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184-199
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, August 4, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1Q-11 KUPARUK RIV UNIT 1Q-11 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/04/2025 1Q-11 50-029-21216-00-00 184-199-0 W SPT 5687 1841990 1500 2400 2400 2400 2400 40 50 50 50 4YRTST P Guy Cook 7/2/2025 Test completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1Q-11 Inspection Date: Tubing OA Packer Depth 340 1800 1725 1720IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250701125541 BBL Pumped:1.1 BBL Returned:1.1 Monday, August 4, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, December 9, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1Q-11 KUPARUK RIV UNIT 1Q-11 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/09/2022 1Q-11 50-029-21216-00-00 184-199-0 W SPT 5687 1841990 1500 1830 1830 1830 1830 25 100 100 100 INITAL P Austin McLeod 10/10/2022 MITIA. RWO. Initial. Sundry 322-413. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1Q-11 Inspection Date: Tubing OA Packer Depth 610 2625 2525 2500IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM221010184146 BBL Pumped:1.4 BBL Returned:1.3 Friday, December 9, 2022 Page 1 of 1 By Anne Prysunka at 9:41 am, Oct 25, 2022 5HJJ-DPHV% 2*& )URP 0RUDOHV7RQ\ 7RQ\0RUDOHV#QDERUVFRP! 6HQW 6DWXUGD\6HSWHPEHU 30 7R 5HJJ-DPHV% 2*& %URRNV3KRHEH/ 2*& '2$$2*&&3UXGKRH%D\ &F +HQVRQ-DPHV 16.5:2&0 &R]E\.HOO\ 6XEMHFW 1DERUV(6 %23(7HVW.584 $WWDFKPHQWV 1DERUV(6 [OV[ dŽŶLJDŽƌĂůĞƐ ϳ ^ZŝŐDĂŶĂŐĞƌ EKZ^>^<Z/>>/E'/E͘ KĨĨŝĐĞϵϬϳϲϳϬͲϲϭϯϮDŽďŝůϴϬϱϳϵϳͲϲϳϮϬ ƚŽŶLJ͘ŵŽƌĂůĞƐΛŶĂďŽƌƐ͘ĐŽŵ ΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎ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ll BOPE reports are due to the agency within 5 days of testing* SSu bm it t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:7ES DATE: 9/16/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #1841990 Sundry #322-413 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:2445 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8" T90 P Pit Level Indicators PP #1 Rams 1 3 1/2" x 5 1/2"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 2 7/8' x 5"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result HCR Valves 2 3 1/8" Gate P System Pressure (psi)3025 P Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1650 P Check Valve 0NA200 psi Attained (sec)21 P BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)116 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 5@1975 P No. Valves 16 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 28 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:6.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 9/15/22 8:54 Waived By Test Start Date/Time:9/16/2022 11:30 (date) (time)Witness Test Finish Date/Time:9/16/2022 17:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Nabors Test with 3 1/2" jnt. Annular tested to 3500 psi Tony Morales /Jim Marmon ConocoPhillips Lenward Toussant/Kevin Barr KRU 1Q-11 Test Pressure (psi): tony.morales@nabors,com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022) 2022-0916_BOP_Nabors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y Samantha Carlisle at 9:03 am, Jul 14, 2022 Ronald Phillips Digitally signed by Ronald Phillips Date: 2022.07.13 14:57:01 -08'00' '65 6)' %23 WHVW WR SVLJ $QQXODU SUHYHQWHU WHVW WR SVLJ 97/ ; ; ; GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.07.21 14:19:07 -08'00' 5%'06 -6% !! "#$ %&%# ' &!(& &!(& )&! "!#$*&% " !! " +#!%,%- *#"# %# ".- $&/# &!(& 0#&$ !! "#$1 "- 2! #" $+#!"/ "##$ 30$ "/&"4+#! " . - 2! &!(&3".-#$#5 !5 %!&" 22 .&% "' $"4$ 22$ *&% 6 $( *#$73"8#.% $9 :;0<=>? +#96&!4$ #4 "=>5 &5 $! &!&2$ 4.#$ "% %-#2&$(!&"4!;-#6#6&!. "*#$%#4'$ & 2$ 4.#$% &2&$(@ @&"4@ @!&"46&%#$ "8#.% $ "=;-#6#6&!6 $(#4 *#$5 0 "> " % $#2&.#%-#%5 "/&"4!%&.(&2&.(#$ 3' -&*#&" A#!% "! $$#A $#&" '$%-#$ "' $ &% "2#&!#. "%&.% #&% ;-#2$ 2 !#46 $( *#$!. 2#' $96 ".4#2 "/%-##"% $# B C. 2#% "% ".4#&%-$##2&.(#$! &"4 "!%& "/&"#6 B C. 2#% " Ronald Phillips Digitally signed by Ronald Phillips Date: 2022.07.13 15:01:50 -08'00' ! "# $ % &&' ( ) * !( '!++(,-./(( 012 & ( 1 03 4 &!'1 ) 5 6 #1$$55770.& ( $#85770.9:& ( 6485770.9:& ( ! $ 1 ) / :&(;$ 1 ) <# 2 "! / :: = <# 2 #$ .- 34=1:>;, 5-5#7 3) :;;, ? % ? 3@6 " > :(, & ? % ? @A= " :;>(, ' " :+>>, " 1$BC? >07 D 8$5# E@$) !? ))$5 ? ( C@- ) # E@ 76- ) ? ) !C. !CB60 '(!'(( '( !'(( & 6-!1B % 6=.7 ' ? ) :+>>,1./ 6" " 2 :$A! ? ? % 6" @A= " ) :;>(,A >$A! ? ? ? ) > :(,A +$A! 6" @6 " ? A ;$A )6" @6 " ? A (1B 6A5 ? )F5, ) 1BG " !4=1 ! ! ? ? " ? 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Name Development ❑ Exploratory ❑ 184-199 3.Address: PO Box 100360,Anchorage Alaska 99510 Stratigraphic ❑ Service ❑✓ 6.API Number: 50-029-21216-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25641 KRU 1Q-11 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7740 feet Plugs measured N/A feet true vertical 6295 feet Junk measured N/A feet Effective Depth measured 7404 feet Packer measured 6876 feet true vertical 6076 feet true vertical 5706 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 65' 16" 101' 101' Surface 3635' 9-5/8" 3670' 3499' . Intermediate Production 7686' 7" 7720' 6282' Liner Perforation depth Measured depth 7120'-7528' feet ���EO :AN 2 �i tR SC, True Vertical depth 5880'-6158' feet Tubing(size,grade,measured and true vertical depth) 3.5" J-55 7293'(MD) 6001' (TVD) Packers and SSSV(type,measured and true vertical depth) Packer Baker Premier pkr 6876'(MD) 5706'(TVD) SSSV none Nipple 506'(MD) 506'(TVD) 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A 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: N/A N/A N/A N/A N/A Subsequent to operation: N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ El WAG Q GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-502 Authorized Name: Kelly Lyons Contact Name: Kelly Lyons/Jan Byrne Authorized Title: Well Integrity Supervisor Contact Email: n1617@cop.com / Authorized Signature: Date: 12/22/17 Contact Phone: 659-7224 Vr` 117-/i ' Form 10-404 Revised 4/2017 ,yr 712/jQ °'� ^ �L /�'�(! ������t'� �.�' �"�� ^� 2017 Submit Original Only • • ConocoPhillips Alaska RECEIVED EIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 DEC 2 7 2017 AOGCC December 22, 2017 Commissioner Hollis French Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner French, Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. KRU well 1Q-11 (PTD 184-199) for two 30' retrievable tubing patches used to repair a known leak above the production packer. Work was performed under Sundry #317-502. Please call Jan Byrne or myself at 659-7224 if you have any questions. Sincerely, Kelly Lyons Well Integrity Supervisor Attachments • • Date Event Summary 06/11/17 (AC EVAL) TORQUE T LDS TO 450 FT/LBS (COMPLETE), T POT (PASS), T PPPOT (PASS), IC POT (PASS), IC PPPOT (PASS), MITIA(FAILED), IA LLR 7.8 GALLONS/MIN @ 1500 PSI. Initial T/I/0 si500/450/270 Stung into T PO TP with 420 psi. Would not bleed to 0 psi. (Fluid) Torqued T LDS to 450 ft/lbs Bled T PO TP to 0 psi through PO tool to 0 psi, verified by cracking slotted bleeder with 0 psi. Internal checks appear to be removed. 15 min= 0+ (Pass) Pressured T PO up to 5000 psi 15 min= 4810 psi (-190) 30 min=4700 psi (-110) Re-pressured up to 5000 psi 15 min=4950 psi (-50) 30 min=4950 psi (0) (Pass) Remained stung in during remainder of testing, remained at 0 psi. Stung into IC PO TP with 0+ psi. (Fluid) (Pass) Pressured IC PO to 3000 psi 15 min= 2920 psi (-80) 30 min= 2900 psi (-20) (Pass) Bled IC PO TP to 0 psi through PO tool to 0 psi, verified by cracking slotted bleeder with 0 psi. Internal checks appear to be removed. Remained stung in during remainder of testing, remained at 0 psi. IA stabilized with 3.6 BBLS pumped and wouldn't pressure past 1500 psi during attempted MITIA. (Fail) IA LLR Initial T/I/O= 575/1500/270 2 min= 590/1500/270 15 Gallons pumped 4 min= 595/1540/270 13 Gallons pumped 6 min= 595/1550/270 23 Gallons pumped 8 min= 600/1550/270 16 Gallons pumped 10 min= 600/1550/270 11 Gallons pumped IA LLR= 7.8 Gallons/min S/I pump, IA depressurized without bleeding. 8 min= 560/500/270 Final T/I/0= si500/445/270 08/06/17 TAGGED FILL @ 7404' RKB (EST 124' OF FILL); MEASURED BHP @ 7390' RKB; SET 2.81" CA-2 PLUG ©6898' RKB. ATTEMPT TO MITT & IA TRACKS. CMIT TO 2500 PSI (PASS). JOB COMPLETE &TURN OVER TO DHD. BEGIN CMIT TO 2500 PSI, PRE=1350/1325/250 INITIAL=2525/2525/260 15 MIN=2500/2500/260 30 MIN=2500/2500/260 ***PASS*** 08/18/17 PERFORM LDL FROM 6898' RKB TO SURFACE & IDENTIFY TBG LEAK @ 100' RKB. MAKE DYNAMIC PASSES & STATION STOPS © 155' & 57' RKB. JOB COMPLETE. 08/24/17 24 ARM CALIPER LOG LOG REPEAT PASS UP FROM 6894' -6740' RKB, LOG MAIN PASS UP FROM 6890' - SURFACE • • 11/13/17 SET LOWER 2.72" PIIP PACKER MID ELEMENT @ 286' RKB. CMIT 2500 ( PASS ) SET UPPER 2.72" PIIP PATCH ASSEMBLY MID ELEMENT @ 256' RKB. CMIT 2500 PSI ( PASS SET LOWER 2.72" PIIP PACKER MID ELEMENT @ 123' RKB. IN PROGRESS. 1st CMIT: INITIAL T/I/O = 600/560/260 LRS PUMP 1.7 BBLS START= 2500/2500/260 15 MINS = 2425/2450/260 30 MINS = 2400/2445/260 2nd CMIT: INITIAL T/I/O = 625/600/260 LRS PUMP 1.7 BBLS DSL TO PT TBG/IA . START = 2500/2500/260 15 MINS = 2450/2490/260 30 MINS = 2450/2460/260 45 = 2440/2450/260 60 = 2425/2450/260 RE TEST START = 2600/2625/260 15 MINS = 2575/2600/260 30 MINS = 2575/2600/260 11/14/17 SET TEST TOOL IN LOWER PACKER @ 123' RKB; CMIT 2500 PSI ( PASS ) SET UPPER 2.72" PIIP PACKER, SPACER PIPE &ANCHOR ASSEMBLY @ 93' RKB. MIT IA TO 2500 (PASS), PULLED TEST TOOL. COMPLETE. T/I/O = 650/625/260 LRS PT TBG/IA TO 2600 PSI W/ 1.7 BBLS. START= 2600/2615/260/0 15 MINS = 2560/2590/260 30 MINS = 2550/2585/260 PASS. MIT IA AGAIN. PRE T/I/O= 700/210/250 START= 1725/2525/250 15 MIN= 1725/2475/250 30 MIN= 1725/2475/250 12/05/17 (SW) STATE WITNESSED (GUY COOK) MITIA PASSED TO 2000 PSI. Initial T/I/O = 1150/650/320 IA FL @ SF. Pressured IA to 2000 psi with 1.1 bbls diesel. T/I/O = 1150/2000/320. 15 min T/I/O = 1150/1890/320 (-110 psi). 30 min T/I/O = 1150/1875/320 (-15 psi). Bled IA to 650 psi in 5 minutes 1 bbl back. Continue to bleed IA to 475 psi in 2 minutes. Final T/I/O = 1150/475/320. Executive Two retrievable TTS tubing patches were set in KRU injector 1Q-11. The lower 30' patch was Summary set from 286' to 256' to patch across an area of high metal loss as per caliper survey data. The upper 30' patch was set from 123' to 93' to patch across an identified leak at 100'. Integrity was confirmed with a passing witnessed MITIA after the well was brought online and stabilized. KUP INJ . 1Q-11 ConocoPhillips . Well Attributes Max Angle&MD TD Alaska Inc Wel lboreAPI/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act 98,0(ftKB) cororm+vni, 500292121600 KUPARUK RIVER UNIT INJ 49.68 7,600.00 7,720.0 ••• Comment 1125(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 10-11.1121/2017334:22 PM SSSV:NIPPLE Last WO: 8/28/2013 43.31 1/5/1985 Verbal schemers(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date - -- HANGER;32.0 y-- -- Last Tag:RKB 7,404.0 8/6/2017 Rev Reason:GLV C/O,SET PATCHES pproven 11/21/2017 I•W!a Casing Strings Casing DescriptionpOD OD(in) .ID 10(in) Top(ftKB) Set Depth(ftKB; Set Dept pth(TVD)...th .Wt/Len(I...Grade Top Thread SURFACEUon 9 5/8 8.921 Top B) (8KB) 3,498.7 36.00 Grad40 WELDED a ,Casing Description OD(in) ID(in) `Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 36.0 101.0 10 .0 62.50 �' J-55 BTC L11.1111.111.1211011111116111111111.1.1 L. 'Grade Top Thread PRODUCTION 7 6.276 33.9 7,719.6 6,282.1 26.00 J-55 BTC __ Tubing Strings sh_,,.ti7 nAn^Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING WO 3 1/2 2.992 32.0 6,862.6 5,697.4 9.30 L-80 EUE-Brd Mod TUBING LEAK;100.0 - CONDUCTOR;36.0-101.0,4 . Completion Details UPPER PATCH;93.0 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com _ (in) LOWER PATCH;123.0 32.0 32.0 0.07 HANGER MC EVOY GEN IV TUBING HANGER 2.950 505.5 505.5 0.77 NIPPLE CAMCO'DS'NIPPLE 2.875"Profile ' 2.875 UPPER PATCH;256.0 7 6,849.9 5,688.6 45.73 LOCATOR BAKER LOCATOR 2.980 LOWER PATCH;286.0 6,850.0 5,688.6 45.72 SEAL ASSY 1 BAKER PBR SEAL ASSY 2.980 Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(IbHI) Grade Top Connection STACKED PACKER 5.03 4.000 6,853.0 6,917.0 5,735.6 NIPPLE;5056 Completion Details L . Nominal ID Top(ftKB) Top(ND)(ftKB)_Top Incl 7) Item Des Corn (in) 6,853.0 5,690.8 45.71 PBR BAKER 80-40 PBR 4.000 6,875.5 5,706.5 45.58 PACKER BAKER PREMIER PACKER 2.870 SURFACE;35.7-3,670.2-4 4 6,898.2 5,722.3 45.46 NIPPLE CAMCO DS'NIPPLE 2.812 I�- 6,909.6 5,730.4 45.37 OVERSHOT BAKER POORBOY OVERSHOT w/6'Swallow 3.625 GAS LIFT;8392.7 Tubing DescriptionI String Ma...I ID(In) I Top(ftKB) -Set Depth(ft..f Set Depth(TVD)(...I Wt(1b/ft) I Grade I Top Connection TUBING original 41/2 2.992 6,916.0 7,294.0 6,001 5 9.30 J-55 FL4S Completion Details Nominal to Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Cam (In) LOCATOR;6,849.9 6,940.4 5,752.0 45.11 PBR BAKER PBR ' 3.000 6,953.8 5,761.5 45.00 PACKER BAKER FHL PACKER 3.000 SEAL ASSY;6,850.0 PBR;6,853.0 7,106.2 5,870.1 44.38 BLAST RINGS CARBIDE BLAST RINGS(5) 2.992 7,272.5 5,986.7 46.45 LOCATOR BAKER LOCATOR SUB 3.000 PACKER;6,875.5 - 7,273.4 5,987.3 46.46 PACKER BAKER FB-1 PACKER 4.000 7,276.7 5,989.6 46.50 SBE BAKER SEAL BORE EXTENSION 3.000 NIPPLE;6,8982 7,287.7 5,997.2 46.62 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,293.2 6,000.9 46.68 SOS BAKER SHEAR OUT SUB 2.992 OVERSHOT;6,909.6 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) 7) Des Com Run Date ID(In) 93.0 93.0 0.21 UPPER UPPER 2.72"PIIP PACKER(SN:CPP35141)25.50' 111/14/2017 1.620 PBR;6,940.4 - PATCH x 2 1/16"SPACER PIPE&ANCHOR LATCH PACKER;6,953.7 ASEMBLY(SN:CPAL35072) OAL=32'MIN ID= 1.62" PATCH;6,985.0 100.0 100.0 0.23 TUBING TUBING LEAK 8/18/2017 0.000 SLEEVE-C;6,992.5 1 LEAK INJECTION;6,992.6 SI.. 123.0 123.0 0.30 LOWER LOWER 2.72"PIIP PACKER(SN:CPP35144/4.01 '11/13/2017 1.620 I� PATCH OAL/1.62"ID) 256.0 256.0 0.55 UPPER UPPER 2.72"PIIP PACKER(SN:CPP35073) '11/13/2017 1.625 PATCH;7,057.0 PATCH 25.49'x 2 11/16 SPACER PIPE&ANCHOR LATCH INJECTION;7,065.4 I tm ASSEMBLY(SN:CPAL35073) 286.0 286.0 0.56 LOWER LOWER 2.72"PIIP PACKER(SN:CPP35143/4.01 11/13/2017 1.625 ! PATCH OAL/1.625'ID) s. y 6,985.0 5,783.6 44.74 PATCH Alpha 21.68'Tubing Patch;w/AVA Ported Nipple @ 2/7/1993 1.875 6989';Setover GLM#12(6985') IPERF;7,120.0-7,212.0T- 6,992.5 5,789.0 44.68 SLEEVE-C AVA TPC SLEEVE 1.875 X 1.387 '12/7/2005 1.375 - _ 7,057.0 5,834.9' 44.44 PATCH Alpha 21.68'Tubing Patch;Set over GLM#13 2/7/1993 1.937 (7058') IPERF;7,224.0-7,232.0 7,287.7 5,997.2 46.62 REDUCER AVA NIPPLE REDUCER 1/25/1993 1.812 7,410.01 6,080.01 48.07 1 FISH 'Missing Valve Parts:Downhole 17/17/1991 I 0.000 INJECTION;7,253.3 J Perforations&Slots Shot LOCATOR;7,272.5 Dens PACKER;7,273.4 _' Top(ND) Btm(TVD) (shots/f - SBE;7,276.7 - Top(ftKB) Btm(ftKB) (RKB) (ftKB) Zone Date t) Type Com 7,120.0 7,212.0 5,879.9 5,944.8 C-4,C-3,C-2, 2/2/1985 12.0 IPERF 5"DA Csg Gun;120 C-1,10-11 deg.phasing REDUCER;7,287.7 7,224.0 7,232.0 5,953.1 5,958.7 UNIT B,10- 2/2/1985 12.0 IPERF 5"DA Csg Gun;120 NIPPLE;7,287.71 .CE' 11 deg.phasing 1 7,366.0 7,450.0 6,050.5 6,106.6 A-4,A-3,10- 2/2/1985 4.0 IPERF 4"DA JJ Csg Gun;120 SOS;7,2932 -a 11 deg.phasing - - 7,510.0 7,528.0 6,146.1 6,157.9 A-2,1Q-11 2/2/1985 4.0 IPERF 4"DA JJ Csg Gun;120 deg.phasing IPERF;7,366.0-7,450.0 Mandrel Inserts FISH;7,410.0 1 Sl rift on Top(ND) Valve Latch Port Size TRO Run - N Top(RKB) (ftKB) _ Make Model 001101 Sery Type - Type (in) (pull Run Date Corn -1 6,792.7 5,648.7 Camco 'MMG 11/2 GAS LIFT DMY RK 0.000 0.0 11/12/2017 ' IPERF;7,510.0-7,528.0 2 6,992.6 5,789.0 MERLA TMPD 11/2 INJPATC 0.000 0.0 12/6/2005 - H 3 7,065.4 5,840.9 MERLA TMPD 1 1/2 INJ PATC 0.000 0.0 2/1/1985 H PRODUCTION;33.9-7,719.6 ° KUP INJ 1Q-11 Conocolhillips Alaska,Inc. Co pups --- 10-11,11/21/2017 3:3425 PM Vertical schematic(actual) HANGER;32.0 •D-1jyrfe °4'a"d7 Mandrel Inserts ! se ati Top(TVD) Valve Latch Port Size TRO Run '- - N Top(RKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn „„,,, „,,,1111.0.11111111.111.=11110 JL.,4 7,253.3 5,973.5 MERLA TMPD 11/2 INJ DMY BK-2 0.000 0.0 2/1/1985 Notes:General&Safety End Date Annotation 10/7/2010 NOTE:View Schematic w/Alaska Schematic9.0 TUBING LEAK;100.0-, I 5/10/2013 NOTE:Waivered Well T x IA Communication"Water Injection Only** CONDUCTOR;38.0-101.0-j I ♦ -- UPPER PATCH;93.0 , 8/18/2017 NOTE:TBG LEAK 100'RKB LOWER PATCH;123.0 UPPER PATCH;256.0 LOWER PATCH;286.0 NIPPLE;505.5 —1174 • • SURFACE;35.7-3,670.2— GAS LIFT;6,792.7 LOCATOR;8,849.9 SEAL ASSY;6,850.0 PER;6,853.0 PACKER;6,875.5 NIPPLE;6,898.2 OVERSHOT;6,909.8 PER;6,940A PACKER;6,953.7 -`Ir -- PATCH;6,985.0 - SLEEVE-C;8,992.5 INJECTION;6,992.6 Ilii PATCH;7,057.01 E INJECTION;7,065.4 I I� (PERF;7,120.0-7,212.0!PERE; ,120.0-7,212.0 IPERF;7,224.0-7,232,U INJECTION;7,253.3 LOCATOR;7,272.5 PACKER;7,273.4 -SEE;7,276.7 I* REDUCER;7,287.71 I NIPPLE;7,287.7 1, IIII SOS;7,2932 IPERF 7,366.0-7,450.0-- FISH;7,410.0 IPERF;7,510.0-7,528.0 PRODUCTION;33.9-7,719.8 • 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regqaalaska.gov• AOGCC.Inspectors(a(alaska.gov phoebe.brooks(a)alaska.gov chris.wallace(o�alaska.gov OPERATOR: ConocoPhillips Alaska Inc, FIELD/UNIT/PAD: Kuparuk/KRU/10 PAD DATE: 12/05/17 OPERATOR REP: VanCamp/Riley AOGCC REP: Guy Cook Well 1Q-11 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1841990 Type Inj W Tubing 1150 1150 1150 1150 Type Test P Packer TVD 5707 BBL Pump 1.1 IA 650 2000 1890 1875 Interval 0 Test psi 1500 BBL Return 1.0 OA 320 320 320 320 Result P Notes: MIITA post patch per Sundry#317-502 Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail • S=Slurry V=Required by Variance I=Inconclusive l I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT KRU 10-11 12-05-17.xlsx • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,December 07,2017 TO: Jim Regg �01 1� SUBJECT: Mechanical Integrity Tests P.I.Supervisor yep 1 CONOCOPHILLIPS ALASKA,INC. 1Q-11 FROM: Guy Cook KUPARUK RIV UNIT 1Q-11 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry ea— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Q-11 API Well Number 50-029-21216-00-00 Inspector Name: Guy Cook Permit Number: 184-199-0 Inspection Date: 12/5/2017 Insp Num: mitGDC171205172722 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I 1Q-11 - Type Inj W 5762 Tubing 1150 ' 1150 - 1150' 1150 PTD 1841990 1Type Test SPT Test psi 1500 - IA 650 2000 ' 1890 - 1875 ' BBL Pumped: 1.1 - BBL Returned: I - OA 320 320 • 320 - 320• Interval OTHER P/F P Notes: MIT-IA post patch as per Sundry 317-502. Little Red Services pump truck used for testing. SCANNED 14i/;a' 0 da ;./ • • Thursday,December 07,2017 Page 1 of 1 OF T I//7, 4. THE STAT • Alaska Oil and Gas of LAsKA Conservation Commission 333 West Seventh Avenue Off, P GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Jan Byrne scANNED NOV 0 9 2017 Well Integrity Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1Q-11 Permit to Drill Number: 184-199 Sundry Number: 317-502 • Dear Mr. Byrne: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this 2- day of November, 2017. RRDfts (,-L - ' .. 2 2017 c e'c • • RECEIVED STATE OF ALASKA OCT 2 5 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon LJ Plug Perforations U Fracture Stimulate LJ Repair Well LJ' Operations shutdown LI Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ ' Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ 1141"A fPatch , Other: E 2.Operator Name: 4.Current Well Class: 5.Permit to all Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 184-199 3.Address: ❑ Service 2, 6.API Number: Stratigraphic P. O. Box 100360,Anchorage,Alaska 99510 500292121600• 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA' Will planned perforations require a spacing exception? Yes ElNo ❑� ✓ KRU 1Q-11 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025641 , Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7,740' - 6,295' . 6898' . 5722' 6898' Casing Length Size MD TVD Burst Collapse Structural Conductor 65' 16" 101' Surface 3,635' 12" 3,670' Intermediate Production 7,686' 7" 7,720' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7120'-7528'% 5880'-6158' 3.500" J-55 7,293' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER PREMIER PACKER MD=6876 TVD=5706 ,Z 3 r i11/46 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑✓ • 14.Estimated Date for 10/30/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑., ' GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned H 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jan Byrne Contact Name: Jan Byrne Authorized Title: Well Integrity Supervisor Contact Email: N1617@conocophillips.com Contact Phone: (907)659-7224 Authorized Signature: 90.- 0 Date: 10/21/17 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3/ , /0r2 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Er Location Clearance El Other: Post Initial Injection MIT Req'd? Yes E"No H i� 7 Spacing Exception Required? Yes ❑ No � / Subsequent Form Required: IG �D RBetS L'�I°U t - 2 2U�f ajark ___� APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 6% \1— h lf �IU3 /o/aSf/7 �D l i/i`!g 1.11/ JSubmit Form and Form 10-403 Revised 4/2017 Approved application is va f r oGhSf om t eA a e of approval. Attachments in Duplicate • • RECEIVED ✓ OCT 2 5 2017 ConocoPh i l lips Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 21, 2017 Commissioner Hollis S. French Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner French, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 1Q-11 (PTD# 184-199). The request is for approval to set two tubing patches to regain tubing integrity. If you need additional information,please contact myself or Kelly Lyons at 659-7224. Regards, Jan Byrne Well Integrity Supervisor ORIG/ NAL • 1Q-11 DESCRIPTION SUMMARY OF PROPOSAL KRU WAG injection well 1Q-11 (PTD# 184-199)was reported to the AOGCC on 6-9-17 for suspect IA pressure increase. The well was shut in and freeze protected. Various diagnostics were performed culminating in a LDL locating a tubing leak at-100'. A caliper also reported two penetrations above 50%, one at 114' and the other at 272'. CPA intends to set retrievable tubing patches over these two locations to repair tubing integrity/ Post installation of the tubing patches the well will be brought online and stabilized for a state witnessed MITIA. Repair Plan: 1. Set two 3.5", -31' retrievable patches in the tubing over the leak and high penetration locations. 2. Perform diagnostic MIT-IA post patch installation. 3. Bring well online. 4. Once well is stabilized perform SW MIT-IA. 5. Submit 10-404. 4 KUP INJ • 1Q-11 ConocoPhillips Well Attributes Max Angle&MD TD Alaska,Inc. • Wellbore API/UWI Field Name Wellbore Status Inc!17 MD(ft0B) Act Btm(ftKB) cn.,ocn'nmps 500292121600 KUPARUK RIVER UNIT INJ 49.68 7,600.00 7,720.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 10-11,8/251201753407 PM SSSV:NIPPLE Last WO: 8/28/2013 43.31 1/5/1985 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;32.0 ,r-�„A�' Last Tag:RKB 7,404.0 8/6/2017 Rev Reason:TUBING LEAK,SEE NOTES pproven 8/25/2017 mar Casing Strings Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(Tye)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 36.0 101.0 101.0 62.50 H-40 WELDED i Casing Description SURFACE OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 95/8 8.921 35.7 3,670.2 3,498.7 36.00 J-55 BTC •�I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 33.9 7,719.6 6,282.1 26.00 J-55 BTC 1 Tubing Strings aA.....n/ Ahn/s c•-•Tubing Description (String Ma...I ID(in) 'Top(ftKB) 'Set Depth(ft..f Set Depth(TVD)(...'Wt(lb/ft) 'Grade 'Top Connection TUBING LEAK;100.0, TUBING WO 31/2 2.992 32.0 6,862.611 5,697.4 9.30 L-80 EUE-Brd Mod CONDUCTOR;38.S-101.0-4 Completion Details Nominal ID Top(ftKB) Top(ND)(RKB) Top Incl(°) Item Des Com (in) NIPPLE;505.5 Et 32.0 32.0 0.07 HANGER MC EVOY GEN IV TUBING HANGER 2.950 505.5 505.5 0.77 NIPPLE CAMCO'DS'NIPPLE 2.875"Profile 2.875 6,849.9 5,688.6 45.73 LOCATOR BAKER LOCATOR 2.980 6,850.0 5,688.6 45.72 SEAL ASSY BAKER PBR SEAL ASSY 2.980 Tubing Description 'String Ma...'ID(in) I Top(RKB) 'Set Depth(ft..J Set Depth(TVD)(...1Wt((blit) 'Grade 'Top Connection SURFACE;35.7-3,670.2- STACKED PACKER 5.03 4.00011 6,853.0 6,917.01 5.735.6 Completion Details Nominal ID IGAS LIFT;6,792.7 ` S Top(ftKB) Top(ND)(ftKB) Top Incl 7) Item Des Corn (in) F 6,853.0 5,690.6 45.71 PBR BAKER 80-40 PBR 4.000 6,875.5 5,706.5 45.58 PACKER BAKER PREMIER PACKER 2.870 6,898.2 5,722.3 45.46 NIPPLE CAMCO DS'NIPPLE 2.812 LOCATOR;6,849.9 6,909.6 5,730.4 45.37 OVERSHOT BAKER POORBOY OVERSHOT w/6'Swallow 3.625 Tubing Description 'String Ma"ID(in) 'Top(ftKB) Set Depth(9..'Set Depth(TVD)(...'Wt((blit 'Grade 'Top Connection SEAL ASSY;6,850.0 TUBING original 41/2 2.992 6,916.0 7,2940 6,001.5 9.30 J-55 FL4S PBR;6,853.0 Completion Details Nominal ID Top(ftKB) Tap(ND)(ftKB) Top Incl(°) Item Des Com (in) PACKER;6,875.5 6,940.4 5,752.0 45.11 PBR BAKER PBR 3.000 6,953.8 5,761.5 45.00 PACKER BAKER FHL PACKER 3.000 I 7,106.2 5,870.1 44.38 BLAST RINGS CARBIDE BLAST RINGS(5) 2.992 NP LU6,13982, , 7,272.5 5,986.7 46.45 LOCATOR BAKER LOCATOR SUB 3.000 7,273.4 5,987.3 46.46 PACKER BAKER FB-1 PACKER 4.000 7,276.7 5,989.6 46.50 SBE BAKER SEAL BORE EXTENSION 3.000 OVERSHOT;6,909.6 7,287.7 5,997.2 46.62 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,293.2 6,000.9 46.68 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PBR;6,940.4 Top(TVD) Top Incl I PACKER;6,953.7- Top(RKB) (RKB) 7/ Des Com Run Date ID(in) 100.0 100.0 0.23 TUBING TUBING LEAK 8/18/2017 0.000 PATCH;6,985.0 LEAK SLEEVE-C;6,992.50- 6,698.0 5,722.2 45.46 PLUG 2.81"CA-2 PLUG 8/6/2017 0.000 INJECTION;6,992.6 6,985.0 5,783.6 44.74 PATCH Alpha 21.68'Tubing Patch;w/AVA Ported Nipple @ 2/7/1993 1.875 6989';Setover GLM#12(6985') 6,992.5 5,789.0 44.68 SLEEVE-C AVA TPC SLEEVE 1.875 X 1.387 1217/2005 1.375 PATCH;7,057.01 • 7,057.0 5,834.9 44.44 PATCH Alpha 21.68'Tubing Patch;Set over GLM#13 2/7/1993 1.937 INJECTION;7,065.4 (7058') 7,287.7 5,997.2 46.62 REDUCER AVA NIPPLE REDUCER 1/25/1993 1.812 7,410.0 6,080.0 48.07 FISH Missing Valve Parts:Downhole 7/17/1991 0.000 _. _ Perforations&Slots Shot (PERF;7,120.0-7,212.04 - Dens - - Top EM/D) Btm(TVD) (shots/f Top(ftKB) Btm MB) (ftKB) (ftKB) Zone Date t) Type Com IPERF;7,224.0-7,232.0- 7,120.0 7,212.0 5,879.9 5,944.8 C-4,C-3,C-2, 2/2/1985 12.0 (PERF 5"DA Csg Gun;120 C-1,10-11 deg.phasing 7,224.0 7,232.0 5,953.1 5,958.7 UNIT B,1Q- 2/2/1985 12.0 IPERF 5"DA Csg Gun;120 11 deg.phasing INJECTION;7,253.3 7,366.0 7,450.0 6,050.5 6,106.6 A-4,A-3,10- 2/2/1985 4.0 (PERF 4"DA JJ Cog Gun;120 11 deg.phasing LOCATOR;7,272.5 7,510.0 7,528.0 6,146.1 6,157.9 A-2,1Q-11 2/2/1985 4.0 IPERF 4"DA JJ Csg Gun;120 PACKER;7,273.4 = deg.phasing SBE;7,276.7 -,..,tom,. If Mandrel Inserts 0-e REDUCER;7,287.7,tI i NIPPLE;7,287.7• 0I, Top(NO) Valve Latch Port Size TRO Run N. Top(RKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Cam 1 6,792.7 5,646.7 Camco MMG 1 1/2 GAS LIFT DMY 'RK 0.000 0.0 9/7/2013 SOS;7,2932 I 2 6,992.6 5,789.0 MERLA TMPD ' 11/2 INJ PATC ' 0.000 0.0 12/6/2005 H 3 7,065.4 5,840.9 MERLA TMPD 11/2 INJ PATC 0.000 0.0 2/1/1985 - - H IPERF;7,366.0-7,450.0 FISH;7,410.0---! - 4 7,253.3 5,973.5 MERLA -TMPD 1 1/2'INJ DMY BK-2 0.000 0.0 2/10985 - Notes:General&Safety - End Date Annotation - 10/7/2010 NOTE:View Schematic w/Alaska Schematic9.0 5/10/2013 NOTE:Waivered Well T x IA Communication"Water Injection Only" IPERF;7,510.0-7.528.0- 8/18/2017 NOTE:TBG LEAK 100'RKB PRODUCTION;33.9-7,719.6 • • cU 1 tn X • N L0 U t•-• V O > ,n W moo❑ ° 3 0 W v CLO Y CU O Y of '^ y O C E a I- Y O C .- u yi }' > ▪ " 01 4 o Y O ti a c Q c > Y (o C a co 'B vart Q =ti 13 t u Q 6 m ❑ Qi N N N r r N N N n s C 0 _ J Ju Q 0 Co 6) Co rn rn rn a' a a a Q E L ° ° n -gi- O Q Q Q Q Q Q Q d d a7 d Y N C to to fn (n �Y C .� yr G a N N N N M M M to to C (9 u Y Z Q v v E \ u L > 73 v F..*ii CO N -0 ,.) 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N, � cq Z b W E2 V a J J J J J J J J J J O ' Cl) M 2 3 E 3 3 3 3 3 3 3 3 3 cu 2 an C3 At--- 1,1-21-Yrfl r MCC Ce X CL W CLCC CL CCM E W W W W W W W W W W W det W > > > > > > > > > > > s a in z Y Y Y Y Y Y Y Y Y Y Y O > > > > > > > > > _, IX fr (XCLCLCLCCOLCLCLCL w Q Q Q Q Q Q Q Q Q Q Q a y a a a a a a a a a a aa > > > > > > > > > > > C O Y Y Y YYYYYYYY - c u OA (0 ` 0 W ,_ CM- N O O O M N co CD X V) .CU l// N ❑ u7 N ,n u) in ,n in o 0 0 0 0 0 0 0 0 0 0 0 E N o o 0 0 0 0 0 0 o o o o LU o C7 # ch -) 1-,AAM66N66 @ Co) o D o x x = 0 0 0 0 0 0 > � a2333 tntntntntn n.J W ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ c as W =C _ CE 0 0O O O O O O 0 0 0 c O O o 0 O O Q o O o 0 C a o o ch .- v o v o ,n 6 '7, E M tD e- In CO r CD CO N WN co O N M M N O O N N M 0 0 G u N NNNNNNNNNNN L. .❑ n O D) O D) T al n R NNNNNNNNNNN O O 0 0 0 O O 0 O 0 0 �. - 0 0 0 0 0 0 0 0 0 0 6,-4 a+ Y O a) 00 to ItIA A N a in In IU CO W to - n U) U) o M/ d (_6 a) O! f- m E v > u CL7 w x t„ CC c C u v Q N �o a` ti ~ v ai Q 0 In v co c rn CO 4, v a, n tv E z Y oo (;t z r' r O N N O 0 0 .. ` 44 In t`o J di T U Y Y Y J LL = m m E (o a O. Q O N 1. J M M M r' M r N Z al (0 m C 1.",-- C N (O N u 4\. O CA atLbG - .. It a` a Q • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Friday, June 9, 2017 10:37 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of IA pressure anomaly KRU WAG injector 1Q-11 (PTD 184-199) 06-09-17 Attachments: 1Q-11 90 day TIO 6-9-17jpg; 1Q-11 schematic.pdf Chris, KRU WAG injector 10-11 (PTD 184-199) is experiencing an IA pressure anomaly. Attempts yesterday to establish a 500psi dP across the tubing and IA were unsuccessful. Two IA bleeds were performed. Each time,the IA pressure would rapidly climb back up to meet tubing pressure at"1200psi. Therefore the well was shut in and freeze protected yesterday. DHD will be obtaining the standard suite of initial diagnostics to include MITIA/packoff and IA drawdown testing, followed by well intervention work with Eline/slickline/coil as needed. The well will remain shut in until the diagnostics can be completed and a plan forward established. Proper paperwork will be provided prior to return to injection. Please let us know if you disagree with the path forward. Attached are the schematic and 90 day TIO plot. Kelly Lyons/ Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 SCAN E® JUN 1 92D17 • • dw•y+No4a 14.14 6 4.6. it • ,►.1 4 • a ►..} ►.p..►.., • P`- - N h ?n Me4 — Q. Q t i 4 A r7 a w `w a 8 rrrr II Isa KUP INN • 1Q-11 K COIIOCoP fillips Ot. Well Attributes Max Angle&MD TD AlaskaInc. Wellbore API/UWI Field Name Wellbore Status Incl(1 MD(MB) Act Btm(ftKB) C.orncoPNllips 500292121600 KUPARUK RIVER UNIT INJ 49.68 7,600.00 7,720.0 Comment H2S(ppm) Dab Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:NIPPLE Last WO: 8/28/2013 43.31 1/5/1985 Well Con89:-10-11,9/9/20131219:15 PM Schematic-Aos of Annotation Depth(ftKB) End Date Annotation Last Mod By End Date __ Last Tag:SLM 7,378.0 7/16/2013 Rev Reason:PULL RHC PLUG,PULL CATCHER 8 osbod 9/9/2013 HANGER,32 PLUG,GLV C/O I jtyL Casing Strings Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 36.0 101.0 101.0 62.50 H-40 WELDED 1 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd SURFACE 95/8 _ 8.921 35.3 3,670.2 3,498.8 36.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd PRODUCTION 7 6.276 33.1 7,719.6 6,282.1 26.00 J-55 BTC Tubing Strings Tubing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR._ TUBING WO Completion Details 3 1/2 2.992 32.0 6,862.6 5,697.5 9.30 L-80 EUE-8rd Mod 38 101 UV Top Depth NIPPLE.500 11 ('WO) Top Incl Noml... Top(NCB) (kKB) (°) Item Deswipdon Comment ID(In) 32.0 32.0 0.03 HANGER MC EVOY GEN IV TUBING HANGER 2.950 505.5 505.5 0.77 NIPPLE CAMCO'DS'NIPPLE 2.875"Profile 2.875 6,849.9 5,688.7 45.87 LOCATOR BAKER LOCATOR 2.980 6,850.01 5,688.81 45.86JSEAL ASSY 'BAKER PBR SEAL ASSY 2.980 SURFACE, 411 L. Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String•••String Top Thrd 35-3,870 STACKED PACKER 5.03 4.000 6,853.1 6,917.0 5,735.5 Completion Details GAS LIFT, Top Depth 6'799 (TVD) Top Incl Nomi... Top(MB) (ftKB) (°) Item Description Comment ID(in) 6,853.1 5,690.9 45.84 PBR BAKER 80-40 PBR 4.000 6,875.5 5,706.5 45.65 PACKER BAKER PREMIER PACKER 2.870 LOCATOR, 6,898.2 5,722.3 45.47 NIPPLE CAMCO DS'NIPPLE 2.812 6,850 SEAL ASSY, / 6,909.6 5,730.3 44.91 OVERSHOT BAKER POORBOY OVERSHOT w/6'Swallow 3.625 0,850 ( PER,0,853 Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd r-- TUBING original 4 1/2 2.992 6,916.0 7,294.0 6,001.4 9.30 J-55 FL4S _L1_ Completion Details PACKER,0,876- Top Depth (TVD) Top Incl Nomi... Top(ftKB) (kKB) P1 Item Description Comment ID(In) 6,940.3 5,752.0 44.81 PBR BAKER PBR 3.000 NIPPLE,8,898 W 6,953.7 5,761.4 44.77 PACKER BAKER FHL PACKER 3.000 WI 7,106.1 5,870.0 44.38 BLAST RINGS CARBIDE BLAST RINGS(5) 2.992 OVERSHOT, 6,91011 7,272.5 5,986.6 46.42 LOCATOR BAKER LOCATOR SUB 3.000 INF 7,273.3 5,987.2 46.43 PACKER BAKER FB-1 PACKER 4.000 it 7,276.6 5,989.5 46.47 SBE BAKER SEAL BORE EXTENSION 3.000 li 7,287.7 5,997.1 46.60 NIPPLE CAMCO D NIPPLE NO GO 2.750 PBR,6.940 7,293.1 6,000.9 46.67 SOS BAKER SHEAR OUT SUB 2.992 PACKER,0,954 silitano PATCH,8,985 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SLEEVE-C, Top Depth 0,993III (TVD) Top incl INJECTION, Top(kKB) (kKB) (1 DescriptionComment Run Date ID(in) 0,993 6,985.0 5,783.6 44.67 PATCH Alpha 21.68'Tubing Patch;w/AVA Ported Nipple @ 6989'; 2/7/1993 1.875 Setover GLM#12(6985') 6,992.5 5,789.0 44.64 SLEEVE-C AVA TPC SLEEVE 1.875 X 1.387 12/7/2005 1.375 P IINJECTION _ ',065 � • 7,057.0 5,834.6 43.71 PATCH Alpha 21.68'Tubing Patch;Set over GLM#13(7058') 2/7/1993 1.937 7,287.7 5,997.1 46.60 REDUCER AVA NIPPLE REDUCER 1/25/1993 1.812 7,410.0 6,080.0 48.58 FISH Missing Valve Parts:Downhole 7/17/1991 0.000 ill - Perforations&Slots shoe Top(TVD) Bbn(TVD) Dens 'PERF, - Top(kKB) Bbn(RKB) (RKB) (RKB) Zone Date (ah-• Type Comment 7,12x7,212 7,120.0 7,212.0 5,879.9 5,944.1 C-4,C-3,C-2, 22/1985 12.0 IPERF 5"DA Csg Gun;120 deg.phasing C-1,1Q-11 7,2241232 7,224.0 7,232.0 5,952.6 5,958.3 UNIT B,1Q-11 22/1985 12.0 IPERF 5"DA Cog Gun;120 deg.phasing 7,366.0 7,450.0 6,050.4 6,106.6 A-4,A-3,1Q-11 22/1985 4.0(PERF 4"DA JJ Csg Gun;120 deg.phasing lig 7,510.0 7,528.0 6,146.1 6,157.8 A-2,1Q-11 22/1985 4.0 IPERF 4"DA JJ Csg Gun;120 deg.phasing INJECTION. 7'259ilMii Notes:General&Safety LOCATOREnd Date Annotation 7,272 10/7/2010 NOTE:View Schematic w/Alaska Schematic9.0 PACKER,7,273 5/10/2013 NOTE:Waivered Well T x IA Communication"Water Injection Only" SBE,7,277 REDUCER, 7,288-N NIPPLE,7,288 Mandrel Details SOS,7,293 Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run N...Top(ftKB) (1 Moire Modal (In) Sen. Type Type (in) (WI) Run Date Com... IPERF, _= 7,450 1 6,792,7 5,648.7 46.03 Cameo MMG 1 12 GAS LIFT DMY RK 0.000 0.0 9/72013 FISH, FISH,7,410 2 6,992.5 5,789.0 44.64 MERLA TMPD 1 12 INJ PATCH 0.000 0.0 12/6/2005 3 7,065.3 5,840.7 43.83 MERLA TMPD 1 12 INJ PATCH 0.000 0.0 2/1/1985 - 4 7,253.3 5,973.2 46.19 MERLA TMPD 1 12 INJ DMY BK-2 0.000 0.0 2/1/1985 IPERF, 7,510-7,528 - PRODUCTION, 33-7,720 TD,7,720 Ima~roject Well History File' CoverOge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Organizing (done) Well History File Identifier Rescan Needed RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No, [] Maps: [] Grayscale items: [] Other, No/Type D Other items scannable by X large scanner Poor Quality Originals: ~-_Z~ OVERSIZED (Non-Scannable) [] Other: , NOTES: [] ' Logs of various kinds [] Other BY: ,~¢~BRE" VINCENT SHERYL MARIA LOWELl. DATE; ~--Z'~ IS/ Project Proofing BY: BEVERLY BR~SHERYL MARIA LOWELL Scanning Preparation x 30 = _ . DATE: BY: Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE' . /' PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION' ~"/YES NO Stage 2 IF N~O IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO (SCANNING IS COM~INT UNLES~ SPECIAL ATi'ENTION IS REQUIRED ON AN INONIDUAL PAGE BASIS DUE TO QUALFFY, GRAY~"'~;~E OR COLOR IMAGES) · I RESCANNED BY: BEVERLY ~REN VINCENT SHERYL '~MARIA LOWELL DATE: Is~ General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScan ned .wpd • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,October 02,2013 TO: Jim Regg (Zen. /(�I71/3 SUBJECT: Mechanical Integrity Tests P.I.Supervisor 1 CONOCOPHILLIPS ALASKA INC 1Q-11 FROM: Chuck Scheve KUPARUK RIV UNIT IQ-11 Petroleum Inspector Sre: Inspector Reviewed B j P.I.Suprv.-..) NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Q-11 API Well Number 50-029-21216-00-00 Inspector Name: Chuck Scheve Permit Number: 184-199-0 Inspection Date: 9/27/2013 Insp Num: mitCS130929072828 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 1 5987 ' ' 350 2460 1 2430 .1 2430 7 Well IQ-11 !Type Inj w 'TVD IA PTD 1841990 . Type Test SPT(Test psl, 1500 OA 1 360 . 420 , 420 420 - INITAL P/F ,7 L I i Interval t P i Tubing 1350 -I 1350 - 1350 1350 Notes: Initial test post workover, SUNNED ' L . ` t Hi 1 Wednesday,October 02,2013 Page 1 of 1 • • Brooks, Phoebe L (DOA) MIt /gL1990 From: NSK Problem Well Supv[n1617 @conocophillips.com] Sent: Wednesday, October 02, 2013 9:37 AM To: Brooks, Phoebe L (DOA) Subject: RE: KRU state witnessed MITIA's: 1Q-11 (PTD#1841990); 2C-05 (PTD#1830990); 2T-28 (PTD#1950920); 2U-07A(PTD#1850910); 30-17 (PTD#1880290); 3Q-05 (PTD#1861960) Attachments: 1Q-11 Well Schematic.pdf; 2U-07A Well Schematic.pdf Hi Phoebe - Not a problem. Current well schematics are attached. Regards, Jolin Oksness Original Message From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooksPalaska.gov] Sent: Wednesday, October 02, 2013 9:30 AM To: NSK Problem Well Supv Subject: [EXTERNAL]RE: KRU state witnessed MITIA's: 1Q-11 (PTD #1841990); 2C-05 (PTD #1830990); 2T-28 (PTD #1950920); 2U-07A (PTD #1850910); 30-17 (PTD #1880290); 3Q-05 (PTD #1861960) Would you please send me the well schematics for the post RWO wells (2U-07A and 1Q-11) so I can verify the packer tvds? Thank you, Phoebe Phoebe Brooks , Statistical Technician II SCANNED 1-)EL 1 0 %013 Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 Original Message From: NSK Problem Well Supv [mailto:n16170conocophillips.com] Sent: Tuesday, October 01, 2013 8:51 AM To: Regg, James B (DOA); Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Cc: Dethlefs, Jerry C; NSK Problem Well Supv Subject: KRU state witnessed MITIA's: 1Q-11 (PTD #1841990); 2C-05 (PTD #1830990); 2T-28 (PTD #1950920); 2U-07A (PTD #1850910); 30-17 (PTD #1880290); 3Q-05 (PTD #1861960) Please find attached forms for recently performed MIT's at KRU. The initial test pressures for well 3Q-05 (PTD #1861960) were not recorded before rigging down the pump truck and sending it to the next location, in an attempt to efficiently progress the work. Unfortunately, due to that the test pressure dropped below the lower threshold, despite passing parameters. This well was called a fail and will be scheduled for a re-test at first opportunity, and an inspector will be invited to witness. Please let me know if you have any questions. • • Thanks, Ron Wilson / Roger Mouser CPAI Field Supervisor, DHD Office: 659-7022 Cell: 943-0167 Pager: 659-7000; #121 2 , 7J `y KUP INJ • 1Q-11 il • �� �I"f Wellbore AP�OWItes Field Name Wellbore Status Inc(('I MD RB)� Act Btm(ftKB) Alagka'IRC` carrc 500292121600 KUPARUK RIVER UNIT INJ 49.68 7,600.00 7,720.0 xcd rui7r�a " Comment H2S(ppm) Date Annotation End Date KB-Ord(R) Rig Release Date well co rq -10-71 8/3,,120,,3 as6:4B AM .SSSV:NIPPLE Last WO: 8/28/2013 43.31 1/5/1985 Schematic-Actoel Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,378.0 7/16/2013 Rev Reason:WORKOVER haggea 8/30/2013 HANGER.32 Casinr Strinrs Casing Description String 0... String ID...Top(ftKB) Set Depth(t...Set Depth(ND)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 36.0 101.0 101.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE 9 5/8 8.921 35.3 3,670.2 3,498.8 36.00 J-55 BTC ;. Casing Description String 0... String ID...Top(ftKB) Set Depth(t..Set Depth(ND)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 33.1 7,719.6 6,282.1 26.00 -55. BTC ilir Thin■Strin.s '' . ' CONDUCTOR, Tubing Description String 0.. String ID Top(ftKB) Set Depth(f..Set Depth(ND).. String Wt...String...String Top Thrd 36-101 TUBING WO 3 1/2 2 992 32 0 6,862.6 5,697.5 9.30 L-80 EUE-8rd Mod Completion Details Top Depth NIPPLE.506 (NO) Top Inc! Nomi... Top(RKB) (RKB) (°I item Description Comment ID(In) 32.0 32.0 0.03 HANGER MC EVOY GEN IV TUBING HANGER 2.950 505.5 505.5 0.77 NIPPLE CAMCO'DS'NIPPLE 2.875"Profile 2.875 6,849.9 5,688.7 LOCATOR BAKER LOCATOR 2.980 SURFACE. 6,850.0 5,688.8 SEAL ASSY BAKER PBR SEAL ASSY 2.980 353,670 Tubing Description String 0... String ID...To KB) Set Depth f...Set Depth(ND) String Wt..Shin String Top Thrd dew- 8 Pt 9 8 P( ) Pt ( P ( )••• 9 8••• g P STACKED PACKER 5 03 4.000 6,853 1 6 917 0 5,735.5 EU Top Depth :WI (ND) Top loci li. Top(RKB) (ftKB) (I Item Description Comment ID(in) 6,853.1 5,690.9 45.84 PBR BAKER 80-40 PBR 4.000 LOCATOR, 6,875.5 5,706.5 45.65 PACKER BAKER PREMIER PACKER 2.870 6,850 SEAL ASSY, �. 6,898.2 5,722.3 45.47 NIPPLE CAMCO DS'NIPPLE w/RHC plug 2.812 _ PBR,6,853 s; 6,909.6 5,730.3 44.91 OVERSHOT BAKER POORBOY OVERSHOT w/6'Swallow 3.625 Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt..String..String Top Thrd TUBING original 4 1/2 2.992 6,916.0 7,294.0 6,001.4 9.30 J-55 FL4S PACKER.6.876 la .i- _ � is HOT. Completion Details _' Top Depth 3 (TVD) Top Inc! Nomi... Top(RKB) (RKB) (°) Rem Description Comment ID(in) NIPPLE.6,898 6,940.3 5,752.0 44.81 PBR BAKER PBR 3.000 6,953.7 5,761.4 44.77 PACKER BAKER FHL PACKER 3.000 OVERS6,9 0 7,106.1 5,870.0 44.38 BLAST RINGS CARBIDE BLAST RINGS(5) 2.992 - 7,272.5 5,986.6 46.42 LOCATOR BAKER LOCATOR SUB 3.000 7,273.3 5,987.2 46.43 PACKER BAKER FB-1 PACKER 4.000 ::::PBR,6940 7,276.6 5,989.5 46.47 SEE BAKER SEAL BORE EXTENSION 3.000 PACKER,6,954 7,287.7 5,997.1 46.60 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,293 1 6,000.9 46.67 SOS BAKER SHEAR OUT SUB 2.992 CATCHER. k w ' 6,964 I ( Other In Hole Wireline retrievable plugs,valves,plumps,fish,etc.) PLUG,6,968 ■14 Top Depth PATCH.6,985 (TVD) Top Intl SLEEVE-C. ) Top(RKB) IRKS) (°) Description Comment Run Date ID(In) 6.993 6,964.0 5,768.7 44.74 CATCHER 124"x 2.72"JUNK CATCHER 7/25/2013 0.000 INJECTION. ) 6993 I 6,968.0 5,771.6 44.72 PLUG WRP @6968 7/25/2013 0.000 , 6,985.0 5,783.6 44.67 PATCH Alpha 21.68'Tubing Patch;w/AVA Ported Nipple @ 6989'; 2/7/1993 1.875 Setover GLM#12(6985') PATCH.7,057 ;' ! INJECTION, 1 6,992.5 5,789.0 44.64 SLEEVE-C AVA TPC Sleeve 1.875 X 1.387 1217/2005 1.375 7,065 P 7,057-0 5,834.6 43.71 PATCH Alpha 21.68'Tubing Patch;Set over GLM#13(7058) 20/1993 1.937 7,287.7 5,997.1 46.60 REDUCER AVA NIPPLE REDUCER 151993 1.812 7 410 0 6 080 0 4858 FISH Missing Valve Pans Downhole 7/17/1991 t . $Iot$, `iT- . Shot 'PERF, 7,120-7,272 Top(TVD) Btm(ND) Dens Top(ftKB)Btm(SKB) (RKB) (RKS) Zone Date (eh.- Type Comment IPERF, 7,120.0 7,212.0 5,879.9 5,944.1 C-4,C-3,C-2, 2/2/1985 12.0 IPERF 5"DA Csg Gun;120 deg.phasing zzzu.232 C-1,10-11 7,224.0 7,232.0 5,952.6 5,958.3 UNIT E,10-11 2/2/1985 12.0 IPERF 5"DA Csg Gun;120 deg.phasing INJECTION, 7,366.0 7,450.0 6,050.4 6,106.6 A-4,A-3,1Q-11 2/2/1985 4.0 IPERF 4"DA JJ Csg Gun;120 deg.phasing 7253 7,510.0 7,528.0 6,146.1 6,157.8 A-2,10-11 2/2/1985 4 0 IPERF 4"DA JJ Csg Gun 120 deg.phasing LOCAinz t sites.°General&Safe PACKER.7,273 End Date Annotation 10/7/2010 NOTE:View Schematic w/Alaska Schematic9.0 SBE,7,277 5/102013 NOTE:Waivered Well T x IA Communication"Water Injection Only" REDUCER. 7,288 NIPPLE,7,288 k , q "` i'. M ndrel Details v- Top Depth Top Port SOS.7,293 ,.„, g,•, (ND) Inc/ OD Valve Latch Site TRO Run N...Top(RKS) (ftKB) (°l Make Model (in) Sery TYPe Type (in) (psi) Run Date Com... IPERF, 1 6,792.7 5,648.7 46.03 Camco MMG 1 12 GAS LIFT SOV RK 0.000 0.0 8/26/2013 DCR-1 FisSH.7,ao el 2 6,992.5 5,789.0 44.64 MERLA TMPD 1 12 INJ PATCH 0.000 0.0 12/6/2005 3 7,065.3 5,840.7 43.83 MERLA TMPD 1 12 INJ PATCH 0.000 0.0 2/1/1985 4 7,253.3 5,973.2 46.19 MERLA TMPD 1 12 INJ DMY 0 0.000 0.0 2/1/1985 IPERF, 7,5107628 erg. PRODUCTION. 33-7,720 TD,7,720 STATE OF ALASKA RECEIVED ALA.OIL AND GAS CONSERVATION COM•ION SEP 10 2013 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon I-- Repair w ell 17 Rug Perforations r Perforate r Other AOGCC Alter Casing f Pull Tubing pw Stimulate-Frac fl Waiver r Time Extension r Change Approved Program rOperat. Shutdown r® Stimulate-Other r Re-enter Suspended Well 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 184-199 3.Address: 6.API Number: Stratigraphic r Service P. O. Box 100360,Anchorage,Alaska 99510 50-029-21216-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25641 • 1 Q-11 • 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 7740 feet Plugs(measured) None true vertical 6295 feet Junk(measured) 7410 Effective Depth measured 7637 feet Packer(measured) 6876,6954, 7273 true vertical 6227 feet (true vertical) 5707, 5761,5987 Casing Length Size MD ND Burst Collapse CONDUCTOR 65 16 101 101 SURFACE 3635 9.625 3670 3499 PRODUCTION 7687 7 7720 6282 SCANNED f1i 0%' 2 1 281. . Perforation depth: Measured depth: 7120-7212, 7224-7232, 7366-7450,7510-7528 True Vertical Depth: 5880-5944, 5953-5958,6050-6107,6146-6158 Tubing(size,grade,MD,and ND) 3.5, L-80,6863 MD, 5698 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER PREMIER PACKER @ 6876 MD and 5707 TVD PACKER-BAKER FHL PACKER @ 6954 MD and 5761 TVD PACKER-BAKER FB-1 PACKER @ 7273 MD and 5987 TVD NIPPLE-CAMCO DS NIPPLE @ 506 MD and 506 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable 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 5114 Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service PI ' Stratigraphic 16.Well Status after work: Oil r Gas r WDSPL Daily Report of Well Operations XXX GSTOR WAG GINJ r SPLUG WIND SUSP 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: 313-351 Contact Jonathan Coberly a(�,265-1013 Email Jonathan.Coberlycop.com Printed Name Jonathan Coberl Title Sr. Wells Engineer Signature Phone:265-1013 Date l Jq/Zvf 3 Lr 3 RBDMS SEP 12 20 o �5 / 3 o,14.6 Form 10-404 Revised 10/2012 / l / l ��,� / / Submit Original Only �I" lli KUP INJ 1Q-11 ConocoPhillips S Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APEUWI Field Name Wellbore Status Ind(°) MD(ft KB) Act Btm(ftKB) con owOhx ps 500292121600 KUPARUK RIVER UNIT INJ 49.68 7,600.00 7,720.0 "" Comment H2S(ppm) Date Annotation End Date KB-Grd(It) Rig Release Date Well can5g.Matt 9/9/2013121915 PM SSSV:NIPPLE Last WO: 8/28/2013 43.31 1/5/1985 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,378.0 7/16/2013 Rev Reason:PULL RHC PLUG,PULL CATCHER 8 osborl 9/9/2013 HANGER,3 32___.. 2.1 PLUG,GLV CIO � i•.. , !, Casing Strings •' Casing Description String 0... String ID...Top(ft613) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd CONDUCTOR 16 15.062 36.0 101.0 101.0 62.50 H-40 WELDED i Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd II _ ' SURFACE 95/8 8.921 35.3 3,6702 3,498.8 36.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String... String Top Thrd PRODUCTION 7 6.276 33.1 7,719.6 6,282.1 26.00 J-55 BTC Tubing Strings Tubing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)... String Wt..String... String Top Thrd CONDUCTOR, TUBING WO 3 1/2 2.992 32.0 6,862.6 5,697.5 9.30 L-80 EUE-8rd Mod as tof I Completion Details LTop Depth NIPPLE,506 (ND) Top Intl Nomi... Top(ftKB) (RKB) 1°) Item Description Comment ID(n) 32.0 32.0 0.03 HANGER MC EVOY GEN IV TUBING HANGER 2.950 505.5 505.5 0.77 NIPPLE CAMCO'DS'NIPPLE 2.875"Profile 2.875 6,849.9 5,688.7 45.87 LOCATOR BAKER LOCATOR 2.980 6,850.0 5,688.8 45.86 SEAL ASSY 'BAKER PBR SEAL ASSY .980 SURFACE, 355670 Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd STACKED PACKER 5.03 4.000 6,853.1 6,917.0 Completion Details 5,735.5 GAS urr, Top Depth 6,793 -� (TVD) Top Intl Nomi... Top(ftKB) (ftKB) (1 Item Description Comment ID(In) 6,853.1 5,690.9 45.84 PBR BAKER 80-40 PBR 4.000 6,875.5 5,706.5 45.65 PACKER BAKER PREMIER PACKER 2.870 LOCATOR,60 - -,..J i 6,898.2 5,722.3 45.47 NIPPLE CAMCO DS'NIPPLE 2.812 SEAL ASSY, --- 6,909.6 5,730.3 44.91 OVERSHOT BAKER POORBOY OVERSHOT w/6'Swallow 3.625 6,850 PBR,6,853 i Tubing Description String 0... String ID...Top(ftKB) Set Depth(i...Set Depth(TVD)...String Wt...String... String Top Thrd _____ TUBING original 4 1/2 2.992 6,916.0 7294.0 6,001.4 9.30 J-55 FL4S Completion Details PACKER,6,876 -,,� Top Depth - (TVD) Top Ind Nomi... ___ Top(ftKB) (ftKB) rt Item Description Comment ID(in) 6,940.3 5,752.0 44.81 PER BAKER PBR 3.000 NIPPLE,6,898 6,953.7 5,761.4 44.77 PACKER BAKER FHL PACKER 3.000 f:' 0 7,106.1 5,870.0 44.38 BLAST RINGS CARBIDE BLAST RINGS(5) 2.992 OVERSHOT, �r 6,910 7,272.5 5,986.6 46.42 LOCATOR BAKER LOCATOR SUB 3.000 i 7,273.3 5,9872 46.43 PACKER BAKER FB-1 PACKER 4.000 7276.6 5,989.5 46.47 SBE BAKER SEAL BORE EXTENSION 3.000 tE ' 7,287.7 5,997.1 46.60 NIPPLE CAMCO D NIPPLE NO GO 2.750 PBR.6.940 I PACKER,6,954 7293.1 6,000.9 46.67 SOS (BAKER SHEAR OUT SUB 2.992 - PATCH,6,985 II Other In Hole.(Wireline retrievable plugs,valves,pumps,fish,etc.) SLEEVE-C, Top Depth 6,993N _ (TVD) Top Inc' INJECTION, Top(ftKB) (ftKB) (°) Description Comment Run Date ID(In) 6,993 6,985.0 5,783.6 44.67 PATCH Alpha 21.68'Tubing Patch;w/AVA Ported Nipple @ 6989'; 2/7/1993 1.875 Setover GLM#12(6985') I 6,992.5 5,789.0 44.64 SLEEVE-C AVA TPC SLEEVE 1.875 X 1.387 12/72005 1.375 PATCH,7.057 INJECTION, 7,057.0 5,834.6 43.71 PATCH Alpha 21.68'Tubing Patch;Set over GLM#13(7058') 2/7/1993 1.937 7,065 7,287.7 5,997.1 46.60 REDUCER AVA NIPPLE REDUCER 1/25/1993 1.812 ill 7,410.0 6,080.0 48.58 FISH Missing Valve Parts:Downhole 7/17/1991 0.000 Perforations&Slots Shot Top(TVD) titer(TVD) Dens I-7.212 Top(ftKB)Btm(ftKB) (RKB) (ftKB) Zone Date (sh... Type Comment 7,720.7,212 7,120.0 7,212.0 5,879.9 5,944.1 C-4,C-3,C-2, 2/2/1985 12.0 IPERF 5"DA Csg Gun;120 deg.phasing _ C-1,10-11 7,2214-7 232 L 7,224.0 7,232.0 5,952.6 5,958.3 UNIT B,10-11 2/2/1985 12.0 IPERF 5"DA Csg Gun;120 deg.phasing 7,366.0 7,450.0 6,050.4 6,106.6 A-4,A-3,1Q-11 2/2/1985 4.0 IPERF 4"DA JJ Csg Gun;120 deg.phasing 7,510.0 7,528.0 6,146.1 6,157.8 A-2,1Q-11 2/2/1985 4.0 IPERF 4"DA JJ Csg Gun;120 deg.phasing INJECTION, 1. 7,253 Notes:General&Safety LOCATOR, -- End- End Date Annotation 7,272 .4 10/7/2010 NOTE:View Schematic w/Alaska Schematic9.0 PACKER,7,273 5/10/2013 NOTE:Waivered Well T x IA Communication**Water Injection Only" SBE,7,277 iiiiii alis REDUCER, In 7,288 NIPPLE,7,288 11b:. NIA Mandrel Details SOS,7,293 j Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run N...Top(RKB) (ftKB) 11 Make Model (in) Serif Type Type I(n) (psi) Run Date Com... IPERF, 7,366-7,450 1 6,792.7 5,648.7 46.03 Camco MMG 1 12 GAS LIFT DMY RK 0.000 0.0 9/7/2013 FISH.7,410 2 6,992.5 5,789.0 44.64 MERLA TMPD 1 12 INJ PATCH 0.000 0.0 12/6/2005 3 7,065.3 5,840.7 43.83 MERLA TMPD 1 12 INJ PATCH 0.000 0.0 2/1/1985 4 7,253.3 5,973.2 46.19 MERLA TMPD 1 12 INJ DMY BK-2 0.000 0.0 2/1/1985 IPE , P 7,510-7,52 RF8 ... 1 PRODUCTION. 30.7,720\ TO 7,720 1 Q-11 Pre-Rig Well Work Summary • • DATE, SUMMARY 5/10/2013 PULLED WRP @ 6970' RKB. JOB COMPLETE. 5/28/2013 STATE WITNESSED (LOU GRIMALDI) MITIA- PASSED; MITOA- PASSED 6/8/2013 (RWO): T-POT PASSED. T-PPPOT PASSED. IC-POT PASSED. IC-PPPOT PASSED. RE- ENERGIZED IC-PO (IC-POT& IC-PPPOT BOTH PASSED POST-REENERGIZED; FAILED PRIOR). FT T& IC LDS SUCCESSFUL. 7/16/2013 TAGGED @ 7378' SLM, EST. 127' FILL. IN PROGRESS. 7/17/2013 MEASURED BHP @ 7386' RKB: 2705 PSI. DRIFT TBG w/2.78"WRP DUMMY TO 6985' RKB. PULLED DV @ 6896' RKB. READY FOR E/L. 7/25/2013 SET WRP AT A CCL STOP DEPTH OF 6957', WITH A CCL TO MID ELEMENT OFFSET OF 11', PUTTING THE WRP SET DEPTH AT 6968'. THE WRP IS SET IN THE FIRST FULL JOINT BELOW THE FHL PACKER. SET WRP WITH 1 11/16" LSST.TOOL LENGTH OF 30.5'AND A MAX O.D. OF 2.78" CORRELATED TO WELL JEWELRY, WITH PACKER AT 6953'AND GLM AT 6896'. CMIT TxIA to 3500PS1 by LRS (PASSED) *See attached report 7/25/2013 SET 124"x 2.72"JUNK CATCHER ON TOP OF WRP @ 6958' RKB. JOB COMPLETE 7/28/2013 FIRED A 5' STRING SHOT WITH 160 GR/FT WITH MID SHOT DEPTH AT 6916'.ATTEMPTED TO CUT WITH RCT. TOOL SHORTED WHILE IN HOLE. ON BREAKING DOWN THE TOOL, FOUND THAT THE LINE WAS SHORTED AT THE JARS. BROKE OFF EACH INDIVIDUAL PIECES MEGGED AND METERED THEM, WITH THE JARS BEING THE ONLY ISSUE FOUND. CHECKED SPARE JARS, CHECK OUT OK. SENT BAD JARS BACK TO DEADHORSE FOR REPAIRS. RECHECKED ALL OTHER TOOL STRING COMPONENTS AND STAGED EQUIPMENT FOR CUT TOMORROW. 7/30/2013 MADE THE CUT AT A CCL STOP DEPTH OF 6904.5 WITH A 11.5 CCL TO CUT OFFSET. AFTER THE CUT, TOOL STRING BECAME STUCK. JARRED IT 16 TIMES. DECISION WAS MADE TO PULL OUT OF ROPE SOCKET. THE TOOL STRING LEFT IN HOLE IS 51.5' LONG AND WEIGHS 313.5 LBS. IT HAS A MAX OD OF 2.75". IT HAS A 1-3/8" FISHING NECK LOOKING UP. 8/1/2013 Pulled E-Line Toolstring @ 6866' RKB ( RCT Separated, — 5' Left Downhole/2.5" OD=Top of Fish); Run 2.80" LIB w/Inconclusive Results; Attempt to Latch Fish w/Overshot; Run 2.5" Hydrostatic Bailer w/Inconclusive Results; Correlate GLM#11 @ 6896' RKB. (Top of Fish is @ 6919' RKB —3' Below Tbg Cut) In Progress. 8/3/2013 Attempt to fish Fish w/Modified AVA Slv(2.80 Top NO-GO 2.75 Slv) @ 6923' RKB (7' Below Cut), lost spangs& Use oil jars to get free(AVA Slv full of fill w/scarring along the outside). Made two attempt's to bail fill w/2.5 bailer and unable to get past 6917' RKB (1' below cut/bailers returning full of fill). Job suspended awaiting Plan Forward. 8/9/2013 BAILED SCALE/SCHMOO @ 6871' SLM. SET CATCHER @ SAME. SET DV @ 6896' RKB, PULLED CATCHER. CIRCULATE @ 2 BPM DOWN TBG, UP IA @ 1100 PSI. RAN 2.25" CENTRALIZER, 5'x 1.5"STEM, 2.25" LIB TO 6886' SLM, LOST SPANG ACTION. LIB SHOWS DAMAGE, PRESUMABLY OF TBG CUT. READY FOR CTU. 8/11/2013 RIH WITH A DOWN JETTING NOZZLE TO WASH AROUND THE FISH AT 6934' CTMD, PUMPED 41 POOH CHASING SAND TO SURFACE, RUN FISHING BHA WITH A 2.55" ID POOR BOY OVERSHOT, UNABLE TO GET PAST THE TBG CUT AT 6901' CTMD, F/P TBG TO 3000', JOB IN PROGRESS. • • ConocoPhillips Time Log & Summary Wellview Web Reporting Report �ilin l`. tl Well Name: 1Q-11 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 8/19/2013 9:00:00 PM Rig Release: 8/26/2013 6:00:00 PM Time Logs 11MIN Date i' 'From' To01" Our S}Deeth E.Depth Phase Code ` Subcode T `Comment „AMP 08/19/2013 24 hr Summary Move out power packs&pipe sheds, Move mats and herculite, Move sub over well head, Lay mats for pipe shed and spot same, Lay mats for power pack,spot pits, pump room, motor,boiler complexes,set rock washer. Work on rig acceptance check list, berm rig and cuttings tank, Build scaffold, Commission air compressors, Hook lines in cellar, Take on 9.6 brine, load shed with 4"dp and 3.5"tbg. Pull BPV. 12:00 13:00 1.00 0 0 MIRU MOVE RURD P PJSM, Move power pack and pipe sheds, Move rig mats and herculite. 13:00 13:45 0.75 0 0 MIRU MOVE RURD P Move sub over 1Q-11. 13:45 16:45 3.00 0 0 MIRU MOVE RURD P Lay mats fpr pipe shed,spot same, lay mats for powerpack, spot pits, pump, motor and boiler complex's, set rochwasher. 16:45 21:00 4.25 0 0 MIRU MOVE RURD P PJSM,Work on rig acceptance check list, SIMOPS:berm returns tank and spot same, Build scaffolding,commission air compressors. 21:00 23:00 2.00 0 0 MIRU MOVE RURD P PJSM, Rig up circ hoses in cellar, Quick rinse pits,Finish commission air compressors, Rig up bails and elevators,take on 9.6 brine, load pipe shed with 4"dp. 23:00 00:00 1.00 0 0 MIRU WHDBO OTHR P PJSM, Rig up lubricator and test same to 2500 psi, Pull H BPV. R/D lubricator. IA=600 psi, OA= 125 psi. 08/20/2013 M/U lubricator and pull BPV, R/U and circ 9.6 KWF down tbg and take returns form IA. Set BPV and test to 1000 PSI. N/D tree and N/U BOPE, install blind rams. R/U and test BOPE to 250/3500 PSI,test witnessed by AOGCC rep. Chuck Scheve. 00:00 00:30 0.50 0 0 MIRU WHDBO OTHR P PJSM, Pull H BPV. R/D lubricator. IA=600 psi,OA= 125 psi. 00:30 00:45 0.25 0 0 MIRU WHDBO SFTY P PJSM, on killing well with 9.6 ppg brine. 00:45 01:15 0.50 0 0 MIRU WHDBO OTHR P Line up and test lines to tiger tank to 2500 psi. 01:15 04:15 3.00 0 0 MIRU WHDBO KLWL P Pump 9.6 ppg brine down tubing @ 2 bpm ICP=1070 psi,taking returns from IA,At 550 strokes had pressure increase to 2450 psi pressure is building and dropping off with 14-18 spm,Acts like the open valve on GLM is trying to plug off. Continue pumping at 14-20 spm keeping pressure below 2500 psi. FCP=2450 psi(Pumped 258 bbls of 9.6 ppg.) 04:15 04:45 0.50 0 0 MIRU WHDBO OWFF P Monitior well at tiger tank for flow for 30 min.. (Static) Page lof8 ' ;FJme;Logs yo-. " °II III,w oh 44 : D"ate 'I III, EtorrSiO'fi "' Dut '! S. Depth E.Depth Phase Code ` Subcode T''ItomMent "? I� III'nl,o■ 04:45 05:00 0.25 0 0 MIRU WHDBO SFTY P PJSM for R/D test lines to Tiger Tank and Pits. 05:00 05:45 0.75 0 0 MIRU WHDBO OTHR P R/D test lines. 05:45 06:00 0.25 0 MIRU WHDBO RTWH P Install H BPV and R/U and to IA BPV as per FMC rep. 06:00 06:15 0.25 MIRU WHDBO PRTS P Pressure test BPV in direction of flow to 1000 psi and chart same. 06:15 07:15 1.00 MIRU WHDBO NUND P Bleed pressure off void and control line. Remove scaffolding.R/U to N/D Xmas Tree. Make marks on tree for orientation and take pictures. 07:15 07:30 0.25 MIRU WHDBO SFTY P PJSM on N/D the Xmas tree. 07:30 08:45 1.25 MIRU WHDBO NUND P Disconnect control line and plug. install HP dart. 08:45 09:45 1.00 MIRU WHDBO NUND P Take bolts off studs on tubing spool. Bolts are rusted together. 09:45 14:30 4.75 MIRU WHDBO NUND P N/U adapter flange and BOPE. Cut riser to size. 14:30 16:30 2.00 MIRU WHDBO NUND P PJSM, install blind rams, hook up choke line and install riser. 16:30 17:15 0.75 MIRU WHDBO RURD P Rig up to test BOPE,fix leak in riser adapter. 17:15 22:00 4.75 MIRU WHDBO BOPE P PJSM, Rig down test joint, riser and adapter. Install silicone on API ring. Re-install riser and adapter flange. Rig up to test BOPE and grease choke manifold. 22:00 00:00 2.00 MIRU WHDBO BOPE P PJSM,test BOPE to 250/3500 PSI with 3-1/2"test joint for 5 min each. Test#1:Top pipe rams, CV 1,12,13 and 14. Test#2: Manual kill and lower IBOP, CV#9 failed.Test#3: Upper IBOP CV 5 and 11.Test witnessed by AOGCC rep Chuck Scheve. 08/21/2013 Cont testing BOPE to 250/3500 PSI. Pull hanger to floor and CBU. L/D 3-1/2"completion as per plan. Set wear bushing and M/U BHA. RIH P/U 3-1/2"tbg w/overshot t/2514',collars on tbg hanging up badly on wear bushing. POOH and remove wear bushing. Cont to RIH w/overshot. 00:00 03:00 3.00 0 0 MIRU WHDBO BOPE P Continue to test BOPE to 250/3500 PSI with 3-1/2"test joint for 5 min each.Test#4: CV 8, 10.Test#5: Dart valve,CV 4,6 and 7.Test#6: Floor valve, CV 2, HCR choke and manual Kill valve.test#7.Manual Choke valve,annular preventer. Test#8: Lower pipe rams.test#9: blind rams, Cv 3 and restest CV9. Accumulator test:System pressure=3,000 psi, pressure after closed=1,700 psi,200 psi attained in 43 sec,full pressure attained in 201 sec.5 Bottle avg= 1,950 psi. CV9 and flange under ram body failedpassed.Test witnessed by AOGCC rep Chuck Scheve. Page of 8 ✓ 'c Date S. Depth E.Depth Phase Code Subc e T A.Comment r 111 03:00 03:45 0.75 0 0 MIRU WHDBO RURD P R/D test equipment,test lines and suck out water from stack. 03:45 04:00 0.25 0 0 MIRU WHDBO SEQP P PJSM, pull dart and BPV as per Cameron Representative. 04:00 05:00 1.00 0 0 COMPZ RPCOM RURD P P/U control Line spool, handling tools,casing tong,elevators and slips. 05:00 06:30 1.50 0 6,907 COMPZ RPCOM PULL P M/U landing joint to Hanger and Kelly up. Back out LDS out and pull hanger to floor. Pull free @ 90k p/u weight. String weight=85k. Disconnect control line, R/U power tongs and L/D hanger. 06:30 08:00 1.50 6,907 6,880 COMPZ RPCOM CIRC P Circulate B/U @ 5 BPM,750 psi, 50%flow. Monitor well, overbalance. Decision made to circulate a total of one full B/U,still overbalance. Pump 20 bbls,9.8 ppg slug. (static) 08:00 09:45 1.75 6,880 4,987 COMPZ RPCOM PULL P POOH laying down 3.5"tubing(60 joints), SSSV and control line. Recovered 33 stainless steel CL bands. 1 band still in hole. 09:45 10:00 0.25 4,987 4,987 COMPZ RPCOM OTHR P Disconnect control line, R/D and send out to beaver slide. 10:00 10:15 0.25 4,987 4,987 COMPZ RPCOM OTHR P Install air slips,stripping rubber catcher and stripping rubber. 10:15 15:15 5.00 0 0 COMPZ RPCOM PULL P POOH laying down 3.5"tubing(160 joints)until cut joint. L/D a total of 220 joints, SSSV,2 pups, 11 GLMs and cut joint.6883.4' 15:15 16:15 1.00 0 0 COMPZ RPCOM OTHR P Clean and clear rig floor.Set wear ring in tubing spool. 16:15 17:00 0.75 0 0 COMPZ RPCOM SVRG P PJSM,Adjust brakes breaks on drawworks. 17:00 20:45 3.75 0 2,514 COMPZ RPCOM TRIP P PJSM, RIH to 2514'MD with 3.5" tubing joint from pipe shed on overshot without grapple in it. (using tubing string as guide for the upcoming fishing job on slickline). Tubing collars are hanging up on wear ring. Decision made to POOH and pull wear bushing. P/U=48K, S/O=48K 20:45 21:00 0.25 2,514 2,514 COMPZ RPCOM OWFF P Monitor well for flow. No flow. Prepare tool to POOH, install stripping rubber. 21:00 22:15 1.25 2,514 0 COMPZ RPCOM PULL P PJSM, POOH from 2514'MD to surface.Actual displacement=8.84 bbls,Calculated displacement=7.8 bbls. 22:15 22:45 0.50 0 0 COMPZ RPCOM RURD P Pull wear ring and inspect. No visible damage or wear. 22:45 00:00 1.25 0 1,403 COMPZ RPCOM TRIP PJSM, RIH with 3.5"tubing stands from derrick on overshot without grapple. X8/22/2013 RIH to top of stub and CBU,space out and set overshot on stub @ 6900'. R/U slickline and make multiple slickline runs, recovered RCT fish. R/D slickline and POOH w/tbg. Page 3 ot'8 • ► bate 'rorri? '70' Dur S. Depth'E.Depth Phase Code Subcocle. .T Gomm 'nt max. o 00:00 03:45 3.75 1,403 6,826 COMPZ RPCOM TRIP P PSJM and RIH with overshot on tubing stands from 1,403'MD to 2,509'MD and on tubing single from 2,509'MD to 6826'MD. 03:45 04:45 1.00 6,826 6,900 COMPZ RPCOM WASH P Wash down from 6,826'MD to 6,900' MD at 5 bpm,525 psi,48%flow. Tagging up at 6,900'MD. Set 5k down, observe 50 psi increase in SPP. Repeat tag @ 6,900'MD. P/U 3 feet and Circulate B/U 04:45 05:45 1.00 6,897 6,897 COMPZ RPCOM CIRC P Circulate B/U at 6 bpm,800 psi, 52%flow,well overbalance. Pump 20 bbls 9.8 ppg slug. Monitor well. Static. 05:45 06:15 0.50 6,899 6,900 COMPZ RPCOM TRIP P Space out, L/D 2 tubing joints. P/U 2 tubing pups and 1 tubing joint. Repeat tag at 6,900'MD.tubing set in slips. 06:15 06:30 0.25 6,900 6,900 COMPZ FISH SFTY P PSJM on P/U and R/U slickline. 06:30 07:30 1.00 6,900 6,900 COMPZ FISH FISH P P/U and M/U slickline as per Halliburton Rep. 07:30 08:45 1.25 6,900 6,900 COMPZ FISH FISH P RIH with 2.5"bailer on slickline and POOH as per Halliburton 08:45 09:15 0.50 6,900 6,900 COMPZ FISH FISH P R/D bailer and inspect. Decision made to RIH on slickline with mangnet. 09:15 10:45 1.50 6,900 6,900 COMPZ FISH FISH P RIH with magnet on slickline as per Halliburton and POOH. 10:45 11:00 0.25 6,900 6,900 COMPZ FISH FISH P R/D magnet and M/U LIB on slickline as per Halliburton. 11:00 12:45 1.75 6,900 6,900 COMPZ FISH FISH P RIH with LIB on slickline and POOH as per Halliburton. Inspect LIB(See Pictures in S drive). Monitor well via trip tank. 12:45 13:00 0.25 6,900 6,900 COMPZ FISH FISH P M/U overshot(2.55"ID,2.85"OD) 13:00 14:30 1.50 6,900 6,900 COMPZ FISH FISH P RIH with overshot on slickline, POOH. No success. 14:30 17:00 2.50 6,900 6,900 COMPZ FISH FISH P M/U and RIH with 2.5"bailer on slickline. POOH.found a bit of asphalti ne/pa rrafi n. 17:00 18:45 1.75 6,900 6,900 COMPZ FISH FISH P M/U and RIH with overshot with added weighted bars on slickline. POOH. No success 18:45 21:30 2.75 6,900 6,900 COMPZ FISH FISH P M/U and RIH with overshot on slickline. POOH. Retrieve the RCT fish and catcher assy. Break assy. 21:30 22:30 1.00 6,900 6,900 COMPZ FISH FISH P PJSM and RIH to install catcher. POOH 22:30 23:00 0.50 6,900 6,900 COMPZ FISH RURD P PJSM and R/D slickline. 23:00 00:00 1.00 6,900 6,763 COMPZ RPCOM TRIP PSJM and R/U power tongs. POOH tubing from 6900'MD to 6763'MD 08/23/2013 POOH with tubing, set&pressure test storm packer. N/D BOP. Change tubing spool and set tension into 7" casing. N/U BOP and retrieve storm packer.POOH w/3-1/2"tbg. 00:00 02:00 2.00 6,763 2,422 COMPZ RPCOM PULL P PJSM and POOH with 3.5"tubing from 6763'MD to 2422'MD. Page 4 of 8 Time Logs •Date From To Dur S. Depth E,depth"Phase. Code Subcode T Comment 111 02:00 03:45 1.75 2,422 0 COMPZ WHDBO MPSP P PJSM and M/U storm packer. P/U 3 joints 4"drill pipe and set as per Baker Rep. 03:45 04:15 0.50 0 0 COMPZ WHDBO PRTS P Pressure test Storm Packer to 2,000 psi on chart. 04:15 04:30 0.25 0 0 COMPZ WHDBO NUND P Drain stack, blow down kill line and choke line 04:30 04:45 0.25 0 0 COMPZ WHDBO SFTY P PJSM on N/D BOPE and Hydratight. OA pressure=160 psi. Bled to 0 psi. 04:45 06:00 1.25 0 0 COMPZ WHDBO RURD P N/D BOP. 06:00 08:00 2.00 0 0 COMPZ WHDBO NUND P Break bolts on McEvoy Genii'Tubing spool and observe some growth. R/U hydratight and use tool as per Hydratight Rep.Total growth=3 inches. R/D hydratight. 08:00 09:15 1.25 0 0 COMPZ WHDBO NUND P Pull tubing spool and pack off.Clean and work lock downs loose as per Cameron Rep. 09:15 09:45 0.50 0 0 COMPZ WHDBO NUND P Mobilize new tubing spool and wachs cutter to the cellar. 09:45 10:15 0.50 0 0 COMPZ WHDBO PULD P PJSM and P/U and M/U spear as per Baker Rep. 10:15 10:45 0.50 0 0 COMPZ WHDBO TRIP P RIH on spear and engage in 7" casing. P/U 130k with top drive to set 7"casing string with 95k in tension. 10:45 11:15 0.50 0 0 COMPZ WHDBO PULD P L/D spear as per Baker Rep. 11:15 12:00 0.75 0 0 COMPZ WHDBO OTHR P R/U wachs cutter as per Cameron Rep. 12:00 13:45 1.75 0 0 COMPZ WHDBO OTHR P Cut 7"stumps with wachs cutter. 13:45 15:45 2.00 0 0 COMPZ WHDBO NUND P P/U and M/U new tubing head and test to 600psi/3000psi for 5 min each.good test. 15:45 16:00 0.25 0 0 COMPZ WHDBO SFTY P PJSM for N/U BOP. 16:00 18:15 2.25 0 0 COMPZ WHDBO NUND P N/U BOP. 18:15 20:00 1.75 0 0 COMPZ WHDBO BOPE P PJSM and R/U to test break to 250psi/3500psi for 5 min each on chart. 20:00 20:30 0.50 0 0 COMPZ WHDBO RURD P R/D test equipment and set wear bushing in tubing spool. 20:30 22:00 1.50 0 0 COMPZ WHDBO MPSP P P/Us storm packer retrieval tool and retrieve same. L/D storm packer. 22:00 00:00 2.00 2,422 120 'COMPZ RPCOM TRIP P PJSM, POOH w/3-1/2"tbg f/2422' to 120'. 08/24/2013 RIH w/3-1/2"stacked packer completion to 2909'. Observed tbg packing off w/parrafin. POOH w/completion and M/U clean out BHA. RIH w/clean out BHA and tag tbg, circ around hot soap pill toi clean up wellbore. 00:00 00:45 0.75 120 0 COMPZ RPCOM TRIP P POOH with tubing from 120'MD, LID 8 singles and LID overshot to pipe shed. 00:45 01:00 0.25 0 0 COMPZ RPCOM OTHR P Clean and Clear rig floor. 01:00 01:30 0.50 0 0 COMPZ RPCOM PULD P Pull wear bushing,M/U X/O on wear bushing puller. 01:30 01:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM on running completion Page 5 of 8 ` FimejLorts • Date '?01r1From To our S. Deoth E.Depth Phase Code Subcode T Comment 01:45 02:00 0.25 0 0 COMPZ RPCOM PULD P Dress threads on Poor Boy Overshot 02:00 03:45 1.75 0 255 COMPZ RPCOM PULD P P/U Overshot, DS nipple, packer and GLM as per detail. M/U wear bushing and set. 03:45 07:30 3.75 255 3,435 COMPZ RPCOM RCST P Run completion with 30 stands of 3.5"tubing to 3435'MD. Parrafin is plugging inside the tubing.Call town. Decision was made to POOH to make a clean out run 07:30 09:30 2.00 3,435 120 COMPZ WELLPF TRIP T POOH with completion string from 2,909' MD to 121' MD. 09:30 09:45 0.25 120 0 COMPZ WELLPF PULD T L/D completion as per Baker Rep. 09:45 11:00 1.25 0 0 COMPZ WELLPF OTHR T Clean and clear rig floor,mobilize baker clean out BHA to rig. 11:00 11:15 0.25 0 0 COMPZ WELLPF SFTY T PJSM on P/U Baker clean out tools from beaver slide 11:15 12:00 0.75 0 0 COMPZ WELLPF PULD T Mobilize Baker tool to rig floor 12:00 12:30 0.50 0 0 COMPZ WELLPF SVRG T Service Rig. 12:30 12:45 0.25 0 0 COMPZ WELLPF PULD T PJSM, P/U clean out BHA as per Baker rep. 12:45 13:45 1.00 0 0 COMPZ WELLPF PULD T Continue to P/U Scraper run BHA as per Baker Rep. 13:45 20:45 7.00 0 6,899 COMPZ WELLPF TRIP T RIH with scraper/overshot BHA to 6914'MD nogo in overshot and set down 5k and confirm top of tubing @ 6899'MD.Actual displacement= 22.44 bbls,Calculated displacement=22.57 bbls. 20:45 21:15 0.50 6,899 6,899 COMPZ WELLPF RURD T PJSM, R/U Little Red and make up cement hose. 21:15 00:00 2.75 6,899 6,899 COMPZ WELLPF CIRC T Pressure test lines to 250/2500 PSI. Pump 200 bbls of 170°9.6 ppg brine with SAFESURF 0 to clean up well @ 2 BPM=150 PSI. 08/25/2013 Circulated well clean from paraffin. POOH w/clean out BHA. M/U and RIH w/3-1/2"stacked packer completion,tag tbg stub @ 6900'. P/U and spot 15 bbls of inhibited brine around lower completion. 00:00 00:45 0.75 6,899 6,899 COMPZ WELLPF CIRC T PJSM,allow hot SAFESURF 0 fluid soak in wellbore to help break up paraffin. 00:45 02:00 1.25 6,899 6,899 COMPZ WELLPF CIRC T Circ @ 6 BPM=950 PSI, 52%flow, increase pumps to 7 BPM= 1150 PSI,55%flow. Observed large amount of paraffin when first started pumping and very dirty fluid at bottoms up. Pump until fluid cleaned up. 02:00 02:15 0.25 6,899 6,899 COMPZ WELLPF OWFF T OWFF,static. 02:15 06:00 3.75 6,899 24 COMPZ WELLPF TRIP T POOH standing back 3-1/2"EUE work string f/6899'to 24'.Actual displacement=24.14 bbls, Calculated displacement=23.13 bbls. Page eof8 dime Logs ti q n dip , r, Date From a 'To Dura = S.Depth E.Depth Phase Code Subcode T Conilnent '11111!'' z 06:00 07:15 1.25 24 0 COMPZ WELLPF TRIP T Observed BHA hanging up inside wear bushing. BOLD's and drain stack, pull 6K over and pull to floor. Observed wear bushing damaged, could not remove from BHA. Clean and L/D BHA as per Baker rep. 07:15 08:00 0.75 0 0 COMPZ WELLPF OTHR T Clean and clear rig floor,wait on wear bushing. 08:00 08:30 0.50 0 0 COMPZ WELLPFSVRG T Service rig. 08:30 12:00 3.50 0 0 COMPZ RIGMNT RGRP T Repair top drive, install new incoder. 12:00 16:45 4.75 0 3,435 COMPZ WELLPF RCST T P/U Overshot, DS nipple,packer and GLM as per detail. M/U and set wear bushing. Run completion with 30 stands of 3.5"tubing to 3435'MD. 16:45 21:00 4.25 3,435 6,795 COMPZ RPCOM RCST P Continue run completion with a total of 70 stands of 3.5"tubing to 6795' MD. 21:00 21:45 0.75 6,795 6,795 COMPZ RPCOM PULD P Retrieve wear bushing. 21:45 23:00 1.25 6,795 6,900 COMPZ RPCOM TRIP P Cont RIH,set down on tubing stub on joint#219 @ 6900'MD w/1'of swallow. Make multiple attempts by rotating pipe 1/4 turn and setting down 5K,10, and 12K to swallow more tubing with overshot, no success. Discuss options with town, packer will be set w/1'swallow. R/U to pump inhibited brine. P/U=80K, S/O=73K.Actual displacement= 22.44 bbls, Calculated displacement=22.58 bbls. 23:00 00:00 1.00 6,900 6,900 COMPZ RPCOM CIRC P Pump 15 bbls of 9.6 ppg inhibited brine @ 5 BPM=600 PSI,displace around overshot up over PBR. 08/26/2013 Set packer and sheared PBR,space out and land hanger.Test tbg and hanger to 3500 PSI on chart. Set BPV and N/D BOPE, N/U tree and test to 5000 PSI. Pump inhibited brine and freeze protect. U-tube and secure well. RDMO 00:00 01:30 1.50 6,900 6,850 COMPZ RPCOM PACK P PJSM,drop ball and rod, pressure up and observe Packer set @ 2900 PSI. Bleed pressure down to 2500 PSI, pressure up IA to 3500 PSI to test packer,good. Bleed off pressure to 0 and OWFF,pressure up to 1500 PSI and shear out PBR,observed shear @ 17K over pull. Pull out of PBR, locate top of PBR while pumping @ 1.5 BPM. Locate fully and obtain space out depth. 01:30 03:30 2.00 6,850 0 COMPZ RPCOM HOSO P Make up space out pups,3.04'off fully located position. P/U and M/U tbg hanger. Drain stack and blow down circ lines. Land hanger and RILD's. Page 7 of 8 ` Time Logs "' 7A �1I Date - From To Dur S.Debth'°`E.Depth Pshase Code Subcode T Con ment 03:30 05:30 2.00 0 0 COMPZ RPCOM PRTS P Test tubing to 3500 PSI f/15 min on chart,good. Bled pressure down to 2500 PSI on tbg and pressure up IA to 3500 PSI for 30 min,good. Bled down IA and tbg to 0 PSI. Ramp up IA to shear SOV,observed shear @ 2100 PSI. 05:30 06:00 0.50 0 0 COMPZ RPCOM OWFF P Back out landing joint and L/D 1 stand of 3-1/2"tbg in derrick. OWFF, static. 06:00 06:15 0.25 0 0 COMPZ WHDBO PRTS P Set BPV and test in direction of flow to 1000 PSI. Clean and clear rig floor. 06:15 06:30 0.25 0 0 COMPZ WHDBO OTHR P Cont to clean and clear rig floor. 06:30 06:45 0.25 0 0 COMPZ WHDBO SFTY P Hold PJSM on N/D BOPE. 06:45 09:00 2.25 0 0 COMPZ WHDBO NUND P N/D BOPE and N/U tree as per Cameron rep. 09:00 09:30 0.50 0 0 COMPZ WHDBO PRTS P Test adapter flange to 5000 PSI f/10 min,good. 09:30 10:30 1.00 0 0 COMPZ WHDBO PRTS P R/U and test tree,tbg hanger and packoffs to 250/5000 PSI on chart, good test. 10:30 11:00 0.50 0 0 COMPZ WHDBO SEQP P Pull TWC as per Cameron rep. 11:00 11:15 0.25 0 0 COMPZ WHDBO SFTY P Hold PJSM on pump inhibited seawater and diesel freeze protect with Little Red. 11:15 13:30 2.25 0 0 COMPZ WHDBO FRZP P Pressure test lines to 2500 PSI, good. Freeze protect well as follows, pumped 175 bbls of inhibited seawater and 80 bbls of diesel down IA taking returns up tbg to Rockwasher 13:30 15:00 1.50 0 0 COMPZ WHDBO FRZP P U-tube well, SIMOPS-blow down steam, clean pits,drip tray and cellar box. 15:00 15:30 0.50 0 0 COMPZ WHDBOOTHR P Off load Rockwasher and clean. 15:30 16:45 1.25 0 0 COMPZ WHDBO RURD P R/D lines in cellar. P/U lubricator and test to 1500 PSI,good. Set"H" BPV. 16:45 17:15 0.50 0 0 COMPZ WHDBO RURD P L/D lubricator,dress tree and secure well. 17:15 18:00 0.75 0 0 DEMOB MOVE DMOB P PJSM, R/D and prep to move. Rig released @ 18:00 hrs. Page 8of8' •1Q-11 Post-Rig Well Work Summary • DATE- SUMMARY 8/22/2013 RIH to top of stub and CBU, space out and set overshot on stub @ 6900'. R/U slickline and make multiple slickline runs, recovered RCT fish. R/D slickline and POOH w/tbg. 8/22/2013 (( RIG JOB ON DOYON 141 )) FISHED BROKEN RCT @ 6934' SLM. SET 2.73"x 123" CATCHER @ 6944' SLM. JOB COMPLETE. 8/23/2013 POOH with tubing, set& pressure test storm packer. N/D BOP. Change tubing spool and set tension into 7" casing. N/U BOP and retrieve storm packer.POOH w/3-1/2"tbg. 8/24/2013 RIH w/3-1/2" stacked packer completion to 2909'. Observed tbg packing off w/parrafin. POOH w/ completion and M/U clean out BHA. RIH w/clean out BHA and tag tbg, circ around hot soap pill to clean up 8/25/2013 Circulated well clean from paraffin. POOH w/clean out BHA. M/U and RIH w/3-1/2" stacked packer completion, tag tbg stub @ 6900'. P/U and spot 15 bbls of inhibited brine around lower completion. 8/26/2013 Set packer and sheared PBR, space out and land hanger. Test tbg and hanger to 3500 PSI on chart. Set BPV and N/D BOPE, N/U tree and test to 5000 PSI. Pump inhibited brine and freeze protect. U-tube and 8/28/2013 (PRE-RWO) BARRIER CONFIRMATION (PASSED). 9/7/2013 PULLED RHC PLUG FROM 6898' RKB. PULLED SOV FROM 6793' RKB, SET DV @ SAME. PULLED CATCHER FROM 6964' RKB. BAILED FILL FROM WRP @ 6968' RKB W/ PUMP BAILER & EQUALIZING SNORKLE. UNABLE TO EQUALIZE WRP. IN PROGRESS. 9/8/2013 MADE MULTPILE 2.5" HYDROSTATIC BAILER RUNS TO WRP. PULLED 2.78"WRP FROM 6968' RKB. LRS PERFORMS MITIA TO 2500 PSI, PASS. COMPLETE. • ww„\ i%%�s� A THE STATE Alaska Oil Gas ` „ALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue ALASY' Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Jonathan Coberly SCANNED NCB\ 4) 8 L013 Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1Q-11 Sundry Number: 313-351 Dear Mr. Coberly: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, la ).e.,t„.}16,c_____ Cathy P. roerster �� Chair DATED this f 5 day of August, 2013. Encl. STATE OF ALASKA q/ \' • A•KA OIL AND GAS CONSERVATION COMMON >7 esilI113 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell (` Change Approved Program r Suspend r Rug Perforations r Perforate r Rill Tubing ", Time Extension V Operational Shutdown r Re-enter Susp.Well j Stimulate r Alter casing Other: 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Development [ Exploratory 184-199 • 3.Address: Stratigraphic r Service - • 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-21216-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No p 1Q-11 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25641 • Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): ' 7740 • 6295 none 7410' Casing Length Size MD TVD Burst Collapse CONDUCTOR 65 16 101' 101' SURFACE 3635 9.625 3670' 3499' PRODUCTION 7687 7 7720' 6282' Perforation Depth MD(ft): , Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7120-7212,7224-7232,7366-7450,7510-7528 5880-5944,5953-5958,6050-6107,6146-6158 3.5 J-55 7294 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER FHL PACKER • MD=6954 TVD=5761 PACKER-BAKER FB-1 PACKER • MD=7273 TVD=5987 SSSV-BAKER FVL SSSV . MD=1905 TVD=1906 12.Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program IT BOP Sketch r Exploratory r Stratigraphic I Development r Service ( , 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/17/2013 Oil I- Gas I WDSPL IT Suspended I 16.Verbal Approval: Date: WINJ GINJ r WAG Pl.4 Abandoned Commission Representative: GSTOR IT SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jonathan Coberly @ 265-1013 Email: Jonathan.CoberIvAcoD.com Printed Name Jonathan Cob I Title: Sr.Wells Engineer Signature Phone:265-1013 Date 7-3-2613 Commission Use Only // 1 Sundry Number:S� Conditions of approval: Notify Commission so that a representative may witness ////// Plug Integrity ""` BOP Test VMechanical Integrity Test ( Location Clearance I RBDMS AUG - 2 ZU1 Other: ,.0/J fr$t 71"0 3 5-OO /J5 c ft t` �Ct / 6 7G�-' fZSStdf M ! TltF rt r,1rtd VVarier fo srf eckr"-vp b a5dI above Ivpper Ir7 j r d ��► . Spacing Exception Required? Yes ❑ No Subsequent Form Required: 1 d -- 4_6,4 ,-e 1 4pp V APPROVED BY Approved by: �/�7�t/L! COMMISSIONER THE COMMISSION Date: g-/'"/3 Approved application is valid for 12 months from tine ate of approval. Form 10-403(Revised 10 012) ra:: 0)) H Submit Form and Attachments in Duplicate ii‘1aS\O oRIGIN ,,� 1\wr� • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 July 3,2013 Commissioner Dan Seamount State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Injector 1Q-11 (PTD 184-199). 1Q-11 was completed into the Kuparuk A, B, and C sand intervals in 1985. 1Q-11 is a water and MI injector that provides pressure support to its surrounding wells. On 1/5/2011 the well was shut in due to J- 55 surface casing concerns. 1Q-11 was brought back online on 5/13/2013 and has been only injecting water under a high pressure pilot waiver on the OA since. By remediating this well we will restore integrity to the tubing and IA and allow the injection of water and MI without waiver. On 6/27/2012 the well failed a MIT-T and IA-DDT. A CMIT TxIA and an updated SBHP are planned for pre-rig. To return the well to un-waivered water and MI injection,the well has been identified as a candidate for a rig workover. The plan for this rig workover is to pull the existing 3 'A" tubing, upgrade the tubing head, and install a new 3 'A"completion with a stacked packer. This new completion will restore both the tubing and packer barriers. The most recent SBHP in the combined Kuparuk A/C interval taken 5/31/2012 measured 2,511 psi at 6,064' TVD is equivalent to an 8.0 ppg EMW. An updated combined SBHP will be obtained during pre- rig work. The current plan is to use 9.6 ppg brine as KWF, but this can be updated based on the new SBHP. A plug will be installed pre-rig in the selective to minimize fluid losses to the reservoir. If you have any questions or require any further information, please contact me at 265-1013 or Jonathan.Coberly@conocophillips.com. Sincerely, ^r/I, Jonathan Coberly Wells Engineer CPAI Drilling and Wells • • 1Q-11 Rig Workover, P&R Tubing w/ Stacked Packer (PTD #: 184-199) Current Status: Kuparuk well 1Q-11 is a Kuparuk A,B,&C sand injector. The well is currently injecting water with a 1,000psi HPP waiver on the OA. Scope of Work: Cut tubing above PBR pre-rig, pull 3 '/2" tubing, scrape the 7" casing, and install new 3 'A" tubing with a stacked packer completion. General Well info: MASP: 1905 P si Reservoir pressure/TVD: Kuparuk A,B,&C-Sand—2,511 psi/6,064' TVD(8.0 EMW)measured 5/31/2012(a new SBHP will be obtained pre-rig) Wellhead type/pressure rating: McEvoy Gen III,3 1/8"Tree,7 1/16"5M tubing head/11"3M casing head Doyon 141 BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: MIT-OA—passed on 5/28/2013 MIT-IA—passed on 5/28/2013 MIT-T—Failed on 6/27/2012 T-DDT—Passed on 6/27/2012 IA-DDT—Failed on 6/27/2012 Packoff tests and CMIT TxIA are scheduled for pre-rig well work Well Type: Injector Estimated Start Date: August 13,2013 Production Engineers: David Lagerlef/Dana Glessner Workover Engineer: Jonathan Coberly(265-1013/Jonathan.Coberly @conocophillips.com) Proposed Pre-Rig Work: Slickline: 1. Get updated SBHP. 2. Pull DV from lower GLM. E-Line: 1. Set plug and catcher in tubing below FHL packer. 2. CMIT TxIA to 3,500 psi. 3. Fire string shot and cut tubing above PBR. Other: 1. PT IC packoffs. FTLDS. 2. Set BPV. Proposed Rig Work: 1. MIRU. 2. Pull BPV. Circulate KWF until well is dead. 30 minute no flow test. 3. Install BPV. PT IA. ND tree. 4. Install blanking plug. NU BOPE.Function and PT BOP rams,annular,and choke manifold to 250/3,500 psi. 5. Pull the blanking plug. Pull BPV. Verify that the well is static. • . 6. MU landing joint.BOLDS.Pull tubing hanger. 7. Reverse circulate to clean well. Monitor to ensure well is dead. 8. POOH with completion. MU storm packer. Set storm packer with tubing hanging below. POOH with packer setting tool. Bleed the OA pressure to 0 psi. PT storm packer. Bleed casing pressure to 0 psi. ND BOPE. ND tubing head. PT packoff to 250/3,000 psi(casing head is rated to 3,000 psi). NU tubing head. NU BOPE. Test BOPE to 250/3,500 psi. TIH and release storm packer. POOH laying down the tubing and storm packer. 9. RIH with tubing and casing scraper/washover assembly to the top of the cut tubing stub. POOH. 10. RIH with new 3 '/2"stacked packer/overshot completion to the tubing stub. "` 11. Spot corrosion inhibited fluid below the bottom GLM to the end of the poor boy overshot. Engage overshot onto the tubing stub. Space out. Drop the ball and rod. Pressure up on the tubing to set the packer. PT the IA to 3,500 psi. Shear out of PBR. Circulate the well over to corrosion inhibited seawater. 12. Land completion in PBR. Space out completion. 13. MU and land tubing hanger. RILDS. 14. PT tubing to 3,500 psi. Bleed tubing pressure to 2,500 psi. PT IA to 3,500 psi for 30 minutes and record casing pressure test on chart recorder. 15. Bleed IA to 0 psi,bleed tubing to 0 psi. Shear the SOV.Monitor well for 30 minutes. 16. Pull landing joint. Install a two way check. Pressure test IA. 17. ND BOPE. NU tree. 18. Pressure test tree and tubing hanger packoffs to 250/5,000 psi. Remove TWC. 19. Freeze protect T and IA. Set BPV. 20. RDMO. Proposed Post-Rig Work: Other: 1. Pull BPV. Slickline: 1. Pull SOV and replace with DV. 2. Pull ball and rod. 3. Pull RHC plug. 4. RIH and pull catcher from the top of plug. 5. RIH and pull plug. Other: 1. Reset the well houses and flow lines. 2. Turn well over to Operations. li • • ConocoPhillips Well: 1Q-11 2013 RWO PROPOSED COMPLETION L API: 500292121600 Conductor: PTD: 184-199 16", 62.5#, H-40 Welded to 101' RKB Wellhead: McEvoy Gen III Retrofit to Gen IV Surface Casing: DS 4-- 9 5/8", 36.0#, J-55 BTC to 3,670' RKB Production Tubing: Production Casing: 3 '/z", 9.3#, L-80, 8rd, EUE 7", 26.0#, J-55 BTC to 7,720' RKB — 2.875"CAMCO'DS'Nipple 4—CAMCO 1.5"MMG GLM I- - 4- Baker PBR • I. r 4_ Baker FHL Packer DS 4—2.813"CAMCO'DS'Nipple ila 4— Baker Packoff Overshot I �-I 4— Baker PBR l 2 / 4— Baker FHL Packer 615 A /64 Perforations: AVA Ported Nipple w/1.375" AVA ~-ID TPC Sleeve Installed MD Zone 7120' Kuparuk-C Injection Mandrel w/1.937" 120'-7212' Ku p ♦—Tubing Patch Installed 7224'-7232' Kuparuk-B _ _ 7366' 7450' Kuparuk-A = = 4—Carbide Blast Rings 7510'-7528' Kuparuk-A = _ 4—Injection Mandrel '_ :' 4—Baker FB-1 Permanent Packer w/SBE Directional: Max Incline: 49.7° @ 7600' le 4.6° 2300' D �_2.75"ID CAMCO'D'Nipple w/ Max Dogleg:9 @ 1.812"ID Nipple Reducer sos 4—Baker Shear Out Sub A t Fill at: 7,411' RKB Last Updated: 3-Jul-13 TD: 7,740' RKB Updated by: JRC KUP , 1Q-11 • ConocoPhillips f \ Well Attributes Max Angle&MD TD )t,C Wellbore API/UWI Field Name Well Status Inc!(°) MD(ftKB) Act Btm(ftKB) 500292121600 IKUPARUK RIVER UNIT INJ 49.68 7,600.00 7,740.0 Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date Well conr.g:-1a-11,sm/2013 z:34:22 PM SSSV:LOCKED OUT Last WO: 43.31 1/5/1985 Schemata-Actual Annotation Depth(ftKB) I End Date Annotation Last Mod...End Date Last Tag:SLM 7,365.0 5/31/2012 Rev Reason:PULL WRP,WAIVERED WELL haggea 5/20/2013 Casing Strings HANGER,32 f Casing Description String 0... 'String ID...Top(ftKB) Set Depth(1_.Set Depth(TVD)...String Wt...String... String Top Thrd CONDUCTOR 16 15.062 36.0 101.0 101.0 6250 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(L..Set Depth(TVD)...String Wt...String...String Top Thrd il SURFACE 9 5/8 8.921 35.3 3,670.2 3,498.8 36.00 J-55 BTC "I; Casing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(TVD)...String Wt..String...String Top Thrd PRODUCTION 7 6.276 33.1 7,719.6 6,282.1 26.00 J-55 BTC Tubing Strings Tubing Description String 0... String ID...Top(MKS) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR. TUBING 3 1/2 2.992 32.2 7,294.0 6,001.4 9.30 J-55 EUE 8RD IPC 36-101 - Completion Details Top Depth SAFETY VLV, 1.906 0..i (TVD) Top Intl Nomi... i Top(ftKB) ("KB) (°) Item Description Comment ID(in) 32.2 32.2 0.03 HANGER MCEVOY TUBING HANGER 3.500 GAS LIFT, 1,906.2 1,905.8 2.02 SAFETY VLV BAKER FVL SAFETY VALVE(LOCKED OUT 3/10/95) 2.810 1,981 6,940.3 5,752.0 44.81 PBR BAKER PBR 3.000 IIII GAS LIFT 3 2,769 11= 6,953.7 5,761.4 44.77 PACKER BAKER FHL PACKER 3.000 IIII 7,106.1 5,870.0 44.38 BLAST RINGS CARBIDE BLAST RINGS(5) 2.992 GAS LIFT, ;., Nore4 7,272.5 5,986.6 46.42 LOCATOR BAKER LOCATOR SUB 3.000 3,064 IIIIII 7,273.3 5,987.2 46.43 PACKER BAKER FB-1 PACKER 4.000 GAS3!455 7,276.6 5,989.5 46.47 SBE BAKER SEAL BORE EXTENSION 3.000 1 7,287.7 5,997.1 46.60 NIPPLE CAMCO D NIPPLE NO GO 2.750 J 1 7,293.11 6,000.9 46.67 SOS BAKER SHEAR OUT SUB 2.992 SURFACE, Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.) 35-3,670 _� Top Depth (TV0) Top Ine! GAS LIFT, y Top(ftKB) (ftKB) (°) Description Comment Run Date ID(in) 3.867 �- 6,985.0 5,783.6 44.67 PATCH Alpha 21.68'Tubing Patch;w/AVA Ported Nipple @ 6989'; 2/7/1993 1.875 GAS LIFT, emr3 Setover GLM#12(6985') 4,305 6,992.5 5,789.0 44.64 SLEEVE-C AVA TPC Sleeve 1.875 X 1.387 12/7/2005 1.375 GAS LIFT, 7,057.0 5,834.6 43.71 PATCH Alpha 21.68'Tubing Patch;Set over GLM#13(7058') 2/7/1993 1.937 4,741 . :j 7,287.7 5,997.1 46.60 REDUCER AVA NIPPLE REDUCER 1/25/1993 1.812 GAS LIFT, 7,410.0 6,080.0 48.58 FISH Missing Valve Parts:Downhole 7/17/1991 GAS LIFT, Perforations&Slots 5,765 Shot Top(ND) Btm(TVD) Dens GAS 6IFI ___ Top(ftKB)Btm(ftKB) (ftKB) (MB) Zone Date (oh.-- Type Comment 7,120.0 7,212.0 5,879.9 5,944.1 C-4,C-3,C-2, 2/2/1985 12.0 IPERF 5"DA Csg Gun;120 deg.phasing GAS LIFT, C-1,10-11 6' 7,224.0 7,232.0 5,952.6 5,958.3 UNIT B,10-11 2/2/1985 12.0 IPERF 5"DA Csg Gun;120 deg.phasing 7,366.0 7,450.0 6,050.4 6,106.6 A-4,A-3,10-11 2/2/1985 4.0 IPERF 4"DA JJ Csg Gun;120 deg.phasing PB6.6,940 7,510.0 7,528.0 6,146.1 6,157.8 A-2,10-11 22/1985 4.0 IPERF 4"DA JJ Csg Gun;120 deg.phasing PACKER,6,954 _ Notes:General&Safety PATCH,6,985 End Date Annotation SLEEVE-C, 10/7/2010 NOTE:View Schematic w/Alaska Schematic9.0 6993 INJECTION, \ 5/10/2013 NOTE:Waivered Well T x IA Communication"Water Injection Only" 6.993 PATCH,7,057 INJECTION. ; 7.065 IPERF,A ar 7,120-7712 -773 7,2247,232 INJECTION, ID 7,253 LOCATOR. 7,272 PACKER.7273 SBE,7277 Mt la REDUCER. IE 7,288 ' NIPPLE.7.288 Mandrel Details Top Depth Top Port SOS,7793 g (TV0) Intl 00 Valve Latch Size TRO Run N...Top(ftKB) (ftKB) (°) Make Model (in) Sery Type Type On) (psi) Run Date Corn... IPERF, - - 1 1,961.4 1,960.9 2.14 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 2/1/1985 7,366-7.450 FISH,7,410 $ 2 2,769.3 2,750.8 21.04 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 2/1/1985 :; _ 3 3,084.2 3,034.8 29.30 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 2/1/1985 EN- 4 3,454.7 3,339.8 39.43 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 2/1/1985 5 3,867.1 3,635.0 46.32 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 2/1/1985 IPERF, 6 4,305.1 3,940.6 45.37 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 2/1/1985 7,510-7,526 _ 7 4,740.5 4,240.9 46.48 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 2/1/1985 8 5,182.4 4,545.8 46.28 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 2/1/1985 9 5,764.8 4,946.9 46.40 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 2/1/1985 PRODUCTION, 10 6,347.6 5,344.9 47.51 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 2/1/1985 TD,O 7,740 7,740 4 • KUP 1Q-11 • ConocoPhillips Ataska,lnc (oovxoPNrlaps ° KB-God(R) Rig Release Date "' 43.31 1/5/1985 Well Cenral -10 , 232013 Sche-11matic 51-Aclual 2:34:22 PM HANGER.32 1 CONDUCTOR, 36101 SAFETY VLV, C..•• ••• { 1,906 C • GAS LIFT, 4 1.961 GAS LIFT. .769 2,769 GAS LIFT, 3.084 GAS LIFT, 3,455 SURFACE. .1 i l 35-3.670 GAS LIFT, 3,867 GAS , 4,305 GAS LIFT, 4,741 Sill GAS LIFT, 5,182 GAS LIFT, 5.765 GAS LIFT, 6.348 —.. s.: .. GAS LIFT, 6,896 PBR,6.940 -.._. . • PACKER,6,954 PATCH,6,985 SLEEVE-C,� 6,993 INJECTION, {{I 6,993 PATCH.7057 7{ INJECTION. 7.065 33- IPERF. 7,120-7,212 IPERF, 7,22a7,232 • INJECTION3, 7,25 LOCATOR, 7,272 PACKER,7,273 SEE.7,277 REDUCER. 7,288N NIPPLE,7,288 Mandrel Details Top Depth Top Port SOS,7,293 .'-. g (TVD) Incl OD Valve Latch Size TRO Run N...Top(ftKB) (EKE) (°) Make Model (in) Bery Type Type (in) (psi) Run Date Corn... 7, IPERF, 11 6,896.0 5,720.8 45.48 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 2/1/1985 3667,450 FISH.7,410 • 12 6,992.5 5,789.0 44.64 MERLA TMPD 1 1/2 INJ PATCH 0.000 0.0 12/6/2005 13 7,065.3 5,840.7 43.83 MERLA TMPD 1 12 INJ PATCH 0.000 0.0 2/1/1985 14 7,253.3 5,973.2 46.19 MERLA TMPD 1 1/2 INJ DMY 0 0.000 0.0 2/1/1985 PERF, 7.510.ERF, PRODUCTION. 33-7,720 TO,7,740 • • • Ferguson, Victoria L (DOA) From: Coberly,Jonathan <Jonathan.Coberly @conocophillips.com> Sent: Thursday,July 25,2013 4:55 PM To: Ferguson,Victoria L(DOA) Subject: RE: 1Q-11 Workover(PTD 184-199, Sundry 313-351) Victoria, Thanks for asking. The bottom of the packer is proposed to be set at approximately 6,885' RKB which is 235' above the top perforation. From the 1-21-1985 CBL the cement top in the production casing is at 5800'with good cement bond to formation and casing to 5940'. Can we get a variance to set the packer at this new depth"'35' above the top perforation? The existing packer has passed a MIT-IA on 5-28-2013, but failed the IA-DDT on 6/27/2012. Thank you, Jonathan Coberty Senior Wells Engineer ConocoPhillips Alaska Inc. 700 G Street(ATO-20-2038) Anchorage,AK 99501 Phone:907-265-1013 Cell:907-538-8398 From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent: Thursday, July 25, 2013 10:49 AM To: Coberly, Jonathan Subject: [EXTERNAL]1Q-11 Workover(PTD 184-199, Sundry 313-351) Jonathan, At what depth will the new packer be set? 20 AAC 25.412(b) reads"The packer must be placed within 200 feet measured depth above the top of the perforations". Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferq use naa l aska.gov 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday,June 14,2013 ��( �( l I 3 P.I.Supervisor j SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1Q-1 I FROM: Lou Grimaldi KUPARUK RIV UNIT IQ-11 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry--1 NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Q-11 API Well Number 50-029-21216-00-00 Inspector Name: Lou Grimaldi Permit Number: 184-199-0 Inspection Date: 5/28/2013 Insp Num: mitLG130528125050 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well i J TVD s75s - IA 700 700 875 875 T yp e In' PTD I841990 ',Type Test SPT'Test psi 1800 OA 3a9 I�sa 1947 1�a 1 Interval ,REQVAR P/F P Tubing 1300 . 1300 1300 1300 - MITOA for compliance with AIO 2B.077.Cre Notes: p w well prepared for test.OA pilot not tested today as SVS crew was unavailable(crew change), - will schedule for later date..4 bbl's diesel pumped,.5 bbl's returned.See"mitLG130528111513"for MIT IA.Packer depth is Tubingxlnner. SatalED FEB 2 0 2014 Friday,June 14,2013 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday,June 14,2013 P.I.Supervisor 6e71 6/1-01,3 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IQ-I1 FROM: Lou Grimaldi KUPARUK RIV UNIT IQ-I l Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IQ-I I API Well Number 50-029-21216-00-00 Inspector Name: Lou Grimaldi Permit Number: 184-199-0 Inspection Date: 5/28/2013 Insp Num: mitLG130528111513 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1Q-11 'Type Inj W .'TVD 5755 IA 1545 3300 - 3185 3160 Type P— - -- � r- 1841990 SPT 2400 510 i 720 720 710 PTD T e Test Test psi l OA l Interval ,REQVAR P/F P Tubin g 1300 1 1300 1300 1 1300 - Notes: MIT IA for compliance with AIO 2B.077.trew well prepared for test.OA pilot not tested today as SVS crew was unavailable(crew change),.. Will schedule for later date. 1.7 bbl's diesel pumped,1.5 bbl's returned.See subsequent record for MIT OA. , SCANNED FEB 2 O 2014 Friday,June 14,2013 Page 1 of 1 • • sirw o[F SEAN PARNELL, GOVERNOR �aT ALASKA OIL .AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 CORRECTED CANCELLATION ADMINISTRATIVE APPROVAL NO. AIO 2B.058 Ms. Kelly Lyons ` `- ProblemWell Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 RE: Corrected Cancellation of Administrative Approval AIO 2B.058 Kuparuk River Unit Well 1Q-11 (PTD 1841990) Kuparuk River Oil Pool Dear Ms. Lyons: Pursuant to ConocoPhillips Alaska Inc. (CPAI)'s request dated July 13, 2011, the Alaska Oil and Gas Conservation Commission (Commission) hereby cancels Administrative Approval AIO 2B.058, which allows continued water injection in Kuparuk River Unit (KRU) well 1Q -11. This well exhibited tubing by inner annulus (TxIA) communication and CPAI did not at the time propose repairing the well to eliminate the problem. The Commission determined that water injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. CPAI has since determined not to operate the well while continuing to perform diagnostic testing. Consequently, Administrative Approval AIO 2B.058 no longer applies to operation of this well. Instead, injection into KRU 1Q -11 will be governed b .rovisions of the underlying AIO No. 2B. DONE at Anchorage, Alaska and dated July 20, 2011. 0 r/ , / %� Daniel T. Se. ount, Jr. Cathy '. Foerster a 'r' ► .rman Commissioner, Chair Com issioner Commi sioner ski uee I dt 9 , t. E ,..,: .,-,.. , ' AMMO • • RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsi- deration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the appli- cation for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or deci- sion on reconsideration will be the FINAL order or decision of, the Commission, and it may be appealed to superior court. That ap- peal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distri- butes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. �� fib=' Fa Fl, ��µ SEAN PARNELL, GOVERNOR tom t t ALASKA OI L AND GAS GA ►�t �r � 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 2B.058 REVISED Mr. Martin Walters Problem Wells Su AAA FEB I 1 Z D 1 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 RE: KRU 1Q -11 (PTD 1841990) Request for Administrative Approval Kuparuk River Oil Pool Dear Mr. Walters: In accordance with Rule 9 of Area Injection Order (AIO) 2B, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby GRANTS ConocoPhillips Alaska Inc. (CPAI)'s request for administrative approval to continue water injection in the subject well. This document clarifies the MIT requirement of Rule 3. No other changes are made. Kuparuk River Unit (KRU) 1Q -11 exhibits tubing by inner annulus communication. Diagnostic testing has confirmed communication; however it has not been possible to positively locate the leak. Testing also confirms the communication is one -way, from the tubing to the inner annulus (IA). The Commission finds that CPAI does not intend to perform repairs at this time, deferring until such time as the leak can be located and necessary intervention determined. Reported results of CPAI's diagnostic procedures and wellhead pressure trend plots indicate that KRU 1Q- 11 exhibits at least two competent barriers to the release of well pressure. The pressure history provided by CPAI with their request for administrative approval shows that the IA pressure has the potential to equalize with the injection pressure. CPAI requests the Commission approve inner annulus pressure equalized up to an injection pressure o f 3000 psi, pP p q P J P P which is approximately 60% of the production casing's minimum internal yield pressure rating. Should the well develop communication to the outer annulus (OA), the 3000 psi injection pressure would represent 85% of the surface casing's minimum internal yield pressure rating. Outer annulus pressures must be monitored and engineering controls must be installed to assure ongoing integrity of the surface casing. With such in place, the Commission believes that the well's condition would not compromise overall well integrity so as to threaten human safety or the environment. AIO 2B.058 Revised • • February 9, 2011 Page 2 of 3 AOGCC's administrative approval to continue water injection only in KRU 1Q -11 is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily; 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. CPAI shall perform an MITIA or TxIA CMIT with tubing plug below uppermost packer every 2 -years to the maximum anticipated injection pressure; 4. CPAI shall perform an MIT -OA every 2 years to 1800 psi; 5. Inner annulus (IA) pressure not to exceed 3000 psi; 6. Outer annulus (OA) pressure not to exceed 1000 psi. 7. Within 30 days of the effective date of this approval, CPAI shall install, maintain and operate automatic well shut -in equipment linked to the well's outer annulus pressure. The actuation pressure shall not exceed 1,000 psi. Testing of the shut -in equipment (surface safety valve and mechanical or electrical pressure detection device) shall be performed in conjunction with production well pilots and safety valves; 8. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 9. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 10. The MIT anniversary date is July 12, 2009. ISKAo DONE at Anchorage, Alaska and dated February 9, 2011 tt ' • Daniel T. Seamount, Jr. Cathy '. Foerster . .rman g,` Chair Commissioner Commissioner AIO 2B.058 Revised February 9, 2011 Page 3 of 3 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. . • Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, January 04, 2011 2:05 PM To: 'NSK Problem Well Supv' , JAN 1. 8 Z ug e Cc: NSK Well Integrity Proj Subject: RE: ConocoPhillips Monthly Injector Report - Dec 2010 -- message 3 Here is the latest addition to the email trail. 20. 2A -03 - AA 2B.050 issued 6/9/2010. 19. 1Y-10 - AA 2B.041 issued 03/11/2009. Well last injected 01/10. 18. 1Y-09 - AA 2B.051 issued 05/20/2010. 17. 1Y-08 - AA 2B.056 issued 10/22/2010. Well last injected 04/07. Are there plans to return the well to operation? 16. 1Y -05 - AA 2B.0015 originally issued 09/12/06, revised 10/21/08. 2 year RST required (condition 3). Original RST 09/01/08, next RST 07/13/10; report "automatically" submitted by Halliburton. Since the RST is a requirement of the AA, the report should be submitted by Problem Wells. 15. 1Y -04 - Last injected 07/09. 7/5/09 email stated intention to keep on injection for diagnostics and possibly apply for AA. Apparently diagnostic results were inadequate for AA. 14. 10-11 - AA 2B.058 issued 11/02/2010. I need to review condition 3 of AA for revision. • m: Maunder, Thomas E (DOA) Sen Tuesday, January 04, 2011 10:53 AM To: NS ell Integrity Proj Cc: 'NSK Pro. -m Well Supv' Subject: RE: Co 'coPhillips Monthly Injector Report - Dec 2010 All, I am continuing to review the ` -cember Monthly Injector report. I am through a to of 13 wells. I wanted to send this latest message due to • .t I have found or not found on 1 Q -02B. A continue to work through the report, I plan to send interim messag- as I get 7 - 10 new wells reviewed. CaII or message with any questions. 13. 1 Q -02B - Well name is 1 Q -02B. Well last injec • 9/10. I do not show having received any specific notification /request in June, 2010 regarding this wel ■ 1 here is an email in the file from 4/20/10 reporting diagnostics accomplished to that time containing a s . emen at you intend to return the well to injection and remove it from the waiver report in May. 12. 1L-05 - AA 2B.054 issued 10/22/21 0. Well last injected 9/10 11. 1 L -03A - Well name is 1 L -0 , • . Permit to Drill # is 199 -037. MITIA failed 1' 25/2010. Well last injected 9/10. 10. 1G-01 - AA 2B. I • issued 7/30/2008. 9. 1F-16A - ell name is 1F-16A. IA DD failed 4/12/2007, but MITs are listed to have passed sin -. Well last injected 4/ 007. AA 2B.018 was issued in October 2007, but no injection has occurred into the well. L. • ing at the pr- : ure plot, it is shown that the IA pressure appears to have been bled off in October and November. as 1/4/2011 • • The following information is received monthly from CPAI. Reporting this information is a requirement of the administrative approval issued that authorizes continued injection /operation of the well where some integrity compromise is known. As of December, 2010 a total of 65 wells are on this report. Not all wells are actively injecting. From: NSK Problem Well Supv [ mailto :n1617 ©conocophillips.com] t t Sent: Saturday, January 01, 2011 10:55 AM "� To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips Monthly Injector Report - Dec 2010 Jim/Tom /Guy, Attached for your records is the ConocoPhillips monthly injector report for December 2010. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 • • ConocoPhillips Well 1Q-11 Injection Data • Tbg Psi • IA Psi • OA Psi I 4000 - 3500 3000 .a' 2500 - a a 2000 - INN 1500 .............'». .,.....•«""""""'✓ • «... • 1000 - • won ■ •■ • ■ •••••••• • 0 09/10 10/10 11/10 12/10 01/11 Date PTD# 184 -199 AIO 2B.058 issued 11/02/2010. TxIA Communication 09/22/10 - MITIA passed 09/29/10 - MITOA passed 11/13/10 - Requested revision to AIO 2B.058 AIO 2B.058 requires any pressure bleeds to be reported monthly Date Start Press End Press Annulus 12/22/2010 1750 800 INNER 12/18/2010 1600 650 INNER 12/14/2010 1550 650 INNER 12/8/2010 1100 700 INNER i • ConocoPhillips Well 1Q-11 Injection Data ♦ Water Injection • Gas Injection I 4000 3500 - 3000 •°- 2500 w c. a 2000 rail a 1500 A dik M lir Y 1000 0 A 500 ♦ • 0 0 1000 2000 3000 4000 5000 6000 7000 Injection Rate, bwpd or mscfpd Date of Water Gas Injected Tubing IA Pressure OA Pressure Injection Injected Pressure (bwpd) (mscfpd) (psi) (psi) (psi) 31- Dec -10 6291 0 1597 800 300 30- Dec -10 6300 0 1598 800 300 29- Dec -10 6300 0 1600 800 300 28- Dec -10 6293 0 1602 800 300 27- Dec -10 6294 0 1601 800 300 26- Dec -10 6300 0 1600 800 300 25- Dec -10 6300 0 1599 800 300 24- Dec -10 6294 0 1599 800 300 23- Dec -10 6254 0 1599 800 300 22- Dec -10 6272 0 1598 1750 300 21- Dec -10 6262 0 1596 1750 300 20- Dec -10 6276 0 1595 1750 300 19- Dec -10 6298 0 1596 750 300 18- Dec -10 6301 0 1598 1600 300 17- Dec -10 6303 0 1601 1550 300 16- Dec -10 6096 0 1563 1550 300 15- Dec -10 5971 0 1541 1550 300 14- Dec -10 6296 0 1597 1550 300 13- Dec -10 5373 0 1439 1550 300 12- Dec -10 4553 0 1301 1550 300 11- Dec -10 4650 0 1318 750 200 10- Dec -10 4694 0 1328 750 200 9- Dec -10 4719 0 1400 750 200 8- Dec -10 4766 0 1347 1100 200 7- Dec -10 4667 0 1350 850 200 6- Dec -10 3835 0 1146 850 200 5- Dec -10 6637 0 1646 850 200 • 0 4- Dec -10 6637 0 1649 850 200 3- Dec -10 6636 0 1650 850 200 2- Dec -10 6581 0 1649 850 200 1- Dec -10 6581 0 1647 850 200 30- Nov -10 6275 0 1592 800 200 29- Nov -10 6052 0 1550 800 200 28- Nov -10 6049 0 .1551 850 200 27- Nov -10 6073 0 1552 800 200 26- Nov -10 6075 0 1553 850 200 25- Nov -10 6075 0 1555 850 200 24- Nov -10 6075 0 1553 850 200 23- Nov -10 6075 0 1552 900 200 22- Nov -10 6074 0 1551 850 200 21- Nov -10 6047 0 1547 850 200 20- Nov -10 6064 0 1547 850 200 19- Nov -10 6050 0 1546 900 250 18- Nov -10 6049 0 1547 900 250 17- Nov -10 6047 0 1545 900 250 16- Nov -10 6068 0 1543 900 250 15- Nov -10 6046 0 1543 900 250 14- Nov -10 6002 0 1536 900 250 13- Nov -10 5924 0 1524 800 200 12- Nov -10 5643 0 1448 650 350 11- Nov -10 5559 0 1448 1250 350 10- Nov -10 5572 0 1447 1250 350 9- Nov -10 5572 0 1445 1250 350 8- Nov -10 5575 0 1440 1750 350 7- Nov -10 5814 0 1435 1750 350 6- Nov -10 5597 0 1422 1150 300 5- Nov -10 660 0 503 750 200 4- Nov -10 0 0 361 750 200 3- Nov -10 0 0 163 750 200 2- Nov -10 0 0 383 750 200 1- Nov -10 4102 0 1226 750 200 31- Oct -10 6058 0 1548 750 200 30- Oct -10 6068 0 1549 750 200 29- Oct -10 6029 0 1549 750 200 28- Oct -10 6071 0 1552 750 200 27- Oct -10 6072 0 1553 1650 200 26- Oct -10 6024 0 1551 1650 200 25- Oct -10 5972 0 1538 1750 300 24- Oct -10 6258 0 1542 1750 300 23- Oct -10 6044 0 1542 750 300 22- Oct -10 5976 0 1507 1750 300 21- Oct -10 5936 0 1507 1750 300 20- Oct -10 3321 0 956 1750 300 19- Oct -10 0 0 289 1750 400 18- Oct -10 1354 0 549 1750 400 17- Oct -10 5336 0 1417 850 400 16- Oct -10 5830 0 1487 850 1600 15- Oct -10 5849 0 1487 1600 400 14- Oct -10 5849 0 1489 2000 400 0 • 13- Oct -10 5841 0 1490 1950 400 12- Oct -10 5840 0 1491 1900 350 11- Oct -10 5828 0 1485 1900 350 10- Oct -10 5809 0 1486 1900 350 9- Oct -10 5807 0 1488 1900 300 8- Oct -10 5795 0 1493 1900 300 7- Oct -10 5764 0 1488 1900 300 6- Oct -10 5817 0 1491 900 200 5- Oct -10 5850 0 1495 900 200 4- Oct -10 5849 0 1493 900 200 3- Oct -10 5844 0 1495 900 200 2- Oct -10 5842 0 1495 900 100 A "71c. SEAN PARNELL, GOVERNOR ALASKA OIL A" GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMUSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 213.058 Mr. Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 NG'ti Anchorage, AK 99510 -0360 RE: KRU 1 Q -11 (PTD 1841990) Request for Administrative Approval Kuparuk River Oil Pool Dear Mr. Walters: In accordance with Rule 9 of Area Injection Order (AIO) 0213.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby GRANTS ConocoPhillips Alaska Inc. (CPAI)'s request for administrative approval to continue water injection in the subject well. Kuparuk River Unit (KRU) 1 Q -11 exhibits tubing by inner annulus communication. Diagnostic testing has confirmed communication; however it has not been possible to positively locate the leak. Testing also confirms the communication is one -way, from the tubing to the inner annulus (IA). The Commission finds that CPAI does not intend to perform repairs at this time, deferring until such time as the leak can be located and necessary intervention determined. Reported results of CPAI's diagnostic procedures and wellhead pressure trend plots indicate that KRU 1Q-11 exhibits at least two competent barriers to the release of well pressure. The pressure history provided by CPAI with their request for administrative approval shows that the IA pressure has the potential to equalize with the injection pressure. CPAI requests the Commission approve inner annulus pressure equalized up to an injection pressure of 3000 psi, which is approximately 60 percent of the production casing's minimum internal yield pressure rating. Should the well develop communication to the outer annulus, the 3000 psi injection pressure would represent 85 percent of the surface casing's minimum internal yield pressure rating. Outer annulus pressures must be monitored and engineering controls must be installed to assure ongoing integrity of the surface casing. With such in place, the Commission AIO 2B.058 November 2, 2010 Page 2 of 3 believes that the well's condition would not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection only in KRU 1Q -11 is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily; 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. CPAI shall perform an CMIT -TxIA eveil-y 2 years to the maximum anticipated injection pressure; 4. CPAI shall perform an MIT -OA every 2 years to 1800 psi; 5. Inner annulus (IA) pressure not to exceed 3000 psi; 6. Outer annulus (OA) pressure not to exceed 1000 psi. 7. Within 30 days of the effective date of this approval, CPAI shall install, maintain and operate automatic well shut -in equipment linked to the well's outer annulus pressure. The actuation pressure shall not exceed 1,000 psi. Testing of the shut - in equipment (surface safety valve and mechanical or electrical pressure detection device) shall be performed in conjunction with production well pilots and safety valves; 8. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 9. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 10. The MIT anniversary date is July 12, 2009. DONE at Anchorage, Alaska and dated November 2, 2010. 11 �A NMI- Daniel T. Serniount, Jr. Cathy . Foerster Norma Chair Com issioner Com inner AIO 2B.058 November 2, 2010 Page 3 of 3 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. I I �I ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 October 15, 2010 amm N q OrT 19 2010 Mr. Dan Seamount ft 01 & onS Cori. Cg Alaska Oil & Gas Commission p th 333 West 7 Avenue Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: ConocoPhillips Alaska, Inc. presents the attached proposal per AID 2B, Rule 9, to apply for Administrative Approval allowing well 1Q -11 (PTD 184 -199) to be online in water only injection service with TxIA communication. If you need additional information, please contact myself or Brent Rogers at 659 -7224, or MJ Loveland / Perry Klein at 659 -7043. Sincerely, /� 4 Martin Walters Problem Wells Supervisor ConocoPhillips Alaska Inc. Cc: Working Well File, Legal Well File ConocoPhillips Alaska, Inc. Kuparuk River Unit 1Q -11 (PTD# 184 -199) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc. proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 213, Rule 9, to continue injection with known annular communication for Kuparuk injection well 1 Q -11. Well History and Status Kuparuk River Unit well 1Q -11 (PTD 184 -199) was drilled and completed in 1984 and 1985 as a development well and converted to a service well in November 1985. 1Q -11 was reported to the Commission on September 23, 2010 as showing signs of T x IA communication. The leak appears to be one way due to passing all tests except an IA drawdown test. The following pertinent diagnostics have been completed to date: Date Test Result Comment 9/29/10 MITOA Passed 9/22/10 T POT Passed 9/22/10 MITIA Passed 9/22/10 IA DD Failed 7/12/09 MITIA Passed Witnessed by John Crisp 11/21/08 MITOA Passed 7/26/06 MITIA Passed Witnessed by John Crisp Due to the nature of the communication, the location of the leak has not been identified. ConocoPhillips requests Administrative Approval which will allow the IA to equalize with the tubing in water only injection at a pressure not to exceed 3000 psi. If the condition of the well deteriorates and the leak point can be identified, repair options will be evaluated at that time NSK Problem Well Supervisor 10/15/2010 1 Barrier and Hazard Evaluation Tubing: The 3 1/2 ", 9.3 ppf, J -55 tubing does not have integrity to the packer @ 6946' MD, based on the failing IA drawdown test outlined above. Production casing: The 7 ", 26 ppf, J -55 production casing has an internal yield pressure rating of 4980 psi and has integrity to the packer @ 6946' MD (5756' TVD) based on the passing MITIAs outlined above. Surface casing: The 9 -5/8 ", 36 ppf, J -55 surface casing with an internal yield pressure rating of 3520 psi set at 3670' MD (3499' TVD) has integrity based upon a passing MITOAs outlined above. Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the production casing. Second barrier: The surface casing is the secondary barrier should the production casing fail. Monitoring: Each well is monitored daily for wellhead pressure changes. Should leaks develop in the tubing or production casing above the surface casing shoe it will be noted during the daily monitoring process. Any deviations from approved MAOP annular pressures require investigation and corrective action, up to and including a shut -in of the well. T /I /O plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. SVS: If necessary for approval, ConocoPhillips will install automatic well shut -in equipment on the well's outer annulus with an actuation pressure not to exceed 1,000 psi. Testing of the shut -in equipment shall be performed in conjunction with production well pilots and safety valves. Proposed Operating and Monitoring Plan 1. Well will be used for water injection only (no gas or MI allowed), IA pressure may equalize with injection pressure not to exceed 3000 psi; 2. Perform a passing MITIA or TxIA CMIT with tubing plug below uppermost packer every 2- years as per AOGCC criteria (0.25 x TVD @ packer, 1500 psi minimum). 3. Perform a passing MITOA to 1800 psi every 2 years; 4. IA pressure not to exceed 3000 psi & OA pressure not to exceed 1000 psi. 5. Submit monthly reports of daily tubing & IA pressures and injection volumes; 6. Shut -in the well should MIT's or injection rates and pressures indicate further problems with appropriate notification to the AOGCC. NSK Problem Well Supervisor 10/16/2010 2 KUP IQ-11 ca-'C1ca�!hips r a Attributes x Angle & MO TD e` InC re APIIUWI Field Name Well Status ( °) MD (ftl(B) Act Btm (ftKB) 0292121600 KUPARUK RIVER UNIT INJ 49.68 7,600.00 7,740.0 Coma a ct H2S (ppm) Date Annotation End Date K"rd IT Rig Release Date ° Well con SSSV: LOCKED OUT Last WO: 43.31 1/5/1985 fi -1 5/1820098:35:33 M Sch atic - Actiatl Annotation Depth (itl(B) I End Date jAnnotation Last Mod By End Date Last Tag: SLM 7,375.0 5/15/2009 Rev Reason: TAG FILL Imosbor 5/16/2009 - - --------- Cissina Strinas CONDUCTOR, String OD String ID Set Depth Set Depth (TVD) String WI String 101 Casing Description (in) (in) Top (ftKB) (ftKB) (ftKS) (IbsM) Grade String Top Third CONDUCTOR 16 15.062 0.0 101.0 101.0 62.50 H -40 SAFETY VLV, v SURFACE 95/8 8.765 0.01 3,670.0 3,498.7 36.00 1,899 PRODUCTION 71 6.151 0.01 7,720.0 6,282.3 26.00 K -55 GAS LIFT, TUb Strin s 1'854 String OD String ID Set Depth Set Depth (TVD) String Wt String Tubing Description (in) (in) Top (ftKB) (ftKB) (ftKB) (IbsM) Grade String Top Thrd GAS LIFT, TUBING 1 31121 2.992 0.01 7,287.01 5,996.7 9.30 J -55 EUE 8RD 2,762 Other in Hole All Jewelry: Tubincl Run & Retrievable Fish etc. Top Depth GAS LIFT, (TVD) Topincl 3,077 To B (MK8) (°) Description Comment Run Dale ID (in) 1,899 1,898.6 2.27 SAFETY VLV Baker'FVL' (Locked Out 3/10/95) 211/1985 2.810 GAS LIFT, 1 ,954 1,953.5 2.12 GAS LIFT MERLA/3.5x 1 /l/DMYBK/ // Comment: STA 1 2/1/1985 2.875 3,447 2,762 2,744.0 20.87 GAS LIFT MERLA/3.5 x 1/1 /DMY /BK/ // Comment: STA 2 211/1985 2.875 SURFACE, 3,077 3,028.4 29.09 GAS LIFT MERLA/3.5x 1/1 /DMY /BK/ // Comment: STA 3 2/1/1985 2.875 3,670 3,447 3,333.7 39.20 GAS LIFT MERLA/3.5xl /l /DMY /BK// /Comment: STA4 2/1/1985 2.875 GAS LIFT, 3,860 3,630.1 46.34 GAS LIFT MERLA/3.5 x 1/1 /DMY /BK/ // Comment: STA 5 2/1/1985 2.875 3,860 4,298 3,935.7 45.31 GAS LIFT MERLA/3.5 x 1/1 /DMY /BK/ // Comment: STA 6 2/1/1985 2.875 4,733 4,235.7 46.50 GAS LIFT MERLAG.5 x 1/1 /DMY /BK/ // Comment: STA 7 2/1/1985 2.875 GAS LIFT, 5,175 4,540.7 46.28 GAS LIFT MERLA/3.5 x 1/1 /DMY /BK/ // Comment: STA 8 2/1/1985 2.875 4,298 5,757 4,941.6 46.41 GAS LIFT MERLA/3.5 x 1/1 /DMY /BK/ // Comment: STA 9 2/1 /1985 2.875 GAS LIFT, 6,340 5,339.8 47.51 GAS LIFT MERLA/3.5 x 1 /1/DMYBK/ // Comment: STA 10 2/1/1985 2.875 4,733 6,8891 5,715.9 45.54 GAS LIFT MERLA13.5 x 1 /l/DMYBK/ // Comment: STA 11 2/1/1985 2.875 6,895 5,720.1 45.49 SLEEVE -C AVA TPC Sleeve 1.875 X 1.387 120/2005 1.375 GAS LIFT, 6,895 5,720.1 45.49 INJECTION MERLA13.5 x 1.5 /1.5/SLEEVE / /// Comment: STA 12 1216/2005 2.875 5,175 6,933 5,746.8 44.83 PER Baker 2/1/1985 1000 GAS LIFT, 6,946 5,756.0 44.79 PKR Baker'FHL'PACKER 211 11985 3.000 5.757 6,978 5,778.7 44.69 PATCH Alpha 21.68' Tubing Patch; w/ AVA Ported Nipple @ 6989'; 2/7/1993 1.875 Set on 2/7/93 over GLM #12 (6985') GAS LIFT, 7,050 5,829.5 43.62 PATCH Alpha 21.68' Tubing Patch; Set on 2/7/93 over GLM #13 2/7/1993 1.937 6,340 (7056) GAS LIFT, 7,058 5,835.3 43.72 INJECTION MERLA/3.5 x 1.5 /1.51PATCH /1// Comment: STA 13 2/1/1985 2.875 6.889 7,246 5,968.2 46.10 INJECTION MERLA/3.5x1.5 /1.5/DMY /// /Comment: STA 14 2/111985 2.875 INJECTION. 7,266 5,982.1 46.34 PKR Baker'FB -1' PACKER 2/1 /1985 4.000 6,895 ?71/1985 2.750 SLEEVEC, _ t 7,280 5,991.8 46.51 NIP Camco'D' Nipple NO GO 6,895 7,280 5,991.8 46.51 NIPPLE AVA NIPPLE REDUCER 1/25!1993 1.812 REDUCER PSR, 6,933- -.. - -- 7,296 5,996.0 46.58 SOS Baker 1/25/1993 2.992 7,287 5,996.7 46.59 TTL Tubing 2/1 /1985 2.992 7,410 6,080.0 48.58 FISH Missing Valve Parts: Downhole 1711711991 PKR, 6, 946 Perforations & Slots shot PATCH, 6,978 Top (TVD) Btrn (TVD) Hens Top (ftKB) Btm (ttK6 (10(13) (ftKB) Zone Date (sh... Type CortmeM 7,120 7,212 5,879.9 5,944.1 C-4, C -3, C -2, 2/2/1985 12.0 IPERF Y DA Csg Gun; 120 deg. phasing C -1, 1Q -11 7,224 7,232 5,952.6 5,958.3 UNIT B, 10-11 2!771985 12.0 IPERF 5" DA Csg Gun; 120 deg. phasing INJECTION, 7,366 7,450 6,050.4 6,106.6 A4, A -3, 1Q -11 2/2/1985 4.0 IPERF 4" DA JJ Csg Gun; 120 deg. phasing PATCH,7,050 -- 7,510 7,528 6,146.1 6,157.81A-2. 1Q -11 201985 4.0 IPERF 4" DA JJ Csg Gun; 120 deg. phasing IPERF, 7,12a7,212 IPERF, 7 -7,232 INJECTION, 7,246 PKR, 7.266 NIP, 7,280 NIPPLE REDUCER, 7,280 SOS, 7,286 TTL,7,287 IPERF, 7,366 -7A _ FISH. 7.410 IPERF, 7,510 -7,528 PRODUCTION, 7,720 TD, 7,740 Well Name 1Q -11 Notes: Administrative Approval Application Start Date 7/1/2010 Days 120 End Date 10/29/2010 Annular Communication Surveillance 3000 WHP 160 _ IAP OAP 140 _ WHT Ar� - 2500 120 2000 • N1 100 LL Q 1500 80 60 1000 40 500 20 0 - -- 0 Jul -10 Aug -10 Sep -10 Oct -10 ia000 i �DGI �MGI o �PWI m 'SWI �BLPD f 4000 2000 0 Jul -10 Aug -10 Sep -10 Oct -10 Date ~ MEMORANDUM To: Jim Regg ~ / P.I. Supervisor ~~ ~( ~Z~~~ (.C FROM: JOllll CT'1Sp Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 14, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1Q-11 KUPARiJK RN iJNIT 1Q-11 Src: Inspector NON-CONFIDENTIAL Reviewed B~ P.L Suprv ~~- Comm Well Name: KUPARUK RN i1NIT 1Q-11 API Well Number: 50-029-21216-00-00 Insp Num: mitJCr090713134702 Permit Number: 184-199-0 ~~ Rel Insp Num: Inspector Name: John Crisp Inspection Date: ~~12/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We]] 1Q"1~ Type Inj. N '1'~ 5756 jA 340 2430 2370 2340 P.T.D 1841990 TypeTest SPT Test psi 2430 QA 110 400 400 400 Interval a~TST p~ r ~ Tubing 19~s zooo zooo zooo NOtes• 4.4 bbl's pumped for test. ~ /UJ/l,~S~ QJ~~SUtJ`~ ! C ~~~~ . +~ ,~;~~~ , ;~~ ' ~, g~ ~~~~~`.": . a e,.. 4- '~ w~~ , . Tuesday, July 14, 2009 Page 1 of 1 ..;w COI'IOCOP~'11"1 p5 Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 4, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~~,~' 1~~ (~,' i Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped November 20, 2008 and the corrosion inhibitor/sealant was pumped December 2-3, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, x~~~~~~~: ~~_ ~ C ~ ~ 2008 Perry Klei ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor! sealant date ft bbls ft al 1 Q-01 184-231 10' 1.25 22" 11 /20/2008 6.80 12/2/2008 1 Q-04 184-234 10' 1.25 22" 11 /20/2008 3.40 12/3/2008 1 Q-07A 198-234 9' 1.10 24" 11 /20/2008 2.95 12/3/2008 1 Q-08A 197-093 8' 1.00 22" 11 /20/2008 3.40 12/3/2008 1 Q-09 184-192 2" NA 2" NA 4.25 12/2/2008 1 Q-11 184-199 4'5" 0.50 22" 11/20/2008 4.25 12/2/2008 1Q-12 184-193 21" NA 21" NA 6.80 12/2/2008 1 Q-13 185-044 18" NA 18" NA 5.10 12/2/2008 1 Q-14 185-045 24" NA 24" NA 4.25 12/2/2008 1 Q-23 195-141 24" NA 24" NA 3.40 12/3/2008 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor í") c? ("'/-' ",û(q C) &\:> DATE: Monday, July 31,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHlLLIPS ALASKA INC IQ-Il KUPARUK RIV UNIT IQ-Il ,\£10\ %\À \ FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ..)Bz.- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IQ-I I Insp Num: mitJCr06073II04215 Rei Insp N urn Permit Number: 184-199-0 Inspector Name: John Crisp Inspection Date: 7/29/2006 API Well Number 50-029-21216-00-00 Packer Depth Pretest Well IQ-II ¡Type Inj. I w TVD 5756 I IA 700 ! 1841990 +- P.T. :TypeTest I SPT Test psi 1500 i OA 480 Interval 4YRTST P/F P /- Tubing 2300 Notes 1.4 bbl's pumped for test. Initial 15 Min. 30 Min. 45 Min. 60 Min. i 1690 I 1630 i 1600 i +---~._-------t-- : 580 I 580 I 580 i i ' . i '2375 2375 I 2375 ,'ò ') ,.:' \~,! t. ;." Monday, July 31, 2006 Page I of I RE: KRU 1Q & lY 4 yr MIT results Subject: RE: KRU 1Q & lY 4 yr MIT results From: NSh ProblEm We11 Supv <n1617(a~conocophillips.com=~~ Date: ti~%ed, 19 Ju12006 10:24:54 -0800 To: Thomas Maunder ~=-tom nlaunder(u'admin.state.ak.us=~~ CC: Jim Rec`. <jimre`~`~raadmin.state.ak.us=> Tom, Wellwork histories for both wells attached. Marie McConnell Problem Well Supervisor 659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, July 19, 2006 8:05 AM To: NSK Problem Well Supv Cc: Jim Regg Subject: Re: KRU 1Q & 1Y 4 yr MIT results • Marie, Further on these wells. I have looked at the well files and there isn't much in them. Last information for 1QQ 11 is the 404 when it was converted to injection in January 1985. For lY-OS the last information aside from an MIT from 2004 is November 1993. Is it possible to pull the "event summary" for the wells and send it in? Thanks in advance. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 7/19/2006 7:33 AM: ~~•''~k~a~i~~. •-~i-%~ ~f~ ~' ' r~'i' Thanks Marie, As you might imagine, some questions: 1Q-11: 1. Was the fluid level at 550' after pumping the 11.4 bbls? If that is so, the original fluid level could have been nearly 1000' down. 2. Was any gas encountered when the pumping equipment was set up? 3. Looking at the TIO plot, the IA pressure is constant throughout the period. Do you think that pressure is valid? 1 Y-O5: 1. Based on the TIO plot, it would appear that the IA and OA are in communication. Is that so? 2. What were the final pressures on the well? Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 7/18/2006 9:56 PM: Tom, Jim, & Bob, 1 of 2 7/20/2006 10:47 AM RE: KRU 1Q & lY 4 yr MIT results • • Attached are 4 yr injector MIT reports for 1Y and 1Q as witnessed by AOGCC inspector Chuck Scheve. All wells passed except for 1Q-11 and 1Y-05. 1 Q-11 (PTD 1841990) did not pressure up after 11.4 bbls were pumped down the IA. The IA FL was found at 550', needing an estimated 15 bbls to load. The well remains on line while diagnostics are in progress. CPAI plans to repeat the witnessed MITIA after it has been loaded. The well was added to the failed MITIA report until a passing MITIA is witnessed. A wellbore schematic and 90 day TIO plot is attached. 1Y-05 (PTD 1830870) pressured up to 2800 psi, then broke down establishing a leak rate of 0.75 BPM @ 2570 psi. A tbg or packer leak is suspected, diagnostics will be completed to evaluate repair options. The well was SI and added to the failed MITIA report until repaired. A repair plan or AA will be submitted once diagnostics are completed. A wellbore schematic and 90 day TIO plot is attached. Please let me know if there are any questions. I will be leaving on 7/19 for 3 weeks. Jerry Dethlefs will be filling in for my vacation from 7/19 to 7/26 when my alternate Perry Klein returns. Marie McConnell Problem Well Supervisor 659-7224 «MIT KRU 1 Q PAD 07-17-06.x1s» «1 Q-11.pdf» «1 Q-11 90 day TIO 7-18-06 .doc» «MIT KRU 1Y PAD 07-17-06.x1s» «1Y-05.pdf» «1Y-05 90 day TIO 7-18-06 .doc» Content-Description: 1Q-11 Wellwork history 7-19-06.pdf 1Q-11 Wellwork history 7-19-06.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: lY-OS Wellwork history 7-19-06.pdf lY-OS Wellwork history 7-19-06.pdf !Content-Type: application octet-stream Content-Encoding: base64 2 of 2 7/20/2006 10:47 AM s • Well History ConocoPhillips 1 Q-11 API / UWI I Field Name 15002921216 KUPARUK RIVER UNIT Well Type Original KB Elevation (ft) Well Status Legal WeIlName Well Services 93.90 INJ 10-11 Daily Operations ~ ' ~_, , C[a~ C ]Lt: v.i I~J~n1P ~~,,-E ~ F;F= L:1 I ~1'l( ~llill I~vNI=~~ `1 21712 0 0 5~1C~2-1 1 10007491 PULLED .VA TF ~ (a~ 69~ ~ PhB MC)DERATE EROSION. TAGGED C? i" ~2' RKB, ESL 146' Fitzpatrick. Chuck FILL SET L375 4VATP( a.698~ RKB. 12/6/2004 '1G~-11 10045300 PULLED 2.31 BRX PLUG @ 1899' RKB. YOAKUM [VVH Maintenance] 12/332004 1i;t-11 10045300 Bleed well, R&R mtemai checks with external allomrte fitfing on Tbg hanger SP's, PPPOT-T GATHMAN failed. I [ANN COM ISSUES, WH Maintenance] 12;212004 1~~-11 '10045300 TEST 281"" BRX PLUG ~ 1899' RKB- FAILED. PULL & REDRESS- RESET SAME. YOAKUM TESTED & PASSED. BLED DOWN TBG TO 300 PSI. N/ELL LEFT SHUT IN. [VJH fv1aintenance] 12/3/2004 iG2-i 1 10045300. PULL 2.Si"" BRX PLUG @ 1899' RKB. BRUSH & FLUSH SVLN @ 1899' RKB. SET SAME YOAKUM PLUG(REDRESSED) @ 1899' RKB. TESTED TO 2500 PSI. PASSED. MADE SEVERAL UNSUCCESSFUL ATTEMPTS TO BLEED DOWN TBG TO 300 PSI. ONLY ABLE TO BLEED DOWN TO 1200 PSI. IN PROGRESS. (WH Maintenance] t1(2fi12004 1Q-11 110045300 (Bleed Tubing, !A & OA, Inoserr 5teeder fittittgs on Tbg ~ iC hangers. +LbVEt_AN[? [ANN COM ISSUES, VVH Maintenance] 11/21/2004 10-11 10045300 SET 2.81 "" PLUG ON BRX LOCK @ 1899' RKB. TESTED PLUG TO 2500 PSI, GOOD. BLED FITZPATRIGK TBG TO 300 PSI, GOOD. [WH Maintenance] 11/2012004 1Q-11 10045300 ATTEMPTED SET 2.81"" PLUG. UNABLE TO WORK PAST 377' SLM DRIFT TBG W~ 2.36"" EITZPATRICK BROACH TO SSSV @ 1899' RKB_ WORK PESTRICTION N// 2.89"" BROACH. IN PROGRESS. 11/10/2004 1G2-11 10044`200 TAGGED @ 7411' RKB, EST. 117' FILL. FITZPATRIGK [Tag] 10/30!2004 1Q-11 10044200 h11RU. BULLHEAD 70 BBLS DIESEL DOWN TUBING. RDMO- CHAMBERS [Hydrates-Ice] 9J12/2004 1Q-11 10041713 TAG ICE PLUG IN TREE 3' ABOVE TBG HANGER. YOAKUM ~Ta9] fif17l2004 10-11 10033276 Energize T PO'Y' seal McCONNELL .[ANN COM ISSUES, VdFi Maintenance] 2!29/2004 10-11 10033276 Energize IC PO Y-seal, PPPOT-IC -passed McCONNELL [ANN COM ISSUES, WH Maintenance] 2/23/2004 10-11 1003.3276 A/C EVAL, POT-IC -failed, Bleed OA for BUR DECHLEFS .(ANN C01~1 ISSUES. WH Maintenance] 7/11/2000 1C~-11 Kd5233 INSTALLED 1.375"" X 1.375""TPC ~ 69.35' RKB_ GOBER [Open C Ise ( Sand] 7/9/2000 1Q-11 K35233 It"JJECTION PROFILE -MAINLY ST09' COUNTS - A SANDS = 30% / C SANDS = 70 % l NO FERGUSON CROSSFLOW 6/26/2000 1G1-11 K85233 FULLED L81"" X 1.375"" AVA TPG SLEEVE @ 6585' RKB, TAGGED FILL @ 7400' RKB EST KENNEDY 128' OF BTM PERF'S COVERED [Open-Close C Sand] 7/iF; 1999 1Q-11 K85174 JE~rfED OUT ICE PLUG FROM 100' Clf~1 TO 140' CTM USING HGT DIESEL CHANEY OVER-DISPLACED TBG Vdl 90 $BLS CAF HOT DIESEL READY FOR INJECTION. [Hydrates-Ice] ~ 8/21/1997 1Q-11 KAWWRK PULLED PLUG AND GAUGES IN ""D"" NIPPLE @ 7280' RKB.""A"" SAND BHP @ 7280' RKB- ELLIS I 3989 PSI. ""C"" SAND BHP @ 7005' RKB-3807 PSI. SET NEW STYLE AVA TPC @ 6985' I RKB. '8/2031997 '.~10-11 KAVWJRK TAGGED l`itC@ 7414' RK,I~: 11d` OFrILL Ai;OVE PERFORATIGNS. SET AVA 1.81"" TNP 'ELLIS ' PLUG IN ""D"" NIPPLE 7280' RKB WIThi AMERADA BOMBS BELOW PLUG FOR A SAND PRESSURE MEASUREMENL 8/19/1997 1(1-11 KAWWRK PULLED L875"" AVA TPG @ 6985' RKB. COULD NUT GET THRU ""U"" NIPPLE TU TAG ELLIS ~ DUE TO THICK ASPHALTENES. IN PROGRESS 3/10M995 1U 11 TAGGED FILL n 7394' RKB (103' ABOVE BOTTOA4 PERFj. OPErJED C SAND. PULLED TPI CHAMBERS SLEEVE ~ 6985' P.KB, RAN TPC SLEEVE @ 6985' RKB. LOCKED OUT SSSV ~ 1399' RKB. I www.peloton.com ~~ Page 1!1 Report P rinted: 7/19/2006 STATE OF ALASKA Email to: Bob Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: ConocoPhillips Alaska Inc. FIELD /UNIT /PAD: Kuparuk /KRU / 1 Q DATE: 07!17/06 OPERATOR REP: Rogers/Ferreira - ASRC AOGCC REP: Chuck Scheve ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Packer Depth Pretest Initial 15 Min. 30 Min. Well 10-01 Type Inj. N TVD 6,126' Tubing 2210 2240 2220 2210 Interval q P.T.D. 1842310 Type test P Test psi 1531.5 Casing 760 2940 2880 2880 P/F P Notes: OA 0 0 0 0 Well 1 O-07A Type Inj. W ND 5,978' Tubing 2300 2300 2300 2300 Interval q P.T.D. 1982340 Type test P Test psi 1500 Casing 410 2970 2880 2860 P/F P Notes: OA 0 20 20 20 Well 1 O-08A Type Inj. W TVD 5,362' Tubing 2200 2200 2200 2200 Interval q P.T.D. 1970930 Type test P Test psi 1500 Casing 710 2900 2870 2870 P/F P Notes: OA 240 510 500 500 Well 10-09 Type Inj. W TVD 5,837' Tubing 2110 2110 2110 2110 Interval 4 P.T.D. 1841920 Type test P Test psi 1500 Casing 1380 2730 2670 2660 P/F P Notes: OA 440 520. 520 520 Well 10-11 Type Inj. W TVD 5,756' Tubing 2100 2100 Interval 4 P.T.D. 1841990 Type test P Test psi 1500 Casing 500 520 P/F F Notes: Pumped 11.4 bbls diesel and IA did not pressure OA 220 280 up above 520 psi. IA FL found at 550', plan to reschedule MITIA after IA is fill up with an estimated 15 bbls. Well 1 Q-12 Type In'. W TVD 5,881' Tubing 1800 1800 1800 1800 Interval 4 P.T.D. 1841930 Type test P Test psi 1500 Casing 1450 2400 2380 2380 P/F P Notes: OA 600 710 710 710 Well 10-13 Type Inj. W TVD 5,850' Tubing 2740 2650 2650 2650 Interval 4 P.T.D. 1850440 Type test P Test psi 1500 Casing 510 1790 1710 1700 P/F P Notes: OA 220 290 290 290 Well 1 Q-14 Type Inj. G TVD 5,947' Tubing 3710 3750 3750 3750 Interval 4 P.T.D. 1850450 Type test P Test psi 1500 Casing 510 1940 1870 1860 P/F P Notes: OA 50 150 140 140 Well 1 Q-24 Type Inj. W TVD 5,895' Tubing 2160 2160 2160 2160 Interval 4 P.T.D. 1951210 Type test P Test psi 1500 Casing 930 2760 2690 2690 P/F P Notes: OA 490 770 740 720 D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test 1 =Initial Test MIT Report Form BFL 9/1/05 MIT KRU 1Q PAD 07-17-06-2.xls 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) ARCO Alaska, Inc... ~! Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 16, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton. Attached in duplicate are subsequent notices following wells at the Kuparuk River Field- on the Well Action Date Performed 1L-1 Conve 1L-7 Conve 1Q-2 Conve 1Q-7 Conve 1Q-11 Conve 1Q-13 Conve 2B-5 Conve 2B-9 Conve 2C-1 Conve 2C-3 Conve 2C-6 Conve 2C-8 Conve 2D-2 Conve 2D-7 Conve 2D-11 Conve 2D-14 Conve 2F-1 Conve 2F-2 Conve 2F-13 Conve 2F-14 Conve 2G-3 Conve 2G-3 Conve 2G-5 Conve 2G-7 Conve 2G-10 Conve 2G-12 Conve 2G-16 Conve 2U-3 Conve 2U-4 Conve 2U-7 Conve 2U-16 Conve 2W-2 Conve 2W-4 Conve rsion rsion rsion rsion rsion rsion rs on rs on · rs on · rs on rs on · rs on · rs on rs on rs on rs on rs on rs on rs on rs on rs on rs on rs on rs on rs on rs on · rs on rs"on rs on · rs on rs on rs on rs O~ 11/18/85 11/18/85 11/17/85 11/17/85 11/17/85 11/17/85 11/23/85 11/23/85 11/19'/85 11/19/85 11/19/85 11/19/85 11120185 11/20/85 11120185 11/20/85 11121185 11121185 11/2~/85 11/21/85 11/14/85 11/14/85 11114185 11114185 11/14/85 11/14/85 11114185 11/16/85 RECEIVED 11/16/85 1 1 / 1 6 / 8 5 JAN.2 11/16/85 11 / 15 / 8~ask~ 0il & Gas Cons. 1 1 / 2 2 / 8 5 Anshor2~ ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA il ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICE, S AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84-199 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21 216 4. Location of Well SURFACE LOCATION' 1431 ' FNL, 1957' FEL, SEC. 26, T12N, RgE, UM BOTTOM HOLE LOCATION- 1078' FNL, 1320' FEL, SEC. 26, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 93.8' (RKB) I ADL 25641, ALK 2572 9. Unit or Lease Name KUPARUK RIVER UNIT 12. 10. Well Number 1Q-11 11. Field and Pool KUPARUK RIVER FI ELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (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 November 17, 1985 Kuparuk well 1Q-11 was converted producer to a water injector well as part of the full waterflood conversion effort. Water is being iniected "A" and "C" sands. from a field into both the RECEIVED .Oil & Gas Cons. ¢ommissi.':~r,~ At}chora, g~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '--~"/~/~"~ ~¢.~,,*~ Title KI IPAR! IK Date The space below for Commission use OPERAT IONS COORD ! NATOR I?!IR!R~ Conditions of APproval, if any: By Order of Approved by COMMISSIONER the Commission Date ................................ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ~ Post Office B~),, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 15, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1Q-11 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/lt GRU12/L05 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA (, ALASKA _ AND GAS CONSERVATION CC~ .~llSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 8/+-199 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21216 4. Location of well at surface LC,'L,A ~ION$ 9. Unit or Lease Name 1/+31' FNL, 1958' FEL, Sec.26, T12N, RgE, UM VE~IFJEDi~ Kuparuk River Unit At Top Producing Interval Surt:.~__ 10. Well Number 1333' FSL, 1/+75' FY/L, Sec. 26, T12N, RgE, UN B.H.~ 1Q-11 At Total Depth 11. Field and Pool 983' FSL, 1176' FY/L, Sec. 26 T12N, RgE, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i l Pool 93.7' RKB ADL 256/+1 ALK 2572 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 12/28/8/+ 01/0/+/85 01/05/85*I N/A feet MS L 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey [ 20. Depth where SSSV set I 21. Thickness of Permafrost 77/+0'ND, 629/+'TVD 7637'ND, 6227'TVD YES~I~ NO[] 1899 feetMD 1/+00' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/SP, FDC/CNL/Cal, CBL, Gyro (GCT) 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-/+0 Surf 101' 2/+" 2/+0 sx CS !1 , 9-5/8" 36.0# J-55 Surf 3670' 12-1//+" 850 sx CS I I I ~, .55{;)-SX C$ I 1 7" 26.0# J-SS Surf 7720' 8-1/2" :~30 SX Cla~s G r & 250 ~; ~ C~ I 24' Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBI'NG RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7510'-7528' 3-1/2" 7287' , 7366'-7450' I~///+ spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 722/+'-7232' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED , 7120'-7212' W/12 spf N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE .... Form 10-407 Rev. 7-1 ~80 GRU12/WC0/+ *NOTE: Tubing was run & the well was perforated 02/0/+/85. Submit in duplicate CONTINUED ON REVERSE SIDE . , NAME Include interval tested, pressure data, all fluids r~over~ and gravity, MEAS. DEPTH TRUE VERT. DEPTH .'GOR, and lime of each phase. , . :, ;, Top Upper Sand 7120=. - 5879~ N/A ~se Upper Sand 7212~ 5~~ Top L~er Sand 73~5~ . 6035~ . ~se Lower Sand .~ 7528~ 6157' . ,.;'~ ,, : . , , 31. LIST OF ATTACHMENTS . . 6yroscopiq Su.vey (?'cop!es) ' 32. ,I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ ~~ Title Associate E,g~neer Date INSTRUCTIONS General:. This for'm 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 !6, and in item 24 show the producing' intervals' for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc.~~ Post Office 'L,,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1985 Mr. L. C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Street Anchorage, AK 99501 Dear L. C. Smith: Per our conversation on September 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfield waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per dri!lsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by apprOximately 10/15/85, prior to waterflood startup. The second stage of Conversions will convert approximately four additional wells per dril!site to achieve a line drive pattern. Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the Commission in working with ARCO Alaska, Inc. in this area. If you have any questions .please call me at 263-4212. Sincerely, T. M. Drumm Kuparuk Operations Coordinator .cc: J.F. Beall TMD:ps:013 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK/~ 'L AND GAS CONSERVATION C( 1MISSION SUNDRY NOTICES AND REPORT ON WELLS 1. DRILLING WELL I-] COMPLETED WELL ~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well N/A 7. Permit No. see attached 8. APl Number 50- see attached 9. Unit or Lease Name Kuparuk River Unit 10. Well Number see attached 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool N/A I see attached 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] RePair Well [] Change Plans [~ Repairs Made [] Other [] Pull Tubing [] Other )~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Pursuant to form 10-403, it is proposed that the attached list cfa^producing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion? to a nine-spot pattern will occur approximately 10/15/85. The second conversion to a line drive pattern will occur approximately 12/15/85. Injection will be into the A and C sands. , SEp2O 19 5 Gas Cons. commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~, /~'~//~ ~~ Title'Kuparuk Operations Coordinator Date The space below for Commission use 9/18/85 Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1-80 ]~eturned / By Order of COMMISSIONER the Commission Date __ Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate 1E- 6 -26 IF- 2 - 4 - 5 - 8 1G- 2 - 3 - 4 - 5 IL- 1 - 3 - 5 - 7 -16 IQ- 1 - 2 - 7 - 8 -11 -12 -].3 -14 IR- 3 - 8 -10 -13 1Y- 1 - 7 -10 -13 2B- 5 - 6 - 7 - 8 - 9 -10 -11 -12 2C- 1 - 2 - 3 - 4 - 5 MARK: 009 Permit 80- 78 82-166 81-211 172 132 162 82-138 149 161 83- 20 84-173 158 123 145 181 84-231 232 218 209 199 193 85- 44 45 85-177 73 96 150 83- 50 68 51 15 84- 4 22 24 28 27 29 35 38 83- 83 93 89 94 99 API 9 Lease & Serial ~ Convert Date 029-20493 25651 469 10/15/85 029-20840 " " 10/15/85 029-20881 25652 2578 10/15/85 20846 " " 10/15/85 20807 " " 10/15/85 20836 " " 10/15/85 029-20813 25640 2571 10/15/85 20824 " " 10/15/85 20835 " " 10/15/85 20908 " " 10/15/85 029-21196 25659 2585 12/15/85 21182 " " 10/15/85 21155 " " 10/15/85 21171 " " 12/15/85 21202 " " 10/15/85 029-21247 25634 2567 10/15/85 21248 " " 12/15/85 21234 " " 12/15/85 21225 " " 10/15/85 21216 " " 12/15/85 21210 " " 10/15/85 21306 " " 12/15/85 21307 " " 10/15/85 029-21406 25635 2568 10/15/85 21333 " " 10/15/85 21351 " " 10/15/85 21385 " " 10/15/85 029-20933 20950 20934 20903 029-21067 21078 21080 21079 21082 21084 21089 21092 25641 2572 12/15/85 25646 2577 12/15/85 " " 12/15/85 25548 2662 12/15/85 25656 25655 25654 029-20962 20972 20968 20973 20978 582 12/15/85 " 10/15/85 " 12/15/85 " 10/15/85 581 12/15/85 " 12/15/85 " 10/15/85 " 10/15/85 2580 12/15/85 " 10/15/85 " 12/15/85 " 10/15/85 RECEI Alaska Oi~ & Gas Cons. Commissior~ Anchorage R..k,'I'UKN TO: ARCO Alaska, Ir~c , Post Offi[ ~ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 aRCO ALASKA, INC. KUPARU K OPE RATION~3 RE COP, DS CLERK ATO-1115B P.O. bOX 100360 AL~CtlORAGE, AK 99510 TRANSMITTAL ENGINEERING TRANSHITTED RECEIPT AND RETURN ONE ,,,,.PREh;SURE BUILDUP DATA lQ-9 C SAND --lQ-9/ ""lQ- 9 / ?'~ lQ--. 11~' .. 'lQ- 13' ". BOTTOM-HOLE- S AMPLE "JI'QL12'A SAND POST FRAC '--~lQ-12 '~'~ SAND -~ 2~-7 ~-A SAND hEREWITH ARE THE FOLLOWING IT.t:24S. PLEASE ACKNOWLEDGE SIGNED COPY OF THIS TRANSMITTAL. W/PRESSURE DATa 5/12/85 3/30/85 3/ 1/85 2/27/85 6/ 1/85 3/13/~5 2/29/85 7/26/85 %°1 A RECEIPT aCKNO~LEDGED: DISTRIBUTION: BPAE f< DRILLI[~G W. PAStiER B. CUIiRI~ER L. OOHNSTON EXXON CHEVRON/-' HOBIL w, PHILLIPS OIL D & M y NSK CLERK J. RaTHMELL.~' STATE OF ALASKA.~. SOHIO ~ UNION'> K.TULIN/PAULT ARCO Alaska. Inc. is a Subsidiary o! AtlanticRichfieldCompany ALASKA OIL AND 8A$ CONSEIIYATION.8OMMISSION .' 3OOl PoRCuPINE DRIVE DATE: TO: RE: ANCHORAGE,ALASKA 99501't'31g 2 TELEPHONE (907) 279,-1433 We wish to bring to your attention that the Commission has no~- yet received the following required items on the subject well which our records indicated was completed /- ~--~.~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled.well. Please submit the above missing material. C. V. Chattertfon/ Chairman lc:C. 024 ARCO Alaska, Inc. Post Office B(["' .}0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 17, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in- duplicate are subsequent notices following wells at the Kuparuk River Field- Well Action 1B-2 Fracture 1B-4 Fracture 1E-lA Cancel la 1E-lA Cancel la 1E-27 Cancella 1E-30 Polymer 1F-6 Cancel la 1F-13 Cancel la 1G-1 Cancella 1Q-5 Acidize 1Q-6 Acidize 1Q-7 Fracture --~'1Q-11 Cancella 1Q-13 Fracture 1Q-14 Fracture 1Q-15 Fracture 1Q-16 Fracture 1Y-2 Conversion 1Y-8 Conversion 1Y-12 Conversi 2A-2 Conversi 2C-8 Cancella 2C-14 Acidize 2H-15 Stimulat 2V-2 Conversi Date Performed 6/14/85 6/14/85 tion (Reperf) tion (Frac) tion (Frac) Project tion (Frac) tion (Frac) tion (Stressfrac) tion (Frac) (Perf) on on tion ion on 1/5/85 6/23/85 6/24/85 6/25/85 7/2/85 7/1/85 7/2/85 7/2/85 3/30/85 3/30/85 3/30/85 3/31/85 7/2/85 6/30/85 5/16/85 on the If you have any questions, please call T. M. 'Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) me at 263-4212. ARCO Alaska, Inc. is a Subsidiary of AtlantlcRichlleldCompany i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~ OTHER [] 2. Nam~0J"qper'a~°r' SKA~KL,U AkA I NC 7. Permit No. · · 84-199 8. APl Number 3. Address. O. BOX 100360, ANCHORAGE, ALASKA 99510 5o- 029-21216 4. Location of Well SURFACE LOCATION' 1431' FNL, 1957' FEL, SEC, 26, T12N, R9E, UM BOTTOM HOLE LOCATION. 1078' FNL, 1320' FEL 9. Unit or Lease Name KUPARUK RIVER UN IT 10. Well Number ~q-ll 11. Field and Pool SEC. 26, T12N, R9E, UM KUPARUK RIVER FIELD 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KUPARUK R I VER O I L 93.8' (RKB) I ADL 25641 . ALK 2572 POOL 12. Check Appropriate Box To Indicate Nature ~)f 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). Due to higher than.expected "A" sand production rates· Kuparuk well 1Q-11 will not be fractured in the "A" sand. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KU PARU K Signed J, ,/~Z~..,~' ~ Title OPERAT IONS COORD ! NATOR The space below for Commission use Date 7/16/85 Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. it Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 18, 1985 C Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1Q-11 Dear Mr. Chatterton: Enclosed is a copy of the 1Q-11 Well History to Well Completion Report, dated 02/04/85. If you questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU9/L72 Enclosure cc: 1Q-11 Well File include wi th the have any RECEIVED Alaska Oil & Gas Cons. Commissio~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office{' : 100360 ' Anchorage, ~.,aska 99510-0360 Telephone 907 276 1215 ~'.'.': F: (.':: 9 A I... A :'? !< ~'.':~, I N ..F:.. ,. A T 'T' ?,.! ' F.: Iii: C 0 F;; I) Z.'.' .... "' ~ E.I-.,i,' '"" A'T 0 -" 'i -i 'i 5 F'.,O, )3{IX t007.:50 A N C I-'I (') F:; A 5 E, A !--'.'. 99'j i 'I I..I ...... I,' il..; .... t C-4 _,o,·-· i~ ..-- il:q-'n,' t (.~ .... ? ,' 'i q-I 0 "' 1 r:.]- ~ ,n,- · ~ r_,!-, t t"' i ~-..f i / lq .... fnx~.. t[2--12,'- t f;-']- i,:. ''>" ..., ..-.'_ 1 ..q-'1 1.x i E-..2~ i g.,.--.? '- i c~ .... ,~/' ' ,~]' AT]:C T:I..Ir.' ,.'7 T A'¥ I C l.: I..I F' ZTAT]:C. T:I..IF' .7.,TAT ]: C ,.r'.','l"IF' .~TAT:I:r',.., .BI'IF' ST,qT.T. C BI"IF:' .~ (.)I::., .'. 'f ~., '[ ]: R ~ T r..~ T Z D H F:' ..~ OE, STAT]:C .~ T A't" .T. C]E': !'-I t"' ~ !3 E .,/,? T A '1" ]: 8 ;~TA. TIC ['.' t"1 I::' 20 r..' / 2. T A T._ I ,_. m 2T.ATIC !~HF' I) A T A E',":~ T A DATA DATA I) A D ,:~ T ~-., E<I"IF' F.,A'TA !.',I"IF' DA'FA :[.]¢ I-.I F' F,, r-':i 'r A -:::I. IF' ~OE/'A' SAN!) F'I:U 2TAT:lC BI"IF' DATA (" 'l / , T'~ I .> L, E ,. F ..:', ,...I F' Z~ LID A"f'A S]"AI"]:C BHF' I)ATA ,?"[' A ']' I C .'E: H F' D A T A S. 0 E,:..7. 5:F[F' 'A' F'I.: U !)ATA .5' 0 E/' F'B U DATE' AF:'F:IL '> © T R r-'.'~ i'.! 2 i"I .[ '"'" *' I I ~:_ NO' · - X ~.,i F 0 L. L r.) H .l: N C. :1:1 E:. J'J ,:, ~ F' L E A ,:, F_'-. r.'. 0 F' Y 0 F T I--I :[ $ 'r I::.: A J'.!.7 j"] .'[ T T A l.., I ? !:J E; ..,, t 4 .. I) T £-T F;,'.: ~ ....... T.': t.t ]' ]: r! fj · DIR:[I..!...:EN[~ ' I..,,I, F'A£1-1ER I_. ~....! [:' !-.I i'.! S T [) N r..~. x x [) i,.~ i"i 0 .T.:: :r !.. F' H :[ I_ I.. :[ F',:.';' [3 :[ l... N,S",' rtl...E:'''' ,.: r, J F: A 3' H iq r.:-L ARCO Alaska, Inc, is ,3 Subsidiary of AtlanticRichlieldCompany ARCO Alaska, In{ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 23, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Revised Well Completion Reports Dear Mr. Chatterton' Enclosed are revised Well Completion Reports for the following wells' 2G-7 1L-2 1L-3 1L-4 1Q-11 1Q-1.2 These reports were revised to reflect the cement quantity used when the wells were Arctic Packed. If you have any questions, please call me at 263-4944. Sincerely, ~ruber Associate £n§~neer JG/tw GRU6/L11 Enclosures RECEIVED APR 2 Alaska 0ii A Gas Cons. C0mmissior~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichtieldCompany " STATE Of ALASKA ALASKA ~-.~ AND GAS CONSERVATION Cd ~IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REVISION OIL [] GAS [] SUSPENDED i-~X ABANDONED [] SERVICE [-1 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-199 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21216 4. Location of well at surface 9. Unit or Lease Name 1431' FNL, 1958' FEL, Sec.26, T12N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. lQ-11 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool 93.9' RKBI ADL 25641 ALK 2572 · 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 12/28/84 01/04/85 01/05/85 N/A feet MSL N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+IYD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 7740'MD 7637'MD YES [] NO [~X N/A feet MD 1400' (Approx) 22. Type Electric or Other Logs Run D I L/SFL/SP, FDC/CNL/Cal 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 101' 24" 240 sx £S II 9-5/8" 36.0# J-55 Surf 3670' 12-1/4" 850 sx CS III & 550 sx CS II 7" 26.0# J-55 Surf 7720' 8-1/2" 330 sx Class G & 250 s: £g I 24. Perforations open to Production (MD+TVD of Top and Bot'tom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None I~/Ar 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. :DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD e Flow Tubing Casing Pressure cALCULATED~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. .ONe' RECEIVED APR 2 5 AJaska Oil & Gas Cons. Co;~mJssJon Anchoraga Form 10-407 JMM2/WC25 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .......................................... , .............. : ............ NAME Include inte~al tested, pressure data, all .fluids' r,~o. ver~ and gravity, MEAS. DEPTH TRUE VERT. DE~TH GOR, and time of each phase;,~,: ._ .. .. ;. -,.. .. ~,-. N/A ,,' ..,', ' N/A .~, ' ...... . . .... ~'.,.' :.','~ - , ., . . , , ,.. ., ,, , .,, . , t'., , ,~ ~,~ C=','"I ';.. . 1',.,../ '. '?~ ;: , '., '. . ~ , .:.. : ',.,,, ,L.~. ~ ~ . . , . , ,, ,,~ ,. : .;,,,. ,' ~ , .",,;',, '~. , , , ,. .... , '} f, ,,. , ,,' ~ ,,, ., . . :. ~. . .,, , .... , . ,. . 31. LIST OF ATTACHMENTS ~ ..... , .... , ~ '~-~ ,, None ', " ,, "' ' ' ~ " , .... :" ' ' ", " -' "'. "".';': .... ' ' ' 32. I hereby certify '{~at ~h~ foregoing 'is t~ge 'a~d.~rrect to ~he best' of'my 'kno~edge . v .: . . :-' :.' , . ~.,, ~, .., :;. ', . . . . Signed ~ ~ Title Associate Engineer Date INSTRUCTIONS General' 'This form 'is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of .Service Wells: Gas injection, water injection, steam injection, air injection, 'salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production .from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to .be separately produced, showing the data pertinent to suCh interval. ,, Item 21' Indicate whether from ground level (G L) or other elevation (DF, KB, etc.). .: Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ALASKA OIL AND f,A$ f, ONSERF/ATION.COHMIS$10N · Bill Sheffield, Governor 300! PORCUPINE DRIVE ANCHORAGE,ALASKA gi) SOl.l'-3f g :2 TELEPHOF, IE (007) 270,-1433 /)fft-~. ,'.?3 F ~.14 y j'T4 flFR D O._.. .--,---- RE: Weli Loc Permit No. ~ Z/_- - ' ' F We wish to bring to your attention that the Commissio. n has yet received the following required items on the_. subject well Which our records indicated was completed_ ~'/ ~'5""-'~-~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled.well. Please submit the above missing material. · Chairman lc:C.024 ARCO Alaska, In{" . . Post Office Box 100360 Anchorage, Alaska 99510-0360 Teleph'one 907 276 1215 ,.. F:~li'. T !J r::N TO' i AI"<CD AI_ASI<A: ]'i"~[;, ?:',0, DOX ~00~60 ANCH(]I'::AF~.E, Al( <;>95I 0 ( [.Ii',1 r.: . .x. 0 I::' El A C'. 1--I ) ( 0 · Iii::~!5 t ,5-"7:777 . I::' .") ..).,..,; 0 .... 7'~ ,:I 0,... 7 :? 5:0 '" 5) 490 600(')'"'B t 8 t 6 E>, 0 5' .-.. 8 0 7 t ':: 000" """ '" <''' ..# (.) I' (:.'" tO 6',' 00'".~ 1 6'7 , 0 F' IE: A C t"1 ) "? -' K:' ~"1 ",) ,4' "") i~l ~ ~ '"'"' ..?(-) , , (:;",'7'" I' ;' ¢.>C~, 605; ().". [.>, 5 .':.'~ (') '? 600 "- ? 0'"'.,.: 8 7:'560-9O56 6r'', 00 .... '" ''> '"' · .., C) 4. ~'Jr~ C) ,'3'500 .... <:),",<:: l o ,. " .:~s~a eli ,& 'Gas.. Cons. Commisslo~ ' ' D A'I" 1:.'". · " I) :r..? "f I::: ]:.,..,.,'.', ~ ,,., "r, :1: (:} ~'~ ' -- ':-:" ':".~n'o~ ~-~- ARCO AtasKa, inc. Post Officj,' ~ 100360 ..Anchor~g~ .daska 99510-0360 Telephone 907 276 1215 .,,.,,..,,...,../. /.-,~ ¢. ~. ~"~ ',.,,.. ~:, :.... ~.) ~',~,.. ' '"',,"',,..:. '; .:., ..... L': .'.'~'. H f:; !:': ~ 0 3 -:' 1 7 --' (ii '::T. ,. ,", ,.::.. i,-i C'.. ('! C.,'7...-,~ ~' ,"~-.' ,,,.,. o ,~, ~ .... ,~,, ];, i' ,'; "; ,.'.," .".:' E,,c' ¢i 'I" L.,"'.~ ,.,"" ' :;..,..."4 .... ,.:."~ ,...,.'=.~ --- '",=, .;.'::' '.. '~'~ ~':.' , t t ~ ~ ' r" !"I ~' ',':' ¢"'" Z "- i .... .=,. .... ,n . ... ": '..,' ...' ~....,. :.... ,.¢.;: .,':'-"~ f"L'.'.; O ,3 3 -.. 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'=' ,.. .:q.., .......... , -=;, '" :D .... r... ,.'?~ H 'C 0 "'~:... ~',....-. i r'~ 'r' ',' ~' ;::..?:, -.. 4 ,. ~ .:. :.: :. , %., ..,,' ~Tr..,,~. ~- .~ . ........ ...~ _P..O?iIF:'L.~TI::: POET F',r;..'¢iC· LOC; i",-' UF..'V'EY ,.:. f~'T.T..C:.. ~{HF'/" ~"'" '" PRE- FF..'A C.'./F:'., 'f', -.-t 2TAT.T.'C ):-:HF:'/T'.~HT F:' F;: E- F' I':;,:~-, C.' / F:'., 'T', T' U ]:: I N ~ ' A ' 5' ;::'~ i".~ ,ri:' F' F;: (:'~ r: F'.T.) LI ' ,r.: ' .~ ~.'..,. ,~.,! P T E.:'.,ff'T' ' C ' ,.c..., ~..-.., i'.~ T) T.r_:: ::;"T' F' ?': L.I F " T:,' I I ,~.? ,L.., r.., r. l ~ ...' l':' r-, c, T .... ~. 1::' ,..s C: Pl.!h! ~E.;.,.:':~6." ~ "'r."'i" '../ z:-., ,_ .., ,-:. ,..: · . L,..L : i... ;'-1', ...... '"'O ;'..! r:' '-., ....... r: ."'.! .:,r :. ~. ...... : i'! M, I .... : '..'' ... ~ '. i": "'i "" '"t .', [::, j .j .,m. L.J... ]i ..... ',..J :,~ .-u' -',.t r"'r'.~., , { !';.il"'~ , ,"~ .~...L.. ARCO Aleak~, Inc. is a Subsidiary of AllanticRichfieldCompany ARco Alaska, Inci¢ · Post'C~ffi'ce L~x 100360 Anchorage, Alaska 99510-0360 l'elephone 907 276 1215 OF'Y .. Ar, r.! C: r'-: n ~, ARCO Alaska, Inc. Post Office ~' '100360 ._Anchor~,ge, ~4~a.~ka 99510-0360 Telephone 907 276 1215 F t:..: ;"i Alaska, I .... ARCO-Post Offi~c= dox 360 Anchorage. Alaska 99510 Telephone 907 277 5637 ']l' ill T .[ ,'? JifI j]j --I'' i[ '~;' Jill l.[ ,? ii" ]i ,':'.';' T il; r", q !: I r.:' l... 1... i(.'.i Iii [:.! !!]~ l.., l..l 0 "[' ]J J'l j'~l"j Ill. l... ]7 )i!': [., l;J '1'' Jl]]?"! '() ]] ;]'].' "f' J::~ ]j[{: !..J '}" ;1] t'.j N ' J('] ll.t' ''' ,~l~1 T ll"i i"'J i..i :'.i r.., .,., .., ARCO Alast(a. Jllc. is a subs~cllary of AllanticR,chHe;dCompany ARCO Alaska, Inc{" ' Post Office'Dox 360' ' .... Anchorage, Alaska 99510 Tele.phone 907 277 5637 R E'T' U R i:! 'T 0 ' ,q F;; C il) Al....¢., S' I< A, ' ]; N C'.. ' R I::. b L)R D ~ C I... Iii; F;; K AT'TN '" ........ , . " I::'.[)~ BOX t ,.-,,~ ~.~ H 0 F:; A G E A I< ? 9'5 i (," ....... . ~.,. · 1' T I!7. D HIE R E 141 T H I? lie CIE I F"T' A N I) · I:;: li!:'F U I:;: N.. O NE. S' ,, (3 F' Ii;: N I"10 I... 1!!: F .1: N A I..~ I::' 1:~;'I N T ,.~ (., I"1 I... U M I') E F;: G IE , , t"," '~"~;~ m,,,-, ~ ,,,,,. ¢.;. ,," '"?' t:.'~;i:':t 'i ' .. .... ,/CY):.)E:F;;I...OOI( ' 0 t --.:0.4 '-:' (i~'.!'~;' ,-' 5" "'~ I) I I... ,/,S' F." I....... ..... .' '" I F'" ¢.t 8'5 /-'.:> "-'-'-- I,', IE N/i,I I::. t.. '..-..., I.,, F' (-'~ F:,' (:) .... O 4--. ,, ,,~'.5:" "'~' ...... I)IEH/NE;tJ""(:.;R F;.:AW. . 6, i .... (',"4 .... 8'.5 ...~2, "-- ' ...... .'0:1; I..v, ,S I" I..." (.¥ I,," 0 t .... 0 4 '"' 8 '.5 I) Iii; N / N Ii!: t.J '"" (:; F;: I:;; A W' .... 0 t ":' 'O/.t, .... o'" '.'5 ~'~:., , ">" '-'-- I> Ii!: ¢"~/' N Iii: [J .... (:; I:;;' F:' ~;'.} I:;; 0" (') '1 ':' () 4 'Iii '.".~; 6 "? 9'(')%~'? 6 t (') ;'~/...., :.,; t .... '7'7¢'.1. <9 ~,) 9.C)..,. '75 ",;'.9 "~ Z. ".7 '4 ' :'" ' ": ~'"' ,.. :., ~ ~ .... (('.::, f ';, ;5.6"7 t '.... 7:70 4 ' ' ..'.S89(.)....'78'7':;,:' 5 r:'l :?O ..... "? .6'7 :? I) Iii: N / N I!!: U .... ('..;. I:;.: I:;: ¢.".~ W * I;IEf.;f)'i',JlEU .... (;-I:;,' RAW." ~) I!!; iq ,,/N Ii!: t., .... t.,.I.,, I::' (3 F;,' (3 I) Iii: N / N Iii: U'"" (:;. I:;~ F:' 0 F;.: O' I) :1:1 .... 2 I'- I...'--' (., R - I) :1:1.../,? F' L. '... (;;. I:;: ........ . ,/ C "(,.'0 Iii: R !... (:.) (:)K .. .... ARCO Alaska, Inc. Is a subsidiary nf Attnnlicf3ichfieldCon-H.:,,~r~y .. ARCO Alaska, InC. l~~ Post Office .. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Harch 20, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1Q-11 Dear Mr. Chatterton' Enclosed is an addendum to the 1Q-11 Well History to include with the Well Completion Report dated 02/04/85. If you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRU5/L35 Enclosure RECEIVED Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inci. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 19, 1985 Mr. C. V. Chatte Alaska Oil and G 3001 Porcupine D Anchorage, AK rton, Chairman as Conservation rive 99501 Commi ss i on Dear Mr. Chatterton- Attached are our notices of intention followin.g Kuparuk Fi eld wells- 1Q-9, 1Q-10, ~, 1Q-12 If you have any questions, please call me to fracture the at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) Alaska. Oil & Cas Cons. C{;mrnission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany (~ STATE OF ALASKA (~- ALASKA OIL AND GAS CONSERVATION C ,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84-199 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 5o- 029-21216 4. Location of Well SURFACE LOCATION' 1431' FNL, 1957' FEL, SEC. 26, T12N, R9E, UM BOTTOM HOLE LOCATION' 1078' FNL, 1320' FEL, SEC. 26, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 93.8' (RKB) I ADL 25641= ALK 2572 12. 9. Unit or Lease Name KUPARUK RIVER 10. Well Number 11. Field and Pool KUPARUK RIVER KUPARUK RIVER POOl Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data UNIT FIELD OIL NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate ~] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" sand in Kuparuk well 1Q-9 be hydraulically fractured and propPed to improve production. The treatment uses gelled water as the pad and carrying fluid and 12/20 sand as the proppant. Gelled diesel will be used as a flush. Lines and equipment will be pressure tested to 5000 psi prior to starting job. Pre-post frac logs are included in the treatment program. Fluid' Gel led water 451 BBLS Gelled diesel 46 .LBS Proppant- 12/20 sand 42,090 LBS ANTICIPATED START DATE' February 26, 1985 RECEIVED FEB 2 o ]985 Naska 011 & Gas Cons. Comml~,i~n Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. //~~._~ (~/~x.~._~ KUPARUK Signed Title 0 P E RAT ! 0 N S The space below for Commission use COORDINATOR Date 2/19/85 Conditions of Approval, if any: Approved by Approved Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Ini. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 12, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the January monthly reports for the following wells: 6-5 2C-13 2U-13 11-15 2C-14 2U-14 17-12 2E-9 2U-15 17-13 lQ-§ 2U-16 L1-9 1Q-10 2W-13 L2-30 1Q-11 2W-14 2W-15 2W-16 WSP-4 WSP-8I If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L143 Enclosures RECEIVED Alaska Oil & Gas 'Cons. C0mrn/ssi0~ Anchorage ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRlchfieldCompany ~' STATE OF ALASKA ALASKA ,- AND GAS CONSERVATION CO( .¢IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well 0qX Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-199 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99S10 50- 029-21216 4. Location of Well at surface 1431' FNL, 1957' FEL, Sec.26, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 93.9' RKB ADL 25641 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1Q-11 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of Januar), , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0300 hrs, 12/28/84. Drld 12-1/4" to 3690'. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 7713'. Ran OH logs. Drld to 7740'TD as of 01/04/85. Ran, emtd & tstd 7" csg. PBTD - 7637'. Secured well & RR ~ 1330 hrs, 01/05/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set (~ 101'. Cmtd w/240 sx CS I1. 9-5/8", 36.0#/ft, J-55, BTC csg w/FS ~ 3670'. Cmtd w/850 sx CS III & 550 sx CS 7", 26.0#/ft, J-55, BTC csg w/FS ~ 7720'. Cmtd w/330 sx Class "G" cmt, II. 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/SFL/SP f/7704' - 3671' WLM FDC/CNL f/7678' - 6890' WLM Cal f/7678' - 3.671' 16. DST data, perforating data, shows of H2S, miscellaneous data NONE Alaska 0ii & Gas C0ns, Cof~mi'ssi°rt AncR0, 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED &~ ~¢.JL.~ TITLE Associate Engineer DATE LC"iS"~' NOTE--Repo on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 JMM/MR59 Rev. 7-1-80 Submit in duplicate Post Office B ,00360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 4, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1Q-11 Dear Mr. Chatterton: Enclosed is the Well Completion Report for 1Q-11. I haven't received the Well History yet, but when I do, I will forward a copy to you. Also, the bottomhole location, geologic markers, TVDs, and tubing details will be submitted when the gyroscopic survey is run and the well completed. If you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRU3/L93 Encl osure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA{ ; AND GAS CONSERVATION cd, ,vllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [~X ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-199 3. Address 8. APl Number P, 0. Box 100360, Anchorage, AK 99510 50- 029-21216 4. Location of well at surface 9. Unit or Lease Name 1431' FNL, 1958' FEL, Sec.26, T12N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 1Q-11 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 93.9' RKB ADL 25641 ALK 2572 12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. J15. Water Depth, ifoffshore 116. No. of Completions 1 2/28/84 01/04/85 01/05/85 N/A feet MSL N/A ' 17. Total Depth (MD+TVD) 18.Plug Back DePth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7740' MD 7637 ' MD YES [] NO I~XI N/A feet MD 1400' (Approx) 22. Type Electric or Other Logs Run DI L/SFL/SP, FDC/CNL/Cal 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i6" 62.5# U-40 Surf 101 ' 24" 240 sx CS I I 9-5/8" 36.0# J-55 Surf 3670' 12-1/4" 850 sx CS Ill & 550 sx CS II 7" 26.0# J-55 Surf 7720' 8-1/2" 330 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET .(MD). PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ,, DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATI° TEST PERIOD Flow Tubing Casing Pressure CALCULATED.k OIL-BBL GAs-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED F'E 0 8 985 Alast(a 0il & Gas Cons. C0mrnission Form 10-407 GRU3/WC67 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ................................................ · ........ · ..................................................................... f:? ;~'*".":r". ":~': .... ' '"'¥'~- ~"~"~' ..... ,. ,, ", . . .' NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEP..T,,H ',:GOR:; and.timeof ea.c.,b phase.'.~: ,. .... ::.-.:.'.: .: ...... : ...... '__.:..:.. . s/^ ~ ., si^ .'. · ' ; ;"- . ';',' ,. . - '.. .... :. ",: i ... . .' .. ~ .,:;i" ' .:'.', ~, ~:"~' · _ . , · · . , !, ;,. ': · . , . . , , ,., '!~ . , ,. 31 LIST OF ATTACHMENTS ,. · · . 32. I her'eby certify that the foregoing is true and correct to the best of my knowledge Signed t/~~~ Title Associate Engineer Date INSTRUCTIONS General' This fOrm is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas' injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference(where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ,, Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27; Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23:. Attached supplemental records for this well should show the details of any multiple stage cement- ing an.d t.he~ 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. · 'I~. '.~ .~ '. 0" Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 1/22/85 1Q-Il Rn CBL f/TD - 3650'. Rn gyro f/TD - surf. RECEIVED OJ~ & 8as Cons. Commissio. Anchorage Drilling s~erintendent Date ARCO Oil and Gas Company Well History - Initial Report- Daily Preba~'e and submit the "Initial Rel~e~t'* on the first Wednesday after a well la spudded or workover operations are stab'ted. Dally wo~ p~tor to slX~ddlng ~ould be ~ummarlze~. on the form giving incluelve dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 504734 l~un~, ~d~ or bo~ugh North Slope Borough ILe--orUnlt ADL 25641 IT,t,e Drill , Complete & Perforate IState Alaska IWell no. 1Q-il Nabors 26E API 50-029-21216 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded IDate IHour 12/28/84 Date and depth as of 8:00 a.m. 12/28/84 12/29/84 thru 12/31/84 1/02/85 1/03/85 Complete record for each day reported 0300 hrs ARCO W.I. IPr or status If a W.O. 56.24% 16" @ 101' 300', (199'), Drlg Wt. 8.7, PV 14, YP 32, PH 10.5, WL 17.6, Sol 4 Accept ri~ @ 1900 hrs, 12/27/84. NU diverter & 20" Hydrl. Spud well @ 0300 hfs, 12/28/84. Drl 12½" hole to 300'. 9-5/8" @ 3670' 3090', (3390'), Tst BOPE Wt. 8.7, PV 4, YP 4 Drl, DD & surv to 3690', short trip, C&C, POOH. RU & rn 91 its, 9-5/8", 36#, J-55 BTC csg & lnd w/FC @ 3586.70' (top), 3670.71' (Btm). M&P 850 sx CS II, followed by 550 sx CS I. D±spl using rig pmp, bump plug. Good rtns thruout job. CIP @ 1345 hrs, 12/30/84. ND 20" diverter. NU & tst BOPE; OK.-- 2174', 4.4°, Sll.5E, 2173.95 TVD, 1.83 VS, 2.78S, .57E 2427', 12 8°, S19.5W, 2423.75 TVD, 36.31 VS, 40.73S, 7.13W 2678', 19.2e, S33.5W, 2664.83 TVD, 104.61VS, 98.81S, 40.02W 3054', 29.3°, S31.5W, 3007.20 TVD, 257.24 VS, 232.25S, 117.38W 3534', 41.8°, S35.5W, 3398.42 TVD, 533.50 VS, 454.60S, 281.60W 3641', 45.2°, S35.5W, 3476.04 TVD, 607.06 VS, 514.56S, 324.37W 9-5/8" @ 3670' 6262', (2572'), TIH Wt. 9.4, PV 15, YP 10, PH 9.5, WL 8, Sol 10 Tst BOPE. Pull tst plug, PU BHA #4, TIH, tag FC @ 3586', tst csg to 1500 psi. DO flt equip + 10' new hole. Conduct formation tst to 12.5 EMW. Drl, Navi-Drl & surv 8½" hole to 6262', POH wet lk'g f/wshout. Chg out Navi-Drl, TIH. 3787', 46.5°, S38.5W, 3577.50 TVD, 7il.40 VS, 602.87S, 384.58W 4732', 46.5°, S38W, 4230.98 TVD, 1394.03 VS, 1138.09S, 808.28W 5168', 46.5°, S39.5W, 4531.10 TVD, 1710.29 VS, 1384.74S, 1006.24W 6051', 47.5°, S40W, 5131.88 TVD, 2357.24 VS, 1883.15S, 1418.94W 9-5/8" @ 3670' 7240', (978'), Drlg Wt. 9.8+, PV 20, YP 8, PH 9.5, WL 5.6, Sol 12 Fin TIH, drl & surv to 7041', CBU, POOH. TIH, drl to 7240'. 6927', 45-1/2°, S40-1/2W, 5734.88 TVD, 2992.33 VS, 2368.13S, 1829.51W RECEIvE D JUN 1 9 The above is correct For form prapara~on-an~'~l~rJ~u~lon~ see Precedurea Manual, SectiOn 10, Drilling, Pages 86 and a7. Date 2/11/85 ITme .... ,.,x .u~$ (;OtiS. C0rilrrlj$$jori D t~r~. ,aS up e r in t end en t ARCO Oil and Gas Company Daily Well History-Final Report Inatructiona: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Rel3ort" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion end representative test data in blocks provided, The "Final Report" form may be used for reporting the entire operation if space is available. J Accounting cost center code District County or Parish State Alaska North Slope Borough Alaska Field Kuparuk River Auth. or W.O. no. AFB 504734 Lease or Unit Title J Well no. ADL 25641 lQ-11 Drill, Complete & Perforate Nabors 26E API 50-029-21216 Operator ARCO Alaska, Inc. Spudded or W.O. begun I A.R.Co. W.I. Jl'otal number of wells (active or inactive) on thisI 56. 2470 cost center prior to plugging and abandonment of this well J Date Hour Prior status if a W.O, 12/28/84 0300 hrs. Complete record for each day reported Spudded Date and depth as of 8:00 a.m, 1/04/85 1/05/85 thru 1/07/85 9-5/8" @ 3670' 7713', (473'), TIH Wt. 9.9+, PV 13, YP 10, PH 9.5, WL 5.6, Sol 12 Drl 8½" hole to 7713', pmp pill, 10 std short trip, C&C f/logs, POOH. RU Schl, RIH, log DIL/SFL/SP f/7704'-3671' WLM. Log FDC/CNL f/7678'-6890' WLM. Rn Caliper f/7678'-3671', RD soS. TIH. 7" @ 7720' 7637' PBTD, 7740' TD, (27'), RR 10.0 NaCl/NaBr Fin TIH, wsh & rm 7466'-7713'. Drl to 7740', circ, POOH, LD BHA. Chg top rams to 7" & tst to 3000 psi. RU & rn 193 jts, 7", 26#, J-55 BTC csg w/2 mkr its. M&P 330 sx C1 "G" w/3% KC1, .7% D-19, .3% D-31, .1% D-6, .2% R-5. Displ w/294.5 bbls 10.0 ppg brine. Bump plug w/3000#. CIP @ 0530 hrs, 1/5/85. Go. od rtns thruout job. ND BOPE. Set 7" slips. Instl pack-off. NU tbg spool, tst 7" to 3000 psi; OK. Inj 6 bbls diesel dn 9-5/8" x 7" ann. RR @ 1330 hfs, 1/5/85. 7" FC @ 7637.13' - 7" FS @ 7717.77' w/btm @ 7719.63' Old TD New TD PB Depth 7740' (1/3/85) 7637' PBTD Re~eased rig Date Kind of rig 1330 hrs. /05/85 Rotary Classifications (oil, gas, etc,) Type completion (single, dual, etc,) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no, Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P, C,P, Water % GOR corrected Gravity Allowable Effectiil~, d~t~ C F ~ The above is correct "',,~UI~I 1 ~,~ Signature VED For form preparation and distribu~ij~n, see Procedures Manual, Section 10, Drilling, Pages 86 and 87, J 2/11/85 Date Title Drilling Super~z~~ GaS i%.r/$. Commissior~ Anchorage $ UB.$ URFA CE DIRECTIONAL SURVEY ~"~ Ul DANCE ~] ONTINUOUS r'~OOL Company ATLANTIC RICHFIELD COMPANY Well Name lQ-11 (1431' FNL, 1958'. FEL, 826rT12~.~rR9E.,UM Field/Location KUPARUK, NORTH SLOPE, ALASKA Job Reference No. } Date. 70073 ~' 12-FEB-1985 Lo(:j{3ed By: WEST/BAUMEI STER Computed By: STEVENS GCT D~RECTIONAL SURVEY CUSTOMER LISI'ING FOR ARCO ALASKAt INC,, KUPARUK NORTH SLOPEr ALASKA SURVEY DATE: ZZ-JAN-SS ENGINEER: ~EST/BAUMEIS[ER ~ETHODS DF COMPUTATION TOOL LOCATION: TANGgNTIAL- AVERAGED DEVIATION AND AZINUTH INTERPOLATION: LINEAR VERTICAL SECTION: hORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 3a OEO 23 ARC:3 ALASKA, INC. 1Q-11 KUPARUK NORTH SLOPE, ALASAA COHPUTAT'I'~N D'ATE~ 11-FE~-85 PAGE DATE OF SURVElt': Z2-JAN-85 KELL'~ 8U:,SHZIdG ELEVATIDId:' ENGINEER: ~EST/BAUM~[STER INT~£POLATED VALUES FOR EVEN 100 FE~T OF #EASURED DEPTH TRUE SUa-SEA COURSE HEASURED VERTICAL VERTICAL DEVIATION AZIHUTH DEPTH D~PTH DEPTH DEG ~[N DEG 0.00 0.00 -93070 0 0 hi 0 0 E 100000 100.00 6030 0 14, hi 71 43 E ZO0.O0 200.00 106030 0 31 N 71 1Z E 300.00 299.99 206.29 0 34 N 54 33 ~. 4,00°00' 399099 306.29 0 38 N a6 37 E 500.00 499.98 406.28 O 46 N 78 36 E 600.00 59909]' 506.27 0 43 S 62 45 E 700.00 699.96 606.26 0 4,4, $ 57 4,3 E 800.00 799.95 706.25 0 47 S 38 37 E 900.00 899.94 a06.2¢ 0 4,9 s 52 30 E S 37 0 E S 36 14 E S 33 6 E S 32 21 E S 33 11 E S 37 45 ~. S 40 50 E 1000000 999.93 906.23 I 0 1100.00 1099.91 1006.21 I 16 1200o00 1199.88 1106.18 I 15 1300.00 1299.86 1206.16 I 28 1~00.00 1399.82 1305.12 1 39 1500000 14,99.78 1406008 I 34 1600.00 1599.74, 1506.04, I 37 1700.00 t699.70 1605.00 I 3~ 1800000 1799066 1705.96 I 57 1900000 1899059 1805089 Z 16 2000.00 1999.51 1~05081 2 13 2100.00 Z099.4,3 200S073 2 26 2100.00 1199.23 2105.53 5 1 2300°00 2298.4,9 2204079 8 49 2400.00 2396.95 2303.25 2.1 27 2500.00 24,94,.34 2400.65 14 13 2600.00 2590.65 2~.96o 95 16 41 2700000 2685077 2592.07 19 2800.. O0 1779.39 2685.69 21 44 2900.00 2871.4,4 2777.7/, 24 4,6 930 J'C) FT 3000.00 1960.78 2a67.0a 27 57 3100.00 3048.31 2954.61 29 45 3200.00 3133094, 3040.24 32 37 3300000 3217.15 3123.45 34, 55 3400.00 3297.38 3203068 38 5 3500.00 33r4.62 3280,.92 4,0 48 3600.00 3448.55 3354,.a5 43 4,9 3700°00 3519.23 342:5.53 46 4 3600.00 3588.07 34,94.37 46 2.9 3900.00 3657.11 3563.41 46 12 VERTICAL DOGLEG RECTAMGULAR CDDRDXNATES HORXZo D~PARTORE SECTXDN SEVERXT¥ IdORTH/SOUTH EAST/MEST DXST. AZXNUTH F~ET DE&/XO0 FEET FEET FEET OEO 0.00 0.00 0.00 N 0.00 -0.08 0.64 0.03 N 0.09 -0.69 0.16 0.25 Id 0.79 -1.58 0.12 0.71 hi 1.65 -2.39 0.21 1.04, N 2.5;, -3.34 0.51 1.23 N 3.83 -3.°~3 0.42 1.06 Id 4.99 -e.23 0.74 0.44 N 6.26 -4.08 0.26 0.4,4, S 7.13 -3.95 0.40 1.47 S 8.23 0.00 Al 0 0 E 0.10 N */4 53 L 0.83 N 1,Z gO E 1.80 N 6~) 50 E 2.74 N 61' 42. E 4.02 N 72 12 E 5.11 N 7]' 59 E 6.28 N 86 i E 7.15 S 86 26 E 8.36 S ~9 50 E -3.73 0.22. 2.57 5 9.25 -3.30 0.30 4.12 S t0.53 -2.92 0.17 5.79 S 12.01 -2034 0.34 7.65 S 13.42 -lo75 0.16 9.71' S 15.15 -1.05 0.17 12.05 S 16o9.0 0.14, 0.14 14.41 S 18.41 0.73 0.25 16.73 S 19.94 L.65 0.55 19.26 S 21.68 2.45 O.ST Z2.ZO S 14.08 9.60 $ 74 29 ~ 11.31 S 66 36 E 13.33 S 64, 16 E 15.45 S 60 19 E 18.03 S 57 10 E gO.TS S 54 30 E 23.38 S 51 51 E 26°03 S 50 0 E 29.02 S 48 21 E 32.76 S 47 19 E 3.08 0.11 25.11 S 3.70 0.98 27.96 S 6.53 4.4,1 33.4,8 S 16.46 4.35 45°35 S 32.117 4,.09 61.94 S 54.40 3.07 83.11 S 80.79 1.52 106.95 S 111.36 2.73 133.13 S 146.31 3.58 162.64 S 184.67 4.58 197.21 S 26.73 E 36.61 S 46 47 E 29.3~' E 4,0.5~' S 46 23 E 31.75 E 46.14, S 4,3 28 E 30.75 E 54.80 S 34 8 E 25.25 E 66.89 S 22 1'0 E 17.31 E 84.90 S 11 4,5 E 4.9! E 107.06 S Z 37 11.29 M 133.61 S 4 50 M 30.30 ~ 165.44 S 10 33 ~ ~8.~4 M 203.0d S 13 47 226.68 3.61 276.64 2.77 328020 2086 383.66 3.37 4,43.29 2.96 506.79 2.85 574.09 2,88 644.81 2.30 717.32 0.10 789.64 0.31 237.25 S b8.77 ~ 247.01 S 16 9 b 278.4,8 S 93.97 d 293.90 S 18 38 a 319.6a S I15.00 ~ 343.25 S 21 21 M 363.53 $ 158.95 d 396.76 $ Z3.3~ M 4,11.36 S 194.61 ~ 4,55.07 S 25 19 M 461.87 S 233.12 U 517.36 S 26 46 bi 515.3a s 273.95 ~ 583.66 s 27 ~9 , 571073 S 316.70 M 653.58 S 28 ~9 , 629062 S 360.40 ~ 725.47 S 29 4~ M ARCO ALASKA. XNg. 1Q-11 KUPARUK NDRTH SLOPE. ALASI~A TRUE SUB-SEA COURSE HEASURED VERTXCAL VERTICAL DEVXATXON AZXHUTH DEPTH DEPTH DEPTH DEG NZN DEG MIN COMPUTATION DATE: 11-FE8-85 PAGE -- DATE OF SURVEY:' 22-JAN-85 XNTERPDLATED VALUES FOR EVEN 100 FEET OF HEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HDRXZo DgPAgTURE SECTZON SEVERZTV N~RTH/SOUTH EAST/MEST DZSTo AZ[HUTH FEET OEO#lOg FEET FEET FEET OEO 4000.00 3726.49 3632.79 45 51 4100.00 3796.29 3702.59 45 38 4200.00 3866.28 3772058 45 33 4300.00 3936.37 3842.67 45 ZO 4600.00 4006.5~ 3912.85 46 11 4500.00 4075.15 3981.45 46 44 4600.00 4143.73 4050.03 46 39 4700.00 k212.40 4118070 .6 36 4800000 6281o26 4187.56 46 la 4900000 4350050 ~256080 46 15 5000.00 *419.29 4325.58 46 34 5100.00 4488.20 4394.50 46 17 SZO0. O0 6557.32 4463.62 46 17 5300.00 6626033 4532.63 46 26 5400.00 ~695023 4601053 46 27 5500000 ~764.09 4670039 ½6 32 5600.00 6832.81 4739.11 46 39 5700.00 ~901.56 4807.88 46 29 5800.00 k970.61 4876091 ½6 21 5900000 5039.60 4945.90 46 29 6000.00 5108.25 5014.55 4~ 41 · 6100.00 5176.52 5082.32 47 5 6200.00 5244.41 5150.71 47 23 6300000 5312.01 5Zla.3! 47 32 6600.00 5379.42 5285.72 47 29 6500.00 '5646095 5353.25 ~7 21 6600.00 5514.97 5421.27 46 54 6700.00 5583.55 5489.85 46 27 6800.00 5652.64 5556.94 46 0 6900~00 5722.38 5628.68 45 27 7000.00 ~792.91 5699.21 44 37 7100.00 5864.53 5770.83 44 18 TZO0.O0 5935.31 5841..61 ~5 40 7300.00 600~.43 5910.73 66 45 7400000 6072.33 5978.~3 47 57 T500.O0 6138.45 6046.75 49 6 7600.00 6203.49 6109.79 49 41 7700.00 6268.17 6174.47 49 41 7740.00 6294.04 6200034 49 41 S 36 56 ~ 861.63 S 36 40 b 933.22 S 36 3, ~ 1004.61 S 36 37 ~ 1015.89 S 36 27 W 1147.10 S 36 28 W 12190~1 S 36 AZ ~ 1292.55 S 36 30 ~ 1365.20 S 36 32 ~ 1437.68 S 36 53 W 1509.79 S 38 52 Id 1582.37 S 38 55 kd 1656.82 S 38 54 id 1727008 S 38 46 id 1799.46 S 38 35 id 1871.93 S 38 30 id 1946.44 S 38 34 Id 2017.09 S 38 47 Id 2089069 $ 39 I id 2162o04 S 39 2 id 2234.42 S 39 13 Id 2307.13 S 39 13 kl 2380.19 S 39 2:) id 2453.60 $ 39 18 id 2527.29 $ 39 17 ~ 2601.14 S 39 22 W 2~74.~8 ~ 39 27 ~ 2748.18 S 39 ~2 ~ 2820.94 S 39 12 d 2893.22 S 39 5 ~ 2964.88 S 39 9 al 303,5077 S 40 23 id 3105054 S 40 21 W 3176.13 S 40 23 id 3248.34 S 40 23 kl 3321.71 S 40 10 id 3396069 S 40 55 ~' 3472.60 S 40 55 ~ 3548.79 S &O 55 ~ 3S79.27 0.37 0.25 0-15 Q.39 2.25 o.28 0.25 0.52 0.41 1.25 1.10 0.13 0.10 0.17 0.05 0.61 0 0.64 0.22 0.33 0.49 0o15 0.62 0.47 0.83 0.78 0.51 0044 0.38 1.17 1.33 lo40 0.79 1.62 0.00 0.00 0.00 93.70 FT 745.05 S 4~,7.09 ~d 866090 S 30 56 H 802.37 S 490.01 Id 940.12 $ 31 24 Id 859.71 S 532.60 kl 1011.32 i 31 4~ ~ 917.01 S 575.01 Id 1082.41 32 974.20 S 617.55 Id 1153.44 S 32 22 ~ 1323.23 S 877.93 id 1587.98 S 33 33 Id 1379058 S 923.48 id 1660.14 S 33 67 1435.79 S 9~8.86 id 1732.12 S 34 0 Id 1492.16 S 1014029 a 1804.25 S 34 1548.71 S 1059.61 W 1876.51 S 36 22 Id 1605.42 S 1134.80 Id 1948.84 S 34 32 1662.27 S 1150.04 id 2021032 S 34 40 1718.9~ S 1195.40 d Z093o75 S 34 48 1775.22 S 1240.89 id 2165.92 S 34 57 Id 1831.44 S 1286.48 d 2238.13 S 3~ 5 Id 1867.65 S 1332037 id 2310.67 S 35 1946.49 S 1378.53 iQ 2383.51 S 35 20 kd 2001032 S 1425.01 ~d 2456062 S 35 2058.31 S 1471.76 id 2530.35 S 35 33 Id 2115.49 $ 1518.50 Id Z604.06 S 35 40 id 2172.53 S 1565.26 W 2671.66 S 35 46 Id 2229.16 S 1611.79 id 21'50.82 S 35 52 Id 2265.34 S 1658o05 id 2823.46 S 35 57 Id 2341.31 S 1703.81 W 2895.64 S 36 2 Id 2396.93 S 1749.01 kl 2967.20 S 36 Z' W 2451.92 S 1793.75 kd 3038.00 S 36 11 2505.65 S 1838.29 id 3107.66 S 36 15 Z559.32 S 1884020 id 3178.11 S 36 21 2614.37 S 1931.03 id 3250.19 S 36 27 Id 2670.23 S 1978.66 id 3323.44 S 36 32 272~050 S 2027.10 id 3398.30 S 36 31' Id 2785030 $ 2076.40 Id 3674.09 S 36 42 28½2.92 S Z126.36 id 35:i0.16 S 36 47 Id 2865.97 S ZX46.36 id 3580.5t:1 S 36 ARCO ALAS~At XNC. IG-11 KUPARUK NORTH SLOPE, ALASKA CONPUTAT,T. gN DATE: Il-FEB-t15 DATE OF SURVEY: 22-JAN-85 KELLY 8USHZN~ ELEVATTON: ENG.[NEE~; ~ESTtI~AUHEX STER XNTERPOLATED VALUES FOR EVEN 1000 FE. ET OF MEASURED DEPT TRUE 5US-SEA COURSE MEASURED VERTZCAL VERTXCAL DEVXATXON AZ[HUTH DEPTH DEPTH DEPTH DEG HXN DEG 93.70 0.00 0.00 -93.*3'0 0 0 1000.00 999.93 906.23 I 0 2000o00. 1.999.51 1905.81 2 13 3000.00 Z960.78 2867.08 27 57 4000000 3726.49 3632.7*9 45 51 5000.00 4419.29 4325.58 46 34 6000.00 5108.25 5014.55 46 41 7000.00 5792.91, 5699.21 44 37 7740.00 6294004 6200.34 49 41 VERTXCAL DOGLEG RECTANGULAR CDDRD~NATgS H~RZZo DEPART~R~ SECTXDN SEVERITY NORTH/SOUTH EAST/MEST DZSTo AZZ#UTH FEET DEG/IO0 FEET FEET FEET OEG NXN 0.00 0.22 0.1Z 3.61 0.37 1.10 0 1.17 0.00 O.O0 N 0.00 E OoO0 # O 0 E 2.57 S 9.,?.5 E 9060 S 74 29 E 25.11 S 26.1'3 E 36.6T S 46 47 E 231.25 S 68.7! Id 247o0Z S 16 9 . 745.05 S 447.09 id 868.90 S 30 58 Id 1323.23 S 8T7.93 N 1587.90 S 33 33 Id 1887o85 $ ~332.37 a 7.310061 S 35 ~2 Id 7.451.92 S 17~3o75 ~ 3038000 S 36 1~ Id 2865.97 S 2146.3~ id 3580058 S 36 49 Id N 0 0 E 0o00 S .~5 59 E -3073 S 43 12 E 3.08 S 27 44 d 22:1.68 S 36 5.~ id 861.63 S 38 52 ~d 1582.37 S 39 13 bi £307.13 S 39 9 Id 303~.77 S 40 55 d 3579.27 ARCO ALASKA, ZNC. la-11 KUPARUK NORTH SLOPEp ALASKA TRUE SUB-SEA COURSE N~ASUREO VERTICAL VERTICAL DEVIATION AZIMUTH OEPTH DEPTH DEPTH DEG HZN OEG HZN COHPUTAT]:gN DATE: 11-FE8-85 PAGE -- DATE OF SURVEY: 22-JAN-S5 KELLY 8USH,T. NG ELEVATZON: ENG T. NEER: WEST/~AUHEXSTeR ZNT£RPOLATEO VALUES FOR EVEN 100 FEET OF SU~-SEA OEPTH VERTICAL DOGLEG ReCTAnGULAR COORDiNATeS MOR~Z. ~EPARTUR~ SECTION SEVEEITY NORTH/SOUTH EAST/WEST O~ST. AZINUTd FEET OEG/IO0 FEET FEET FEET OEO 0.00 O.O0 -9.:1.70 0 0 N 0 0 ~: 95.70 93.70 0.00 0 11 N 24 6 E 193.70 193.70 100.00 0 31 N 71 57 E 293.71 293.70 200.00 0 34 N 54 26 E 393.1'1 3~3.70 300.00 0 37 N aS 53 E 493°72 ;*93.70 400.00 0 ;*7 N 78 30 E 593.73 593.70 500.00 0 ;*2 S '63 48 E 693.7~ 693.70 600.00 0 ;,6 S 60 I E 793.15 793.70 700.00 0 46 S 38 35 E 893.r6 893.70 800.00 0 51 $ 52 28 E 0.00 0.00 0.00 N 0.00 -0.06 0.53 0.02 N 0.07 -0.64 0.14 0.23 N 0.73 -1.52 0.09 0.67 N 1.60 -2.34 0.2.6 1.04 N 2.47 -3.27 0.41 1.21 N 3.74 -3.92 0.46 1.10 N 4.92 -4.22 0.70 0.46 ~ 6.19 -,.10 0.25 0.38 S 7.08 -3.95 0.55 1.42 S 8.16 -3.76 0.20 2.48 S 9.18 -3.32 0.33 4.02 S 10.43 -2.96 0.27 5.68 s 11.93 -2.38 0.26 7.52 S 13.33 -L.78 0.15 9.64 S 15.03 -1.10 0.30 11.91 S 16.81 -0.20 0.08 1;** 26 S ~8.32 0.67 0.31 16.58 S 19.a5 1.60 0.46 19.12 S 21.56 2.41 0.67 22.03 S 23.93 993.77 993.70 900.00 1093.79 1093.70 1000.00 1193.81 11~3.70 1100.00 1293.84 1293.70 1200.00 1393.08 1393.70 1300.00 1493o92 1493070 1~00.00 1593.96 1593.70 ZSO0.O0 169;*.00 1693.70 1600.00 11,94.04 1793.70 1700.00 189;*.11 1893.70 la00.00 3.05 0.06 Z½o94 3.65 0.91 21,.80 &.22 4.29 33.02 15.81 4.50 ;.4.65 32.25 4.14 61.32 54.24 3.02 82.96 8~.69 1.56 107.74 11~.21 2.33 135.50 151.97 3.13 161,o62 195.04 4.46 Z06.63 59 S 36 17 E 15 S 37 22 E S 36 1 E 38 S 40 53 E 34 S 33 24 E 37 S 32 14 E 33' S 33 ZZ E 55 S 37 24 E 16 S ~0 19 E 1994.19 1993.70 1900.00 2 13 S 43 17 E 2094.26 Z093.70 2000.00 2 23 S 40 5! E 2194.4~5 2193.70 2100.00 4 49 S 10 14 E 2295oL6 2293.70 2200.00 8 37 S LZ 53 W 2396.69 2393o70 2300.00 11 20 S ZO 0 d 2~99033 2493.70 2400.00 14 12 S 22 23 ~ 2603.19 2593.70 2500.00 16 44 S 30 14 ~ 2708.~3 ~693~70 2600.00 19 38 S 33 ~7 ~ 2815.~1 2793.70 2700.00 22 b S 28 5~ ~ 2924.64 2893.T0 2800.00 Z5 53 S Z7 0 d S 30 36 d 246.19 S 37 7 M 303ol;* S 37 6 d 367.57 S 37 11 M 440040 S 37 23 ~ 523.50 S 37 13 ~ 618.68 S 36 57 ~ 723.25 S 36 49 M 827.72 5 36 ~1 d 930.57 3037.41 2993.70 2900.00 28 44 3152.58 3093.70 3000.00 31 2 3271.56 3193.70 3100.00 34 7 3395.32 3293.70 3200.00 37 56 3525.37 3393.70 3300.00 41 30 3663.47 3493.70 3400.00 45 20 3808.18 3593.70 3500.00 46 30 3952.82 3693.70 3600.00 46 4 4096.29 3'793.70 3700.00 45 38 4239.17 3893.70 3800.00 45 32 4.82 4.27 3.52 2.96 2.79 1.77 O.OZ 0-19 0.21 0.19 S 36 31 d 1032.56 93.70 FT- 0.00 N O 0 E 0.07 N 15 55 E 0.77 N 72 24 E 1.73 N 67 18 E 2.68 N 6~ 13 E 3.9.3 N ~Z S e 5.05 N 77 25 E 6.21 N 85 35 E 7.09 S 86 57 E 8.28 S 80 7 E 9.51 S 74 53 E 11.18 S 68 54 E 13.21 S 64 32 E 15.31 S 60 33 E 17.86 S 57 19 'E 20.60 S 54 40 E Z3.ZZ S 52 5 E 25.86 S 50 7 E 28.82 S k, 6 25 E 32.53 S 41 21 E 26.56 E 36.45 S 46 49 E 29.21 E 40.32 S 46 ,Z5 E 31.61 E 45.75 S 43 48 E 30.91 E 54.30 S 34 41 E 25.48 E 66.40 S 22 33 E 17.31 E 1t4.76 S 11 49 E 4.45 E 137.83 S Z 21 E 12.89 W 136.11 S 5 25 W ~.~ 33.15 id 170.86 S 11 11 ~ 53.26 ~ 213.39 S l& 27 ~ 252.81 S 77.34 W 264.37 S 17 0 ltd 299.96 S 109.52 W 319.33 S 20 3 W 350.58 S 149.40 W 381.09 S 23 4 W ;*09.06 S 192.86 id 452.25 S 25 14. W 475.14 S 243.27 id 533.79 S 27 6 W 550.90 S 300.92 W 627.73 S 28 38 W 634.36 S 353.96 id 731.36 S 2~ SO ~ 717.92 S 426.73 W 835.X7 S 30 43 W 800.25 S 4a8.43 W 937.53 S 31 23 W 882.18 S 549.26 e 1039.19 S 31 54 W C~HPUTATI3N DATE: 11-FE6-85 PAGE ARCO ALASI~At ZNCo 13-11 KUPARIJK NORTH SLOPEr ALASK, A DATE DF SURVEY: Z,Z-JAN-8$ KELLY BUSHING ELEVATZ'ON~, ENGINEER: IdEST~BAU#EIST~R 93070 FT- INTERPOLATED VALUES FDR EVEN 100 FEET OF SU~-SEA DEPTH TRUE SUB-SEA COURSE HEASURED VERTICAL VERTICAL DEVZATZON DEPTH DEPTH DEPTH OEO H~N DEG VERTICAL DOGLEG RECTANGULAR C~DRDLNATES HDRZZo DEPARTURE SECTION SEVERITY #ORTHdSOUTH EAST/IdEST DIST.. AZIHUTfl FEET DEG/I. O0 FEET FEET FEET DEG #Ial 4381o54 3993.70 3900°00 45 46 4527008 4.093.70 4000000 46 43 4672.74 4.193.70 4100o00 46 37 4818000 4293070 4200.00 46 14 4962.72 4.393070 ,6300.00 46 36 5107~96 k~93.70 ~00.00 ~6 5252.68 ~593.70 ~SO0.O0 ~6 22 55~3.01 ~793.70 ~700.00 ~6 31 5688.54 ~893.70 4800.00 46 32 S 3,6 31 mi 1133.84 S 36 30 ti 1239o52 S 36 2B id 1345.37 S 36 3?. ~ 1450.68 S 38 19 ~ 1555026 $ 38 5~ ad 1660.~8 S 38 50 d 1765.19 5 38 37 ~ 1870.32 S 38 29 ~ 1975.63 S 38 ~* ~ 2081.37 2.034 0.31 0.48 0.35 1.65 0o14 0o10 000~ 0069 0.28 963.53 S 609067 Id 1140.2~ $ 32 19 Id 1048059 S 672.49 H 1245oll S 32 40 bi 1133081 S 735.31 ~ 1351.41 $ 3Z ~8 b 1218051 S 798.05 ti 1456059 $ 33 13 ~ 1302.06 S 86,1..00 ti 1560.98 S 33 Z8 I~ 1384006 S 927.10 id 1665.87 S 33 48 g 1465.46 S 992.80 ~ 17F0.09 S 34 6 k , 1547.46 S 1058.60 M 1874090 S 34 22 . ~ 1629.83 S 1124.2Z ~ 1979.96 S 34 35 M 1712.,6 S 1190.19 ~ ZOa5.&~ S 3~ ~ ~ 5833044 ~993.70 4900.00 46 20 5978081 5093.70 5000.00 46 42 6125..24 5193.70 5100.00 47 10 6272.91 5293.70 5200.00 47 6421.12 5393.T0 5300.00 4'7 30 6568081 5493.70 5400000 47 6714073 5593.70 5500.00 46 6859005 5693.70 5600.00 45 45 TO01.1Z 5793.71 5700001 44 37 7140.92 ~893oT0 5800000 44 S 39 I kl 2186.23 S 39 1[ ~ 2291073 S 39 14. ~ 2398.68 S 39 ZO d 2507032 S 39 19 ~ 2616.70 S 39 25 ~ 2725037 S 39 1~ d 2831.61 S 39 6 bi 2935.66 S 39 9 ad 3036056 S 40 3~ ad 313~0Z2 0o17 1794000 S 1256013 Id 2190o0~ S 3* ~g ~ 0.77 1875.93 S 1322061 ~ 2295.30 S 35 11 Id 0.51 0.17 0.64 0.60 0.48 1.17 1.37 1958.81 S 1390o23 ~ 2402.02 S 35 21 , 2042.86 S 1459.09 id 2510042 S 35 32 Id 2127052 S 1528036 Id 2'619059 S 35 41 Id 2211.55 S 1597.30 Id 2728.06 S 35 50 Id 2293.60 S 1664.81 id 2834.12 S 3,5 58 Id 2374.24 S 1730.58 ~ 2938.01 S 36 5 ~ 2452.53 S 1794.25 ~ 3038.79 S 36 11 ~ 2527.45 S 1856.95 ~ 3136.28 S 36 18 ~ 7284035 5993.70 5*900000 46 37 74.32009 6093.70 6000.00 48 24 7584089 5193071 6100001 49 42 7739o~7 6293.70 6200.00 49 41. 7]'40. O0 6294.04 6200034. 49 41 S 40 21 ~ 323bo96 S 40 16 ad 3345.63 S 40 48 ~ 346L.09 S 40 55 ~ 3578086 S 40 55 ~ 3579.27 0.90 1.29 3072 0.00 0.00 2605.68 S 1923.65 ti 3238.83 $ 3~ 26 g 2688.47 S 1994.15 d 3347.32 S 36 33 id 2776059 S 2068.86 ~ 3462060 S 36 41 Id 2865.66 S 21~6.08 ~ 3580.18 5 3~ 49 Id 2865097 S 21~6034 Id 3580.58 S 3& 49 . C3HPUTATZJN DATE: 11-FE~-85 PAGE 6 ARCO ALASEAt 1~-11 KUPARUK NORTH SLOPEr ALASKA .HARKER TaP UPPER SAND BASE UPPER SAND TOP LOMER SAND BASE LAMER SAND PBTO TOTAL OEP'TH 9ATE OF SURVEY: 22-JAN-85 RELL¥ 6USHING ELEVATLON: 9,3.70 FT ENGINEER: WEST/3AUMEISTER INTERPOLATED VALUES FOR CHOSEN HORIZONS HEASUREO DEPTH SURFACE LOCATION TVD R~CTANGULAR COORDXNATBS FRDH RB SUB-SEA NORTH/SOUTd .EAST/WEST 7120.00 7212..00 73~5.00 7528.00 7637.00 77~,0.00 587a.aL 5785.11 zs16oz9 s 18&To~9 W 5943.69 5~49.99 2565.86 S XBBgoTB W 6035.18 59~1.~8 2639.37 S 1952o3~ W 6156.75 6063.05 27~3.69 S 20~0°79 W 6Z27o~2 &133.72 2~06o6'2 S 209,o&9 W 6Zg~.O~ 6Z00.3~ 2865.97 S 2X46o34 W ARCH ALASKA. INC. 1G-11 KUPAR~JK NORTH SLC)PE~ ALASKA 93°70 FT' MARKER TOP UPPER SANO BASE UPPER SAND TOP LO~ER SAND BASE LOWER SAND PBTO . TOTAL DEPTH HEASURED DEPTH aELOg KB ?2ZO.00 7212.00 73~5.00 7528°00 7637.00 ~TaO.O0 5878o81 59,~3o69 6035.18 6156.7S 6Z2T.~.Z 629,I. O~. 5765.11 2516,,Z9 S 184]'o:~9 I,I 5849.99 2565°86 S 1889.78 ki 59,~1.~,8 2639.37 S 1952.3~ ~ 6063.05 2743.69 S 20~0.7g ~ 6133.72 2806.62 S 209~.a9 ~ 6200.3& Za6~.97 S Z~6.3& ~ ggEt U~ FINAL WELL L3CATION AT TO: TRUE SU~-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 77½0.00 629~.. 0~. 6ZOO.3A, HDRZZDNTAL DEPARTURE DISTANCE AZ~HUTH FEET DEG SCHLUMBERGER ARCO ALASKA, INC. 1~-11 KUPARUK NORTH SLOPE, ALASKA JANUARY 22, 198S TVW PLOT FROM OCT DATA dOB REFERENCE 7007~ WELL: IQ-Ii SURFACE LOCATION: 1431' FNL, 1958' FEI,, S26, T12N, R9E, UM VERTICAL PROJECTION NE -4000 -~lO00 -ZOO0 - 1000 0 0 1000 ZOO0 9000 4000 PROJECTION ON VERTICAL PLANE OF AZIMUTH Zl8 SCALEO IN VERTICAL DEPTHS HORIZ SCALE = 1/I000 IN/FT WELI.: iQ- 11 · SURFACE LOCATION: 143.1' FNL, 1958' FEI., S26, T12N, R9E, UM HORI ZOMTAL PROJECTION NOR?~ 1000 R£F 70079 SCALE = 1/I000 IN/ET -IOO0 -ZOO0 -9000 -40OO -5000 -6000 SOUTH -7000 -7000 NEST -6000 -~000 -4000 -9000 -2000 -1000 0 1000 EAST Su~ge~t~ form to be insertcd in each "At{ .ye" well folder to d'.eck for timely ccmpliance with our regulations. · ' Operato'r/we~i N~e and ~umker Reports and Materials to be received by: Required Date Received Remarks Ccmpletion Report . Yes 4,': ..... .P · Core Chips '' /~':'/~ ..... "" : K ' · .... . , Core Description /~/: ,.'~,~i~3 ~ , ,, , .,Registered Su/vey Plat y'~..,: /l Inclination Survey · .,,.':... , ,, ....... .........~, , ? % ......-~' ......... ':~ ulrec~lonai burvey ~".? ' ........ ".~' ........ . .. .,. ex, f /0-,, Drill St~ Test Re~s ~ ,:,,~, , ARCO Alaska, Ir~.- Post Offic'~ ..ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/22/85 Transmittal No: 4989 RETURN TO: ARCO ALASKA, INC. AnTTN: Records Clerk TO-1115B · 0. Box 100360 chorage, AK 99510 ' Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH LIS TAPES Schlumberger ~/69930 2C-15 .... 12/30/84 · f/699.25 2W-I2 12/29/84 Run 1 3090 - 7178 " 27 05 - 8064 (Computed 1/19/85) (Computed 1/18/85) ~/69923 2W-11 ..... i.- 12/22/84 #69956 2W-13y .1/06/85 #69944 iQill / 1/04/85 Run 2 Run 1 2467 - 6660 4117.5-9151.5 3625 --7723.5 ~/699.43 2E-9-~/' 1/04/85. " 3856.5-8143 (Computed 1/16/85) (Computed 1/21/85) (Computed 1/21/85) (Computed 1/20/85) /cat .-~ ~ .- --~ /~ .~ ..; ...... ,,, Receipt Acknowledged: Date: DISTRIBUTION B. Currier Drilling W. Pasher State of AK BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D&M NSK Ops. J. Rathmell Well Files ARC,'D Alaska. Inc. is a subsldier¥ ol AtlanltcRichfieldCom~3,~ny , MEMORANDUM TO: TttRU: FROM: State of 'Alaska ALASKA OIL AND GAS CONSERVATION COPR~ISSION C. ~ftterton ..~?':.¥. Lonnie C Smith "~' ?' Commissioner Edgar W. Sipple, Jr Petroleum Inspector DATE: FILE NO: TELEPHONE NO: January 9, 1985 D.EWS.3 SUBJECT: Witness BOPE Test on ARCO' s Kuparuk lQ-11, Sec. 26, T12N,R9E,Ubl, Permit No. 84-199, Nabors Rig 26E. Monday, December, 31 1984: Mike Minder and I traveled this date from ARCO's p~Udhoe Bay DS 17-13 (subject of another report) to ARCO's Kuparuk iQ-Ii, Nabors Rig 26E, to witness a BOPE test. The drilling contractor was in the process of running casing. %]~e BOPE test commenced at 5:45 am and was concluded at 7:10 am. There were no failures. I filled out the AOGCC BOPE inspection report which is attached to this report. In summary, I witnessed the BOPE test on ARCO's Kuparuk iQ-II, Nabors Rig 26E. Attachment. 02-00IA(Rev, 10/79) 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator Well / ~ ~- Location: Sec ~..& Drillins Contractor Date Representative Permit t/ ~ Casing Set Representative Location, General ~ ~ Well Sign ~/%' ACCUMULATOR SYSTEM General Housekeeping~ Reserve Pit ~Rig e3 /c_ Mud Systems Visual Trip Tank Pit Gauge Flow Monitor Gas Detectors Audio BOPE Stac~ Annular P. reventer Pipe Rams Blind Rams~ Ch/o~ Line Valves H.C.~.. Valve ~"~'"fl ~i~ V a 1 v es ~ Check Valve Test Pressure Full Charge Pressure ~OD Pressure After Closure /~-% ~ Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: :Controls: Master Remote Test Results: FAilures ---- C) ---- Test Time / hrs. Repair or Replacement of failed equipment to be made within : ~- psig psig / ~.[.. %' ~ min~O sec. ~ min psig. ..',~ ! ("? . ~'/6' /~/,/,~,,? ,~ :~, ,, ~,~:.,:; ~-'f Blinds switch cover Kelly and Floor Safety Valves Upper Kelly ~/l~ ~'~est Pressure Lower Kelly ~)~ ~est Pressure Ball Type ~/< "~/Test Pressure Inside BOP ~/~ ~'~est Pressure Choke Manifold ~-~ Test Pressure No. Valves ~ ~/~/~3 ~ //)'k~ //.j' No. flanges Adjustable Chokes .% ,,'vfl~' choke Hydrauically operated / days and Inspector/ Commission of>ice notified. ..... Remarks: ~,"~ / Distribution orig. - A0&GCC ,,,,,o/~,,, cc - Operator ~.?.. ,~,';' cc - Supervisor Inspector ,":"." ,'.t~'~., .... ' ARCO Alaska, Inc.{ Post Office bu',,' 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 26, 1984 Mrs. Elaine Johnson State of A1 aska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - lQ Pad Dear Elaine, Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, O. Gruber Associate Engineer JG/tw GRU2/L44 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ i i i i i "'"~%984,418.67- Lat. 70°22'06.68Q5" · - ... ~'.': '...-.. . ..... :..:...-~..:. WELL cj i' 527~784.98 Long.149046'P-7.189'' :" .' .. " .. ' .Pod Elev. 56.6 O.G. Elev. 50. l ' .. .' ' 1,840' FEL 1,452' FNL '"-.. · · -- WELL I 0 Y = 5,984,429.02 Lat. 70°22'06.7849'' · ''~./ Pod Elev. 56.6 O.G. Elev. 50.:5 ~ 26 25 1~899' FEL 1,441' FNL WELL I I Y =5,984,459.44 Lot. ~22'06.8895" [ PHASE [ AS-BUILT x: 527,666.83 Long. 149°46'30.643'' PQd El ev. 56.7 ~G. Eiev. 50.6 -,'~ WELLS I Thru 8~ 1,95s' EEL 1,4~1' EEL I ' ' WELL 12 Y=5'984'449'95 Lot. 7~22'06.9949" X = 527~607'.83 Long. 149e46'3~368'' Pod Elev. 56.6 O.& Elev. 50.8 2,017' FEL .1~420' FNL ' ' WELL I~ Y=5,984~804.50' ' Lot. ~°22'10.4801" X = 5~7~670.55 ~ng. 149°46'30.500" Pod Elev. 55.3 0.~ Elev, 48.6 1~95Z' FEL 1~066' FNL WELL 14 Y=5,984,794.20 Lot. 70°22' 10.5766" X = 5~7~729.40 ~ng. 149046'28.774'' Pod Eiev. 55.3 O.G. Elev. 48.5 1~895' FEL 1~076' FNL WELL 15 Y=5,984,783.67 Lot. ~22'10.~708" WELLS 9 Thru 16 x= 5Z7,788.50 ~ng. 149°46'27,046" Pod Eiev. 55.5 O.G. Elev. 48.0 ' " 1~854' FEL 1~087 FNL ,': ~' ' ~ "' .... WELL 16 'Y= 5,984,773,22 Lat. 70°22'i0,1659" . , . X= 527,847.58 Long. 149°46'25.~19'' Ped Elev. 55.3 O.G. Elev. 48.3 1~775 FEL 1,098' FNL NO SCALE LOCATED IN PROTRACTED SECTION 26 ._~ ~ ~ ~. ~. ~ ~ ~.-.~...~.~..,.4.~... TOWNSHIP 12N, RANGE 9E, uMIAT MER. 3~t o~wo ~cc~ NOTE' S~S~S OF .OS~T~O. ~S aOaUaENTAT~ON ~-~ .... ' *~'&q'Z~'~~ AND 19-2 PER LHD ~ ASSOCIATES , .., ~ .... ,,. ' ~ 2~ ~ I ~~ I ~9" ~ ~ ~ ~ ~t i ~ I HEREBY CERTIFY ,HA- I AM PROPERLY REGISTERED AND'. E~THIS SURVEY L~C[NSED TO F,ACT~C[ LAUD SUrVEYinG ~, THE STATE OF L~~ ~ UNDER MY DIRECT SUPERVISION ANE THAT ALL DETAILS ArE CORRECT AS OF OCTOBER 15, 1984. ' :' . ARCO Alaska, Inc. ' ~~A . . ' ~ Kuparu" Project North SIo~e ,.Drilling l ~ ~ , LOCATIONS ~ Oote' Ocr. 11~!984 Sc~te: AS SHOW~ October' 31, 1984 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box !00360 Anchorage, Alaska 995] 0-0360 Re: Kuparuk River Unit !Q-11 ARCO Alaska, Inc. Permit No. 84-199 Sur. Loc. 1431'FNL, 1957'FEL, Sec. 26, T12N, RgE, UM.. Btmho!e Loc. !078'FSL, l129'F~L, Sec. 26, T12N, R9E, I~... Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required, Samples of well .cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a 'tape containing the digitized log information shall, be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the 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 commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, As amended. Prior to commencing operations you may be contacted by a representative of the Department' of Environmental Conservation. To aid us tn scheduling field work, please notify this office 24 hours prior to commencing installation of th~ blowout prevention. I.{r. Jeffrey B. Ke~v.~n Kuparuk River Unit ]Q- 11 _O October 3!, ]994 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. I~.re a diverter s~-stem is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testin~ before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly~ yours, /-~' ~. ....... -~ / z/ , ....... . /.. .... :.~' ~,/ / , ,/ C. V. Chattert°h Chai~an of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COMMISSION be EncloSure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation W/o encl. ARCO Alaska, Inc.l~r'_ Post Office _ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 19, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1Q-11 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 1Q-11, along with a $100 application fee ° Diagrams 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 We estimate spudding this well on January 4, 1985. If you have any questions, please call me at 263-4970. Sincerely, Ar~i ng Engineer JBK/JG/tw GRU2/L21 R£C£i Attachments VED 41aska Oil ~ ~a~ Co~. A~cborage Co~~ ARCO Alaska, Inc. is a Subsidiary of AflanticRichfieldCompany t0 STATE OF ALASKA ,,~" ALASKA ,L AND GAS CONSERVATION C(~,,,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL [~]X SINGLE ZONE~, DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE I_~ -2. Name of operator ARCO Alaska, Inc. ~ _ 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Locationofwellatsurface ...... 9. Unitorleasename 1431' FNL, 1957' FEL, 5ec.26, T12N, RgE, UN Kuparuk River Uni At top of proposed producing interval 10. Well number 1429' FSL, 1406' FWL, Sec.26, T12N, RgE, UM 10-11 At total depth 11. Field and pool 1078' FSL, 1129' FWL, Sec.26, T12N, R9E, UM Kuparuk River Field [- 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. Kuparuk River 0i 1 Pool RKB 93.9' PAD 56.9' ADL 25641 ALK 2572 , 12. Bond information (see ~20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 1129 feet 10-12well 56' @ 2419'ND feet -- 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 7713' MD, 6287' TVD feet 2560 01/04/85 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2757 psig@ 80°F Surface KICK OFF POINT 2109 feet. MAXIMUM HOLE ANGLE 46 Ol(see20AAC25.035 (c) (2) 5166 psig@ gl/~9 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 24" 16" 62.5// H-40 Weld 80' 36' I 36' 116'I 116' + 200 cf 12-1/4" 9-5/8" 36.0# J-55 BTC 3622' 36' I 36' 3658'I~ :~494' 850 sx Cold Set III + I HF-ERW ~ ] 600 sx Cold Set II 8-1/2" 7" 26.0# J-55 BTC 7678' 35' II 35' 7713'1 6287' 300 sx Class G HF-ERW I I ~ I 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7713' MD (6287' TVD). Selective intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2757 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to, releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 10-11 will be 56' away from 10-12 at 2419'MD. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (see attached sheet) .23. I hereby certif~y..that·///~.~/~~the foregoing is true and correct to the best of my knowledge /~//~ T h e sP ace b~'~¢C~p~f'//~ss i or~'-~e CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required APl number ~]YES /~-NO I--] YES [~4110 [~[Y E S F-]NO 50- O Permit number Approval date ~?-~.~ .~ ..--~ 10/31&84 SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY ~_Y/'~)'/~"'~/'J~/~~F~~-'' ,COMMISSIONER DATE ~¢, 1~-~ ¢1,- ........ L ~ /. ( ~l,__~~~ by order of the Commission Form 10-401 G 7PD0~ ~ / Submit in triplicate Rev. 7-1-80 PERMIT TO DRILL 1Q-11 The well will be completed by the workover rig using 3-1/2", 9.2#/ft, J-55, 8rd tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. ,RECEIVED Anchorage ~.~~~- ~:~ ~' .......... ~ ..................................... ~ ............. ;-~T 7~-~ .... ~'-,'~'~:',"~-'~' -T',: '~ ....... ~ .... ..: ...... ~*',~ ...... ::':'~ ~-',,'-'~ ...... 7 t' :-7:-': "; ;'; ~ ..... - - 1 ........ T ........ T - - ..... ~ .... ' ..... ~ ........... t ................. q ................... ............. ~ ....... q · ~ ................................... .... ~ - , . . , ~ ............ ~ ................... ............... ........ ;;:.:,:::;;:.: ..... i ................... . ..~ ~ .... ,. ~ ,,. : ~ ~ . ~ , , , ~ ~. ~ ..... : : : ; : ; : ,' .... : , i , ~ , 1, : . . . , , , , ; : .~. ............. , ..................................................... ~ ~-' , 1~_~ ~r''Tm, u'e,,~ ~u~,e ,,TOn-a~,~ *~e'~=a ~~, ~ ~nnn_ ':''":'. 'X:"':':'.__ .~g~a~:r__, A~nI:F,_ :'~:.', ~ " , : .....:~' ....... ~ ~ ~ . , . ~ ' , , ~ . ......... ~ ................... .' ~., ~ %"ARR~I~' RMT~ ' TV[.~gg4 TM~-7~R~ ~~)~R' ...: ..... : .., .... ~...: : :~ ~T'~,[O~"~' TvD-~028, rMD=Z$3F: DliP-321~Sg ........ · :..: ~ ~-'~l.~: S~D', ~' ' TVl ~.e'~ ~ · T~.?S~3 D~.: . ...... . ........................ , ...................... T~ .(L~}- PT) TVD,,6287 THD-?~t3 ~ EP-3~3* - ~: : . - ·. . : : : , , .... · ,- _.~-.: .... i ~ - - : : .. : : : _ ~ ~ - _ .......... , .... , .................. , ..... ~ . ~ , . , ....... ~ .................. , . . .............. ~ ...... ~ ..... ; ........... . ....... , ........................................ ~ ....... v~', ,c~Lo~,~. ........ : ........ t : .... :- i ........ ~ ' ~ ~ ...... ~ , . ~ , ...... : i ~ ['' AlaSka Oil~ Gas COns. CominiSsi°n ............... ~ ~ . . ~. ........... F ' ' ' ~ " ! A'oh°r~g~ 7~":"': .........:: ...... ~. ' ' ~ ,. ~ . ~ ' ' . ' ~ .............................. ~ ..... i ' '. -' HOR i 710NT,,,&L '.F ROJFCT 'i ' :": -' SCkLEi( ;N ' '1000 FEET i ...... ~RCO. ALASKA,. INC. · ..... ~ · 'i''' =^D 1Q..NELL NOt 1 ' PROPOSED . !.:-:---~.~ '-:CUP^RUK FIELD .NORTH SLOPE. [ sTac ' .......... I . ,. EASTMAN WHi · -I ._.. i ....... ! .. ~ ........ ? .......... ; - ' , ... . 1 . . . ! .... ~ . . . ......... ' '"t ........... ! ......................... , .......... ' .... ---~.. , . - ~E.ST--fE-AS-T- ........ 1 ~ ., :000 ' ' iO00:' .. ~ ~000.~ ....... ! : SURF^CiE LOCATION, ............... ~ ........... -;14.31' FNL, .1957' FEI, - · ............................................. :SE~; '26',-'T12N, 'RgE ............ ....... : .......... t i · ' · t , ----TVD 5994 1 ! ' 'TMD-7288 ' ] ..... i . . DEP-3226 , ' : t i TD ,-~OUT~-25~ ,, ~- i(LuOOT1 -] ---TAR~'T'-L-OCATION { ............ j ! 320',z FSL.! 1320'; FWL } ..... · SEC** ,26, T12N. RgE . i J ro Fi-} ~' ' · ; k'E:ST: 2003 ~ ...... j , ~ ....... ~ ..... ~ ........ , . . . & !Ga~ ,Cons. Co~misslon Anchorage 400J ~ 200j Ii00 UPARU? .F. IE~D,. NpRTH j~LOPE~i! ASTI4AIN--'WH ! ' N ,"' i PATHS· EXT I I ,! I 600 16"-2000 psi Tankcc s1'.artSng beach. 'i'ankco quick connect: atty. 16" X 20" 2CX)O psi ¢Jouble stu(3oed ac~apter. 10" ball valves~ hyOraulicall~ ac%uaseO, ./10" lines closure of annular preventer. 20" 2000 psi annular preventer. 20" bell nipple. b Haintenance & Ooeration 1. Upon initial installation close annular preventer an~ verify ~hat bail valves have opened properly. 2. Close annular preventer an¢ blow air through Civertmr lines every q2 hours. Close annular preventer in t)qe event that gms or fluid flow to surface is OetecteC. if necessary, ~nually overriOe an~ close ball valve to upwind Civerter line. Do not shut in ~ll under any circumstan:es. 1G" Conductor RECEIVED OCT 2'6 Alaska Oil & Gas Cons. Commission Anchorage PIP5 ~ D;AG~aJ~ ~1 5000 PS; ~S~ ~OP ~" 3. ~3' - 3000 ~$~ z ~3-5/8' - 5OO~ s~ool 5. !3-5/E' - 5000 ~si ~e rams · 7. ~3-5/~' - SOO0 ~si ~e rams 8. !3~~I8' - 5000 ~si ~l~n~ rams g. !3-~18' - ~OO0 ~$i ~nnu~ar F ~. CHECX AN~ KiLL ACC~U'.~TO~ ~SOO PSl ~O~NSTiEJ~ OF T~[ REGULATOr. 3. O£SE~vE T!~E. T'ME~ CLOSE ALL A~.L ~N:TS A~E CLDS~'~ ~i~"H, C.~RGING ~L,q"q,P DKF. ~. EECD~ ON NkDC REPORT. THE ACCEPTABLE LD~E~ -I. FiLL 5DP STACK AND ~',,NiIFC)LD ',,';TN ARCT,].' 2. CHECK 'NAT ALL MOL~ DOWN SF.~.~'S A~~. ~'~,' ' ~ '~'" .... ~.~_. RU~ ~N LOCK .~O~N $C2-."WS iN DON'T TEST AC, z~iN~ ~Oc~,~ A. TEST ALL CCh~I=ON~h'TS T~ Z.:~ P~:' AN,, HOL$' ~ i )',!NUTE~.. -'..-'Er,' .. TO Z-.'IO ~:. . OPEN ANNLJLA~ ~EVENTER AN: C'-~r TOP .ET, OF -~r. VAL\~S. TO ZE~C, =.<: T~ TEST~._,-~.. W';T)',' Z~O0 PSi LIP-CT~,EA~ OF ','AL','[ AND ZERO ~'.~' lO. INC~E. kSE P~.rssuRE T0 q.=OD pC.] AND MOL; ~ I NUTES BL'~.':..D TO ZERO ~S ]. il. OP"..N BOi'q'O)'l SET OF PIF~. ;.~J~.S. BACK OFt RUNNING JOINT AND PULL Ob'T OF MOLE. CLOSE ~L]N'D RA?,S AND TEST TO 3000 PS1 FOR I0 ~,IN.N.'T.:S. ~.Z.OPEN BLIND R~wj kND ~ECDvE~ TEST ~LU;. ~N]FOL~ AND L~N~S ARE r~JLL 0F A~CT:C ~L, VALVES ARE S~ iN DK~LL NG t F_ i3. TEST STANDPIPE VALVES TC 2000 ~S:. Alaska Oil & Gas Cons. Commie)ion ro~ S;GN ANT SEND r~ DA~LL~NG PE~FO~ C~;L~ BO~c T~' ONC~ A WE~K ~NC r~NC- Anchorage · ' ' T~DN~LY OPE~TE SOPE GAILY. CHECK LIST FOR NEW WELL PERMITS Lease & Well No. ITEM APPROVE DATE (2) Loc ¢ /,>,,~',.,, ,' ,: (2 thru 8) · · 3. 4. 5. 6. 7. (8) (3) Admin f.) ~' / ':~ ~'-~'~/ . (9 t~t~ 11) 10, (10 and 12) 12. (4) Casg /~TN /D'a-?-~9 (13 thru 21) (22 thru 26) 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. (6) Add: /,/~# 27. YES NO · , Is the permit fee attached .......................................... ~,/~/~__.. Is well to be located in a defined pool ............................ 6{:'~_a..,.,a__ Is well located proper distance from property line .~.?~___ Is well located proper distance from other wells ................... ~_, Is sufficient undedicated acreage available in this pooi (,~ ~ Is well to be deviated and is well bore plat included ................ ~" ~ Is operator the only affected party ................................. "i.~, Can permit be approved before ten-day wait ........................... ,"' ~ Does operator have a bond in force .................................. (."", Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... ,, , Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. ~-~ Is old wellbore abandonment procedure included on 10-403 ............ Is adequate 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 ~r~ psig .. ~ Does the choke manifold comply w/AFI RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. ~. REMARKS N~ T- $ o IgfW ! TF~D ~-~ o Geology: Engineering: HWK ~ LCS / BEW WVA~ ~ JKT~HJH JAL ,~I~~M ~ " rev: 12/08/83 ~,loq ' T'PD, &Zo:~£~ 7'- POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE Well History File APPENDIX Information of detailed nature that is not padicularly 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 effod has been made to chronologically organize this category of information. ¸i' .. ' ' - _. -2'0 },.3 :b ;L } 7 ~. .2-i :-:. ,.. 2-33 3;::C z 3 !0~ V' -}9}.25:50 _. 5::31- . . -99::. -_:..35 5...7 _:0 10-.$2_::4 - '5 ,,_.'-5;0
