9- APERF,0,830.08.850.0- APERF;8,850.08,864.0 PRODUCTION;32.1-9,096.4- 1G-12 WELL WORK SUMMARY DATE SUMMARY PRE- RIG WELL WORK 12/15/2014 (PRE-RWO) FUNCTION TEST ALL LDS (SEVERAL LDS AND GN SEIZED), T POT PASSED, T PPPOT PASSED, IC POT FAILED, MITOA PASSED TO 1800 PSI. 1/6/2015 BRUSH n' FLUSHED TBG; PULLED HFCV © 8266' RKB; SET 2.81 XX PLUG © 8204' RKB & DEPLOYED AVA CATCHER ON TOP; PULLED OV @ 7043' RKB. IN PROGRESS. 1/7/2015 PULLED GLV'S & SET DV'S @ 6470', 5868', 5144', 3919', &2047' RKB. IN PROGRESS. 1/8/2015 SET DV© 7043' RKB; PULLED 1" DV @ 8168' RKB; CIRC OUT 242 BBLS SW & 75 BBLS DIESEL (U- TUBE FP). LRS PERFORMING CMIT. IN PROGRESS. 1/9/2015 PULLED CATCHER @ 8204' RKB. BAIL SCALE FROM XX PLUG @ SAME. IN PROGRESS. 1/10/2015 BAIL FILL & PULL 2.81"XX PLUG @ 8204' RKB; MEASURED BHP @ 8650' RKB. READY FOR E-LINE (RCT). SBHP of 2680 PSI Measured 1/11/2015 FIRED A 5' STRING SHOT WITH MID SHOT AT 8598'. CORRELATED TO MANDREL AT 8322'. STRING SHOT WAS 5' LONG WITH 160 GR/FT. 1/22/2015 FIRED CENTER OF 160 GR/FT STRING SHOT AT 8344', CCL TO MID STRING SHOT OFFSET: 4.9', CCL STOP DEPTH: 8339.1'.. LOG CORRELATED TO TUBING TALLY RECORD DATED DEC 25, 1985. JOB IN PROGRESS. 1/23/2015 FIRE 160 GR/FT STRING SHOT AT 8179', CCL TO MID STRING SHOT OFFSET: 4.9, CCL STOP DEPTH: 8174.1'. LOG CORRELATED TO TUBING TALLY RECORD DATED DEC 25, 1985. ATTEMPT TO FIRE 2" RCT AT 8599'. ENCOUTERED SHORT IN THE TOOLSTRING. JOB IN PROGRESS. 1/24/2015 PULLED INTO DESIRED CCL STOP DEPTH TO FIRE THE RCT AT 8599'. OPEN EMA ANCHORS AND SET THEM AT 1600#. DETERMINED WE WERE 5' DEEPER THAN DESIRED DEPTH. INSTRUCTED TO CLOSE ANCHORS AND PULL INTO POSITION AGAIN. ENCOUNTERED A SHORT IN THE TOOLSTRING, NOT ALLOWING US TO CLOSE THE ANCHORS. PULLED UP TO STROKE THE JARS, RELEASED AT 1450#. BEGIN TO PUH AND GET STUCK AT 8250', CANNOT MOVE TOOLSTRING UP OR DOWN. SET DOWN TO RECOCK JARS. INSTRUCTED TO PULL UP TO MAX SAFE PULL OF 1950# AND STROKE JARS TO GET FREE. NOTICE A DROP IN TENSION ONCE 2000#WAS REACHED. POOH AND NOTICE THAT UP WEIGHT IS 400# LESS THAN PREVIOUSLY RECORDED. ONCE ON SURFACE, VERIFIED THAT TOOLSTRING HAS BEEN LEFT DOWN HOLE. CLEAN PULL OUT FROM ROPE SOCKET. READY FOR S/L 2/2/2015 RECOVERED E/L TOOLSTRING @ 8233' SLM. COMPLETE. 2/5/2015 SPOTTED IN ELINE EQUIPMENT, CHECKED OUT TOOL STRING, EVERYTHING STAGED FOR TOMORROW. 2/6/2015 RIH WITH RCT 2000, UNABLE TO MAKE CUT DUE TO SHORT IN TOOL STRING. LEAVE EQUIPMENT STAGED TO MAKE CUT TOMORROW. 2/7/2015 WENT TO SET ARMS FOR THE CUTTING PASS AND FOUND THE TOOL STRING TO BE SHORT AGAIN. AS WE WERE PULLING UP HOLE TO BECAME STUCK AROUND 8230'. AFTER WORKING THE TOOL STRING FOR SOME TIME, MOVED CLOSER AND CLOSER TO PULL OUT TENSION UNTIL WE CAME FREE FROM THE WEAK POINT. FISH LEFT IN HOLE IS 48.5' LONG, HAS A MAX OD OF 2"AND WEIGHS 344 LBS. A PDF OF THE FISH IS POSTED IN THE 'S' DRIVE UNDER THE "ELU 1659" FOLDER. 2/9/2015 BRUSH AND FLUSH TBG W/2.77" GAUGE RING TO 8603' RKB (BRUSHED SBR THOROUGHLY/ RECOVERED STRING SHOT REMNANTS ON BRUSH). READY FOR E-LINE. 2/11/2015 (PRE RWO): FT LDS AND GN'S, WILL HAVE TO RETURN @ LATER DATE TO FUNCTION TEST REMAINING SEIZED LDS AND GN'S. 2/13/2015 RIH WITH FIRST CUTTER TOOL STRING. CORRELATE TO GLM AT 8322'. FIRE FIRST CUTTER AT 8598', FIRE AT A CCL STOP DEPTH OF 8592.7'WITH A 5.3' CCL TO CUTTER OFFSET. 2/14/2015 MADE TUBING CUTS © 8344'AND 8179'. ALL TUBING CUTS WERE MADE WITH RCT 2000-200. ALL TUBING CUTS WERE CORRELATED TO GLM @ 8322' IN THE TUBING TALLY. ConocoPhiIIips Time Log & Summary Wellview Web Reporting Report Well Name: 1G-12 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 2/27/2015 6:00:00 AM Rig Release: 3/15/2015 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 32/25/2015 24 hr Summary Rig released form 3F-06 at 0900 HRS. Prepare rig for move. Pull Handy Berm, and slop tanks. Move pits, and load Downey camp, shop and pits for move. Move sub base and lay over derrick. Move Pits, Downey Camp and Shop to 1G pad. Spot shop. Spot Downey Camp and berm up. Begin moving Rig Sub from 3F pad. 09:00 12:00 3.00 0 0 MIRU MOVE RURD P Rig released from 3F-06 at 0900 HRS. Prepare rig and modules for move. Pull Handy berm, and rig down slop tank. Load and move equipment to 1G pad. Note: Slickline still working on 1G-11, and Roads and pads performing dirt work. 12:00 18:00 6.00 0 0 MIRU MOVE MOB P Trucks on location at 12 Noon. Prep equipment and load the Camp office, shop and pit module, for move to 1G pad. Continue haul equipment to 1G pad. 18:00 00:00 6.00 0 0 MIRU MOVE MOB P Move sub base and lay over derrick. Move Pits, Downey Camp and Shop to 1G pad. Spot shop. Spot Downey Camp and berm up. Begin moving Rig Sub from 3F pad. Establish communications link. 02/26/2015 Move Rig Sub from 3F access road to 1G pad. Spot rig over well.While maneuvering rig movement system motor required replacement due to failure. Replace motor. Spot rig sub over well. Spot pits to rig. Spot Cutting box. Berm up rig, pits and cuttings box. 00:00 06:00 6.00 0 0 MIRU MOVE MOB P Move Rig Sub from 3F access road to 1Q. Stopped at 1Q for change out. Berm Up Downey Camp and prep 1G-12 well and area around well for rig. 06:00 10:00 4.00 0 0 MIRU MOVE MOB P Move Rig Sub from 1Q to 1G pad. 10:00 12:00 2.00 0 0 MIRU MOVE MOB P Hang tree in cellar. Raise the Derrick. 12:00 12:45 0.75 0 0 MIRU MOVE MOB P Maneuver Rig Sub to spot over well. Drive motor failure in movement system. 12:45 19:30 6.75 0 0 MIRU MOVE RGRP T Replace movement system motor. 19:30 00:00 4.50 0 0 MIRU MOVE MOB P Spot Rig over well. Spot pits up to Rig Sub. Spot Cutting bin. Berm up around rig, pits and cuttings bin. 02/27/2015 Hook up interconnects to include fluids and electrical lines. Spot and hook up mud shack. Perform rig acceptance checklist.Accept Rig. Pull BPV. Kill well. Set BPV. Nipple Down Tree. Set Test Dart. RIG ACCEPTED @ 06:00 Page 1 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 0 0 MIRU MOVE RURD P Rig Up interconnects. Continue to berm up around rig and pits. Raise Cattle Chute, Bridle Down. Check pumps and fluid connections, connect electrical lines. Set mud shack and connect electrical and communications lines.Work on rig acceptance checklist. RIG ACCEPTED @ 06:00 06:00 07:30 1.50 0 0 MIRU WELCTL WAIT T Take on 8.6 ppg seawater to the pits. Phase 3 weather and road conditions on 1G access road. 07:30 09:30 2.00 0 0 MIRU WELCTL RURD P Berm around cellar and beneath fuel tanks. Set up rig floor for operations. 09:30 11:30 2.00 0 0 MIRU WELCTL MPSP P Rig Up lubricator. Test to 2500 psi. Pull BPV.Tubing=m 400 psi; IA= 940 psi, OA=540 psi. 11:30 12:30 1.00 0 0 MIRU WELCTL RURD P Rig Up lines to squeeze manifold. Run air and steam to tiger tank and choke shack to ensure lines are clear and all connections are secure. Rig up lines to tree for well kill. 12:30 13:00 0.50 0 0 MIRU WELCTL SFTY P PJSM for well kill operations. 13:00 15:45 2.75 0 0 MIRU WELCTL KLWL P Kill well. Test hard lines to 3000 psi. Open tubing to choke house and bleed to 450 psi. Bleed Annulus to 400 psi. Kill well by pumping 360 bbls of 8.6 ppg seawater down tubing and taking returns out annulus to choke shack and tiger tank while holding back pressure. Clean returns at 346 bbls pumped. Losses-45 BBLS 15:45 16:00 0.25 0 0 MIRU WELCTL OWFF P Monitor Well. observe both tubing and annulus on vacuum. 16:00 17:30 1.50 0 0 MIRU WELCTL CIRC P Reverse 1 hole volume with Deep clean mixed into 8.6 ppg seawater to clean pipe prior to pulling and laying down. pumped down IA returns out tubing. Pumped 4 bpm/321 psi. Pumped 282 bbls with a loss rate calculated during pumping at 91 bbl/hr. Static loss rate calculated at 49 bbl/hr. 17:30 18:45 1.25 0 0 MIRU WELCTL RURD P Blow down lines and Choke Shack. Rig down lines, 18:45 19:00 0.25 0 0 MIRU WELCTL OWFF P Monitor Well. Both sides on slight vacuum . 19:00 20:30 1.50 0 0 MIRU WHDBO MPSP P Set BPV.Test from below with rolling test and observed BPV leaking. Pull BPV and reset with spare BPV and roll test spare BPV. Good test. 20:30 23:30 3.00 0 0 MIRU WHDBO NUND P Nipple down tree and adaptor. Function all LDS. MU 3.5" IBT X-Over for Hanger with 11-1/2 turns to the right. Install test dart. Page 2 of 17 Tinie Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 0 0 MIRU WHDBO NUND P Nipple up BOPE. 02/28/2015 Nipple Up BOPE.Test BOPE,Witness waived by AOGCC Rep Jeff Jones.Test gas alarms and Koomey, 5 bottle avg 2035 psi,full press 2900,after functioning all 1775 psi,200 psi recovery in 21 sec,full pressure in 89 sec. Upper IBOP and Lower Well Control Valve need to be tested after repair. Shut Down wait on Phase 3 weather. 00:00 03:00 3.00 0 0 MIRU WHDBO NUND P Nipple Up BOPE, Install DSA. Set Stack, Install Riser,Tighten turnbuckles. 03:00 04:30 1.50 0 0 MIRU WHDBO NUND P Change out bottom rams to 7"solid body rams. 04:30 07:00 2.50 0 0 MIRU WHDBO RURD P Make up TIW@ valve. Rig Up test equipment and pick up and make up 3.5"test joint. Prepare 7"test joint. Fill stack and choke manifold with fresh water for test. 07:00 08:00 1.00 0 0 MIRU WHDBO BOPE P Perform Body test. PSI leaking off, no visible leak. Leak located in Upper IBOP and Lower well control valve. Test without those components and body test passed. 08:00 13:30 5.50 0 0 MIRU WHDBO BOPE P Perform initial BOPE test per ConocoPhillips/AOGCC requirements at 250/2,500 psi with 3 1/2"and 7"Test Joints. Perform the Koomey draw down test. Test Gas Alarms. The State's right to witness the test was waived by AOGCC Field Inspector, Jeff Jones.All pressure tests PASS except for Upper IBOP and Lower Well Control Valve.All tests recorded on a chart. Koomey draw test, good.4 bottle avg 2035 psi.Accum Pressure 2900 psi, Manifold Pressure 1600 psi,Annular Pressure 1000 psi. Pressure after all rams functioned 1775 psi.200 psi recovery in 14 sec,full system pressure 83 sec. 13:30 14:30 1.00 0 0 MIRU WHDBO RURD T Rig down and Blow down lines and test equipment. 14:30 17:00 2.50 0 0 MIRU WHDBO RGRP T Change Out Upper IBOP and Lower Well Control Valve due to failure during Shell test. Service. SIMOPS: Service Top Drive and grease back up wrench knuckle while saver sub is out. 17:00 00:00 7.00 0 0 MIRU WHDBO WAIT T Shut Down due to Phase 3 weather. Continue filling IA every 2 hours. 33/01/2015 Continue to wait on Phase 3 weather. 00:00 00:00 24.00 0 0 MIRU WHDBO WAIT T Shut Down due to Phase 3 weather. Continue filling IA every 2 hours. 33/02/2015 Continue to wait on Phase 3 weather. Continue/Complete BOP Test. Pull 3.5"completion. Lock down seized. ND BOP. Grind lock down off. NU BOP.Test break to 250/2500 psi. Pull 3.5"completion. Page 3 of 17 Tithe Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 07:00 7.00 0 0 MIRU WHDBO WAIT T Shut Down due to Phase 3 weather. Continue filling IA every 2 hours. 07:00 07:30 0.50 0 0 MIRU WHDBO BOPE T Test Upper!BOP and Lower Well Control valve. Both test are PASS. 07:30 08:00 0.50 0 0 MIRU WHDBO RURD T Rig down test equipment 08:00 08:45 0.75 0 0 MIRU WHDBO MPSP P Pull BPV. 08:45 10:00 1.25 0 0 COMPZ RPCOM RURD P RU GBR tongs and handling equipment, SLB spooling unit. Make Up crossover to pull hanger, landing joint and crossover to make up to top drive. 10:00 11:00 1.00 0 0 COMPZ RPCOM PULL P Back Out Lockdown Screws. Attempt to pull hanger, hanger not moving. 11:00 14:00 3.00 0 0 COMPZ RPCOM PULL T Function each screw individually and check to see if hung up. Pull against each one by one. 1 upper Lockdown screw found to be sheared. 14:00 14:30 0.50 0 0 COMPZ WHDBO MPSP T Set BPV. 14:30 15:00 0.50 0 0 COMPZ WHDBO NUND T Nipple Down stack to work on lockdown screw. 15:00 16:00 1.00 0 0 COMPZ WHDBO OTHR T Grind off end of sheared lock down screw per CIW Rep. 16:00 17:30 1.50 0 0 COMPZ WHDBO NUND T Nipple Up BOPE,Adapter,torque all bolts. 17:30 18:00 0.50 0 0 COMPZ WHDBO BOPE T Test Break on BOPE to 250/2500 psi. charted. 18:00 18:30 0.50 0 0 COMPZ WHDBO RURD T Rig Down Test Equipment and blow down lines. 18:30 19:00 0.50 0 0 COMPZ WHDBO MPSP T Pull BPV. 19:00 19:30 0.50 0 8,149 COMPZ RPCOM PULL P Pull on completion. Observe cut part at Up wt 130k. Up wt after free 92k. Pull hanger to floor. 19:30 19:45 0.25 8,149 8,149 COMPZ RPCOM OWFF P Monitor well.Well on taking fluid. 19:45 23:30 3.75 8,149 6,210 COMPZ RPCOM PULL P Lay Down old 3.5"EUE8rd tubing while spooling control line. 35 Stainless Steel bands recovered. 23:30 00:00 0.50 6,210 6,210 COMPZ RPCOM RURD P Rig Down SLB spooling unit and clear form rig floor. 03/03/2015 Lay down 3.5"de-completion;262 joints+cut joint recovered. M/U RBP and RIH and set at 510'(COE). POOH. Test RBP to 1000 psi for 10 minutes-good. N/D BOPE and tubing head. R/U Hydratight and grow casing(9"of growth). Pull packoff, install new packoffs and tubing head. Test packoffs 250/3000 psi-good. Install DSA. N/U BOPE. 00:00 03:00 3.00 6,210 4,200 COMPZ RPCOM PULL P Continue to Pull and Lay Down 3.5" EUE8rd completion. Observe well out of balance.Well still taking fluid but slight flow from tubing. 03:00 03:45 0.75 4,200 4,200 COMPZ RPCOM CIRC P Circulate hole volume.Trace crude in brine observed after Bottoms Up.5 bpm/270 psi. 03:45 04:15 0.50 4,200 4,200 COMPZ RPCOM OWFF P Monitor well.Well taking fluid and balanced. Page 4 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 09:00 4.75 4,200 0 COMPZ RPCOM PULL P Continue to Pull and Lay Down 3.5" EUE8rd completion;262 joints+cut joint length of 13.80'. 09:00 09:30 0.50 0 0 COMPZ RPCOM RURD P Rig down GBR casing equipment. Clean and clear rig floor 09:30 10:00 0.50 0 0 COMPZ WELLPF SVRG P Daily inpsection and service top drive. 10:00 10:30 0.50 0 0 COMPZ WELLPF BHAH P M/U BOT Retrievable Bridge Plug 10:30 11:00 0.50 0 0 COMPZ WELLPF TRIP P RIH with bridge plug on 3 1/2" DP to 517'. 11:00 11:30 0.50 0 0 COMPZ WELLPF MPSP P Set RBP, as per BOT rep at 510'. PUW/SOW 36K. 11:30 12:00 0.50 0 0 COMPZ WELLPF TRIP P POOH with setting tool, 5 stands. 12:00 12:30 0.50 0 0 COMPZ WELLPF MPSP P R/U and test RBP to 1000 psi for 10 minutes on chart-good. 12:30 13:30 1.00 0 0 COMPZ WELLPF NUND P Drain stack. N/D BOPE. 13:30 16:00 2.50 0 0 COMPZ WELLPF NUND P Bleed OA pressrure from 580 psi to 0. Remove bolts and lock down screws on tubing head. Rig up shackles and cables with top drive, and put steam on tbg head allowing it to heat up. Utilize wedges to bump tbg head free, and pulled free at 30K. 16:00 17:30 1.50 0 0 COMPZ WELLPF CUTP P R/U Hydratight and grow casing 9". Initial pressure 14,000 psi with 2 hydratight Jacks. 17:30 18:30 1.00 0 0 COMPZ WELLPF WWSP P Remove casing packoff. Clean up wellhead and install new packoffs. Rework lower lock down screws veifying fully functional. 18:30 20:00 1.50 0 0 COMPZ WELLPF HOSO P R/U Hydrtight; reland casing in compression-4 hydratight jacks used 6000 psi on system to re-land. RILDS. 20:00 22:00 2.00 0 0 COMPZ WELLPF NUND P N/U new tubing spool. Test Packoffs 250/3000 psi for 10 minutes-good. 22:00 23:00 1.00 0 0 COMPZ WELLPF RURD P Clear cellar area, load DSA in cellar and steam. 23:00 00:00 1.00 0 0 COMPZ WELLPF NUND P N/U BOPE and DSA. Install Riser. 33/04/2015 N/U DSA and BOPE, install test plug. Change LPR to 2-7/8"x 5"VBR's. Attempt to test BOPE breaks and LPR;flange leak(test spool/DSA). N/D, install new API ring. N/U and test 250/2500-good. M/U RBP retrieval tool and retrieve RBP. M/U BHA#3 Overshot with Grapple. RIH with BHA#3 to 7,599. 00:00 01:30 1.50 0 0 COMPZ WELLPF NUND P Continue to N/U DSA and BOPE. 01:30 02:00 0.50 0 0 COMPZ WELLPF BOPE P Install test plug. 02:00 03:00 1.00 0 0 COMPZ WELLPF NUND P Change out Lower Pipe rams from 7" back to 2-7/8"x 5"VBR's 03:00 04:30 1.50 0 0 COMPZ WELLPF BOPE T Fill stack. Pick up 3-1/2"test joint. Test Lower pipe rams and breaks 250/2500 psi. Low test passed; high test flange leak between test spool and DSA. Page 5 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 06:00 1.50 0 0 COMPZ WELLPF BOPE T Tighten flange between test spool and DSA. Pressure up. Still leaking. Re-tighten flange. Pressure up and observe leak 06:00 07:30 1.50 0 0 COMPZ WELLPF NUND T N/D BOPE, observe debris on API ring between DSA and test spool. Install new API ring. 07:30 08:30 1.00 0 0 COMPZ WELLPF NUND T N/U BOPE 08:30 09:30 1.00 0 0 COMPZ WELLPF BOPE P Fill stack, P/U 3-1/2"test Joint. Test Lower pipe rams and breaks; 250/2500 psi-good. 09:30 10:00 0.50 0 0 COMPZ WELLPF RURD P R/D testing equipment. Suck out stack and pull test plug 10:00 10:30 0.50 0 0 COMPZ WELLPF RURD P Install wear ring. 10:30 11:00 0.50 0 5,050 COMPZ WELLPF MPSP P M/U RBP retrieval tool. RIH to 505', engage RBP and release. 11:00 12:00 1.00 505 0 COMPZ RPCOM TRIP P Monitor well for 10 minutes,taking fluid. POOH wth RBP. 12:00 14:00 2.00 0 314 COMPZ RPCOM BHAH P P/U Fishing BHA#3-overshot. 14:00 17:30 3.50 314 3,626 COMPZ RPCOM PULD P Single in hole with BHA#3 from 314' to 3,626'. 17:30 18:00 0.50 3,626 3,626 COMPZ RPCOM SVRG P Daily inspection and servicing of top drive. 18:00 22:15 4.25 3,626 8,072 COMPZ RPCOM PULD P Continue to single in hole with drill pipe from 3,626'to 8072;. 22:15 23:00 0.75 8,072 6,841 COMPZ RPCOM TRIP P POOH standing back 13 stands to pick up all drill pipe from shed to 6,841'. 23:00 00:00 1.00 6,841 7,599 COMPZ RPCOM PULD P Continue to single in the hole with drill pipe from shed with BHA#3 to 7,599' 03/05/2015 Continue to RIH with BHA#3 to 8,072'. Establish parameters. Wash down and tag fish at 8,177'. Engage fish and jar until sheared out(90K over). POOH with fish. Recovered SBR, Packer, (2)GLMS down to pre-RWO cut at 8,344'. L/D fish. M/U BHA#4 washover assembly and RIH to 8,199'. Slip and cut drilling line. RIH to 8,250'and establish parameters. 00:00 00:30 0.50 7,599 8,072 COMPZ RPCOM PULD P Continue to single in the hole with BHA#3 from 7,599'to 8,072' 00:30 01:00 0.50 8,072 8,182 COMPZ RPCOM FISH P Establish parameters. PUW 170K, SOW 97K. Obtain SPR's. Wash down at 2 bpm, 190 psi. Tag up on fish at 8,177'with 5K down. Pick up to 8,172'. Establish rotary at 23 rpms 6900 ft-lbs. Slack off over fish to 8,182(5'of swallow)with 20K down. Page 6of17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 02:00 1.00 8,182 8,140 COMPZ RPCOM JAR P Pick up to 200K and allow jars to bleed x2. Jar at 215K x 6; 225k-230K x 7;240k-245K x 10; 250 x 5. Observe fish shear at 260K jar,weight dropping off to 125K. Pick up to 8,140'observing 5-10K drag. Establish circulation at 2 bpm 270 psi and slack off;observe increase in pump pressure to 400 psi. Pick up and pump pressure decrease to 300 psi. Shut down pumps and monitor well for 10 minutes. 02:00 04:00 2.00 8,140 8,140 COMPZ RPCOM CIRC P Circulate hole volume at 3 bpm 390 psi. Observe a small amount of gas breakout just prior to bottoms up, clearing up at bottoms up. Monitor well for 10 minutes. 04:00 04:30 0.50 8,140 8,140 COMPZ RPCOM SFTY P Post jarring derrick inspection 04:30 05:00 0.50 8,140 8,140 COMPZ RPCOM SVRG P Daily inpsection and service of top drive 05:00 09:00 4.00 8,140 500 COMPZ RPCOM TRIP P POOH with fish from 8140' PUW 175K to 500' 09:00 12:00 3.00 500 0 COMPZ RPCOM PULL P L/D BHA and fish. Recovered: SBR, Otis RRH packer,Tubing joint, GLM, (2)tubing Joints, GLM and cut joint down to 8,344'. 12:00 14:00 2.00 0 587 COMPZ RPCOM BHAH P Pick up BHA#4,wash over assembly. 14:00 17:30 3.50 587 4,088 COMPZ RPCOM TRIP P RIH with drill pipe from 587'to 4,088' PUW 88K. 17:30 18:00 0.50 4,088 4,088 COMPZ RPCOM SVRG P Daily inspection and service top drive 18:00 22:00 4.00 4,088 8,155 COMPZ RPCOM TRIP P Continue running in hole with BHA#4 from 4088'to 8,199'. PUW 170K, SOW 99K. 22:00 23:30 1.50 8,155 8,155 COMPZ RPCOM SLPC P Slip and cut drilling line, service drawwork brakes,attempt to calibrate block height. 23:30 00:00 0.50 8,155 8,250 COMPZ RPCOM TRIP P Continue to RIH to 8,250'. Establish parameters PUW 165K SOW 97K, pump pressure 1020 psi at 6 bpm, free torque 8000 ft-lbs at 20 rpms. Obtain SPR. 03/06/2015 Ream down to top of fish. Wash over fish; attempt to wash down to 8,625'. Unable to wash past 8,396'with varying parameters. Attempt to rotate down, stall out at 8,395'. Circulate bottoms up. POOH. M/U BHA#5 Baker Rattler tool. RIH and engage fish with 8'of swallow. Establish circulation to begin rattling at 2 bpm, Pull on fish from 10-25K while rattling. Fish free. Circulate annular volume. POOH. Page 7 of 17 Tiflis Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 8,250 8,396 COMPZ RPCOM REAM P Wash down from 8,250';6bpm 1080 psi. Tag up on fill at 8,324'(tubing stub at 8,342'tallied out). Attempt to work through. Rotate down to 8,340 at 20 rpms 6,000 ft-lbs. Shut down rotary and work from 8,324'to 8,340' with no drag. Slack off and observe washpipe slide over tubing stump. Wash down to 8,380'at 8 bpm 1850 psi with WOB 5-10 Kft-lbs;work pipe at areas with 10Kft-lbs. Second pass 0-3 Kft-lbs. Continue to wash down from 8,380'to 8,396'with WOB increasing to 10-15 Kft-lbs,work pipe at 15 Kft-lbs, second pass 0-3 K ft-lbs. Note 60 bph losses at 8 bpm. 02:00 04:30 2.50 8,396 8,396 COMPZ RPCOM REAM P Attempt to work past 8,396'. Unable to work past 8,396'varying pump rates from 6 bpm to 9 bpm with up to 25K WOB. Pump 15 bbls high viscosity sweep. Still unable to work past 8,396'. Tight spot noted at 8,394;. Pick up to 8,388'and establish rotary at 15 rpms 6400 ft-lbs. Ream down to 8,395',took weight and torqued up to 10,000 ft-lbs. Attempt a second time with same results, observe 20-25 K drag off. Pick up to 8,345'with drag. Work from 8,345'-8,396'until no drag. Consult with town and attempt rotating once more with same results. 04:30 09:00 4.50 8,396 587 COMPZ RPCOM TRIP P Monitor well for 10 minutes. POOH with BHA#4 to 587'. Observe 5-10K drag off bottom,with as much as 25K drag dropping off. 09:00 11:00 2.00 587 0 COMPZ RPCOM BHAH P L/D BHA#4 as per Baker. Observe scarring and scratches on outside and inside of Drag tooth Shoe. 11:00 11:30 0.50 0 0 COMPZ RPCOM SVRG P Daily inspection and servicing of top drive. 11:30 13:30 2.00 0 0 COMPZ RPCOM WAIT T Wait on rattler tool from Baker shop. Clean and clear rig floor. Prep for BHA#5. 13:30 14:30 1.00 0 555 COMPZ RPCOM BHAH P M/U BHA#5 Baker Rattler tool. Function test once in the hole 2 bpm 1000 psi-good. 14:30 18:00 3.50 555 8,336 COMPZ RPCOM TRIP P RIH with BHA#5 to 8,335'. Page 8 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 19:00 1.00 8,336 8,349 COMPZ RPCOM FISH P Establish parameters. PUW 170K/SOW100K. Free torque 9000 'ft-lbs at 20 rpms. Rotating weight 130K. Slack off and observe top of fish at 8,342'. Swallow 8"of fish to 8,349'and stack 10K. Pick up 20K over bleed jars. Flush mud pump#2 with clean fluid. 19:00 20:30 1.50 8,349 8,091 COMPZ RPCOM JAR P Establish circulation at 2 bpm 1380 psi to begin rattling. Pick up 5-10K over and observer over pull fall off. Continue working rattler tool with less overpull falling off. Work up to 25K over varying pump rates from 1-3 bpm and varying overpull. Pull 4', overpull falling from 20-25K over to 10-15K over. Continue working with varying parameters. Observe weight fall off. Pick up with 15K drag,fish free. 20:30 22:30 2.00 8,091 8,091 COMPZ RPCOM CIRC P Drop dart to open circulation sub and circulate annular volume at 5 bpm 1530 psi. Spot high vis pill on bottom to mitigate losses. Monitor well for 10 minutes. Well taking fluid. 22:30 23:00 0.50 8,091 8,091 COMPZ RPCOM SFTY P Post rattling derrick inspcetion. 23:00 00:00 1.00 8,091 6,095 COMPZ RPCOM TRIP P POOH with BHA#5 to 6,095'. 03/07/2015 Continue to POOH with BHA#5. L/D BHA. Fish recovered down to pre-RWO cut at 8,598'. L/D blast ring joints,XO's, and tubing. M/U BHA#6 Junk Mill cleanout assembly. RIH to 8,271'. Wash down to 8,594'. Circulate hole clean. Spot high viscosity pill to minimize losses. Static loss rate of 7-9 bph. POOH with BHA#6 to 5,000'. 00:00 02:45 2.75 6,095 587 COMPZ RPCOM TRIP P Continue to POOH with BHA#5 from 6,095'to 587' Monitor well at BHA, taking fluid—7 bph. 02:45 04:15 1.50 587 254 COMPZ RPCOM BHAH P L/D BHA.Rack back DC's. Breakout and lay down Jars&Overshot assembly. 04:15 06:00 1.75 254 254 COMPZ RPCOM RURD P R/U GBR powerr tongs, load PESI tools, false table and crummy tongs, to break blast joints. 06:00 11:00 5.00 254 0 COMPZ RPCOM PULL P L/D Fish.Tubing recovered down to pre-RWO tubing cut at 8,598'. Significant scale observed on tubing. Pictures taken and posted. All blast rings recovered;0.65'of blast rings broken. 11:00 13:00 2.00 0 0 COMPZ RPCOM RURD P R/D PESI and GBR. Clean and clear floor area. NORM inspect blast joints and rings for disposal. 13:00 14:30 1.50 0 324 COMPZ RPCOM BHAH P M/U BHA#6 Junk Milli clean out assembly. 14:30 18:00 3.50 324 8,271 COMPZ RPCOM TRIP P RIH with BHA#6 to 8,271'. Page 9 of 17 Tittle Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 20:00 2.00 8,271 8,271 COMPZ RPCOM REAM P Establish parameters; PUW 175, SOW 95K, RotW 125K. Free torque 9,300 ft-lbs at 65 rpms. Establish circulation at 7 bpm 1450 psi. Wash down from 8,271'to 8,594'. Observe 10-15K WOB from 8366 to 8461', work through with WOB 0-3K on second pass. Observe 5-10K WOB from 8540 to 8594';work through with WOB 0-3K on second pass. Pick up to 8,271'and drift down to 8,594'- good. Pump out to 8,271'. 20:00 22:00 2.00 8,271 8,271 COMPZ RPCOM CIRC P Circulate high viscosity sweep. Minimal returns. Spot high viscosity pill on bottom to assist in mitigating losses. Monitor hole for 10 minutes 7-9 bph static loss rate. 22:00 00:00 2.00 8,271 5,000 COMPZ RPCOM TRIP P POOH with BHA#6 to 5,000'. 03/08/2015 Continue to POOH and L/D with BHA#6. M/U BHA#7 overshot with 3-1/2"grapple and RIH to 8,553'. Establish parameters,engage fish and jar x 2 at 60K over; fish free. Circulate hole clean. POOH with BHA #7; fish recovered down to seal assembly. Pick up BHA#8 reverse circulating junk basket and RIH to 8,595'. Daily seawater loss 163 bbls;total 2170 bbls. 00:00 01:30 1.50 5,000 324 COMPZ RPCOM TRIP P Continue to POOH with BHA#6 to 324'. 01:30 04:30 3.00 324 0 COMPZ RPCOM BHAH P Lay Down BHA, stand back drill collars. 11 lbs of material recovered from boot basets including 6 peices of blast rings(1-2"). Material recovered primarily scale. *Note daylight savings time begins 04:30 05:00 0.50 0 0 COMPZ RPCOM SVRG P Daily inspection and service of top drive. 05:00 06:00 1.00 0 321 COMPZ RPCOM BHAH P M/U BHA#7 Overshot with 3-1/2" grapple 06:00 09:30 3.50 321 8,553 COMPZ RPCOM TRIP P RIH with BHA#7 to 8,553'. 09:30 11:00 1.50 8,553 8,537 COMPZ RPCOM FISH P Establish parameters PUW 170K, SOW 105K, RTW 125K at 20 rpms at 7Kft-lbs. Establish circulate at 2 bpm 170 psi and wash down to 8,594',tag with 10K down. Pick up and work pipe down to 8,600' stacking 10K down. Pick up and establish rotary. Rotate down at 20 rpms to 8,601'. Pick up with 50K over falling off. Increase pump rate to 5 bpm and work pipe down to 8,602'. Fish engaged. Pick up and bleed jars. Continue to work pipe down to 8,604'. Pick up and jar X 2 with 60K over. Fish free. Pick up to 8,537'. 11:00 12:00 1.00 8,537 8,537 COMPZ RPCOM CIRC P Circulate and condition mud at 6 bpm 1,050 psi. Page 10 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:30 0.50 8,537 8,174 COMPZ RPCOM TRIP P POOH from 8.537'to 8,174'. 12:30 13:00 0.50 8,174 8,174 COMPZ RPCOM SVRG P Daily inspection and service of Top drive. 13:00 16:30 3.50 8,174 321 COMPZ RPCOM TRIP P POOH with BHA#7 from 8,174'to 321'. 16:30 18:00 1.50 321 0 COMPZ RPCOM BHAH P Stand back DC, L/D BHA#7. 18:00 19:00 1.00 0 0 COMPZ RPCOM PULL P Lay down fish: recovered 1 cut joint, GLM, 1 full joint, seal assembly with bow spring centralizer. Hole observed mid joint above seal assembly. Significant scale observed on pipe(Pictures in well file). 19:00 20:30 1.50 0 332 COMPZ RPCOM BHAH P Pick up BHA#8; Reverse circulating Junk basket. 20:30 00:00 3.50 332 8,595 COMPZ RPCOM TRIP P RIH with BHA#8 to 8,595'. 33/09/2015 Establish parameters. Wash down at 7bpm from 8,595 to 8,661;tag packer top with 10K down.Work pipe while circulating through RCJB. Spot high viscosity pill to mitigate losses. POOH with BHA. Break out boot baskets and RCJB, Significant scale and fine metal returned. M/U BHA#9 RCJB and boot baskets. RIH to 8,535'. Wash down at 8 bph, tag packer at 8,661'. Work pipe. Spot high viscosity pill. POOH. no junk recovered. R/U and begin BOPE test 250/25000 psi. Right to witness waived by Matt Herrara. Daily fluid loss to formation 83 bbls;total 2253 bbls. 00:00 01:30 1.50 8,595 8,661 COMPZ RPCOM WASH P Establish parameters PUW 170K, SOW 105K, RTW 140K. 7000 ft-lbs free torque at 20 rpms. Establish circulation at 7 bpm 2000 psi. Wash down from 8,595'to 8,661',tag with 10K down. Pick up and establish rotary at 20 rpms,slack off and tag. Continue working pipe while circulating through RCJB. Spot high viscosity pill to minimize losses. Monitor well for 10 minutes. 01:30 05:00 3.50 8,661 322 COMPZ RPCOM TRIP P POOH with BHA#8 to 322'. 05:00 06:00 1.00 322 0 COMPZ RPCOM BHAH P Stand back drill collars. Break out Boot baskets and RCJB. Significant scale and fine metal recovered from boot basket 06:00 07:00 1.00 0 322 COMPZ RPCOM BHAH P Make up BHA#9 RCJB and boot baskets 07:00 10:30 3.50 322 8,535 COMPZ RPCOM TRIP P RIH with BHA#9 from 333'to 8,535'. 10:30 11:00 0.50 8,595 8,661 COMPZ RPCOM WASH P Establish parameters, PUW 165K, SOW 100K free torque 6,000ft-lbs at 25 rpms. Wash down at 8 bpm, 2500 psi. Tag packer at 8,661'with 10K down. Pick up and establish rotary at 60 rpms 6,000 ft-lbs of torque. Ream down and work pipe, no over pull. Shut down and monitor well for 10 minutes,taking fluid 11:00 11:30 0.50 8,661 8,661 COMPZ RPCOM SVRG P Daily inspection and service of top drive 11:30 12:00 0.50 8,661 8,270 COMPZ RPCOM TRIP P POOH with BHA#9 RCJB to 8,270' no over pull. Page 11 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:30 0.50 8,270 8,270 COMPZ RPCOM CIRC P Spot high viscosity pill to mitigate losses. 12:30 16:30 4.00 8,270 333 COMPZ RPCOM TRIP P POOH with BHA#9 from 8,270 (PUW 165K)to 333(PUW 40K) 16:30 17:30 1.00 333 COMPZ RPCOM BHAH P Lay down BHA#9; break out boot baskets and RCJB. No material recovered. 17:30 18:00 0.50 COMPZ RPCOM RURD P R/U and pull wear bushing. 18:00 19:00 1.00 COMPZ RPCOM WWWH P R/U and M/U BOPE stack jetting tool. Clean and Jet out BOP Stack. 19:00 21:00 2.00 COMPZ WHDBO RURD P R/U to test BOPE. Set test plug,fill stack and choke. 21:00 00:00 3.00 COMPZ WHDBO BOPE P Test BOPE to 250/2500 psi. State's right to witness waived by Matt Herrara. 1) Blind rams; Rig floor Kill; Outer test spool vavle, IBOP; Choke valves 1, 2, 3, 16-pass 2) Bline rams, HCR kill, inner test spool valve, manual IBOP;choke valves 4, 5,6-pass. 3) Blind rams; man. Kill; inner test spool; HT38 TIW; choke valves 7,8,9. -pass 4)Super choke, manual bean choke 5) Blind rams; Manual kill; inner test spool valve; HT38; chokes 10, 11 - pass 6)Blind rams; Manual Kill; chokes 12, 13, 15-pass 03/10/2015 Continue testing BOPE;witness waived by Matt Herrera. Test Accumulator system; Initial pressure 3000 psi,final 1700 psi; 1st 200 recharge 14 seconds,total 92 seconds. (5)N2 bottles at 1975 psi. M/U BHA#10 packer retrieval tool and run in hole to 8,559'. Slip and cut drilling line. Establish parameters. Tag packer at 8,661', mill to 8,663'. Chase packer to 8,850'. Engage fish, pick up with 15K drag to 8,274'. Spot high viscosity pill to mitigate losses. POOH. No fish recovered. M/U BHA#11 Itco spear and RIH to 6,548'. Daily fluid lost to formation 129 bbls,total lost 2382 bbls 00:00 02:30 2.50 0 0 COMPZ WHDBO BOPE P Continue to test BOPE 250/2500 psi. Test witness waived by Matt Herrera. 7)Annular with 3-1/2"TJ; Manual Kill; 8rd TIW; Choke valve 14-pass 8) Upper Pipe rams with 3-1/2" TJ;Choke HCR; Manual Kill;8rd TIW -pass. 9) Upper pipe rams with 3-1/2" TJ;Manual Choke; Manual Kill; 8rd TIW-pass. 10)Lower pipe rams with 3-1/2"; 8rd TIW. Accumulator test:starting pressure 3000 psi, final pressure 1700 psi. First 200 psi recharge 14 seconds, full recharge 92 seconds. 5 N2 bottles at 1975 psi. Page 12 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:00 0.50 0 0 COMPZ WHDBO RURD P Rig down and blow down. BOPE test equipment Rig down safety valves. L/D test joint. 03:00 03:30 0.50 0 0 COMPZ WHDBO RURD P Pull test plug. Install wear ring. 03:30 04:00 0.50 0 0 COMPZ RPCOM SVRG P Daily service and inspection of top drive. 04:00 05:30 1.50 0 327 COMPZ RPCOM BHAH P Pick up BHA#10; Packer Retrieval tool to 327. 05:30 09:30 4.00 327 8,559 COMPZ RPCOM TRIP P RIH with drill pipe to 8559'. 09:30 11:00 1.50 8,559 8,559 COMPZ RPCOM SLPC P Slip and cut 108'of drilling line. Service drawworks brakes. 11:00 14:30 3.50 8,559 8,850 COMPZ RPCOM MILL P Establish parameters: PUW 175K, SOW 100K, RTW 125K. Free torque 6,000 ft-lbs at 60 rpms, pump pressure 2100 psi at 7 bpm. Shut down rotary and pumps. Slack off to 8,667'(mill depth 8,661')and tag packer. Pick up and establish rotary (60 rpms)and circulation(7bpm). Mill from 8,661'to 8,663'with 5-15 Klbs weight on mill(WOM)and 10K- 15K ft-lbs of torque. Observe WOM fall off. RIH to 8,850'and tag packer with 30K down. 14:30 15:00 0.50 8,850 8,274 COMPZ RPCOM TRIP P POOH to 8,274',above perforations. 15:00 16:00 1.00 8,274 8,274 COMPZ RPCOM CIRC P Circulate high viscosity pill to mitigate losses. Monitor well-10 bph losses. 16:00 19:30 3.50 8,274 327 COMPZ RPCOM TRIP P POOH from 8,274" UW 170K to 327'. 19:30 21:00 1.50 327 0 COMPZ RPCOM BHAH P Lay down BHA. No fish recovered. Observed four peices of curved metal jammed around the inside of the packer retrieval spear ranging from 3-1/2"long to 6"long and up to 1/4" thick(pictures in well file). Break out and clean out boot baskets: 27 pounds of metal shavings recoverd from boot baskets. 21:00 22:00 1.00 0 309 COMPZ RPCOM BHAH P M/U BHA#11 Itco Spear with 3.947" grapple, bumper sub, oil jars, pump out sub and 9 joints of drill collars. 22:00 00:00 2.00 309 6,548 COMPZ RPCOM TRIP P RIH with BHA#11 to 6548'. 03/11/2015 Continue to RIH with Itco Spear to 8836'. Establish parameters. Slack off and tag fish at 8,858'. Pull 50K over,fish free. POOH with 5-10 K drag. L/D fish: Otis packer and tailpipe recovered. M/U BHA#11 Cleanout assembly. RIH and hard tag at 8,857'. Circulate hole clean. POOH with cleanout assembly. Rig up GBR. Daily fluid lost to formation 184 bbls,total lost 2566 bbls 00:00 01:15 1.25 6,548 8,836 COMPZ RPCOM TRIP P Continue to RIH with Itco spear from 6,458'to 8,836' Page 13of17 Tinie Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 02:15 1.00 8,836 8,836 COMPZ RPCOM FISH P Obtain SPR's. Establish parameters PUW175K SOW 105K pump pressure 270 psi at 2 bpm. Wash down to 8,858'tag top with 10K down. Pick with 25K overpull. Slack off and tag up at 8,858'. Pick up to 225K(50K over)break over to 185K. Monitor well x 10 minutes. 02:15 02:45 0.50 8,836 8,350 COMPZ RPCOM TRIP P POOH to 8,350',above the perfs. with 5- 10k drag. 02:45 03:45 1.00 8,350 8,350 COMPZ RPCOM CIRC P Circulate annular volume. Spot high viscosity pill to mitigate losses. 03:45 04:15 0.50 8,350 8,350 COMPZ RPCOM SVRG P Daily inspection and service top drive. 04:15 08:30 4.25 8,350 309 COMPZ RPCOM TRIP P POOH with BHA#11 Itco Spear and the Packer Fish. 08:30 09:30 1.00 309 0 COMPZ RPCOM BHAH P Lay down BHA#11...Spear Assembly and the Otis Packer/Tailpipe Fish, complete. Clear and clean Floor. 09:30 10:30 1.00 0 347 COMPZ WELLPF BHAH P Make-up BHA#12, cleanout assembly as follows: 6 1/8" Bladed Junk Mill, 3 ea Boot Baskets, Bit Sub,6 1/8"Smooth String Mill, 2 ea String Magnets, Bumper Sub, Oil Jar,6 ea 4 3/4"Drill Collars,XO. 10:30 14:30 4.00 347 8,857 COMPZ WELLPF TRIP P Trip in with BHA#12 with 3 1/2"Drill Pipe from the Derrick 8,801-ft.with no problems. Bring pump on line at 3.8 bpm/600 psi. Continue in to 8,857-ft dpmd. Set down hard. Made no further hole. 14:30 16:00 1.50 8,857 8,857 COMPZ WELLPF CIRC P Circulate hole volume at 6 bpm 1100 psi. Spot high viscosity pill to mitigate losses. Monitor well, loss rate 7 bph. 16:00 20:00 4.00 8,857 348 COMPZ WELLPF TRIP P POOH from 8,857'to 348'. Monitor well,taking fluid. 20:00 22:30 2.50 348 0 COMPZ WELLPF BHAH P Lay down BHA. L/D drill collars. L/D Clean out BHA-clear rig floor of Baker tools 22:30 23:00 0.50 0 0 COMPZ WELLPF SVRG P Daily inspection and service top drive. 23:00 00:00 1.00 0 0 COMPZ RPCOM RURD P Rig up GBR, check completion equipment. 03/12/2015 Run in hole with lower completion to 8,760'. Rig up E-Line. Run in hole with GR/CCL on E-line. Coorelate to K-1 marker at 8,198'from 10/4/1983 log. Space out Wearsox on depth. Drop ball. Pressure up to 1500 psi to set F-1 packer. Shear out'J'Hydraulic tool. Pull out of hole laying down drill pipe to 5,054'. Daily fluid lost to formation 92 bbls. Total lost 2,658 bbls. 00:00 01:30 1.50 0 0 COMPZ RPCOM RURD P Continue rigging up GBR tongs, change out elevators. 01:30 03:00 1.50 0 127 COMPZ RPCOM PUTB P RIH with lower completion. Baker lock Wearsox. 03:00 03:15 0.25 127 127 COMPZ RPCOM RURD P Change out pipe handling equipment for 3-1/2"pipe. 03:15 04:30 1.25 127 219 COMPZ RPCOM PUTB P Continue to pick up lower completion and RIH with lower completion. Page 14 of 17 • Tithe Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 04:30 11:00 6.50 219 8,796 COMPZ RPCOM RCST P RIH with lower completion on drill pipe to 8,796.0-ft dpmd. Up weight= 165K. Down weight= 107K. Install the TIW Valve. Ready Floor for E-Line ops. 11:00 12:30 1.50 8,796 8,796 COMPZ RPCOM ELOG T E-line Unit delays in getting to location due to getting equipment started in-38 deg F weather. 12:30 15:30 3.00 8,796 8,796 COMPZ RPCOM ELOG P HES E-Line Unit arrived on location. Spot Unit. Begin rigging up. (remind E-Line Crew to take extra warm-up breaks as needed and the possibility of frost bite). 15:30 15:45 0.25 8,796 8,796 COMPZ RPCOM SFTY P Safety meeting with All. 15:45 16:30 0.75 8,796 8,796 COMPZ RPCOM ELOG P Hang sheaves. Make-up Tool String. Rig up complete. 16:30 18:00 1.50 8,796 8,796 COMPZ RPCOM ELOG P Run in the hole with CCL and GR. Zero at rig floor. RIH to 8,590'. Coorelate to K-1 Marker at 8,198' from October 4, 1983 log. Make two passes to verify. POOH with E-Line 18:00 19:30 1.50 8,796 8,796 COMPZ RPCOM FLOG P R/D E-Line. 19:30 20:45 1.25 8,796 8,603 COMPZ RPCOM PACK P Pick up 1';space out as determined by E-Line. Drop ball. Pump ball down at 1 bpm until it seats. Pressure up to 500 psi and hold for 1 minute. Continue pressuring up to 1500 psi; observe 7K drop in weight. Hold 1500 psi. Slack off, set 10K down on packer to confirm its set. Pressure up to 2,000 psi. Pick up and observe'J' Hydraulic tool shear at 10K over. 20:45 00:00 3.25 8,603 5,054 COMPZ RPCOM PULD P Blow down top drive. POOH laying down drill pipe. to 5,054'. 03/13/2015 Continue to POOH laying down drill pipe. L/D'J'Hydraulic tool. Rig up and RIH with 3-1/2"completion as per detail. Make up head pin and circulate 1 bpm, observe pressure increase as seals enter SBE. No-Go seals. Pick up out of SBE. Circulate corrosion inhibited seawater(1%Conqor 303) 00:00 07:00 7.00 5,054 0 COMPZ RPCOM PULD P Continue to POOH laying down drill pipe from 5,054'. Lay down'J' Hydraulic tool. Pull Wear Bushing. Wash Stack. Clean and clean Floor. 07:00 08:00 1.00 0 0 COMPZ RPCOM RURD P Ready Floor to run the Upper completion. Rig up GBR equipment. 08:00 08:30 0.50 0 0 COMPZ RPCOM SFTY P Hold Safety and operations meeting with all. 08:30 12:00 3.50 0 444 COMPZ RPCOM PUTB P Pick-up and make-up the Upper Completion Jewelry as designed. 12:00 23:30 11.50 444 8,610 COMPZ RPCOM PUTB P Continue to run the 3 1/2"Upper Completion in with single 3 1/2" Tubing from the Pipe Shed, as designed. M/U head pin on joint 265. Circulate at 1 bpm to locate seals. Observe pressure increase as seals engage SBE. NO-GO seals. Pick up out of seals Page 15 of 17 Tirhe Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 8,610 8,606 COMPZ RPCOM CRIH P PJSM with all hands involved. Rig up and start pumping corrosion inhibited fluid off the truck 3 bpm 265 psi. 03/14/2015 Continue to pump corrosion inhibited seawater(1%)Conqor 303. Space out lower set of seals. Drop ball and rod and pressure up to set FHL packers. PT packer to 1000 psi-good. Shear out PBR. NO-GO 80-40 seals. Space out 7'above NO-GO. M/U hanger and land tubing. RILDS. Pressure test tubing to 3000 psi, pressure test IA to 2500 psi. Shear out GLM. Set BPV and test. Nipple down BOPE. Nipple up tree and install 4-way cross. Test tree and hanger void 250/5000 psi-good. Pull BPV. Freeze protect well with 65 bbls of diesel Set BPV. RDMO *Rig released at 24:00 00:00 02:00 2.00 8,606 8,606 COMPZ RPCOM CRIH P Continue to pump corrosion inhibited seawater(1%congor 303)at 3 bpm 270 psi. 02:00 03:30 1.50 8,609 8,609 COMPZ RPCOM PACK P Space out seals 1'from fully located. Drop ball and rod and allow to drop. Pressure up on tubitng to 2000 psi to set packer. Bleed off pressure. Pressure up on IA to 1000 psi for 10 minutes to test packer-good. Bleed pressure 03:30 04:45 1.25 COMPZ RPCOM HOSO P Pressure up on tubing to 2000 psi and overpull 15,000 lbs, observe PBR shear out. Slack off and no-go 80-40 seal assembly. Mark pipe. Calculate space out. L/D two joints and a partial. M/U space out pup, full joint, hanger and landing joint. Cycle mud pumps and slack off. Observe seals enter PBR. Hang completion string. Run in lock down screws. 04:45 06:00 1.25 COMPZ RPCOM PRTS P Rig up and pressure test tubing to 3,000 psi for 15 minutes. Bleed tubing pressure down to 1,500 psi and block in. Pressure up on the IA to test the Casing and the Packer at 2,500 psi x 30 minutes. Good. Bleed IA to"0"psi...bleed Tubing to "0"psi. Pressure up again on the IA and observe the SOV shear open at 2,100 psi. All test recorded on chart. Lay down Landing Joint.. 06:00 06:30 0.50 COMPZ RPCOM OWFF P Monitor Well,static x 30 minutes. Good. 06:30 07:30 1.00 COMPZ WHDBO MPSP P Drain Stack. Install BPV. 07:30 08:00 0.50 COMPZ WHDBO MPSP P Pressure test the BPV from below at 1,000 psi x 5 minutes. Record on chart. 08:00 12:30 4.50 COMPZ WHDBO NUND P Nipple down BOP Stack and set back on the Stump. (SIMOPS...start to clean Pits. Clean out under Rotary Table. Blow down lines. Change out Elevator Bails and ready for annual inspection). 12:30 14:00 1.50 COMPZ WHDBO NUND P Nipple up 3 1/8"x 5K Tree. Page 16 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 14:30 0.50 COMPZ WHDBO PRTS P Pressure test Hanger void at 250 psi x 5 minutes and at 5,000 psi x 10 minutes. Good. 14:30 16:00 1.50 COMPZ WHDBO NUND P At the Request of CPF-1 Production Engineer/Anchorage Engineer...Nipple down the Swab Valve, 3-Way Cross, and the Wing Valve. Nipple up a 4-Way Cross. Nipple back up the Wing Valve and the Swab Valve. 16:00 17:00 1.00 COMPZ WHDBO PRTS P Pressure test the Tree at 250/5,000 psi. Record on chart. 17:00 17:30 0.50 COMPZ WHDBO MPSP P Pull BPV and test dart 17:30 19:30 2.00 COMPZ WHDBO FRZP P Spot up and rig up Little Red Services. PT lines to 2500 psi. Freeze protect well with 65 bbls of diesel at 2bpm. ICP 150, FCP 350 psi. 19:30 21:00 1.50 COMPZ WHDBO FRZP P Allow diesel to U-Tube. R/D Little red services and hoses. 21:00 21:30 0.50 COMPZ WHDBO MPSP P Set BPV; final pressures IA=0, OA=0 TBG=0. 21:30 00:00 2.50 DEMOB MOVE RURD P Remove secondary annulus valve. Install gauges, secure well. Suck out cellar, rig down hardline. 'RIG RELEASED 24:00 3/14/15 Page 17 of 17 1G-12 WELL WORK SUMMARY DATE SUMMARY POST RIG WELL WORK 3/28/2015 PULLED BALL & ROD, RHC © 8496' RKB. TAGGED © 8850' SLM. SET 2.812" PXX PLUG WITH DUAL GAUGES © 8626' RKB. SET BAITED PRONG @ SAME. IN PROGRESS. 3/29/2015 PULLED DV© 8362' RKB, SET CV @ SAME. MEASURED C SAND BHP @ 8425' RKB: 2739 PSI & FALLING. PULLED SOV© 6922' RKB, SET OV© SAME. PULLED DV @ 5973' RKB, SET GLV @ SAME. IN PROGRESS. 24041 WELL LOG TRANSMITTAL DATA LOGGE 5/5/2015 M K.BENDER To: Alaska Oil and Gas Conservation Comm. March 23, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED APR 032015 RE: Correlation Record: 1G-12 Run Date: 3/12/2015 AOGCC 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 1G-12 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20109-00 SCANNED MAY 0 $ 2015 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. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:MAL"z 6-0m-eat 183132 15483 WELL LOG TRANSMITTAL DATA LOGGED /Grroi5 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. March 2, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED MAR 0 6 2015 RE: Tubing Cut Record: 1G-12 AOGCC Run Date: 2/13/2015 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 1G-12 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20109-00 SCANNED '• 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. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 6...enzt dS-‘32 _1DEIVED 2-5dio4 WELL LOG TRANSMITTAL FEB 13 2 015 DATALOGGED 5 AOGCC K.BENDER E M.K.BENDEF To: Alaska Oil and Gas Conservation Comm. February 4, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED Ail i-' .) 1 RE: String Shot Record: 1G-12 Run Date: 1/22/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd.,Anchorage, AK 99518 FRS_ANC@halliburton.com 1G-12 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20109-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: iit/211--adlix-14/) 6...ekzat 1' 53-‘32 153 ,3 WELL LOG TRANSMITTAL DATA LOGGED 2/S/2015 K ENDER To: Alaska Oil and Gas Conservation Comm. January 20, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 > jW7.2 f ry rF8 05 ?G RE: String Shot: 1G-12 Run Date: 1/11/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1G-12 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21009-00 pgyl � l y! Satiti PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE A'I hNTION OF:" `y Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ��✓Q���V �ye�� - ` ge Project Well History File~er Page XHYZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~-(~- L~- Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: ~ OVERSIZED (Non-Scannable) [] Other: -*' ,: D~ Logs of various kinds NOTES: Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS~ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Scanning Preparation BY: BEVERLY BREN VINCENT SHERYL(.~_MAR_~IA~OWELL Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: 7(~) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: Stage 2 ~ x30 =._.~+[~ = TOTALPAGES ~ YES NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IE REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ General Notes or Comments about this file: Quality Checked (do..) 1G-12 (PTD 1831320) Report of~ed TIFL • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Wednesday, September 10, 2008 9:00 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: 1 G-12 (PTD 1831320) Report of failed TIFL Attachments: 1 G-12 schematic.pdf; 1 G-12 90 day TIO plot.jpg Tom, Jim Kuparuk gas lifted producer 1G-12 (PTD 1831320) failed a dia nostic TIFL on 09/09/08 and has been added to the weekly SCP report. The TIO prior to the test was 2 00/900. A leaking GLV is suspected. Slickline will troubleshoot the GLV's and repair if possible. Attached is a 90 day TIO plot and a wellbore schematic. «1G-12 schematic.pdf» «1G-12 90 day TIO plot.jpg» -~ Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~'~'~ Jf~j~, ~~ ~ ? ~ ~ r 12/10/2009 KRU 1 G-12 PTD 183-132 9/ 10/2008 Ti0 Pressures • u ,- -1 ion©cal~hilli~s Alaska, fnc. 1 G-12 API: 500292100900 sssv SSSV Type: LOCKED OUT (1965-1966, ~-~-,=~- OD:3.500) Annular Fluid: G L'ft 'i Reference Lo KRU 1 G-12 Well T e: PROD An le TS: 42 de 8385 Orig 10/2/1983 Angle @ TD: 43 deg @ 9116 :om letion: Last W/O: Rev Reason: NEW GLV DESIGN I nn Dates Last Update: 10/4/2007 as , Last Ta :8884' TD: 9116 ftKB MandrelNalve ~ -.'~ 1 ~- ~'' Last Ta Date: 11/20/2006 Max Hole An le: 54 de 3500 __ __ __ (2037-2038, i~ - ~--- --- - G St ' ALL STRINGS Gas Lift MandrelNalve 3 (51345135, Gas Lift MandrelNalve s (7032-7033, SBR (8194-8195, OD:3.500) PKR (ezzo-fizz1, OD:6.156) Perf (8385-8458) Pert (8537-8589) TUBING (a-asst, OD:3.500, ID:2.992) PKR (8663-8664, OD:6.156) NIPPLE REDUCER (8680-8681, OD:2.750) SOS (8690-8691, OD:3.500) asmg rln_g - Deserl tion _ Size _ To Bottom _ TVD Wt Grade Thread r ~ CONDUCTOR 16.000 0 100 100 65.00 H-40 SUR. CASING 10.750 0 2302 2117 45.50 J-55 I I PROD._CASING _ 7.000 _ 0 9096 68_21 26.00 J-55 __ I Tubing String -TUBING T - __ _ ~" ~ Siz? Top Botto m TVD ' Wt Grade _ Thread I 11II ~ 0 0 ~ 8691 6523 9.30 J-55 8RD EUE - - J Perfo rations Summa __ ~; ~ ~ ~ ~ erval TVD Zone _ Status Ft SPF Date T e Comment " .~~ ~- 8385 - 8458 6297 - 6351 C-4 C-3 73 12 12/25/1983 IPERF DA Perf Gun, 120 de 5 8537 - 8589 6410 - 6448 C-1,UNIT 52 12 12/25/1983 IPERF 5" DA Perf Gun, 120 deg B ~ 8812 - 8830 6612 - 6625 A-5,A-4 18 4 6/23/1984 IPERF 2 1/8" Ri idJet 90 de . Ph " ~ ~ 8830 - 8850 6625 - 6640 A-4 20 8 8/13/1993 IPERF Titan HC, 180 deg 2.5 ~ Phasin ~ 27 de . CCW 8850 - 8864 6640 - 6650 A-4 - -- 14 4 6/23/1984 - IPERF - 2 1/8" RigidJet, 90 deg. PF - - -~' Gas Lift Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv I Cmn i 1 2037 1903 Otis SPM GLV 1.0 BK 0.156 1235 9/16/2007 l T~ r+~ A 2 3909 3175 Otis SPM DMY 1.0 BK 0.000 0 9/16/2007 .J= 3 5134 4002 Otis SPM GLV 1.0 BK 0.188 1290 9/16/2007 4 5858 4509 Otis SPM DMY 1.0 BK 0.000 0 11/10/200 5 6460 4923 Otis SPM DMY 1.0 BK 0.000 0 8/22/2001 r~ 6 7032 5312 Otis SPM OV 1.0 BK 0.250 0 9/16/2007 7 7619 5733 Otis SPM DMY 1.0 BK 0.000 0 11/10/200 8 8158 6126 Otis 6PM DMY 1.0 BK 0.000 0 11/18/199 Production Mandrels/Valves _ , _ _._ -- St - ~ MD ~ TVD ~ Man Mfr M _ an Type V Mfr Type - - ~ V OD Latch i Port ~TRO Date Run ~Vlv _ . lU 83ZZ bZSU UUS JYM 11 8625 6475 Otis SPM _ _ i Other plugs equip., etc . -PATCH ____ t De th TVD T e , 8603 6459 PATCH Patch; Set_ HES Tbg 15' , Other __ egui .etc lu s, _ _ . -JEWELRY __ De th TVD _ T e 1965 1842 SSSV Camco TRDP-1A Loc r 8194. 6153 SBR Otis ~: - ' =~'~ 8220 6173 PKR Otis RRH 8663 6503 PKR Otis WD ___ 8680 6515 NIPPLE AVA; Set on 8/26/94. A __ REDUCER = 8680 6515 NIP Camco 'D' Ni le NO G - - 8690 6523 SOS Otis _ -. 8691 6523 TTL General Notes _ Date _ Note HFCV DMY 0 9/15/200; 0 8/8/1994 i Out on 4/23/90) 2.813 2.813 2.970 4.000 profile 2.25" 2.250 2.992 I Ili 6/10!1999 NOTE: Ni le Reducer a ears to have AVA rofile instea~ 6/10/1999 NOTE: Leak detected in tubin below rior atch tubin lei 2/30/200 NOTE: WAIVERED WELL: IA x OA ANNULAR COMMUN Pa Pert (8812-8864) IG-12 (PTD 1831320) failed TIFL . Regg, James B (DOA) . Page 1 of 1 From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Wednesday, September 05,20071 :32 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity proj Subject: 1G-12 (PTD 1831320) failed TIFL Attachments: 1G-12 schematic.pdf; 1G-12 90 day TIO plot.gif Tom & Jim, 1(7.. 6[ (1£ {õ7 i <.41 q Kuparuk gas lifted producer 1G-12 (PTD 1831320) failed a TIFL on 09/04/07 and has been added to the SCP report. The TIO immediately prior to SI for the TIFL was 250/880/800. A leaking GL V is suspected. Slickline will trouble shoot the tubing leak and repair if possible. ./ Attached is the schematic and the 90 day TIO plot. Please let me know if you have any questions. «1G-12 schematic.pdf» «1G-12 90 day TIO plot.gif» Brent Rogers Problem Wells Supervisor 659-7224 5CANNED SEP 272007 9/25/2007 . ,.' ~.. ,..-".,~ - . .. í11e:i/IQ/tempfTemporaf)' SSP (8194·8195 003500) PKR (8220-8221 00:6156) Perf (8385-8458) Perf (8537-8589) TUBING 10:2.992) PKR --~ sos Perf (8812-8864) ~ 2 --"- ~ =1 - ~ =--= ~ ð::>::>V lPe: lVell letion: _1:ISI VVI\. Ref Loo Date: TD: ~lF IAí.:iFìLL Last U¡¡date: Las! 'aa: í 8884' ~~ -ªªºº- Size 16.000 10.750 7.000 ,p Tlmil¡¡¡d 100 í 2302 100 ~ill UK Ie (,"~I!\.I"" ~ 6297·6351 8537 . 8589 6410 6446 ! Bottom ! 8691 8RD EUE ! ¡ lom~ C-4,C-3 5" DA r-err uun, 120 de¡:¡ ('.1 ¡NIT 52 (PERF 5" DA t'err í.:iun, 120 dag B :::M~ :~'~M,"~~; V~, v~~- 4 ~~ ND!, ,_ ,.. ~~~~~~~ 2037 903 s C J .188 1: 12 ~~09 i : C J :~~g 1: 19 lit 4923 s .000 I 5312 s JJOO 8158 ~~~~ ~ ==ti=:t=-~=-:~t=--tjíTI~~~t====1 MD TVD ~~~ Man Type I V Mfr V Typev-oo;-GtChTPõrtl TRO:~i.mT~1 8256 6200 Otis SPM ~~~1'O II . ~2 62JiO Otis SPM 1.0. Otis SPM : ! Depth TVD Tvpe 10 ! ~ :~ SBR s flli~ PKR PKR NIPPLE .- ! 6503 6515 :0 6515 10 6523 11 6523 Notes ~ote V\lU on 8/26/94. A VA -- Cameo 'D' ",¡"",,,, "'t" GO Oiis 2.750 2.992 2.992 S f--- dIJIJ""I,,,,io below WELL IA " U IJ"'''''', '''''''''''RKB. ¡UN r=. 1= Scblumbel'gel' (], 08/22/07 NO. 4384 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 2, '7 Z007 (;O!1'\f(ìlss\on Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 f' iI'. ~ \ líj~l D þ..\)\') ä ~rØ't\f:J Field: Kuparuk Well Color CD Log Description Date BL Job# 1 R-27 11850425 FPIT ¡q / -/0;) 08/18/07 1 31-08 11839638 LDL J-7r(", - rJ.h\ 07/28/07 1 2M-19 11813070 INJECTION PROFILE I JTl' ,'1 I -~-:l 07/29/07 1 3G-26 11813071 LDL JC;O¡ -r-;'; ."f:: 07/30/07 1 1R-18 11837482 SBHP/DDL IC? I -' (',15'9- 07/31/07 1 1Y-01 11813072 INJECTION PROFILE U:œ.. - 1~3-OSÖ 07/31/07 1 2C-08 11813073 INJECTION PROFILE' / JTI" J1roz' -r-A.< 08/01/07 1 3H-32 11837483 LDL :J¡y-¡ -~." 08/01/07 1 1Y-10 11837485 INJECTION PROFILE U~ J ~~ - rJ5'"" j 08/03/07 1 3G-08 11813075 PRODUCTION PROFILE' 1&:!;f) - () "S- 08/04/07 1 1A-06 11837486 INJECTION PROFILE iy:r.~ ./"ifl-II (.". 08/04/07 1 2N-337B 11837489 PRODUCTION PROFILE . ~N_ -I(A' 08/06/07 1 2U-08 11813076 LDL WI7t /1«' - 1">9- I 08/06/07 1 1 G·12 11837490 PRODUCTION PROFILE 1f¡3 - ~d. 08/07/07 1 2N-343 11745232 MEM INJECTION PROFILE . UI(' _ ,q"'¡(- rA~ 08/08/07 1 2N-327 11837491 SONIC SCANNER r9ö "'i- --DIn ~ 08/08/07 1 2N-327 11837491 SONIC SCANNER-FMI ......"'..... .r ""- 08/08/07 1 3K-01 11632749 PRODUCTION PROFILE . /1ffD ~ ID( 08/12/07 1 2X-04 11846430 INJECTION PROFILE (J:]:.(' I<$¡3 -1I'k 08/13/07 1 2Z-29 11850419 SBHP SURVEY /1r'lr ~J (:JCJ 08/13/07 1 2X-19 11850420 SBHP SURVEY I ~ Ö - /--:+,<,- 08/13/07 1 1A-20 11850421 SBHPSURVEY I~f)-JL~ 08/14/07 1 1 F-13 11850422 SBHP SURVEY U"If' Js.:3. -li./<.J 08/14/07 1 1H-10 11846432 SBHP SURVEY ¡OJ-:2. -~ 08/14/07 1 1 Q-1 0 11846431 SBHP SURVEY I~¡ J - Jct'$r 08/14/07 1 2U-05 11846433 INJECTION PROFILE l }'3:..(11. Hrf)-n/4j( 08/15/07 1 2D-12 11846434 PRODUCTION PROFILE I fI'-/ - d74 08/16/07 1 2H-06 11846435 LDL Jìir~ -/¿,o, 08/17/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ';)7{ . . Schlumbergep - .,-.C~\NEO R t:. t:. ~f"r ') 0 LûGS 1 'Lv ;..¡ U . 'f\ _ _ f' 0(\1\1\\$5\0.. r 1''''5 'v-" _ . .~ ~. GaS vv\' . \~Cl~ V" . t\P. )..)Ç - . þ..ncnOfð'jv ...!, 'If{\b Vi \\'" b) t. L~ U E-¡;-¡ \ Ai. \ \.~ (.,s \) - I\.~\'t,.i .1Id <J" SCMr'\')~~ -- : Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well Job # Log Description Date 10-02 11166733 INJECTION PROFILE 11/30/05 1 E-07 11154107 PROD PROFILE WIDEFT 01/01/06 1 E-1 05 11141240 INJECTION PROFILE 12/30/05 1 G-12 183-\~~ 11144060 PROD PROFILE WIDEFT 12/28/05 1 L-28 11141239 PROD PROFILE WIDEFT 12/29/05 38-08 11154108 PRODUCTION PROFILE 01/02/06 38-02 11154109 INJECTION PROFILE 01/03/06 NO. 3644 Com pany: Field: BL 1 1 1 1 1 1 1 .-------... S'GNED:é~1J(Jr® ¡ dJ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. DATE: 01/05/06 Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Color ~ CD -' í~ 9D 116 ARCO Alaska, inc.~.~ Post Offic 'x 100360 Anchorag~ ..,~aska 99510-0360 Telephone 907 276 1215 October 7, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL A(~TION ~l"~ --1A-03 Stimulate ~-i3z. -1G-12 Stimulate c/~.o~ ~1 H-01 Perforate -- 2C-09 Stimulate ~cf-:z?.t 3H-14 Stimulate if you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior .Engineer Kuparuk Petroleum Engineering RECEIVED 0CT 1 1 1993 Alaska 0il & Gas Cons. uummisslu' Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6003-C STATE OF 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 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 268' FSL, 818' FWL, Sec. 29, T12N, R10E, UM At top of productive interval 1556' FSL, 1275' FEL, Sec. 32, T12N, R10E, UM At effective depth 1206' FSL, 1034' FEL, Sec. 32, T12N, R10E, UM At total depth 1148' FSL, 995' FEL, Sec. 32r T12N~ R10E, UM 12. Present well condition summary Total Depth: measured 91 1 6 feet true vertical 6835 feet 6. Datum elevation (DF or KB) RKB 99 7. Unit or Property name Kuparuk River Unit 8. Well number 1G-12 feet 9. Permit number/approval number 83-132 10. APl number 50-029-21009 11. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) None Effective depth: measured 9 01 4 feet true vertical 6760 feet Junk (measured) None Casing Length Structural Conductor 100' Surface 2 51 3' Intermediate Production 9 0 6 3' Liner Perforation depth: measured 8385'-8458', true vertical 6296'-6351 ', Size Cemented I 6" 212 SX CS II 10-3/4" 1010 SX AS III 250 SX AS I 7" 975 SX Class G Measured depth 100' 2550' 9096' 8537'-8589', 6413'-6448', 8812'-8864', 6612'-6650', 8830'-8850' 6625'-6640' Tubing (size, grade, and measured depth) 3.5", 9.2#, J-55 @ 8670' Packers and SSSV (type and measured depth) PKR: Otis RRH @ 8220' & Otis WD @ 8663'; SSSV: Camco WRDP ~ 1965' 13. Stimulation or cement squeeze summary Refractured "A" Sand on 9/12/93. Intervals treated (measured) 8812'-8864', 8830'-8850' Treatment description including volumes used and final pressure 14. True vertical depth 100' 2302' 6820' RECEIVED ,q r,T 1 1 199 ~,laska UiI & L~as Cons. C0m~ Anchorage Pumped 33 Mlbs of 16/20 & 43 Mlbs 12/18 ceramic proppant into form.rfp was 6750 psi. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1 t 42 64 1350 165 3 2 9 ~,x 410 122 1050 187 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil X Gas ~ Suspended Service 17. I hereblp.e.~ertify that the foregoing is true and correct to the best of my knowledge. Sicjned~~'v~~,' ~ Title Senior Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE sS~Otl RECEIVE ARCO Alaska, Inc. ~ Subsidiary of Atlantic Richfield Company WELL DAY / OCT 1 1 199~ KUPARUK RIVER UNIT Al,~k,-, Oii &" "' I I [' -----:~"i~'' WELL SERVICE REPORT DF~C~ION OF WORK CONTRACTOR 1 KEY PERSON PBTO m~a~) ~ [ LAS3 TAG (R~a~)a)ATE LOG ENTRY I .~C/cc# ' Anchorage [F~ELD COST'T,. ' "I'AdC~ULA"" ~COST s/~¢~c.~ Is//K~ f SSSV TYPE / STATUS PAGE ~ OF / ~'~ CHECK THIS BLOCK' IF SUMMARY CONTINUED ON BACK J ~/coMPL'E'~ "~ ,IN'CO~, LETE ' Weather I Temp. I Chill Factor i Visibility i Wind Vel. I Signi~i-~. - ~ /// ~ STATE OF ALASKA ALA,.;,,,A OIL AND GAS CONSERVATION COMMI~,..;ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate X Other __ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 $. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 268' FSL, 818' FWL, Sec. 29, T12N, R10E, UM At top of productive interval 1556' FSL, 1275' FEL, Sec. 32, T12N, R10E, UM At effective depth 1206' FSL, 1034' FEL, Sec. 32, T12N, R10E, UM At total depth 1148' FSL, 995' FEL, Sec. 32, T12N~ R10E, UM 12. Present well condition summary Total Depth: measured 9 1 1 6 feet true vertical 6835 feet 6. Datum elevation (DF or KB) RKB 99 7. Unit or Property name Kuparuk River Unit 8. Well number 1G-12 9. Permit number/approval number 83-132 10. APl number 50-029-21009 11, Field/Pool Kuparuk River Oil Pool Plugs (measured) None feet Effective depth: measured 9 01 4 feet true vertical 6760 feet Junk (measured) None Casing Length Size Structural Conductor 105' 1 6" Surface 251 3' 1 0 - 3 / 4" Intermediate Production 9063' 7" Liner Perforation depth: measured 8385'-8458', true vertical 6296'-6351 ', Cemented Measured depth True vertical depth 212 SX CS II 1 05' 1 05' 1010 SX AS III 2550' 2302' 250 SX AS I 975 SX Class G 9096' 6820' 8537'-8589', 6413'-6448', 8812'-8864', 6612'-6650', 8830'-8850' 6625'-6640' Tubing (size, grade, and measured depth) 3.5", 9.2#, J-55 @ 8670' Packers and SSSV (type and measured depth) PKR: Otis RRH @ 8220' & Otis WD @ 8663'; SSSV: Camco WRDP @1965' 13. Stimulation or cement squeeze summary Reperforated "A" Sands on 8/13/93 Intervals treated (measured) .,~ i!i ~';' ~ Reperforated A4 from 8830'-8850'@ 4 spf Treatment description including volumes used and final pressure A~aska 0ii & Gas (J0~is. N/A Annhnr~n,~ 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation I 42 64 1400 220 Subsequent to operation 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations X 1 42 64 1400 165 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~lned "~{~ ,X~,~'~ Title Senior Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of Allantic Richfield Company WELL SERVICE REPORT WELL IG-IZ. (~0NTRACTOR REMARKS IPBDT FIELD-DISTRICT-STATE~'~ L4. IDAY~ OPERATION AT REPORT TIME DATE KUPARUK PETROLEUM ENGINEERING RECEiV[D Alaska Oil & Gas Cons. [--I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemp' 1 Chill Fact°r I Visibility !Wind Vel'Report OF OF miles 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 dupl following wells a icate are subsequent notices on the t the Kuparuk River Field: Well Action Date Performed 1F-1 Fracture 1F-3 Fracture 1F-5 Fracture 1F-9 Perforate 1F-9 Fracture 1F-1 0 Perforate 1F-1 0 Fracture 1F-11 Perforate 1F-1 3 Perforate 1F-1 4 Perforate 1F-1 4 Fracture 1F-15 Perforate 1F-15 Fracture 1F-16 Perforate 1G-7 Choke 1G-1 0 Perforate 1G-1 0 Fracture 1G-12 Perforate 1G-1 2 Fracture 6/10/84 6/11/84 6/12/84 6/16/84 6/19/84 6/14/84 6/18/84 6/19/84 6/19/84 6/22/84 6/23/84 6/17/84 6/21/84 6/19/84 5/4/84 5/29/84 5/30/84 5/29/84 5/31/84 RECEIVED Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany ~--.. STATE OF ALASKA ALASKA . AND GAS CONSERVATION C, 0vllSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, !NC. 3. Address 4. Lo&at~on'~f°We~i' ......... SURFACE LOCATION' T12N, RIOE, UM ANPU~D ~1~' Al ACVA QQ~, I ~1 268' FSL, 818' FWL, SEC. 29 7. Permit No. 83-!32 8. APl Number 50- n'~o_'~ no9 9. U n i t'~ ~' L"e~s~'l~a~e' KUPARUK RIVER UNIT 10. Well Number 1G-12 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 99' (RKB) I ~ ADL 25640, ALK 2571 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER 0IL P00I NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [~ Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe ProPosed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On May 31, 1984, the "A" sands of Kuparuk well 1G-12 were hydraulically fractured and propped to improve production. treatment consisted of 320 BBLS of gelled diesel as pad and carrying fluid and 4600 and 7400 LBS of 20/40 and 16/20 respectively, as proppant. The sand, 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 0 191)4 Alaska Oil & Gas Cons, Commission Anchorage 14. [ hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title OPERATIONS The space below for Commission use 6/26/84 COORDINATOR ~te Conditions of Approval, if any: Approved by COMMISSIONER By Order of 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 99510-0360 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 1F-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 1 F-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-1 2 Perforate 5 / 29 / 84 1G-1 2 Fracture 5/31/84 ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichlieldCompany RECEIVED JUL 0 Alaska Oil & I~as Cons. Commission Anchorage STATE OF ALASKA ..... ALASKA _ AND GAS CONSERVATION C~ MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2' Na~Pe~[°~S KA, INC. 7' Pe~m~'-N~32 3. Adpress 0 BOX 100360 ANCHORAGE ALASKA 99510 8'AP'~]~-er21009 · ' ~ ~ 50-- OTHER [] 4. Lo~tion of Well SURFACE LOCATION' 268' FSL, 818' FNL, TZ2N, R10E, UM SEC. 29 5. Elevation in feet (indicate KB, DF, etc.) 99' (RKB) 6. Lease Designation and Serial No. ADL 25640, ALK 2571 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1G-12 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER 0IL 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). On May 29, 1984, the "A" sands of Kuparuk perforated for production. After testing the well was shot with a wireline conveyed well 1G-12 were the lubricator gun. to 3000 psi, Interval (MD)' 8812' - 8864' (4 SPF) RECEIVED JUL o 19B4 Alaska Oil & Gas Cons. Commission Anchorage Signed Title OPERATIONS COORDINATOR The space below for Commission use Date 6/26/84 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Dace Form 10,,403 'Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Ir" Post Office. cl0x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Hay 14, 1984 Mr. C. V. Chatterton Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Orive Anchorage, AK 99501 Dear Mr. Chatterton. Attached are notices of intention to stimulate Kuparuk wells- 1G-10 1G-12 1G-14 1G-15 1G-16 3C-6 the following v questions please ,~Milde L. Laue rKuparuk Operations Coordi ator MLL/kmc Attachment (In Triplicate) call me at 263-4253. RECEIVED MAY (id & G;~.$ Coils. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompany ,~---, ~-" STATE OF ALASKA .---- -'---- ALASN C.',_AND GAS CONSERVATION. ;, ,IlSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER I~ 7. Permit No. 2. N~(~f~P~ai~SKA, INC. 83 - 1 32 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21009 FSL, 818' FWL, SEC. 29 9'ufftJ°lS)~.~t~an~lVER UNIT 4. bq~¥}il~y~oA~~ LOCAT ION- 268' T12N, R10E, UM 5. Elevation i§ ~e~t (itc~t~IB, DF, etc.) 12. Lease 'gna i d Serial o 2571 10. V¥~j_N~r~ber ~1.~.~)~_~ RIVER FIELD KUPARIJK 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) (Submit in Duplicate) Perforate ,~l 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). ARCO Alaska proposes to hydraul ical l y fracture the "A" sand to improve production. Lines and fracturing equipment will be pressure tested to 5000 psi. Treatment will use gel led diesel to carry 20/40 sand as proppant. Expected treatment volumes' Diesel 18,300 gal Ions Proppant 20/40 sand 21,000 lbs. Expected start date' 5/17/84 Work RECF!VED MAY 1 Alaska 0il & Ecs (;¢:;s. Commission 14. I hereby ce_rti~W that tJ;~e foregojng)~ true and correct to the best of my knowledge. //,~~/~/.4.j~ KUPARUK Signed Tit~e OPERAT!ON$ COOP. D! NATOR The space below for Commission use Date 5/14/84 Conditions of Approval, if any: Approved Copy R~turned By Order of Approved by. - COMMISSIONER the Commission Date Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KUPARUK Ei.IGINEERING q"iTTAL # TRA~. ~-, TO' ~ FROM- D. Fay Allison WELL NAME- see below Transmitted herewith are the following: PLEASE NOTE: BLU~LINE SEPIA, F - FILM, T - TAPE, PC - PtIOTOCOPY PT 'ACKNOWLEDGED: LEASE RETURN RECEIPT TO · ARCO A~ AS.-,A, Al'TH' D. FAY ALLISOI,I - ATO/1115-B ,,~..! P. O. BOX 100360 ' Ah~HO~,A,.~E, AK. 995].0 ARCO Alaska, Inc. Post Office Box ~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 18, 1984 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT- 1G-12 Dear Mr. Chatterton- Enclosed are the the subject well. 263-4944. well completion report and gyroscopic survey for If you have any questions, please call me at Sincerely, Gruber Associate Engineer JG-tw GRU5/L127 Enclosure Alaska 0il & Gas Cons. O, ommi$u[on Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany · , '-- : STATE OFALASKA -~ - ~ ALASKA _.. AND GAS CONSERVATION CE 41SSlON WELL COMPLETION'OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, inc. 83-132 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21009 4. Location of well at surface 9. Unit or Lease Name 268' FSL, 818' FWL, Sec.29, T12N, R10E, UM T~.,~:;.'::~:-;,~ Kuparuk River Unit At Top Producing Interval ,':,'-.,,,_C i 10. Well Number ' 1G-12 1556' FSL, 1275' FEL, Sec.32, T12N, R10E, UM i~,urf.__l~___i At Total Depth ! :5. j~. __~_~.! 11. Field and Pool 1148' FSL, 995' FEL, Sec.32, T12N, R10E, UM --~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 99' RKB ADL 25640 ALK 2571 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 09/19/83 10/02/83 12/26/83 N/A feet MS L 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+ l-VD) 19. DirectionaISurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 9116'MD,6835'TVD 9014'MD,6760'TVD YES IX1 NO []I 1965 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/FDC/CNL/Cal/SP/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 105' 24" 212 sx CS II 10-3/4" 45.5# J-55 Surf 2550' 13-1/2" 1010 sx AS !11 & 250 sx &S I 7" 26.0# J-55 Surf 9096' 8-1/2" 975 sx Class G & 250 sx &S I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD .. interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8589' - 8537' 3-1/2" 8689' 8220' & 8663' 8458' - 8385' w/12 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO I TEST PERIOD I~ Flow Tubing Casing PressUre ,- CALCULATED~1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE Aiaska 0il & ' Form 10-407 GRUS/WCl4 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ',. 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 8384' 6296' Base Upper Sand 8588' 6447' NONE Top Lower Sand 8804' 6606' Base Lower Sand 8958' 6719' 31. LIST OF ATTACHMENTS Drilling Flistory, Completion Summary~ Gyroscopic Survey (2 COPies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge /-7/-/'- '- .... ~" 7'/ / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 1G-12 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 1430 hrs, 09/19/83. Drld 13-1/2" hole to 2575'. Circ & condition hole. Ran 66 jts 10-3/4" 45.5# J-55 HFERW BTC csg w/shoe @ 2550'. Cmtd 10-3/4" csg w/1010 sx AS III & 250 sx AS I. Bumped plug. Tstd csg to 1500#. ND 20" Hydril & diverter. Performed top job w/72 sx AS I. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Witnessed by Ed Sipple, AOGC rep. 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. Cont drlg 8-1/2" hole to 9075'. Ran logs DIL/SFL/FDC/CNL/GR/CAL/SP f/9042' to 2548'. Reamed hole to 9075'. Cont drlg 8-1/2" hole to 9115' TD as of 09/30/83. CBU. RU & ran 212 jts 7" 26# J-55 HFERW BTC csg w/shoe @9096. Cmt 7" csg w/975 sx class G". Bumped plug w/3000 psi floats held ok. Instld 7" pack-off & tstd w/3000 psi - ok. Top off 7" csg w/diesel. ND BOPE. Arctic Pack 7" x 10-3/4" ann. w/250 sx ASI + 94 bbls light wt arctic pack secured well and released rig @0400 hrs on 10/2/83. HILL/DH51 11116183 1G-12 COMPLETION SUMMARY RU Dresser-Atlas. ND master valve & adapter flange. Ran GR/CBL/VDL/CCL f/9002' - 1750' Ran Gyro f/surface - 8950'. NU master valve & adapter flange. RD DresSer-Atlas. Secured well. Accepted rig @ 0500 hrs, 12/23/83. ND tree. NU BOPE & tstd to 3000 psi - ok. Perforated the following intervals w/12 spf, 120° phasing' 8589 8577 8557 8458 8445 8425 - 8577 - 8557 - 8537 - 8445 - 8425 - 8405 8405 - 8385 TIH w/wireline & set pkr @ 8663'. Ran 3-1/2" completion assy w/tail 8689', pkr @ 8220', & SSSV @ 1965'. Tstd packoff to 3000 psi - ok. Set pkr. Installed BPV. ND BOPE. NU tree & tstd to 3000 psi - ok. Pulled "C" lock & bar f/SSSV. Disp well w/crude & diesel. Tstd tbg to 3000 psi - ok. Set BPV. Secured well & released rig @ 0700 hrs, 12/26/83. GRU5/CSIO:tw I ~11 ~ I V~ i ';:5, , L. LII'IFU I H 1% UI~ PHI ~ ~U~;~ 0 ~U~L.U~ J b ~LI~V~ l KUPARUK ~:'~. , OCTOBER 6, 1983 dOB NUNBER ~K-BO-30108 ALA'.SKA :'~ ' '~::, KELLY BUSHING ELEV. = 99.00 FT. z :'.:~::::'~;~:'.':.:~:}:~..t.. x.'<' . ;..' :: ..'...~ .;"..;xxx::'~.:'.x'.'.x:'.=';'~:..'.xxxt:.::~.~: ?':: >'"~'~t?"">'~]~::' '?"."'::'~;~',:::":":~:': '.'.x~ xx'..':=~xx.~x;':;~;..c~'::.:;. ;'":>:' '"'":::"" ':"~8~: ':~"~'':> ~;':.:~.:'.~:{'{~:{:~:;=~;~:~:~%';:~:~<~:~};:~=~'.~=~:)~;=:.:.{.~'. x=:;x~::;:~{;~:;': ..;:. :;>.;r. :.. ':~t¥=}~::~]p.~??~':'.;~:~?::7'~: :=:::&~'~.~=~:~ :?.:::~:. ~" :'::'.:.'.::'.~ .kx..:'.~m".;:~::::'~x~=~:~?.?.}~:':'.~;:~ x'.:~:.~;~=~:~%~::}.:{:~=~;'~:': ....~<.. :.;. ~.~:c:~ '.; .~..:;~?.~;):.=...c... :~':"::t::~:}::~.{':. :~'.~:~:~:~:.: m]".;?:.:.r'.. :~7~''. . : :: .' ~ ~EASLIRED VERTZC~L VERTICAL ~NCL ~N~T[ON DIRECTION SEVERITY RECTaNGULaR OOORD~N~TES VERT ~C~L DEPTH DEPTH DEPTH DEG fl~N DEGREE~ DEG/1OO NORTH/SOUTH E~ST/~EST SECTION : : :: ...: ........ ~..... :..,. ,... ?::~+,,:: :..:~:.':: ~ ~.~..~ ........ ,.~.?::?:~:~¥:?:::::,~::~:::~. ,....~?~ ?: ,.,? ~..:::::'~:?~::.,~'::.....:, .......... . ~ E]:r:',:::.::..%:~'.:.::':::.,~:~..,?::?:%:.:?:::.~:~: ......... ......?: ~::~:.:;::.::::::.?::.~..~:~ .~ :... ~;..:::.... g ? : . .. 300 299,99 200.99 0 21 N 55, 0 E 0.16 1.17 N 1.59 E 0.06 400 399.99 300,99 ,0 a2 N 57,&9 E 0.18 1.61 N 2.2S E 0.13 t 900 896.84 7'37.84 13 35 , S 61.89 E' 4.69 16.80 S 41.57 E 38.'P2 looo e 4.43 s 55, E 3.2e 30.3s s E 20 1500 1442.27 1343.27 32 53 ' S 47.69 E 1.57 167.21 S 230.38 E 273.93 . · 47.80 E 2.09 202.68 S 2~9.43 E 325.96 1 60O 1 527 20 1 428 20 30 48 t 2100 1954,90 1855.90 34 46 S 40.39 E 2.22 386.76 S 450.70 E 582.74 J. 2200 2036, 05 1937.05 36 43 S 39.50 E 2.02 431.54 S 488.20 E 641.12 , .,'" , ' ~ ' ' .~::.,.'.:;::~"' · ". : :-..':" T ' :' :;".'.':";'" :' '": ~"' ' '".' 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TRUE SUB-SEA TOTAL MEASURED VERT I CAL VERT I CAL RECTANGULAR COORB I NATES · MD-TVD VERT I CAL 2000 1871.78 1772.78 344.97 S 414.08 E 128.22 121.65 3000 2~09.43 2510.43 873.79 S 824.20 E 3~0.57 2~2.35 .;¢1;.~;;¥.;:>::¥fi;,.:.;,, :,., :; .., ..... : .... . ,>. :.:::.:i'il:i:i¢,::...LI.,,'. ;...l,.f::..;:;:;.~';.5 ' '?.;. ;,.;;,;; : ':;:::.';%',:I71' '"' :;.,.%'l..:;..ll';%..:.;:?...,:.¥l¥;1;:l~::'~l~(¥:¥:I~1~¥;:::¢:,.1 ' '.iii~i~i:.~i?;;;:~:i~ii;,,i~::';~.~,:,;~ ;.. ~:, ~000' ::,$i~iii:¢;::!'.ii~ii~;~ ~i;~::~:~:iii~;~iii~ii~i~iii¢.;~:~.::i~!~ :',',i~¢:ii~iiii~i~,,~i~iIi~ili!ill!iiiiii~.~'i~,i i~.:i;:.~?:.~i~ii!~iiii iif~i ¢i~.~i'i]:i:'l:~ii ~i.?':~ !ii ii~i:~i~ iii ~i i?i!~::i?.~?~i;i?ii.lli;?;, ii ;.ili!i~i ( ?~ii~ !~.~;~:.~i ~:~;i!iiiii~iiii~'?. ii;i !!i;~:ii?:i'~?i~i!;!!?, :? ;(:~:;/.?:;;: :. ;f:.; :/': .: 800C) 6007.87 5~C)8.87 37~0.31 ~ 3032.19 E 1 ~2.13 281 . 15 9000 ~74~. 74 &.650.74 4334. ~4 S 3423.02 E 2250.2~ 258.12 :::::':~:*::::~;:::;:~ :~'?~"::~ ....... ....................... ?.:,:~ii:~ :::~? ............. i~M~ii~:?.~.::~...~:'~:'~ ...... ~ ........ ~ ................................... ~ ~ ~ ~:~:* ..................................................................... ..~'.~? .::~:::~;~,.~...' ........................... 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'::P '.? .'(:2: ':'::?'?PL":":::~ ================================== :!::~: ::~: ::::::::::::::::::::::::: :'.:~':~,?:!:~:~:~:?~ ::~::$ ::;]::' ':':': ": :' ? ::::", !'':'~' P:: :: '~' ': :::':::P: · ' ':':::::' ": v,.. ?. -.:, ,.: .... 0 0 0 i.i?x iii ii~ i! !!i i ?,.i ?:i :x :i: ~iii ':i ik:i..'.i 7..'.i'.i~i',iii'.'.~iii~i~i~i'.~ii!il: i: ~',ii "..i~ ~'.!~ ~ ........... ';::x:: :!: ~: :i :x ~::ii:<.i¢i'.?,~i~?.i:i.:'.ii i:i'.ii~:i ii:.!';i ?.? !;~.: ii:.:iii' ........ I<LIPARUK OCTOBER ALASKA "',:;,:',',:: ':'::'; ,',. ' x: :,';i:.:',' :':: ::. . :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: TRUE SUB-SEA TOTAL ~B~TE ........................................................................................................... : ,,,.l. i,, .i.i...,., i. i ,..i i .... ..i 1983 JOB NUMBER AK-BO-30108 KELLY BUSHING ELEV. = 99.00 FT. 3137 24',99. O0 2600. O0 958. 3296 2799, O0 2700. O0 1059.19 S .~ ",.~, ": ::L:'::ii:![i?h."' ........ 885.24 E 438.78 53.68 955;. 82 E 497.07 58.29 , , · '.': · ,:.,; .: .¢.:~:~ ::::::::::::::::::::::::: ~,,,,~ ' :,:: i 4094 3299. O0 3200. O0 1571 . 51 S 1308.01' E 795.52 49.29 4243 3399.00 3300. O0 1661 . i .............. '- -. .... _~.'!_ ':.i.i . · . '. · ? · ~' .:' ': : · ' : i 'r .: ' ======================= :,:~.::' ' ' . . :.::~.: ' '-'::: . :.:.:..:::~::: :>i:' :::::::::.' ,' ' ,i.'~, ;::: :' :;::';:;. ': ': , :% :' .:..x .' ', '-,.~., '::: :.:. ' .::: :... ' : ::::::::::::::::::::::::::: ? :. 4..'..3.......4. a :::::k:: ....... -' 4,~.~ .' ......... ~&~o~'-'?:'..:~': ~0.~,.0....~'~'~ ...................... ~.9.~=i,~:..S..,.:'?:.~.?':::.::~a::..7. :..E.: ' ::"'¥ ....... ~o'.':-'~? ':': :'- ........ ~6-::':':'.2z-' ....... ::'.':: ' · .:~> '?' ... ::. :r'.?.' .~'. 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' .... -'"' ...... ? 2 .... ~_ ...... MEA~C;LIRED VERTICAL VERTICAL RECTANGULAR COORDINATES ' MD-TVD VERTICAL , , , ,~ a..:.~.: ,.:..,~.~'_a_~:,, ~ ........................... :.:..: ...... :' 2279 2099. O0 2000. O0 468.90 S 518.99 E 180.43 25.57 2409 21~. O0 2100.00. 533.17 S 571.68 E 210.47 30.04 '"':'.;: ?.~::'~: ":~' '7:' ~.:?:: ;. ' ~ ': "j:~ :':~?~'~',:~' ""'~ "'"':~::::?':~' "~!'"'~ ~ ~H~:H:H;~:~'"' ........ "~'+'h,?;?' '"x:':h~::::~:~ :~?x::,;:h' :~'.;!H:::'::'::'.~" :~ ,, '. ,',x:m,'.' . ,,...x ~:;':' u~:~.~%z.::i:~:i.i?.c:.: ~. i. ::~.~ ~:~?i¥~i:iv::~::~i:..::~:::i::~k~-~-~c:~i:~i:?z~:-~:~i~i.:.~.~:~:i~:i:?i~i~:::i-~:~:i~<:~:?~i:i~..~:`:i:~?~:~:::~iic.:i:~i~:::~i.~:::i:i.::i:i.ie.?i:~:~:i-~:i:~:~:~ ::::::::::::::::::::::::::::::::::::: ~. :~ .: ~s~ ::: :..:~::~ ~ ~ :::: i ~:::: ~ ~ ~: ~::: ~: ~: : :: ~ .~..: :. :~ ;~: ~ .,.. ,;,?,, :, 0 0 KLIPARLIK OCTOBER 6, 1983 JOB NUMBER AK-BO-~01oc, ALASKA KELLY BUSHING ELEV. = ~9.00 FT. ~T~ flfl:::6~D~ ~61.~?H~ D~ ~M l~Fi ~D~ .F~ ~1..1~ =~ ~C~u;'.~[~'.~ ;~:~ ::::~::,~;::]k :.: t:::::L':; :C/:.~;?~?,~:::~::[::{::~:.:::~:::,::~?.'v": '~'~' '.'""~":'<'??'::':"[""';':::.::?:'"":?':<'~7'~; .... '",::~! ...... : :'::::?' ~;' :~ :';'~ "~:' ":':': >: :::. 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' '" ........... :"::?~:':::'::¥ ....... "?~ ...... :':" :'?:''': ...... ' ...... ..... : ................ ~869 519?. O0 5100. O0 3190.03 S 251 ? · 08 E 1670.33 47.02 7014 5297. O0 5200. O0 326'2.49 S 2587.75 E 1715.35 45.02 : · ": : :: ::: .:. '. ::'.L: ================================================ :: ::::::::':: :::: :::. :::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::.,.:::.::: :: ::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::.. 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' .......... ~ . ~: ~] . : .... ;~ ; ~ -~ : ................................. . ...................... ~: ........ ~;,~..~ ........................ ~ ............... ~ ...... ~,.~,~...~ ....~.,~.~,.~ ..,~ ~.,.~~.~.~.~,.~.~..~,.~>~:..~ .~.~,~ ...................... ~..~ ........ .~.~.-.~ ................ .. ~ ~ ::, ::..~+ ...... : :,.: .:~::.:: ...::.:..::.;.. :.:,: :.: ]~ ~: :::::::::::::::::::::::::::::: :.::. :,::~ ¥.~: ::.:. ?.:. : .:: ::;: .:::.:..:~::;:.:~:~?::~:~.'~::~':-~x:..~:::~x::::::::~.::::~:~::~:~:~:::.:.'~:::~:~::~::':::::~:~?:~.-~¥.:.::.~::~:::~::':~:~.~:;~;'.~:.;~..~:~:.:~::.:'.:.~+:.` · :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :':':::.:~? :':::' :' ' ~:~:' ~':" ': ~ '. ' ':" ': "::. ::'::::.':":: :':' :'. ':,::, ' :::::::::::::::::::::::::::::::: :~':':'::' ':"~::?'"' "~]~?~' Y;:'~S~ ~',:~:~HH~?~'~: '~:~ ,~ ~?~ ::~:::~::~:~::~;~:~::~:::?~:H..:~:~:~:~::::~?~]~::~:~:~:?~:~:::~:~::~:H?:X:is;~:~:~:~:::~.~:~.~:~:~:~::~:~:~:~i~y~:?:~:?~;~?.~.%`.~.:~.?:~:~ ':.::.,?.~.~,:L.::::.::;.:::::.::.:', '.':.~.: '.':':.~: :--=~ ':" ~ II I i iiii ~ , ~ .... ' '::::% '"' "": '" ' : '' ~':' '"' ' : · .,.%.,;:: . .,,::.,: : :. : :.?..:',:.. :;'.'::::::?:?: 4::?.;::: ;~;[ · ' ,;:. ':. ".. .'," · "' ::' ..; ,.. . .. ..: . ' 0 · DERIVED USING DIL DEPTHS AND SPERRY ~UN SURVEY rlATA , ?.i..~../i.i.i.::~.~:~..~.:.:.~.~:.i.~.!.~!~.i.~.~:..~i.!.!::./i~.~i.~.~.~.~.::.~.?:.:.:,?.,,'''''~?''~''.'!ii'.,,%???''':: ~ ""~':"":~',~i':iiii~.,,%h',,i,"'i~,h,'"'::':~,:i,.,.'~:" ?~2~ i'ii i~: ::.?.,,;::'i'.'/~i ~:.:~ "' '~.~ ':' ....... ~,., .................................... .~,..:~,......... ................................. .~..::~ ................ :::::::::::::::::::::::::::::::::::::.::.~:...:..:..:: .................. :,:,:.:..~ .................... ~C~:::~.::::..~,~:....?~~~.~ TOP UPPER SAND 8384 62~. 82 · 196.82 3991 . ~7S 3187.02E ' .... '"' .~' .'"' "::':?::':::~?.:?, :(~F ':: ', '..:': ~', :':~:~:~:~:L[ ~:~::'::,:; ,.: . ' .... :.,., :,'.': ', ..... ~,. h~': , J::,~:'.:h'~J'[':::::h,:::h:'~.):~: ~., ,: ~: ,,' ~: · ~,~ '~ ~ TOTAL DEPTH EIRILLE~ ' 911~ ~83~. 02 ~736.02 4399. E, OS 34~7.33E '.: ::...': .:::h : .::::: :. '::' ::::~ ~. :.h':~ ":~:E::~:~'~E~:E~:~E:~:::E,: :~:E~:~:?i:~::::~ ::::::::::::::::::::::::::"::~::::~., ::.::::::: :::~: f:~::::::~ ~:::~h, :p :.:~:::::~::::::~:::::~'~: h:::: ,h:h:,:h:~:::[E~E::h I .... ':... ::, ':. ':' : '.,::. '. .... ......... ============================ ....... ~::~:~::,:~:~ :~'::::~ ............ ',.'::.::::::~:::~.:~::~:~.~J~":~t~:~::~."~::: =~:::~::~:":~:~" ~.::~':,,:~:~. ~:::~,~:~:~::~E~. ~:~' ~ ........ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ............. ~'.~=:.~ ........ ' ............ :~::::~ ........... '.~: :, ~ ' ...... ' · ARCO ~, INC. Our Boss Gyroscopic Survey Job No. kK-BO-30108 Well: ~.1 G-12 (SEC 29 T12N R10E) Kuparuk Field North Slope, Alaska Survey Date: October 5, 1983 Operator: Samec Scale: 1" = 1000' O C -! 0~30. O0 TRUE NORTH Surface Location 268 FSL 818 FWL oo' oo b. o0 --1000.00_ ~3000. OO ~'~ _ _ _ -4000. O0 --5000.00 HOPiIZONTRL PF~QJECTION 1 ARCO ALASKA, INC. Our Boss Gyroscopic Survey Job No. AK-BO-30108 Well: ~.1 G-12 (SEC 29 T12N R10E) Kuparuk Field North Slope, Alaska Survey Date: October 5, 1983 Operator: Sam~c Scale: 1" = 1500' O, OO 1500.00 3000.00 4500.00 8000.00 5601.68' @ S 38° 14' E C 7500.00 ,sbo. oo 30~0. oo 45~0. oo 6~bo. oo VERTICRL PROJECTION Suggested 'form to be inserted in each "Active" well folder to d~eck for timely ccmpliance with our regulations. ' 'Operator, Wel'~ and Materials to be received by: /--~',"~' ~,~"~-' ~/7"' Reports Date / Required Date Received Remarks __ ,, ,,, ~ , _ Completion Report Yes -- '. ,~ ~to~ ~s I-- / ~- ~'9' d-ii ~-:- : · . , , _~, . . Core ~scrip~on ~ g~ Registered ~ey Plat ~- ~, , . I'nclina~on S~ey .~~ , . ~+//. ....... ~~' Drill St~ Test Re~s .~... ~' ?.~, , ms R=, Yes ~ , ARCO Alaska, Inc./- Post Office bux J00360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 17, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1G-12 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, i~ Gruber Associate Engineer GRU5/L120:tw Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~.~ - STATE OF ALASKA ALASKA AND GAS CONSERVATION Ci IlSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ERX OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-132 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21009 4. Location Of Well Surface: 268' FSL, 818' FWL, 5ec.29, T12N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 99' RKB 6. Lease Designation and Serial No. ADL 25640 ALK 2571 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 16-12 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. ND master valve & adapter flange. Ran GR/CBL/VDL/CCL f/9002' - 1750'. Ran Gyro f/surface - 8950'. NU master valve & adapter flange. Secured well. Accepted rig ~ 0500 hfs, 12/23/83. intervals w/12 spf, 120° phasing: ND tree. NU BOPE & tstd to 3000 psi - ok. 8589' - 8577' 8577' - 8557' 8557' - 8537' 8458' - 8445' 8445' - 8425' 8425' - 8405' 8405' - 8385' Perforated the following TIH w/wireline & set pkr ~ 8663'. Ran 3-1/2" completion assy w/tail ~ 8689', pkr @ 8220', & SSSV @ 19~5'. Tstd packoff to 3000 psi - ok. Set pkr. Installed BPV. ND BOPE. NU tree & tstd to 3000 psi - ok. Pulled "C" lock & bar f/SSSV. Disp well w/crude & diesel. Tstd tbg to 3000 psi - ok. Set BPV. Secured well & released rig @ 0700 hrs, 12/26/83.,~,., i~ .i, ~ !i ;,' i~ i... ,6 14. I hereby ~that the forego;~_~r~:~d,,correct to the best of my///~J~--_~,~ J.~ knowledge. Signed Title Area Dri 11 ing Engineer The space b~ow ~r ~'oj~m issio n use Conditio~ of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10403 Rev. 7-1-80 GRUS/SN60 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box o00 Anchorage, Alaska 99510 Telephone 907 277 5637 January 5, 1984 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Commission Dear Mr. Chatterton' Attached are sundry notices for wells' 1G-9 1G-9 IG-10 1G-11 -1G-12 1G-13 1G-14 1G-15 1G-16 fracture 3erforate 3erforate ~erforate )erforate )erforate )erforate )erforate )erforate action on the following If you have any questions, please Charles K. House ~' ~Kuparuk Operations Coordinator CKH/kmc Attachment (In Triplicate) call me at 263-4527. ARC© AIc, s~,~_ ir~c. i~ a subsidiary of AtlantJcRichficidCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~/~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [~ ~'-~' 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-132 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21009 4. Location of Well SURFACE LOCATION' 268' FSL, 818' FWL, SEC. 29 T12N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 99 ' (RKB) 12. I 6 . Lease Designation and Serial No. ' ADL 25640, ALK 2571 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1G-12 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOr 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). ARCO Alaska, Inc. proposes to perforate the following depths in the Kuparuk "A" sand: 8833 - 8860'. All perforating will be conducted with 4 SPF through-tubing guns. A 3000 psi lubricator will be used on all wireline work. Lubricator will be pressure tested prior to doing the work. All circulated and flowed fluids will be diverted to tankage on location. Expected start date' t2 19-85 14. I hereby certify ,~hat the foregoing is,true and correct to the best of my knowledge. The space b~low or Commission use OPERAT I ON$ COORDINATOR Conditions of Approval, if any: ORI(~I~[ SI6~[D BY LOH~IE C. SMITH Approved by COMMISSIONER Approved Coi.*.'f Returned By Order of the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 Rev. 7-1-80 ; KUPARUK E'NGIHEERING TRANSHITTAL # ~ ~/ 1~. ~/. 2'$ /Transmltted herewith are the following- FROM: D. Fay Allison WELL NAME- PLEASE NOTE'(~)-BLUEL]'NE:~- SEPIA, F- FILM, T- TAPE, PC-PHOTOCOPY RECEIPT AC .,NOI,',LED~r_.D PLEASE RETURN RECEIPT TO' u/ti r_.: .... ARCO ALASKA, INC. ATTN: D. FAY ALLISON - ATO/1115-P, P. O. BOX 100360 ANCHORAGE, AK. 99510 K'UPA,~JJI< FJ',G ! NEERI KG TO: DATE: F-R~v1: D.W. Bose/Shelby J. FMtthc~s ' Transmitted herewith are the ,~ol Iowin9- PLEASE NEr'FE: BL - BLUELINE, S - SEPIA, F - FlU, A, T - TAPE, PC - PROTOODPY' ~ (.L:./,¢._5.:7 ~/// lb-15 lb-l/ .RJECE I ~ ACKND.'¢ Ff~FD: /LFJ~E P~N IECfl PT TO: AD~ ALASKA, II',C. '- ~ "'"~"'~"~'-'~~--~~ ATTN- DIE~Y J. P. O. ~X 100360 ~~E, ~(. 99510 ARCO ~,laska, Inc.~ Post Office b,.,x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 18, 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 Monthly State Reports for the following wells: 1F-13 1G-12 1F-14 1G-13 1F-15 1G-14 1F-16 1G-15 1G-16 Thank you. Sincerely, JBK/SH1: ih ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany -, ' "' ~--- STATE OF ALASKA ._---. ~ ~. ALASKA (~- ,ND GAS CONSERVATION CO :SSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-132 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21009 9. Unit or Lease Name 268' FSL, 818' FWL, Sec. 29, T12N, R10E, UM Kuparuk River Unit 4. Location of Well at surface 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation,and Serial No. PAD 63' 99' RKB ADL 25640 ALK 2571 , 10. Well No, lC-12 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of October ,1983 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1430 hrs, 09/19/83. Drld 13-1/2" hole to 2575'. Ran, cmtd, & tstd 10-3/4" csg. Performed top job. Cont drlg 8-1/2" hole to 9075'. Ran logs. Cont drlg 8-1/2" hole to 9115' TD. Ran, cmtd, tstd 7" csg. Arctic Pack 7" x 10-3/4" Top off 7" csg w/diesel. Secured well & released rig @ 0400 hrs. on 10/2/83. SEE DRILLING HISTORY ann 13. Casing or liner run and quantities of cement, results of pressur9 tests 10-3/4" 45.5# J-55 HFERW BTC csg w/shoe @ 2550'. Cmtd w/lO10 sx AS III & 250 sx AS I. 7" 26# J-55 HFERW BTC csg w/shoe @9096. Cmtd w/975 sx class "G" cmt. 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFT,/EDC/CNL/CA~/S?/GR f/9042' to 2548' I 6. DST data, perforating data, shows of 1-12S, miscellaneous data . . , . 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. "; 'Z :/, NOTE--Rep~rt o~/this ~/r,~ is requ.red for each calendar month, regardless of the status of operations, and must be file~,n (~uplicate with the Alaska Oil and Gas Conservatid~ Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate 1G-12 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well ~ 1430 hrs, 09/19/83. Drld 13-1/2" hole to 2575'. Circ & condition hole. Ran 66 jts 10-3/4" 45.5# J-55 HFERW BTC csg w/shoe @ 2550'. Cmtd 10-3/4" csg w/1010 sx AS II I & 250 sx AS I. Bumped plug. Tstd csg to 1500#. ND 20" Hydril & diverter. Performed top job w/72 sx AS I. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Witnessed by Ed Sipple, AOGC rep. 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. Cont drlg 8-1/2" hole to 9075'. Ran logs DIL/SFL/FDC/CNL/GR/CAL/SP f/9042' to 2548'. Reamed hole to 9075'. Cont drlg 8-1/2" hole to 9115' TD as of 09/30/83. CBU. RU & ran 212 jts 7" 26# J-55 HFERW BTC csg w/shoe ~9096. Cmt 7" csg w/975 sx class G". Bumped plug w/3000 psi fl oats held ok. Instld 7" pack-off & tstd w/3000 psi - ok. Top off 7" csg w/diesel. ND BOPE. Arctic Pack 7" x 1'0-3/4" ann. w/250 sx ASI + 94 bbls light wt arctic pack secured well and released rig @0400 hrs on 10/2/83. HILL/DH51 11/16/83 ARCO Alaska, Inc' Post Office t~ox 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 Monthly State Reports for the following wells' 1G-10 1F-10 1G-11 1F-11 1G-12 1F-12 1F-9 1F-13 Thank you. Sincerely, in 'A~~t ~~c~ t Drilling Engineer jBK/SHIO-sm Enclosures Al,.'.'.s~. Oil &. ,Sas cons. Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA' AND GAS CONSERVATION C( i~ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIO 1. Drilling well)~ Workover operation [] I 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 4. Location of Well 268' at surface 99510 FSL, 818' FWL, Sec. 29, T12N, RIOE, UM 6. Lease Designation and Serial No. ADL 25640 ALK 2571 5. Elevation in feet (indicate KB, DF, etc.) PAD 63' 99' RKB 7 Permit No. ~3-132 8. APd ~_mJ~r0 0 9 50-- 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1G-12 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool September 83 For the Month of. ,19 ,12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1430 hfs, 09/19/83. Drld 13-1/2" hole to 2575'. Ran, cmtd, & tstd 10-3/4" csg. Performed top job. Cont drlg 8-1/2" hole to 9075'. Ran logs. Cont drlg 8-1/2" hole to t~115' TD. Preparing to run 7" csg as of 09/30/83. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 10-3/4" 45.5# J-55 HRERW BTC csg w/shoe ~ 2550'. Cmtd w/1010 sx AS II I & 250 sx AS I. 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/FDC/CNL/CAL/SP/GR f/9042' to 2548' 16. 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. NOTE--Re s is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas'Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate 1G-12 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well Ia 1430 hrs, 09/19/83. Drld 13-1/2" hole to 2575'. Circ & condition hole. Ran 66 jts 10-3/4" 45.5# J-55 HFERW BTC csg w/shoe @ 2550'. Cmtd 10-3/4" csg w/1010 sx AS III & 250 sx AS I. Bumped plug. Tstd csg to 1500#. ND 20" Hydril & diverter. Performed top job w/72 sx AS I. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Witnessed by Ed Sipple, AOGC rep. 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. Cont drlg 8-1/2" hole to 9075'. Ran logs DIL/SFL/FDC/CNL/GR/CAL/SP f/9042' to 2548'. Reamed hole to 9075'. Cont drlg 8-1/2" hole to 0115' TD as of 09/30/83. CBU. Preparing to run 7" csg as of 09/30/83. HILL/DH48 10/17/83 M EMORAN DUM State of Alaska ALASKA OIL .A~D -GAS CO~$ERVATIO~;-'- COM~-~ISSIO~ TO: - . on DATE: Septe~ber 23, 1983 ~ ~ ,~;~ FILE NO: 108A:DI T~RU: ~nnie C. Smith ~ Commissioner ~ TSkEPHONE NO: FROM: Edgar W. Sipple, Jr / SUSJECT: ~trole~ Ins~ctor Witness BOPL Test on ARCO's 5uparuk 1G-12, Sec. 29, TllN,~105,U.H., Pert. it ~-~o. 83-132 Do~on ~ig ~.7o. 9. Wednesday, September 21., 1983: I traveled this date from Parker ~1 '('subject'-of another repo'~t) to ARCO's Kuparuk 1G-12, to witness a BOPE test on Doyon ~7o. 9. The drilling contractor was in tb.e process of nippling up. · The BOPE test commenced at '7:50 pm and was concluded at 10:10 p],~. There were no failures. In sumr'.~z~~, I witnessed the BOPE test on A~CO's ~uparuk 1G-12, Do~'on Rig ~-]o. 9. Attach~-~ent ' 02-00IA(Rev. 10/79) O&G fl 4 4/80 STATE OF AI,ASKA ALASKA OIL & GAS CONSERVATION COHMISSION B.O.P.E. Inspection Report Inspector Operator . ~~ .. Well ;G-~7_, . Location:. Sec D~ Drilling Contractor Date Well /--~ - / Permit # . . ~3--/~ ~- ~,~ ~ Casing S~t ~ ~f~.O ~t. . . Representativ~ ~0 ~ ~,dt%l ~ ~ ~ Location, General Well Sign General Housekeeping Reserve pit 'Rig o~ ACCU}4ULATOR S'YSTEM Full Charge Pressure ~. 7~ pressure After Closure / 7~70 BOPE Stack A_.~.nular wr_jN en~ Pipe Rams _ Blind R.~S cn~ Line Valves . K~i~ B~n~ Valves ' Valve Test Pres sure ~Oo,~ ps.ig psig 200 psig Above Precharge Attained: 0 min 3~ sec 3 min (~;Ssec Full, Charg_e Pres~ure ~taine_.d: Cqntrols: Master d~ ~ Remote ~ ~% Blinds switch cover '/~ .._ Kelly and Floo_r S_~afety Valves - Upper Kelly ~ -Test Pressure Lower Kelly.. ~ Test Pressure Ball Type-*" ~ Test Pressure Inside BOP &~l( Test Pressure Choke Manifold ~'~ ~;~Test Pressure No. 'Valves /3 No. 'flanges ~ 9-- -' Adjustable Chokes. I ~ 0~ ilydrauically operated choke i ~, Test Results: Failures ----- c) ~ Repair or Replacement of failed equipment to be made within Inspector/Commission office notified. . Test Time ~hr-s.. 2~) xa',~. , 7.'zo Dis tribution orig' - AO&GCC cc - Operator cc - Supervisor. ARCO Alaska, In~ Post Office =ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 26, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1G-12 Dear Mr. Enclosed complete Si nce 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 3, 1983, your Si ncerely, a~~~g Engineer JBK/GRU4L37:tw Enclosures If you have any ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA -- ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. .., ARCO Alaska, Inc. 83-132 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21009 4. Location of Well Surface: 268' FSL, 818' FWL, 5ec.29, T12N, RIOE, UN 5. Elevationinfeet(indicate KB, DF, etc.) 99' RKB 6. Lease Designation and Serial No. ADL 25640 ALK 2571 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1G-12 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. (Submit in Triplicate) Perforate ~( Alter Casing [] Perforations Stim u late [] Abandon [] Stim u lat ion Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other I~X 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 Abandonmentsee20 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 3, 1983 Subsequent Work Reported · ,,~.~ ......... 14. I hereby cert~y that the foregoing i~ true and correct to the best of my knowledge. The space ~W f~r ~mission use Condition~f Appr~lDf any: ORIG NAL SIGNEll Approved Returnee' BY LOH,IE C. SMITll B¥Orderof .~- (~-(~ 3 Approved by. COMMISSIONER the Commission Date Form 10403 Rev. 7-1-80 GRU4/SN18 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Au~ast 25, 1983 Mr. Jeffrey B. Kewin Senior Dri!ling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Re: ~nparuk River Unit IG-12 AR6~ Alaska, inc. Permit No. 83-!32 Sur. Loc. 268'FSL, 818'FI~, Sec. 29, T12N, R10E, ~. Btmhole LOc. 4590'F~L, 4680'FW~, Sec. 32, T12t~, Dear ~r. Kewin: Enclomed i~ the approved application for permit to drill the above referenced well. if coring i~ conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a nmd log are. not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log infor~ation shall be submitted on all logm for copying except experimental tog~, velocity surveys and dipmeter surveys. ~any rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to co~encing operations you ~ay be contacted by the Habitat Coordinator's Office, Department of glsh an~ Game. Pollution of any waters of the State is prohibited by AS 46, C~ap~er 3 Article 7 and tb~ regulations uro~nulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to co--ricing operations you may be contacted by a representative of the Department of Ln-~_ron~enta! Conservation. To aid u~ in scheduling field work, please notify this office 24 hours prior to co~ncing installation of the blowout Mr. Jeffrey B. Kewin Kuparuk River Unit -2- August 25, 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. W~ere a dlverter 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. C. V. -Chatterton Chairman of sv ORDH~ OF Ti~H CO~;~d~CS~ON Alaska Oil and Gas Conservation Comission be~6:H/A Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office ~-_x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 22, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1G-12 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 1G-12, along with a $100 application fee. A diagram showing the proposed horizontal and vertical projections of the wellbore. o A proximity plat. A diagram and description of the surface hole diverter system. o A diagram and description of the BOP equipment. Since we estimate spudding this well on September 9, 1983, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, A,~~ En~~ln~er dBK/d~4L24 :tw ^ttachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany · "% STATE OF ALASKA ALASKA (J,L AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE 0~( MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 268' FSL~ 818' FWL, Sec,29~ T12N, RIOE, UN At top of proposed producing interval , 3829' FNL, 2440' FWL, Sec. 32, T12N, ~'"¢~0// At total depth 4590' FNL, 4680' FWL, Sec. 32, T12N, RIOE, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 99', PAD 63' 12. Bond information (see 20 AAC 25.025) Statewi de Type Surety and/or number Federai insurance Company #8088-26-27 9. Unit or lease name Kuparuk River Unit 10. Well number 1G-12 11. Field and pool Kuparuk River Field _ Kuparuk River 0il Pool Amount $500,000 13. Distance and direction from nearest town 30 mi, ~ of Deadhorse miles 14. Distance to nearest property or lease line 600' @ TD feet 16. Proposeddepth(MD&TVD) 17. Numberofacresinlease 9799' MD, 7230' TVD feet 2459± 15. Distance to nearest drilling or completed 1G-11well 60' @ surface feet 18. Approximate spud date 09/09/83 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2663 psig@ 8_i0°F Surface KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 46 oI (see 20 AAC 25.035 (c) (2) 3109 psig@.6674 ft, TD (TVD) 21 Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT SIZE Hole 3-1/2" 8-1/2" 7" 22. Describe proposed Casing 16" 10-3/4" Weight 65# 45.5# 26# CASING AND LINER Grade Coupling H-40 Weld J-55 BTC HF-ERW J-55 BTC HF-ERW Length MD TOP TVD 80' 36' I 36' 2471' 35' I 35' I 'l MD BOTTOM TVD 116'l 116' 2506' I12200' I (include stage data) ± 250 cf 950 sx Arctic Set IV & 250 sx Arctic Set I 9766' 33' I 33' 9799'17230' 535 sx Class G extended I I 460 sx Class G neat program: Est. TOC= 2506' ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 9799' MD (7230' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2663 psig. Pressure calculations are based on current reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. The cement will be brought 500' above the top of the shallowest hydrocarbon zone or to the 10-3/4" shoe. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Completion operations with the workover rig will be covered under a separate sundry notice. 1G-12 will be 60' away from 1G-11 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x ~0=3/4" annulus of this well. The 7" x 10-3/4" annulus will be left with a non-freezing fluid during any interruptions/~//z~,~_//.in the disposal p~o~ess. SIGNED //.~'~ //~.~ TITLE Area Drilling Engineer DATE The space bel~f~c~¢sion"~usef-/~ - / / CONDITIONS OF APPROVAL Samplesl~YES required I! Mud log required I Directional Survey required APl number ~JO I ~JYES ~NO I ~YES E~NO 50- O'~,~-- ~'/Oc' ) Permit number , -~ I Approval date ~%'" L~ j)~//8~ SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY--// ~//,.,~~~,COMMISSIONER DATE _A_u~,~t 25, 1983 ~' '/. ~....-~'/~{/"~/~/'~~ by order of the Commission Form 10-401 GRU4/PD7 / / Submit in triplicate n__. PHASE II AS BUILT WELLS 9 thru 16 29 PHASE ! EXISTING WELLS I thru 8 DRILL SITE I G CONDUCTOR · /~BUILT LOCATIONS WELL 9 Y: 5,981,093.18~. Lat. 70°21'33.3989'' ×: 540,558,976 Long.,149040'I4.036'' 444' FSL 780 FWL WELL I0 Y = 5,981,034.771 Lat. 70°21'32.8237'' X 54.Q,577_.I8 6 Long. 149°40' 13.660~' 386' FSL 793' FWL WELL II 5~980,9'76.130 ?40,585.500 FSL Lat. 70°21'52.2462-'' Long. 149°40'13.279 II I 8O6 FWL WELL 12 WELL 13 WELL 14 y =r 5,980,917. 6';'6 -X = 540,598.709 268' FSL Y = 5,980,838.4'80 X= 540,247. I 191 FSL Lat. 70°21 '31.6706" L0ng.,149°40' 12_.902" 818' FWL Lat. 70°21'30.9103'' Long. 149044)'23.183'' 466' FWL Lat. 70°21'31.4858" Y = 5,~80,896.919 X= 540,234,22-4 Long. 149 °4-0'23.563'' 250' FSL 454'FWL WELL 15 WELL 16 Y: 5,980,955. X: 540,22Q.882_ 30 9' FS L Y: 5,981,014.002 Lat. TO°21 '32.0642" Long. 149 40 2.3.9;44 441' FWL Lat. 70°21'32.6388" X: 540,20%93.2 Long. 149°4-0'24.313'' 367' FSL 428' FWL .'51 I 32_ NOTE:BASIS OF ELEV. I$ TBM 1--6 souTH PER LHD 6~ ASSOc. NOTE: BASIS OF LOCATION IS MONUMENT' IG MIDDLE AND IG SOUTH AS SET BY L.H.D. 15 ASSOC. LOCATED IN PROTRACTED SECTION 2_9, TOWN 12 N., RANGE IOE., UMIAT MERIDIAN. This Surve' 31 33 34 DS iA T. I2N ;R IOE. ~ ~,,MIAT MER. I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, AND THAT THJS PLAT REPRESENTS A SURVEY' MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF: ARCO Alaska, Inc. Kuparuk Project DRILL SITE I-G CONDUCTOR AS BUILT LOCATIONS drawn by' E.H. dwg. no.'9.05.107.11d 2. --l--4--1"----"---- ' ' ' ~~ ..... I ! I i ' ~ ~ ; I ' ' ~ I ! i ~ ' ,--~--'.~--I__ ~,. : : ; ~~~~~~.F"'. t "! ! : ! ! i ! i i i ,: ~ I I I : ~ ' ' ' ' ~ : ' '" ": ' : i ~ ; ' ~ : '--r-- ~ ~ ~ ~ ~ ~ ~ :" ! i ! i , I~ : '. ~ ~ I i I i i :: ~ '! ~ ' , ,, , , ~ . ,, · ,, , .,, ,,.. ::, ..,,:~" ~~ ::':,:, ~ : !~! .".:~ ~-';'~'i · : , ~ , ~ ' , ! I , , I ~ I I ' ,,, , ', ..... -, , i ~]', ~, , i,,.,,~ ~,.',, .,,.b-~ !.,,,,,,,, ..,,,. :.-. ,, I, t i II -- : ~ ~ , : ' iii; : i .... '. t · . , : , , i : ?II--'i--T--11 i [ [ ~ ___L-- ~__]--L--' ~ .... I , i II I , ~ ~ . ,: . ::"~ , .,.. ~, t . . ~ !III, !Iii ii'._; ~ : i i ! ~ ! O i : ~ , ~"l,ll~G'~: /":,'~ : : ~ ~ : : .... ~ : , : , : ,, i : I i ! I ! -i :, i I ! ii [ i } ! ,,,,:, -- , ,',w ' , ' , ' : ' : ! i i 1 ~OOi !_ i ; ~, , : ~ '~ ii, ; ! : : , .... ....... ,~ ~iil , : ! ': ! : : i : : ' '~ ' ' i "I i J i i ' ~ ' I i : : i I I ~ ~ ~ : :-i ~i:: ' i ' ,:,, : i I II ,ili .,~.., -- ii~ , , : , ~ : ~ ' ..... ~ ~ ' ' ~ ' [. i~ ,' ~ ; , :-~l i I ~ i ', I ! i ! I I ! ~ ''Ir I :. i : i ~ i i I , i i : ! ; : ~ ~ : ' : ~ ~ ' ' ' ~ ! ! ~ ! ', ~~~~ ~ , · I i i i --,--;~ ! i ~ ! ~ .... I 'J ~l I .... ~ . ' : : : ~ ~ .... ' ; ' ' : ~~ i ~ I ~ ' _. ~ , . , : , - ~~ . ~ , , , , : : ; ~ : , ~ : , , . ~ ~ . , . ~ ~ , ....... ~ ' ........ ' ; ' I ' . , , I ] I I , , ...... ~ ' ' I ' ' ' _ ~~ ~ , , ,:,,. ~ ..... ' ' .....'''' '' ' ''J ! J ~, ~ ~ t J , i .:. , , . - ' x ~ : : ~ ~ ; , ~~ j ~ ! ~ ~ ~ j ~ i I ! ! ~ I ! I ! I L L ~~~~ ~ '- : ' : · ~ N I ~ ~ :, · ' ', , i , ; ~~~ ' ' : . ~~~~ i l I. I I t t'J i! : , , , , ! ' ' ~ : ; ' : ~ ' - - ' - I ' , ' i ~ ! ~ ~ i , : . r ; :; ; i : '. :: , ~ : :j I , ~ .~ , ; , w ' ' ' ' ~~~~ ~~' · ' ' ' ' ' i i i. ·~' : : [~ : ~ ; ~ ~ : - ~ ~ ; :, '. . ~ , ; ~ : ' i ~ . '- ' ' ~ ' ~ ~ ' ' i ~ [ t ~ · ~ J ; : '.: '. ; . ~ ~ f i (' . ~ : : ~ : i '. ~ ! i i i ~ 'Iii ': . , · ' ! , ~ ' : ~ I ' I ~ ' ~ : ; ~ : ~ :~_ ~ i~ ~ : i ~ ~ ' ~ ~ ~ T :--~v i i j ~ , J - : : ~ ~ : ' : ' ' · ~ ,~; ~ ¢/' ~ ':.~ ,; ~ ' . : ' : , ; - -~ ; i : , , · Q. . Surface Diverter Ssstem -~ 1. 16" Bradenhead. 2. 16" ×-20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/10" lines to reserve pit. Valves to open automati-~x cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell ~nipple. 16" Conductor Maintenance & Opera.tion ~- . 1. Upon initial installation close annular i preventer and verify that bal 1 valves I - have opened properly. I 2. Close annular preventer and blow air ~_ . through diverter lines every 12 hours. 3; Close annul ar preventer in the event that gas or fluid flow to surface is 'detected. If necessary, manually over= ride and close ball valve to upwind diverter line. Do not. shut in well under an~, circumstances. J ~,~NUL.~, PREVENTOR 1 BLIND 8 ) ) . P i PE ) C' P~MS 13-5/8" 5000 PSt :RSRRA BOP sTACK I. 16" Bradenhead 2. 16" 2000 PSI x i0" ~:'-~'~ ?SI c-_sine, head 3. 10" 3000 ?SZ tubing he~_d · ~ II ~ lO 3000 PSi x 13-5/3= 5500 -'S adapter spool -:'. 5. 13-5/8" 5000 PSI pipe 6. 13-5/8" 5000 PSI drilling spogl w/choke and kill lines . 13-5/8" 5000 PSI pipe_ rares~ ... 13-5/8" 5000 PSL blind r~,,ns -- -. 13-5/8" 5000 PSI anr-~lar e ACCL~-IULATO~ C.L~A£ITT TF_ST C) - .() ] t_ J- p i p£ R~,qS ) -'s ( 1. ~-IECK ~.','D FILL ACCLC-'-..n..A.-[OR ?__S£R~I~- l'O P,~P~---~ l.i-YE[ WITR HYD?AUL!C FLUID. 2. ASSURE l?JT A~-i~T~ P~E ~I~ 1'500 PSI 3. ~S~YE TIHE Th~ C~E ~ C~iTS S~T~- ~_~LT ~IO REC02~ ~ T~ ~ P~~ ~I~ ' ~ OFF. 4. ~9~ 0N I~DC R~T. ~ A~E~A~ L~ LDJIT IS 45 SE~;;~ ~I~ TLqE ~A~ 1~ PSI ~ N I;~ P P~SU2~. 13-5/$' .-COP STA~-< TEST I. FILL BOP STAC~ '~{O ,~,%XLmDLD l~ITH ,L-~'~i: DI~EL. ~E~ TPAT ~ HO~ ~ S~ J~ ~Y ~.A~D. PP~D~E~-~I/~ DEPT~ T~T ~ ~'I~ S~T A:8 S~T IX ~U~3. P~ I~ LO~ ~N SC~JS IN 3. ~E ~'C'IU~2. PR~;~R ~D C~-O~ ~ ~P~S Y;LY~ ON l-~q I FOLD. ~T ALL C~q~;E;~S TO ~ ~Z ~'O ~g F~A 'C ) F ' - ' . m~. 4" ~ - - --- 8. ~.~:v~v~oi~r~~'~or~. ' D ~ - ~o ~oPsz. ~ . 9. ~1 TOP S~ OF PiP= ~ - ' - S~ ~ PIPE ~;L~J. J , . lO. IN~,~E PP, ESSU?~ T0 3~ ~ ~.,D ~ ~3P. 10 '~ . HIICJT~. B~ED TO Z~ 2SI_ D ~~ -' .' ~ ,q;g TEST TO ~ - _ ..... ~ ..~_._ B~ED T0 ZERO PSI. ' ' / : .-. ~ - _ ..- v[~. - .. _ - ' (1) Fee <2) Loc · thru 8) 4. 5. 6. 7. 8. (3) Admin .~_~' ~-~-~ 9., ~ thru '11) 10, 11, (4) Casg ~/~,~ ~'-~-~'~ (12 th~u ~0) (21 thru 24) (6) Add:~, ~~. ~-~-~ 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. (:.'.'Company · ' ' YES .,,", :-',: j,,.:, '::.' . . ,','~"~ . ,.',.~. ,~ ..:,[', . . ., ·. Is the. permit fee a tached · . Is well to be located in a defined pool.. ........................... · Is well located proper distance from property line ................. ' Is well located proper distance from-other wells .................... · Is sufficient undedicated acreage available in this pool ........... · Is well to be deviated and is well bore plat included ................ ly ' Is operator the on affected party ..... ; ........................... Can permit be approved before ten-day wait .......................... Does operator.have.a bond in force ' ... ' ...... Is a conservation order needed ... Is administ'rative approval needed ~'''''''1.'~'"''''''''''11~''1'"11 , . . Is conductor string provided .................. .. ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover 'all 'known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.'. .Is this well .to be kicked off from an existing welibore ............. Is 'old wellbore abandonment procedure included on 10-403.. ....... ,... Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... ,'~ Are necessary diagrams'of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to.~OOo psig .. //~, Does the choke manifold comply w/API RP-5.3 (Feb.78)'. ................. Additional requirement ' Additional Remarks: Geology: Engil~e~er lng: _ii ff ni -- WVA~ JKT~HJH -- 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. VERIF'IC~'rIr~N U~IT TYPE C&TE SIZE CODE nO0 oOo 015 065 OOO 000 005 065 000 000 007 065 OOO 000 004 065 OhO 000 004 065 000 000 002 065 000 nO0 00~ 065 0o0 O00 006 065 fi00 OOO 00] 065 V P 010. ~q 02.. v ~: ~ I F ! C a T I r)~'~I L, I ,q T l N C P.~I G E: 2 ALA. S[<.~ CO~PUTTNG CENTER **~**.****~**.*.*********************************************************************** 2.750 a 62.0 DF ?,450 a 62,0 OF 1.24~ S 145'0 DF 1/p Oto,HO~ ~EPlFICt~T[©N I3ISTING PA~E 3 1 4 1. IT API APl Ami l'r T o 0 0 f'} H ~ ~u '7 fl O U t4 u ~,,~ 7 0 0 ~ V 7 1 0 C~P]' 7 31, 32 ~H 42 6B 2 C/C3 G/C3 CPS 42 34 CPS 42 3~ 93 !~,~ a~ 28 3 42 42 42 (} o G~,PI .t2 31 32 PEPP CO[)F 73 65 66 FILE 0 0 0 0 o 0 0 0 0 0 0 0 0 0 0 ~C N T R Y fi 0 . ,1. I!u 0 PROCESS L g' V E [,, 0 0 0 0 0 0 0 0 0 0 0 0 0 SAMPLE 1 ,1., 1 1 .1, I, REPR C 0 P Fi 68 68 68 68 68 6~ 68 ) E P T ;P ~ H.O'F! IR A T )EPT ;P '~EP'T ~ ~T 9 0 ( ) f ] . O0 0 {l) -22. ~43'1 (;p 3, q ? 3 H P :'<, P, .~ ~9o0. r~oo0 $vY,iI -25.6250 GR 2 4336 H CrJl': 2:7520 PNR~. 8800.0000 -23.593N 2, ti 1. 76 w C NI'., 2.0703 2 J.. 09,38 667.5(., 00 2.2695 3.1543 92.0625 1528.0000 4.4609 8,1016 77.0000 2128.0000 3.05~6 4.7656 92,8!25 2262,0000 3.127o I [., iq F'C h, l., II, M 2 294 21 2 4,6 342 92 .1035 !LO .8730 DRHO ,O00O CaLl .0938 .7344 ILD .2500 CALl .0625 6,1445 II.,l) 29,4434 DRHO 695,5000 C~I,I 77,0000 4,2344 ILD 30,0293 t)RHO 723.0O00 CAY,I 92,P!25 2,8437 1.2H32 8.5000 2.6094 0.0220 13,6406 5,6953 0.1475 9.0781 4.~172 0,0542 9,4922 VP 010.HO2 VF~,~[PIC~,~I!3~,~ I.,ISTI~.G PAGE ~ P -2&. F~281 P - 27,4. 375 H [l ~:~ 2, ,1 ] g 9 EPT flSO<). O00O P -29, ~ 7.19 , ,418 {"l P - 16, ~ 2 ~t 1 HOP 2,4414 EFT ~200 o()(lO P N f1 B 2,3594 ,P -21 ,fi469 p ~ T 3.714 ~t ~.~ 3,5723 .... ,, . . %, H O P 2..a 4. 3 ,I ~P~T 3.4.355 )~Pff 7700.0000 _ . 7 ,R 1.64 7 g, 31 '2. 5 24 3 9.00 O 0 3,1 1.~ 2656 2,~770 4.7383 '79. g 375 2614,. 0(~00 2.~9~5 2n, 375o '2466, l! (') D 0 2,1133 ~ 751.0000 3.5781 1.52.375n ~ 7 44,0000 2.6699 ]2q,7500 17~5.~000 . . ].~734 !34,1.~5o ~,8223 3,q375 1_ () 5, '750 (1 !886.0[)~0 7,132a 29,9316 772. 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