Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
197-109
ORIGINATED TRANSMITTAL DATE: 5/8/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5416 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5416 3K-35 50029227750000 Plug Setting Record 24-Apr-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 197-109 T40392 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.08 13:10:13 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com WELL LOG TRANSMITTAL #904453342 To: Alaska Oil and Gas Conservation Comm. January 17, 2018 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVE!) Anchorage, Alaska 99501 DATA LOGGED FEB 01 2018 ,cX2 01 K BENDER AOGCC RE: Leak Detect Log with ACX: 3K-35 Run Date: 11/23/2018 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS ANC@halliburton.com 3K-35 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-22775-00 Leak Detect Log with ACX (Processed Log) 1 Color Log 50-029-22775-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 %ANNMd FRS ANC@halliburton.com Date: Signed: M/12.4.....4) 6..ekirat .6---T- • • r� N ~ 1 (� w T.¢ v r O > E /�'� W Q p " bocv zo v -0 O M Y O ca E I--- Y ° c N U > i 000 _ U . a c co , o cz } a Y r c =p a Q a ° E a Cr CO Y In a 0 r r N- N- r r N v ) 0 '0 N r E o -o O ° C) _ N V) h ,- N 0 h CO Q) N N N N N N CO O Y i c Q Z Q °co N ] E -O u Y v YO CO O f () v -0 v) U c i v U.' 0 J -I _J -I -1 -I °A c — U w W W W W W W W , v 'c .-+ I- LL LL LL LL LL IL LI- ID+' N N N co I- a Q Q Q Q Q Q Q cu li)a c +' w G Cr) aZ Z Z Z Z Z Z N L N 0 v I ° LL LL LL L.L. LL LL LL rY Q C > ch U v v a1 C, d fp c a) L O Gi E a; • Z7 v a v u v U w O i v Immo• 0 OC a ~ > rraa a o 0 c0 � CU Q v a c a 0 la 4 0) 0 LL �M �,y O G J Q C Q Jam. GS [8 � o m = aa o 1 0 'CS m U F a N O • F z La d CCI y 411n tn > 1-4 x' >° 4-, LU ii RI • 46 d v> 44 ~ \ v al x O N Z W.2• �i F, cd W O es Z e V a J J J J J J J 7 4 `')CO � FE33333intn 333 ..... 1110"1111 WWWWWW Ce fn W W W W W W W w > > > > > > > Z Y Y Y Y Y Y Y CCCYCLCLCZCYCL < < < < < < < a a a a a a aQ > > > > D > > CO YYYYYY Y ' WU o OA O co O D o o v E C 4 a, ci 0 0 0 0 0 0 0 d �f• �� W. 0 0 0o 0 0 0 CD - V' o o CO CO 00 CO o > > cnVI c V C7 W: 0000000 a c a Q w o EY WO O O o r O U CC lD 0 0 0 0 0 0 0 f� : Q N. V) N N O O O) O a+ h h CO CD c0 CO CO ++ •- °- Cr) I,- r O Cr) M CO O IN N N O rC N NNNNNNN y) L• r N N N N NNN fa C u O 0 O O O O O O O L ° U 0 0 0 0 0 0 0 +' +� C ° ri CO N N l') CO u) u) v) 4,Cl. C O c Cw D 0 • W p .- aa u o w E E w MMOZM rv el 6 Zm M o 0 co ro +, + E ar y o' = d_ 11 J Y Y CO N N cO , 4-1 o Q Q N W M M N N � z0n N ou N V 1 OO 3 = ' EE c t0 -4 "."--L ro c ` aNF- aa H �9-�- ‘ocl • zGgs% WELL LOG TRANSMITTAL#902803145 DATA LOGGED 11/10/2015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. November 5, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper(MFC): 3K-35 Run Date: 10/2/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3K-35 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22775-00 CANNEL; PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: PP9✓Q��,ctyta XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. / ?~'~-/0~ File Number of Well History File PAGES TO DELETE RESCAN n Color items - Pages: n Grayscale, halftones, pictures, graphs, charts - Pages: [] Poor Quality Original'- Pages: [] Other - pages: DIGITAL DATA [] Diskettes, No. n Other, No/Type -OVERSIZED .Logs of vadous kinds o Other Complete COMMENTS: Scanned by: ae,~-.y Mitdred-D'amtha (~Lowell TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: /si STATE OF ALASKA RECEIVED ALA ,OIL AND GAS CONSERVATION COMB ,ION REPORT OF SUNDRY WELL OPERATIONS NOV 20 2013 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate r Other r �' Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extensiorl GC Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development (;r Exploratory r 197-109 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-029-22775-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25629 • 3K-35 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 9118 feet Plugs(measured) None true vertical 6804 feet Junk(measured) None Effective Depth measured 9014 feet Packer(measured) 7862,7915,8148 true vertical 6796 feet (true vertical) 5892, 5932,6106 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121' SURFACE 5257 7.625 5298 4101 PRODUCTION 8323 5.5 8362 6268 LINER 966 3.5 9114 6898 Perforation depth: Measured depth: 8580-8600, 8616-8638 S NNED S N 2 {T 014 True Vertical Depth: 6436-6452,6465-6483 G Tubing(size,grade,MD,and TVD) 3.5, L-80,7881 MD, 5906 TVD Packers&SSSV(type,MD,and TVD) PACKER -BAKER PRODUCTION PACKER @ 7862 MD and 5892 ND PACKER-BAKER"SABL-3"PRODUCTION PACKER @ 7915 MD and 5932 TVD PACKER-SABL-3 LINER TOP PACKER @ 8148 MD and 6106 TVD NIPPLE-LANDING NIPPLE @ 513 MD and 513 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development 17• Service r Stratigraphic r- 16.Well Status after work: Oil 17. Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Ian Toomey Caa,263-4773 Email Ian.A.Toomey @conocophillips.com Printed Name Ian Toomey Title Wells Engineer Signature �— Phone:263-4773 Date //- /9-/3 VL f= /)- 1 RB MS NOV 2 O Form 10-404 Revised 10/2012 i olit !4 /� Submit Original Only 1.-- i KUP PROD 3K-35 ConocoPhillips I Well Attributes Max Angle&MD TD Alaska.Inc. Weilbore API/UWI Field Name Wellbore Status Ind C) MD(ftKB) Act Btm(ftKB) maps 500292277500 I KUPARUK RIVER UNIT PROD 48.47 2,550.00 9,118.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 36-35,11/1 5/201 3 10:40:28 AM SSSV:NIPPLE 150 12/8/2011 Last WO: 'End 31.72 7/21/1997 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation -Last Mod By End Date • HUNGER 268 >,. ■ Last Tag.SLM 8,823.0 8/3/2013 Rev Reason:WORKOVER haggea 11/13/2013 . . . .. .. Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread N. _ CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len p...Grade Top Thread MI I� SURFACE 7 5/8 6.750 41.1 5,298.0 4,100.9 29.76 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...'Wt/Len(I...Grade Top Thread I PRODUCTION 512 4.653 38.8 8,3620 6,267.7 15.50 L-80 LTC-MOD CONDUCTOR;41.0.121.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread LINER 312 2.992 8,147.5 9,1117 6,898.3 9.20 L-80 ABM-BTC Liner Details NIPPLE;513.1 ® Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Intl C) Item Des Corn (in) 8,147.5 6,106.1 40.94 PACKER BAKER KBH-22 w/SABL-3 LINER TOP PACKER 2.780 Tubing Strings Tubing Description I String Ma...'ID(in) 'Top(ftKB) 'Set Depth(ft..f Set Depth(ND)(...IWt(lb/ft) 'Grade 'Top Connection `II r TUBING WO-2013 3 1/2 2.992 26.8 7,88051 5,906.1 920 L-80 IBT-M Completion Details GAS LIFT;3.152.3 Nominal ID I "I Top(ftKB) Top(TVD)(RKB) Top Incl(°) Item Des Com (in) I 26.8 26.8 0.10 HANGER HANGER,TBG,FMC 2.992 513.1 512.7 5.19 NIPPLE NIPPLE,LANDING,312","DS",2.875",EUE8RMOD 2.875 GAS LIFT;5,017.8 7,799.9 5,846.2 42.01 NIPPLE N PPLE,LANDING,WIRHC-M PLUG 2.812 7,844.1 5,879.0 41.98 SEAL ASSY BAKER SEAL ASSY,80-40,GBH22 2.980 7,847.6 5,881.6 41.98 PBR BAKER 80-40 PBR 3.000 ��I 7,861.2 5,891.7 41.95 ANCHOR BAKER KBH-22 ANCHOR SEAL ASSY 2.990 i 7,861.8 5,892.2 41.95 PACKER BAKER FA-1 PRODIUCTION PACKER 3.000 it 7,873.8 5,901.1 41.92 OVERSHOT BAKER POORBOY OVERSHOT 3.610 SURFACE,41.15,298.0 Tubing Description I String Ma...'ID(in) 'Top(ftKB) Set Depth(ft..'Set Depth(TVD)(...'WI(1b/16 'Grade 'Top Connection TUBING WO-2009 3 12 2.992 7,875.5 8,114.0 6,080.8 9.30 L80 EUE8RD GAS LIFT;6.318.2 i STACKER PACKER Completion Details 'Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Ind I") Item Des Com (in) GAS LIFT;7,263.7 7,898.6 5,919.6 41.85 SEAL ASSY BAKER 80-40 LOCATOR SEAL ASSEMBLY w/2' 3.000 SPACE OUT(12'SEAL)5,921.4 41.85 PBR BAKER 80-40 PBR 11.1 7,914.6 5,931.5 41.88 ANCHOR BAKER KBH 22 ANCHOR SEAL ASSEMBLY 3.250 . 1060 GAS LIFT;7.746.5 7,915.4 5,932.1 41.88 PACKER BAKER"SABL-3"PRODUCTION PACKER 2.760 8,089.9 6,0627 41.19 NIPPLE HES"XN"NIPPLE w/2.75"PACKING BORE 2.635"NO 2.635 GO NIPPLE;7,799.9 r 8,107.7 6,076.1 41.12 OVERSHOT BAKER POORBOY OVERSHOT w/2.80'SWALLOW 3.600 Tubing Description I String Ma...I ID(in) 1 Top(ftKB) 1841 Depth(R..'Set Depth(ND)I...'Wt(IWft) 'Grade I TOP Connection TUBING Original 3 1/2 2.9921 8,110.01 8,147.5 6,106.1 9.30 L-80 ABM-EUE SEAL ASSY;7,&4.1 Completion Details Nominal ID PBR;7,817.6 ) :. Top(ftKB) Top(ND)(ftKB( Top Inc!(°) Item Des Com (in) ANCHOR;7,861.2 8,125.8 6,089.7 41.04 NIPPLE CAMCO D'NIPPLE 2.750 PACKER;7,861.6 ' 8,133.0 6,095.2 41.01 LOCATOR BAKER LOCATOR 3.000 8,133.4 6,095.5 41.01 PBR BAKER PBR 10'STROKE 3.000 1 'Irl OVERSHOT;7,873.8 8,146.8 6,105.6 40.94 ANCHOR BAKER KBH-22 ANCHORAGE SEAL NIPPLE- 3.000 SEAL ANCHORED TO SABL-3 LINER TOP PACKER Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SEAL ASSY;7,898.6 ' ° Top(TVD) Top Ind I PBR;7,901.0 Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) ANCHOR;7,914.6 8,085.0 6,059.0 41.20 Fish PIECES OF BROKEN GRAPLE 10/23/2013 0.000 PACKER;7,9154 _ 8,085.9 6,059.7• 41.20 CATCHER 2.79"JUNK CATCHER 8/4/2013 0.000 8,089.9 6,062.7 41.19 PLUG 2.75"XXN PLUG 8/3/2013 0.000 CATCHER;8.0B5.91 Perforations&Slots PLUG;8,089.9 Shot NIPPLE;8,089.9 :. Dens If 1 Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ttK8) (ftKB) (ftKB) Zone Date t) Type Com 8,580.0 8,600.0 6,436.2 6,452.1 A-3,3K-35 7/21/1997 4.0 IPERF 2.5"HSD;160 deg. I/ � OVERSHOT;8,107.7 i,lIll CCW Frei 8,616.0 8,6380 6,464.9 6,482.6 A-2,3K-35 2/28/2002 ' 4.0 APERF 2.5"HSD,180 phase NIPPLE;8,125.8 •s• Mandrel Inserts li St LOCATOR;8,733.0 at! C PBR;8.133.4 ' on Top(ND) Valve Latch Port Size TRO Run o ANCHOR SEAL;8,146.9 'C*-• No Top(ftKB) (MB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m 1.71.irl 1 3,152.3 2,591.6 CAMCO KBG29- 1 GAS LIFT GLV INT 0.156 1288.0 11/12/2013 1R ■ 2 5,017.8 3,904.3 CAMCO KBG29- 1 GAS LIFT GLV INT 0.188 1,327.0 11/12/2013 1R 1 3 6,318.2 4,7952 CAMCO KBG29- 1 GAS LIFT OV 'INT 0.188 0.0 11/12/2013 1R PRODUCTION;38.8-8,362.0 4 7,263.7 5,455.3 CAMCO KBG29- 1 GAS LIFT DMY INT 0.000 0.0 10/23/2013 1R 5 7,746.5 5,806.5 CAMCO KBG29- 1 GAS LIFT DMY 'INT 0000 00 10/23/2013 IPERF;8,580.0-8,600.0 1 R I -- - Notes:General&Safety APERF;8,616.08,638.0 End Date Annotation 4/10/2009 NOTE:WORKOVER 4/18/2009 NOTE:View Schematic w/Alaska Schematic9.0 7/25/2013 NOTE:200"JUNK MILL REMOVED OBSTRUCTIONS @ 8597'8 8626' LINER;8,147.5-9,113.7 3K-35 Pre and Post Well Work Summary Pre Rig Well Work Summary DATE SUMMARY 4/17/2013 TAGGED @ 8570'SLM, EST. 48' FILL. BRUSHED PATCH INTERVAL. DRIFTED TBG WITH 2.74"x 20.9' DUMMY PATCH TO 7900' RKB. READY FOR TBG PATCH. 6/27/2013 GAUGE TBG W/2.74 GAUGE RING TO XN NIPPLE @ 8089' RKB; BRUSH XN NIPPLE AND GLM'S; TAG FILL @ 8563'SLM (EST. 57'OF FILL)&MEASURE BHP (4145 psi) @ 8578' RKB. SET 2.75 XXN PLUG W/ FILL EXTENSION @ 8089' RKB(GOOD DDT); SET JUNK CATCHER ON TOP OF XXN @ 8079' RKB. IN PROGRESS. 6/28/2013 PULLED EX PACKING DMY FROM STA#5 @ 7847' RKB (POCKET OPEN); PULLED GLV'S FROM 6337', 5004', 3012' RKB. AND SET DV'S; CMIT TO 2500 PSI ** PASS** /DDT TO 500 PSI **PASS** 7/21/2013 SET EXT. PKG BOTTOM LATCH DV @ 7847' RKB. PULLED JUNK CATCHER @ 8061' RKB. EQUALIZED& PULLED 2.75"XXN PLUG. IN PROGRESS. 7/22/2013 DRIFTED TBG WITH 2"SAMPLE BAILER. TAGGED @ 8570'SLM. READY FOR CTU. 7/25/2013 Ran 2.60"junk mill to remove hard obstructions at 8,597-ft and 8,626-ft RKB, clean down to 8,800-ft RKB with no more obstructions encountered, moderate scale in returns. Ready for Slickline. 8/3/2013 TAG TD @ 8823' SLM (EST. 197'OF RAT HOLE). SET 2.75 XXN PLUG @ 8089' RKB. PASSED 2500 CMIT TxIA. IN PROGRESS. 8/4/2013 SET 2.79"JUNK CATCHER ON TOP OF XXN PLUG @ 8083' RKB; PULL DV @ 7847 RKB. JOB COMPLETE. 8/16/2013 (PRE-RWO): T POT-PASSED; T PPPOT-PASSED; IC POT-PASSED; IC PPPOT-PASSED;ALL T LDS'S FUNCTIONED PROPERLY. 9/10/2013 (PRE RWO): SCLD (PASSED)TO 1000 PSI. 9/11/2013 (PRE RWO): T X IA DDT(IN PROGRESS). 9/12/2013 (PRE RWO): T X IA DDT(PASSED). Post Rig Well Work Summary 11/9/2013 DELAYED START, HIGH WINDS. GAUGED TBG TO 2.77"TO 0/S @ 7855'SLM. STARTER ON CRANE ENGINE OUT, WAIT ON MECHANIC TO CHANGEOUT. IN PROGRESS 11/12/2013 PULLED SOV @ 6318, DVs @ 5017', &3152' RKB; SET OV @ 6318'. SET GLVs @ 5017' &3152' RKB; ATTEMPT TO PULL CATCHER&SET DN @ 8039'SLM (CATCHER @ 8085' RKB). IN PROGRESS ConocoPhilli s Time Log & Summary p Weaview Web Rebottle." Report Well Name: 3K-35 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 10/10/2013 9:30:00 AM Rig Release: 10/25/2013 6:00:00 PM Time Logs Date From ' To Dur S.Depth E. Depth Phase Code Subcode T Comment 10/10/2013 24 hr Summary Move rig to center pad. **Rig Accept 09:30**Disassemble Hydril double gate&shaffer single gate.Assemble newly dressed and certified shaffer double gate&single Hydril. Hang tree in cellar, Pull over 3K-35 and spot equipment, install cuttings tank, R/U hard line in cellar and cuttings tank. Begin taking on 8.6#Seawater with 1%safe lube, Pull BPV-SITP= 100 psi, SICP=220 psi. Pressure test surface lines 250/2500 psi. Bleed off well, reverse circulate 60 bbls @ 2 bpm, ICP 550/FCP 230 psi. Start pumping down tubing. 07:00 16:30 9.50 MIRU MOVE MOB P Pull off of 3K-23,spot rig on pad and perfrom BOPE swap. Hang tree in cellar. Rig accept @ 09:30 hrs due to covering install of BOPE due to corrosiion wear on stack. 16:30 19:00 2.50 MIRU MOVE MOB P Spot rig over well,set down containment around cellar and cutting tank. 19:00 21:00 2.00 MIRU MOVE RURD P R/U hard line to kill tank,valves&kill lines on tree. Load fluid in the pits and spot cuttings tank. 21:00 23:00 2.00 MIRU WHDBO MPSP P PJSM-R/U lubricator,test to 1000 psi. Pull BPV.Tubing pressure 100 psi&IA 220 psi.Test all surface lines 250/2500 psi to kil tank. Held Pre-spud with Toli's crew 23:00 00:00 1.00 MIRU WELCTL CIRC P PJSM-open well to kill tank,strap- 27 bbls. Start killing the well taking returns to kill tank. Start 2 bpm @ 660 psi reverse circulating 60 bbls. Stop&pump long way 3 bpm @ 610psi. 10/11/2013 Kill well with 8.6#Sea water pumping 3 bpm,total of 250 bbls pumped,clean SW to surface. No-flw check, install BPV,test 1000 psi, ND tree, NUBOPE. Install 2 7/8"X 5"VBR's. BOPE test 250/5000 psi. Pull BPV &blanking plug. P/U landing joint,tubing hanger free @ 90K. Could not work string free-max P/U weight 170K. Start loading workstring while waiting on E-line crew. 00:00 02:00 2.00 MIRU WHDBO CIRC P Pump SW down tubing @ 3 bpm ICP 630 psi, IA pressure 120 psi. Pump 190 bbls down tubing/total of 250 bbls pumped. Stop-FCP=0. Blow down lines.30 minute no-flow check. 246 bbls for returns/250 bbls pumped. 02:00 02:30 0.50 MIRU WHDBO MPSP P Install BPV,test 1000 psi. 02:30 03:30 1.00 MIRU WHDBO NUND P ND tree, Inspect API ring groove& TBG hanger threads, Install BP. 03:30 05:30 2.00 MIRU WHDBO NUND P NU BOPE. Page 1 of 14 . Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 05:30 09:00 3.50 MIRU WHDBO OTHR P Install 2-7/8 x 5 VBR's in LPR's, UPR's and Blind Rams. 11"Hydril VBR's-changed Top seal and Packers 11"Shaffer VBR's-Change Top Seal 09:00 15:30 6.50 MIRU WHDBO BOPE P Begin testing BOPE 250/5000 psi -State test waived by Jeff Jones. During body test Grey lock fittings had numerous leaks. Replace seals and re-test. 15:30 16:30 1.00 MIRU WHDBO BOPE T Continue with BOPE test,250/5000 psi. Over run of 12 charge for NUBOPE&test. 16:30 18:00 1.50 MIRU WHDBO MPSP P Pull Blanking plug and BPV. Make up landing joint. 18:00 19:00 1.00 COMPZ RPCOM SEQP P PJSM-BOLDS, Hard line froze to Kill tank following BOPE test. 19:00 22:00 3.00 COMPZ RPCOM PULL P Pull on tubing string, hanger came free @ 90K,continue to work tubing with max. P/U of 170K. Cannot work string free. Pump 3 bpm @ 480 psi, circ B/U and try to work string.-no luck. Call out E-line. 22:00 00:00 2.00 COMPZ RPCOM CIRC T Wait on E-line. Continue to cirdulate 2 wellbore volumes&try to work string free. Begin loading workstring 3.5"PH-6 into pipe shed. 10/12/2013 Hold 30K on string, R/U E-line, RIH for string shot @ 7875', POOH P/U RTC cutter-RIH cut tubing @ 7875'. RD Eline. P/U on string&pull hanger to the floor 95K P/U weight. Circulate 2 X Bottoms up pumping 5 bpm @ 1180 psi. No flow Start Pulling tubing string. 00:00- 06:30 6.50 COMPZ RPCOM OTHR T Continue loading PH-6 workstring. Wait on E line to arrive. 06:30 16:30 10.00 0 7,875 COMPZ RPCOM ELNE T Spot Eline equipment, land TBG in 120k tension, 30k OSW. Held PJSM, RU Eline. PU and RIH w/ string shot and shoot @ 7,875-ft, POOH. RIH w/RCT Cutter and cut 3-1/2 TBG @ 7,875-ft. Observed cut -good. POOH and RD Eline. 16:30 17:00 0.50 7,875 7,845 COMPZ RPCOM PULL T Pull hanger to rig floor and lay down same @ 95k up wt. 17:00 18:00 1.00 7,845 7,845 COMPZ RPCOM CIRC T Circulate 2 hole volumes @ 5 bpm @ 1,180 ICP and 1,140 FCP. 18:00 18:30 0.50 7,845 7,845 COMPZ RPCOM OWFF T NFT -Good. 18:30 00:00 5.50 7,845 2,800 COMPZ RPCOM PULL T POOH laying down 3-1/2 decompletion from 7,845-ft to cutjt. Kick out pipe every 1000ft,tally. 10/13/2013 TOOH with 3 1/2"decompletion string,started to see corrossion on pins&collars only from joint#145 (3300')to surface. Recovered cut joint#247-14.26'at surface. P/U fishing BHA#1 Itco spear,jars, subs& drills collars.TIH P/U 3 1/2"PH-6 workstring. CBU from 7835', P/U weight 123K,down 95K. RIH latch into fish,jars fireing 50K over 175K,straight pull to 275K. No luck fishing, release from fish,derrick inspection and flow check,TOOH. Page 2 of 14 Time Logs Date From To Dur S.Depth E. Depth Phase ` Code '` Subcode T Comment 00:00 04:00 4.00 2,800 0 COMPZ RPCOM PULL P Continue POOH with tubing string from 7875' Corrossion noticed on pins from joint 145(3300')out to 247. Heavy build up on collars 227&247,tubing is clean.Cut joint#247=14.26'at _ surface. 04:00 06:00 2.00 0 0 COMPZ WELLPF PULD P Load BHA and drill collars into pipe shed. Change floor equipment for running PH-6 pipe. 06:00 08:00 2.00 0 296 COMPZ WELLPF PULD P PJSM, P/U BHA#1 Baker inner grapple spear, oil jars and pumper subs. 08:00 16:00 8.00 296 7,855 COMPZ WELLPFPUTB P RIH w/BHA#1 PU 244 jts of 3-1/2, 12.95 lb/ft, P-110, PH-6 Hydril work string 16:00 16:15 0.25 7,855 7,855 COMPZ WELCTL OTHR P Gather SPR's Pump 1 20 spm @ 480 psi 40 spm @ 1320 psi Pump 2 20 spm @ 520 psi 40 spm @ 1340 psi 16:15 16:30 0.25 7,855 7,880 COMPZ WELLPF FISH P Continue to RIH and Engage 3-1/2 TBG stub @ 7,875-ft to 7880-ft. 123k up wt/95k do wt with pumps on 16:30 20:00 3.50 7,880 7,880 COMPZ WELLPF JAR P Continue jarring on fish,jars fireing 50K over string weight 175K. Straight pull to max of 280K. 20:00 21:00 1.00 7,880 7,880 COMPZ WELLPF SFTY P Release from fish-Perform derrick inspection.-flow check. 21:00, 00:00 3.00 7,880 233 COMPZ WELLPF TRIP P TOOH with fishing BHA#1 standing back workstring. 10/14/2013 TIH with 4 3/4"wash over shoe&pipe,establish rates above fish.Tag TOF @ 7875', rotate over @ 7 rpm, pumping 4 bpm @ 1200 psi. Clean down to No-go 7892', set down 5K, cycle pipe and circulate well clean. Pump 35 bbls Hi Visc, lots of hard packed formation sand and scale over shakers. Clean up well-TOOH.TIH with 4 11/16"overshot and latch onto fish @ 7875'. No luck recovering after 3 hours of jarring. Difficult time backing overshot off of fish, had to work it multiple times with higher rpm and weights.TOOH. 00:00 02:00 2.00 233 0 COMPZ WELLPF PULD P Lay down BHA#1 02:00 03:00 1.00 0 318 COMPZ WELLPF PULD P P/U BHA#2 with 4 3/4"wash over shoe and pipe,jars and Drill collars. 03:00 06:00 3.00 318 7,875 COMPZ WELLPF TRIP P TIH with BHA#2 to TOF @ 7,875-ft. 06:00 09:00 3.00 7,875 7,892 COMPZ WELLPF FISH P M/U TD. Est. parameters,Tag TOF @ 7,875-ft and rotate over at 7 rpm and circulating @ 4 bpm @ 1200 psi, No-go set down 5k @ 7,892-ft. Circ. well clean out, (2 hole vol.), Pump 35 bbl hi visc sweep and Circulate surface to surface @ 7 bpm @ 3,250 psi. 09:00 09:30 0.50 7,892 7,892 COMPZ WELLPF OWFF P Monitor well for flow-No flow. Blow down Top drive. 09:30 13:00 3.50 7,892 318 COMPZ WELLPFTRIP P PJSM, POOH from 7,887-ft to 318-ft. Page 3of14 • Time Logs Date From To Dur S. Depth E.Debth!Phase Code Subcode T Comment 13:00 13:30 0.50 318 0 COMPZ WELLPF PULD P POOH and lay down wash over pipe and shoe. 13:30 14:30 1.00 0 292 COMPZ WELLPF PULD P PU and RIH w/4-11/16"OS w/3-1/2" spiral grapple, Plain control and 3-5/8"Type A Packer on 3-3/8"OD DC's to 292-ft. 14:30 17:30 3.00 292 7,875 COMPZ WELLPF TRIP P RIH w/BHA#3 from 292-ft to 7,875-ft. 17:30 21:30 4.00 7,875 7,875 COMPZ WELLPF FISH P Engage fish and Begin jarring on fish, String weight 125K,Jars firing 50K over, straight pulling to 270K max pull.Work string with no movement for 3 hours.Total of 61 jar licks. Decision made to release-difficult time releasing from fish, rotating 30 rpm-torque up when P/U. Set back down and increase RPM to 60, continue to work string up while rotating,took 75K over to break over and release. 21:30 23:00 1.50 7,875 7,870 COMPZ WELLPF CIRC P Sitting 2ft above fish,circulate 20 bbls hi-visc sweep pumping 5 bpm @ 1800psi.followed by 8.6#Brine. Perform derrick inspection. Very light sand returns with sweep. 23:00 00:00 1.00 7,870 7,870 COMPZ WELLPF SFTY P Blow down top drive,set up rig floor for TOOH, perform no-flow test. PJSM-TOOH 10/15/2013 Continue TOOH. UD Baker fishing assembly. P/U and RIH with Packer on Working String. Circ CI brine around packer and set packer.TOOH standing back w orking string(split)in Derrick. 00:00 05:00 5.00 7,870 0 COMPZ WELLPF TRIP P TOOH with Fishing BHA#3 05:00 07:00 2.00 0 0 COMPZ WELLPF PULD P Stand back 3 stands DCs. LID BHA #3 and inspect grapple. 07:00 08:30 1.50 0 0 COMPZ RPCOM PULD P Mobilize Baker hand and packer with poor boy overshot lower completion. 08:30 10:00 1.50 0 0 COMPZ RPCOM SLPC P Slip and Cut and service drawworks. 10:00 15:00 5.00 0 7,880 COMPZ RPCOM RCST P Pick up Baker Poor Boy Overshot and Packer assembly with"J" setting tool. Trip in hole on 3 1/2"PH-6 workstring. Locate top of stump @7875'. Shear pins in overshot 6K over. No go out 25K and pick up 1'placing Top of Packer at 7861'. Mule shoe @ 7880' UP Wt. 125K DN.Wt.92K 15:00 16:00 1.00 7,880 7,880 COMPZ RPCOM CRIH P Pump 10BBLs of 1%Baker Petrolite CRW-132. Chase with 60BBLs of 8.6ppg sea water placing CI around packer and inside packer assembly. Page 4 of 14 Time Logs Date From To Our S. Depth E. Depth Phase Code Subcode T` Comment 16:00 17:00 1.00 7,880 7,880 COMPZ RPCOM PACK P Drop 1 7/16"Ball and allow to fall. Pressure up to 700psi and shear sub. Incrementally stage pressure up to 2500psi. Lost 12K on weight indicator. Pick up and confirmed latch. Shear out at 125K 17:00 17:30 0.50 7,880 7,880 COMPZ RPCOM OWFF P Check well for flow for 30 min. Good 17:30 23:00 5.50 7,880 0 COMPZ RPCOM TRIP P Trip out of hole standing back working string. (Splitting pipe in Derrick.) 23:00 23:30 0.50 0 0 COMPZ RPCOM PULD P LID Baker running tool as per Baker Rep. 1 7/16"Ball recovered on seat. Seal ring intact on box connecction. 23:30 00:00 0.50 0 0 COMPZ RPCOM RURD P Clean and clear rig floor. R/U to run 3.5"completion. 10/16/2013 RIH with 3.5"completion. Set anchor assembly and PBR,shear out of PBR, circ CI brine and space out, hang off 3.5"upper completion.Attempted 3500 psi pressure test on tubing,bled off after 1 minute. Mobilize slickline to rig for leak detection. R/U slickline and RIH testing below each GLM. Presure test 4 indicated leak coming from GLM#3 with SOV. 00:00; 09:30 9.50 0 7,815 COMPZ RPCOM RCST P RIH with 3.5"completion to 7815' 09:30. 12:00 2.50 7,815 7,815 COMPZ RPCOM CRIH P Spot 31BBLs of 1%Baker Petrolite CRW-132 from anchor assembly up hole to#3 GLM with SOV. 2.8 BBUMin 529psi 12:00 12:30 0.50 7,815 7,860 COMPZ RPCOM PACK P Engage top of packer with anchor assebly at 7860'. Set down 25K pull 10 over set back down and confirmed latched. Up Wt.97k Dn Wt.75k Pressure up to 1800psi and held. Pick up and shear PBR at 123k 26k over 12:30 13:00 0.50 7,860 7,879 COMPZ RPCOM HOSO P Space out and land hanger. Pick up 5.81'pup 2.27'away from fully located. RILDS 13:00 14:00 1.00 7,879 7,879 COMPZ RPCOM PRTS P PJSM on testing tubing and IA. Rig up test manifold. 14:00 17:30 3.50 7,879 7,879 COMPZ RPCOM PRTS T Attempt to pressure test tubing to 3500psi, held for 1 minute then began to bleed off,fluid coming out IA. Closed in IA and built to 600psi tubing stabilized at 1200psi. Bled off tubing and IA held 600psi. Bled IA off and pressured up tubing to 1000psi and held good.Attempted to go to 1500psi and began communicating to the IA. Conitnue to trouble shoot while calling out slickline with hole finder. 17:30 21:00 3.50 7,879 7,879 COMPZ RPCOM RURD T PJSM.Move in and Rig up HES slickline. Page 5 of 14 . Time Logs Date From To Dur S.Depth E. Depth Phase< Code Subcode T Comment 21:00 21:15 0.25 7,879 7,879 COMPZ RPCOM PRTS T Pressure test lines to 1000 psi, ramping up to 2000 psi.Test 21:15 00:00 2.75 7,879 7,879 COMPZ RPCOM SLKL T RIH with hole finder slickline tool. Deploy at 7879'SLM,pull up to position 1 @ 7821'SLM(middle of joint below bottom GLM#1), pressure to 1000 psi,bled off 150 psi in 10 minutes, pull up to poisition 2 @ 7280'SLM in full joint below GLM #2, pressure to 1000 psi, observed pressure bleed off 200 psi in 10 minutes, pull up to poisition 3 @ 6367'SLM in full joint below GLM#3, pressure to 1000 psi,observed pressure bleed off 200 psi in 10 minutes, pull up to poisition 4 @ 5037'SLM in full joint below GLM#4, pressure to 1000 psi,observed no pressure bleed off in 10 minutes. Leak indicated in GLM#3 SOV. POOH. 10/17/2013 RIH with slickline to pull SOV in GLM#3. Replace SOV. Pressure up to test,will not hold pressure. Remove SOV and replace with dummy, pressure up to 3500 psi to test,bled off. Decsion to pull completion to change out GLM#3(with 200 psi SOV). POOH to GLM#3 1510'MD.Test original GLM#3,failed. Replace with new GLM/pups and replace joint above and below.TIH with new GLM and 3.5"completion. 00:00 00:15 0.25 7,879 7,879 COMPZ RPCOM PULD T L/D HES slickline leak detection tool, P/U OK1 valve pulling tool. 00:15 00:30 0.25 7,879 7,879 COMPZ RPCOM PRTS T Pressure test slickline packoff to 2000 psi. 00:30 04:00 3.50 7,879 7,879 COMPZ RPCOM SLKL T RIH with OK1 valve pulling tool. Pull SOV in GLM#3. POOH. RIH with new SOV and replace in GLM#3. Pressure up while setting new SOV to 750 psi. Pressure bled off quickly when slickline unseeded SOV in the GLM. 04:00 04:30 0.50 7,879 7,879 COMPZ RPCOM SLKL T POOH with SOV that did not remain in GLM#3. 04:30 05:00 0.50 7,879 7,879 COMPZ RPCOM SLKL T Slickline redress new 2000 psi SOV that failed to stay in GLM#3 and set up for 2nd attempt to set new SOV in GLM#3. 05:00 13:00 8.00 7,879 7,879 COMPZ RPCOM SLKL T RIH with new SOV to set in GLM#3. Attempt to pressure test to 1500psi and would not hold. POOH with running tool. Pick up pulling tool and retrieve SOV,packing torn and valve bent. RIH with dummy valve, attempt to pressure test to 1500psi and not holding. POOH with running tool and pick up D&D hole finder RIH and test @6310' 1000psi for 10 minutes good. POOH with D&D hole finder and rig down slick line. 13:00 14:00 1.00 7,879 7,860 COMPZ RPCOM TRIP T BOLDS, LID landing joint,hangar, space out pup. PJSM POOH 3.5" tubing. Page 6of14 Time Logs Date From To '°Dur S.Depth E.Depth Phase Code Subcode T Comment 14:00 17:30 3.50 7,860 1,510 !COMPZ RPCOM TRIP T POOH standing back tubing and UD jewelry from 7860 to 1510,at GLM #3. 17:30 19:30 2.00 1,510 1,510 COMPZ RPCOM PULD T Test GLM#3 and pup to 3500 psi. Test failure. UD GLM#3 pups and joint above and below GLM#3, P/U replacement GLM and pups for GLM #3, replace joints above and below GLM position. Replacement GLM has 2000 psi SOV. GLM is 16905-02. 19:30 01:00 5.50 1,510 6,311 COMPZ RPCOM RCST T TIH with 3.5"tubing and jewelry from 1510'MD to 6311 'MD 10/18/2013 Continue TIH with completion to locate.Space out and hang off completion.Test tubing ,tubing test failed (x2). Call Engineer. Call to mobilize SLB digital slickline. RIH w/SLB slickline with temp log and flow rate tool. Lose communication, POOH slickline, Slickline cable maintenance, RIH to relog to bottom and back out. Log inconclusive. Call Engineer. R/U to test BOPE.Test BOPE. 00:00 02:00 2.00 6,311 7,852 COMPZ RPCOM RCST T TIH with 3.5"tubing and jewelry from 6311'MD to 7852'MD 02:00 03:30 1.50 7,852 7,849 COMPZ RPCOM RURD T Make up space out and hanger. Pick up 7.80'pup. R/U for testing. Land hanger.space out is 3.40'. 03:30 06:30 3.00 7,849 7,849 COMPZ RPCOM PRTS T Test tubing to 3500 psi for 30 minutes.Tubing never held pressure and bled off 1500 psi in 2.5 min. Bled off pressure,checked everything and pressured up again. Bled off again leveling off at 500 psi after approximately 20 minutes. Contact Engineer. Decision made to mobilize digital slickline for leak detection. Contact AOGCC for weekly BOP test notice.Test waived by Jeff Turkington at 5:45am 10/18/2013 06:30 08:00 1.50 7,849 7,849 COMPZ RPCOM PRTS T BOLDS, pull hanger to floor and unsting from PBR. Close upper pipe rams. Pressure test well bore to 3500psi for 10min.-Good Monitor OA during test start at 50psi rise to 100psi. 08:00 09:00 1.00 7,849 7,849 COMPZ RPCOM PRTS T Land hanger and sting back into seals. RILDS. Pressure up on tubing to 1500psi, leaking immediately. Bleed off and prepare for Digital Slickline. 09:00 13:00 4.00 7,849 7,849 COMPZ RPCOM SLKL T PJSM with Schlumberger Digital Slickline crew. Rig up DS with full pressure control. Pick up Temperature log tool and Leak Detection Spinner tool. Pressure test lubricator to 3000psi. Page 7of14 • • Time Logs Date From To ' Dur S. Death E. Death Phase Code Subcode T Comment 13:00 15:00 2.00 7,849 7,849 COMPZ RPCOM SLKL T RIH 100 ft/min logging static well temperature data. At 5600'experience intermittent tool failure. RIH to 7849'and attempt to log up and re-establish communication. Unsuccessful. POOH with DS for line cutting maintenance. 15:00 17:30 2.50 7,849 7,849 COMPZ RPCOM SLKL T Digital slickline line cutting. 17:30 21:30 4.00 7,849 7,849 COMPZ RPCOM SLKL T RIH with digital slickline, log static well temp from 5600'to 7849'. Run Temperature log tool and leak detection spinner from 7849'to surface.6790'is where logging tool began working, lost communication below that. 21:30 22:45 1.25 7,849 7,849 COMPZ RPCOM RURD T R/D SLB digital slickline, R/U BOP test eqpt. R/U blanking plug. 22:45 00:00 1.25 7,849 7,849 COMPZ RPCOM BOPE T BOP test.Test#1 Blinds, Kill Line valve#13, Choke valves#4, 11, 12, 3.5"8rd Safety Valve, Hyd TD;Test #2 Blinds, HCR Kill, Choke#7, 9, 10, 3,3.5"IF dart, Manual TD.Test waived by AOGCC Rep Jeff Turkington. 10/19/2013 Cont Test BOPE. Pull BPV. BOLDS, pull and UD hanger. POOH standing back 3.5"completion.check every connection for proper make-up or signs of leak or damage.circulate hole volume @ 3000'MD. Pull seal to floor and inspect/redress.put DS 2.812 nipple above joint above seal assembly and TIH with 3.5"completion with ball on seat in nipple testing regularly to ensure tubing has no leak. PT and fail(x6)at 1710'. 00:00 02:00 2.00 7,844 7,844 COMPZ RPCOM BOPE T BOP test.Test#3 LPR, choke #2,5,8;Test#4 Annular choke#6; Test#5 UPR, Choke#1;Test#6 Choke HCR;Test#7 Man choke.Kummy test, 1850 four bottle average, 200 psi @ 15 sec,full pressure @ 90 sec.Test waived by _AOGCC Rep Jeff Turkington. 02:00 03:00 1.00 7,844 7,844 COMPZ RPCOM RURD T Rig down test joint and blow down lines. 03:00 05:30 2.50 7,844 7,844 COMPZ RPCOM PLUG T Pull blanking plug and BPV, had trouble pulling valve due to sand around it. 05:30 06:00 0.50 7,844 7,844 COMPZ RPCOM THGR T Back out LDS and pull hanger. 06:00 10:45 4.75 7,844 3,000 COMPZ RPCOM TRIP T POOH racking back completion inspecting all connections for 'abnormalities. Connection at 3,250'appeared to show signs of fluid travel through the threads. Depth matches up with minor abnormality in temperature log. •Change out joints 92&93. Replace with new joints and adjust tally. Page 8 of 14 • Time Logs Date From .To Our S.'Depth E. Depth!Phase Code Subcode T Comment 10:45 11:45 1.00 3,000 3,000 COMPZ RPCOM CIRC T Circulate 100BBLs around to condition fluid&hole. 3bbl/min 158psi Blow down lines. 11:45 14:00 2.25 3,000 0 COMPZ RPCOM TRIP T Continue to trip out of the hole no other signs off tubing abnormalities. Replace seal rings while coming out. Lay down and inspect the seal assembly. 14:00 18:00 4.00 0 0 COMPZ RPCOM SVRG T Service rig while waiting on nipple for completion. 18:00 18:30 0.50 0 0 COMPZ RPCOM PULD T P/U new nipple and put into shed. 18:30 22:30 4.00 0 1,710 COMPZ RPCOM RCST T P/U and RIH with completion to —1710'. 22:30 00:00 1.50 1,710 1,710 COMPZ RPCOM PRTS T Attempted pressure test of first 1710' of completion. Pressure test fails each time at a pressurte loss rate of 100 psi per minute. Call Engineer. Decision made to POOH in—500' increments(testing at each incremental stop). 10/20/2013 POOH in 500'increments. PT to find leak. PT at 1200'(fail),700'(fail). PT RHC plug(x3),fail.wait on slickline. Change out RHC plug, PT(pass), RIH to 1500'. PT(fail), POOH. Change plug to"XX"plug.Test (pass), RIH with completion. PT at 1500'(pass), PT at 2750'(pass), PT at 3800'(fail), POOH to find leak. 00:00 04:00 4.00 1,710 0 COMPZ RPCOM TRIP T TOOH standing back tubing and laying down jewelry. PT completion string every 500'. PT @ 1200'and 700'(fail), Pull X nipple to floor and test(x3)(fail). Call Engineer. Decision to mobilize HES Slickline to cahgne out plug. 04:00 07:00 3.00 0 0 COMPZ RPCOM SVRG T Service rig.Wait on HES slickline. 07:00 08:30 1.50 0 0 COMPZ RPCOM RURD T HES Slickline change out RHC plug and stand by while PT of plug. 08:30 12:00 3.50 0 1,512 COMPZ RPCOM TRIP T Trip in hole and test tubing to 3,500psi at 150'-Good. Test tubing to 3,500psi at 1512'-Fail test 12:00 14:30 2.50 1,512 0 COMPZ RPCOM TRIP T Trip back out of the hole test at 1,000%500%150'to 3,500psi-Fail all tests. 14:30 15:00 0.50 0 0 COMPZ RPCOM RURD T Lay down"X"nipple and pull ball and rod and RHC plug. Replace with"XX"plug 15:00 00:00 9.00 0 3,800 COMPZ RPCOM TRIP T Pick up"X"nipple with"XX"plug installed.Test to 3,500psi-passed. Trip to 1512'test to 3,500psi(pass), Trip to 2750'test to 3,500psi(pass), Trip to 3800'test to 3,500psi(fail). Decision made to POOH to find leak. 10/21/2013 POOH to find leak, PT at 3350'(fail), PT at 2810'(fail), GLM#3 found leaking. LD and replace SOV.TIH pressure testing. RU slickline, RIH pull dummy valve, replace with SOV, PT SOV/tubing(pass). RIH pull"XX" plug. RD slickline. Page 9 of 14 Time Logs, Date AFtom To Dur S. Depth E. Depth''Phase Code Subcbde T Comment 00:00 03:00 3.00 3,800 1,460 COMPZ RPCOM TRIP T POOH to find leak, PT at 3350'(fail), PT at 2810'(fail),GLM#3 found leaking. Mobilize HES slickline for replacement of SOV in GLM#3. 03:00 03:30 0.50 1,460 1,460 COMPZ RPCOM PULD T LD GLM#3 and setup for HES slickline crew to change out SOV. 03:30 06:00 2.50 1,460 1,512 COMPZ RPCOM OTHR T Pull SOV on GLM#3. Found to be sheared. PU new valve and replace. Test above SOV @1512' 3500psi-Good 06:00 16:00 10.00 1,512 7,825 COMPZ RPCOM TRIP T Trip in hole with completion filling pipe every 500' Test tubing at 3800', 4800',5800',6800', 16:00 17:30 1.50 7,825 7,825 COMPZ RPCOM RURD T PU and RU slickline. 17:30 21:00 3.50 7,825 7,825 COMPZ RPCOM SLKL T RIH with slickline, pull dummy valve in GLM#3, POOH. RIH with SOV 2000 psi IA to tubing and set. POOH. 21:00 21:30 0.50 7,825 7,825 COMPZ RPCOM PRTS T Pressure test tubing to 3500 psi for 10 minutes. 21:30 23:30 2.00 7,825 7,825 COMPZ RPCOM SLKL T RIH with slickline. Pull"XX"plug in X Nipple above seal assembly. POOH. 23:30 00:00 0.50 7,825 7,825 COMPZ RPCOM RURD T RD slickline. 10/22/2013 Locate out.Space out and land hanger. RILDS.Attempt to pressure test tubing to 3,500psi-fail. Communication to IA.Test 1500psi down IA and held. Decision made to POOH with completion. Unland hanger. Move remainder of workstring from DS of derrick to ODS derrick. Circulate hole clean taking returns to the Kill tank. Flow check well. POOH with completion racking back in derrick. Set wear bushing. Pick up anchor retrieving tool and trip in the hole with 3 1/2"PH-6 work string out of the derrick. 00:00 00:30 0.50 7,825 7,825 COMPZ RPCOM RURD T PJSM with new slickline crew. Continue RD slickline. 00:30 01:30 1.00 7,825 7,825 COMPZ RPCOM RCST T PU wt=95k, SO wt=75k. Locate, see positive pressure indication.fully locate @ 27'down joint 251. 01:30 03:00 1.50 7,825 7,853 COMPZ RPCOM PULD T Space out using pup joints 9.84', 7.81'and 5.85'. PU hanger and MU landing joint.land hanger. 03:00 04:00 1.00 7,853 7,853 COMPZ RPCOM RCST T Land hanger. RILDS. RU to test tubing and IA. 04:00 09:00 5.00 7,853 7,853 COMPZ RPCOM PRTS T Test tubing to 3500 psi..Test failed 5.5GPM returns up IA immediately pump 1.5 BBLS to 3500 psi presssure dropped back to 500 psi and held. Pressure test IA to 1500psi and held good. 09:00 10:00 1.00 7,853 7,853 COMPZ RPCOM THGR T BOLDS and lay down hanger 10:00 12:30 2.50 7,853 7,853 COMPZ RPCOM OWFF T Monitor well and move work string to off driller side so that the completion string can be stood back 12:30 13:30 1.00 7,853 7,853 COMPZ RPCOM CIRC T condition mud circulated out treated brine with 160 BBLS of clean brine ICP=600 PSI , FCP=625 PSI. @ 3 BPM 13:30 14:00 0.50 7,853 7,853 COMPZ RPCOM OWFF T monitor well for flow for 30 mins. Page 10 of 14 • • Time Logs Date From To li Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00° 20:30 6.50 7,853 0 COMPZ RPCOM TRIP T POOH with completion string standing it back. Monitoring hole on trip tank. Seals in good condition when pulled out. All jewelry in good condition. 20:30 21:30 1.00 0 0 COMPZ RPCOM WWWH T Set wear bushing.6 3/8"ID 6 15/16" OD 8"Length 21:30 00:00 2.50 0 3,950 COMPZ RPCOM TRIP T Pick up Baker Anchor/PBR retrieval tool S/N10621294. 2.75 ID 4.78 OD.2.88'Assembly length. Trip in hole on PH-6 work string. Monitor returns on Trip Tank. 10/23/2013 RIH with 3 1/2"PH-6 Work string with PBR/Anchor retrieval tool. Release PBR anchor assembly. Circulate bottoms up. Flow check. POOH. Lay down PBR/Anchor assembly damage to the latch mechanism but all pieces intact. Pick up slick seal assembly and TIH on PH-6.Test Packer to 3500psi down tubing-Fail initial test. Pressure test IA(Top of Packer)to 3500psi and Passed. Pressue test down tubing again to 3500psi and packer tested-Good. Cycle stinging seals in and out and pressure testing to 3500psi passed. Rig down and blow down testing equipment. 00:00 03:30 3.50 3,950 7,841 COMPZ RPCOM TRIP T Continue to trip in the hole with PBR/Anchor Retrieving assembly on 3 1/2"PH-6 workstring. Monitor displacement to the trip tank. 03:30 04:30 1.00 7,841 7,845 COMPZ RPCOM FISH T Kelly up to top drive. Establish parameters: Up Wt. 123K Dn Wt. 88K Rot.Wt. 105K TQ 1900 Ft/lbs at 12rpms Engage top of PBR at 7845' Set 15K down, Pick up and pull 10K over. Confirm engagement. Slack off to 115K, 10k over rotating weight. Rotate 14 turns at 3500 ft/Ibs tq. Keeping 10K pulled over. Release PBR/Anchor. 04:30 05:30 1.00 7,835 7,835 COMPZ RPCOM CIRC T Circulate and condition hole. Circulate bottoms up 3bpm 561 psi 05:30 07:00 1.50 COMPZ RPCOM OWFF T Flow check well Blow down top drive greased crown 07:00 12:00 5.00 7,835 0 COMPZ RPCOM TRIP T POOH with PBR. K latch was cracked but all there. Seals looked new. No indication of leak found in seal area 12:00 17:30 5.50 0 7,858 COMPZ RPCOM TRIP T Made up&RIH with testing seal assembly for packer. Rig up testing equipment on top of joint and stab into seals setting 10k down. Page 11of14 • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 17:30 23:00 5.50 7,858 7,858 COMPZ RPCOM PRTS T Attempt to pressure test down the tubing testing the packer from the well bore pressure side. Came up to 3500psi bled down to 1500 psi in 5 minutes. Communication to the IA observed at surface. Pressure bled down to 700psi in 30. Bleed off remainder pressure and close annular preventer,pressure test the IA staging up 1500psi 5 min,2500psi 5 min,3500psi 15min all tests passed. Bleed pressure down and open annular preventer. Set 20k down on packer. Pressure test down tubing to 3500psi for 30 minutes-Good. Bleed off and pull out of seals and set 10k down pressure test down tubing again for 30 minutes at 3500psi-Good. Bleed off and unsting from seals come back down and set 1K attempt to test pressure came up to 2250psi and pumped seals out.Set 3k down pressure up to 2600psi and pumped seals out. Set 6k down and pressured up to 3150psi and pumped seals out. Set 10k down and pressured up to 3500psi for 30 minutes-Passed. Bleed off and close annular preventer pressure up to 3500psi on IA monitoring tubing for 30 min-Passed. No increase in tubing pressure during test. OA pressure came up to 100psi. Bled off pressure and opened annular preventer. Packer tested good after pressuring up on IA. 23:00 00:00 1.00 7,858 COMPZ RPCOM TRIP T Blow down lines and rig down test manifold. Pull 2 stands and stand back. 10/24/2013 Cut&Slip Drilling Line. POOH with Seal assy.on 3 1/2"PH-6 racking back. Pull wear bushing. Make up and run completion assy. Spot corrosion inhibited brine at 7853'. Engage top of packer at 7858'confirm latched and Pressure test to 3500psi Good. Bleed to 1500psi Shear out PBR. Space out and land hanger. Pressure test tubing to 3500psi for 30 minutes Good. Bleed to 2500psi and line up to test IA. 00:00 03:00 3.00 7,655 7,655 COMPZ RPCOM SLPC T Cut&Slip drill line. Change out brass on dead man. Monitor well on trip tank. 03:00 06:00 3.00 7,655 0 COMPZ RPCOM TRIP T Trip out of the hole with seal assembly on 3 1/2"PH-6. Monitor displacement on the trip tank. Check crown-o-matic 06:00 08:30 2.50 7,655 0 COMPZ RPCOM TRIP T continue to POOH with test seals. Laid down seals 08:30 09:30 1.00 0 0 COMPZ RPCOM OTHR T Drain stack&pull wear ring Page 12 of 14 Time Logs Date From To Dur S.'Depth E. Death Phase Code Subcode T Comment 09:30 18:00 8.50 0 7,853 COMPZ RPCOM TRIP T PU PBR&RIH with completion string. 18:00 19:00 1.00 7,853 7,853 COMPZ RPCOM CRIH T Pump 33BBLs of 1%CRW132 Corrosion inhibitor chase with 55 bbls spotting up to GLM#3. Pump at 3bpm 520psi 19:00 21:00 2.00 7,853 7,858 COMPZ RPCOM ANCR T Engage top of packer with anchor/PBR assembly at 7858'. Up wt 98k Dnwt75k Set 10k down Pull 10k over Set 30k down Pressure test Tubing to 3500psi for 30 minutes-Good Bleed to 1500psi. Pick up to 130k, 32k over,and shear PBR. 21:00 22:00 1.00 7,858 7,858 COMPZ RPCOM HOSO T Perform Space out. Pick up 2.10',7.81', 9.84'pups. Spaced out 2.49'from No Go to Top of PBR Land hanger and RILDS. 22:00 23:00 1.00 7,858 7,858 COMPZ RPCOM PRTS T Rig up to pressure test Tubing and IA. 23:00 00:00 1.00 7,858 7,858 COMPZ RPCOM PRTS T Pressure up to 3500psi on tubing held for 30min.-Good Bleed down to 2500psi and line up on IA. 10/25/2013 Pressure test IA to 3500psi-Good. Bleed off IA and then Tubing. Pressure up on IA and shear SOV @1800psi. Install BPV and Test. N/D BOPE. N/U Tree and test. Freeze protect. Install BPV. RDMO to 3K-17 00:00 01:00 1.00 7,858 7,858 COMPZ RPCOM PRTS P Pressure test IA to 3500psi for 30min.-Good Bleed IA down then Tubing. Pressure up on IA side and shear SOV @ 1800psi Blow down and rig down testing lines. 01:00 02:00 1.00 COMPZ RPCOM MPSP P Set BPV and test from below to 1000psi for 10minutes-Good 02:00 04:00 2.00 COMPZ RPCOM NUND P Nipple down BOPE. Open bottom ram door cavity and inspect. No debris. 04:00 06:00 2.00 COMPZ RPCOM NUND P Nipple up Tubing head adapter and tree. 06:00 09:00 3.00 COMPZ RPCOM PRTS P Test adaptor to 250/5000 psi,test tree 250/5000 psi 10 min's each test. 09:00 10:00 1.00 COMPZ RPCOM MPSP P Pulled BPV 10:00 14:00 4.00 COMPZ RPCOM FRZP P PJSM. RU LRS. PT lines to 2500 psi. Pump 130 bbls of Diesel to freeze protect well from 6318'to surface. RD LRS 14:00 15:00 1.00 COMPZ RPCOM MPSP P Install BPV. Page 13 of;.14 Time Logs Date From To Dur S.heath E. Depth Phase Code Subcode T Comment 15:00 18:00 3.00 COMPZ RPCOM DMOB P Prep well and equipment for move. Rig Released @18:00 hrs 10/25/2013 for move to 3K-17 Page 14 of 14 OWE • LL LOG TRANSMITTAL DATA LOQGGGED �.a�L 2o13 M K BENDER um To: Alaska Oil and Gas Conservation Comm. October 14,2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 " Anchorage, Alaska 99501 3 SCANNED DEL 1 0 2013 RE: Tubing Cut Record, String Shot Record: 3K-35 Run Date: 10/12/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Matthew Cook,Halliburton Wireline&Perforating, 6900 Arctic Blvd.,Anchorage,AK 99518 matthew.cook@halliburton.com 3K-35 Digital Data in LAS format, Digital Log Image file 1 CD Roni 50-029-22775-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LET'1'ER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook @halliburton.com Date: Signed: l ~ u STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~~~~ V E® I~AY l ~ 2009 s ®ns. COn'Itl'tISS10t6 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ ~laska~}i~& G a AA ~~ ~~ Alter Casing ^ Pull Tubing ^~ Perforate New Pool ^ Waiver ^ Time ExtensrorF°h~~8 Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ • Exploratory ^ 197-109 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22775-00 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 66' 3K-35 8. Property Designation: 10. Field/Pool(s): ADL 25629 Kuparuk River Field /Kuparuk River Oil Pool • 11. Present Well Condition Summary: Total Depth measured 9118' feet ~ true vertical ~~~b l ;Zb feet Plugs (measured) " . Z.~~ r Effective Depth measured 9014' feet Junk (measured) true vertical 6796' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SURFACE 5252' 7-5/8" 5298' 4101' PRODUCTION 8312' 5-1/2" 8362' 6268' LINER 967' 3-1/2" 9114' 6899' Perforation depth: Measured. depth: 8580'-8600', 8616'-8638' q~~'~ i~'~~;~ ~, ;~ ~'~Ua true vertical depth: 6436'-6452', 6465'-6483' Tubing (size, grade, and measured depth) 3.5", L-80, 8114' MD. Packers & SSSV (type & measured depth) Baker $ABL-3 liner top pkr, Baker'SABL-3' pkr @ 81x8', 7915', Camco'DS' nipple @ 488' 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 Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation 120. 1188 1863 -- 204 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ ~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: none contact Erik Nelson @ 263-4693 Printed Name ik Ne O Title Wells Engineer Signature ^ Phone: 263-4693 Date ~ 'G`~~ Pre ared b Sharon a Dr ke 263- 612 .r _ ~ ~~IGINAL ~ ~.~~~~, Form 10-404 Revised 04/2006 ~ +~ l~~'t' ~3~ugq'~jtjOriginal Only CanotoPhillips ... N.;., .t, Irx;. HANGER. 27 CONDUCTOR, 0-121 NIPPLE. 688 GAS LIFT, 3.010 GAS LIFT, 5,003 SURFACE, __ 41-5,298 GAS LIFT, 6,335 GAS LIFT, -_ ].845 LOCATOR, 7,899 PBR, 7 901 ANCHOR SEAL. 7.915 PACKER, 7,915 NIPPLE, 6.090 OVERSHOT. 6.108 NIPPLE. 6.126 LOCATOR, 8.133 PBR. 8.133 ANCHOR SEAL 8,147 PRODUCTION, 39-8.362 IPERF. 8.580-8.600 APERF, 8.616-8.636 ~'• ~ KUP • 3K-35 ~ { ,Well Attribute Wellbore APUUWI s Max Angle & MD ', TD Well Status Prod/Inj Type Incl (°) MD (NKBI Act Btm (NKB) Field Name 500292277500 ! iKUPARUK RIVER UNIT .PROD 48.47 2,55000 9.118.0 Comment 'M25 (ppm) Data Annotation iEnd Date I KB-Grd (N) ~. Rig Release Dat ~ SSSV: NIPPLE ( I 160 7/1/2008 ~Last WO: 4/17/2009 31.72 7/21/1997 , Annotation Depth (NKB) (End Date Annotation End Date ~I Last Tag: SLM 8.574.0 11124/2008 (Rev Reason WORKOVER I 4/1872009 Casin Strin s Casing Description String 0... ,String ID ... Top (ftKB) Set Depth (f... Sat Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 0.0 121.0 121.0 62.58 H-40 Casing Description String 0... (String ID ... Top (NKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top ThrO SURFACE 7518 I 6.750 41.1 5,298.0 4,100.9 29-76 J-55 Casing Description String 0... String ID ... Top (NKB) Sal Depth (f... Set Depth (ND) ... String Wt... String ... _ String Top Thrd PRODUCTION 51/2 ~'I 4.653 38.8 8,3620 6,2676 15.50 I-80 Casing Description String 0... String ID ... Top (NKB) Sel Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd LINER 31/2 2.992 8,147.5 9,113.7 6,898.3 9.20 L-80 ABM-BTC Liner Details ,Top Depth I, ' (ND) 'Top Incl Top (ftKB) (kKBI (°) i Item Description Comment I ID (ir 8.14 /.6 6.106.1 40.94 I PACKER (BAKER KBH-22 w/SABL3 LINER TOP PACKER 2.7E Tubing String Tubing Description s String 0... Skiing ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... Skiing Wt...'String ... (String Top Thrd :5 S" Star-k~r F'a~-krr 3 1'2 2.992 26.8 8.114.0 6,080.8 9.30 L80 IBTM TUt31NG Com letion D etails Top Depth (ND) Top IrKI Top (ftKB) (NKB) (°) Item Deserlptbn Comment ID (in) 26.8 26.8,E 0.29~ HANGER 3 1!2 EUE FMC Tubing Hanger w/ 3 1/2 EUE Pup Jt. 3.500 487-8 487-5 4.55 NIPPLE Camco "DS" Nipple w72-875" ID 2.875 7,898) 5,919.6 41.551 LOCATOR Locator Sub 8 Seal Assembly (12 N seal) with 2 H Space out 3.000 7,901.1 5,921.7 42.44 PBR Baker 80-40 PBR 3.250 7,914.6 5,931.7 42.30 ANCHOR BakerKBH-22 Anchor Seal Assembly 3.060 SEAL 7,915.4 5,932.2 42.30 PACKER Baker "BABE-3" Production Packer 2.760 8,089.9 6,062.7 4121 NIPPLE HES "XN" Nipple w/ 275" Profile w/ RHC Plug in place 2.635 8,107.7 6,076.1 41.1210VERSHOT Baker "PoorBoy Overshot w/5.80'Swallow 3.600 Tubing Description (String 0... String ID ... Top (NKB) Set Depth (f... Sat Depth (ND) ... String Wt... String ... String Top Thrd I 6,106.1 9.30 L-80 I -ABM-EUE TUBING Onginal 31/2 2.992 I 8,110.0 I 8,147.5 ( _ I Completion Details ~'. ToP De Pth '~ -...--. (ND) Top Incl i Top (ftKB). (NKB) ', (°) Item Description Comment ID (in) 8,125.811 6,089.11 4104'NIPPLE CAMCO'D'NIPPLE 2.750 8,133.0 6,095.2 41.01ILOCATOR BAKER LOCATOR 3.000 8,133.4 6,095.5 41.01'PBR BAKER PBR 10' STROKE 3.000 8,146-9, 6.105.6' 40.94'ANCHOR (BAKER KBH-22 ANCHORAGE SEAL NIPPLE -ANCHORED TO SABL-3 3.000 ' SEAL ,LINER TOP PACKER i ~ - - - -_-. _ _ _. (Perforations 8 Slots - _ '' Shot -1 - ~ Dens Top (TVD) Btm (ND) Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date ish... Type Commerd 8,580. 8.600 6,436.3 1 I 6,452.1 A-3, 3K-35 •7/21/1997 4-0 IPERF 2.5" FISD; 160 deg. CCW 8.61G' 8 6381 6 464.9 6 482.6 A-2, 3K-35 12/28/2002 4.0 APERF 2.5" HSD, 180 phase __ I Notes: General 8 Safe End Date Annotation 4/18/2009 NOTE: VIEW SCHEMATIC w/Alaska SchemaDc9.0 Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run Stn Top (NKB) (NKBI (°) Make Model (in) Serv Type Type (iN (psil Run Data Comm... 1 3,010.2 2,491.2 45.31 Camco KBG 2-9 1 GAS LIFT DMY INT 0.000 0.0 x.4/16/2009 2 5 002.7 3,893.5 44.83 Camco KBG 2-9 1 GAS LIFT DMY INT 0.000 0.014116/2009 3 6,335.3 4,806.7 47.38 Camco KBG 2-9 1 GAS LIFT DMY INT 0.000 0.0 4/16/2009 __ 4 7,386.2 5,543.2 43.69 Camco KBG 2-9 1 GAS LIFT DMY INT 0.000 0.0 4176/2009 5 7,845.1 i 5,879.7 41.98 Camco KBG 2-9 1 GAS LIFT DMY INT 0.000 0.0 4/1G/2009 LINER. 8.148-9.114 TD. 9,116 3K-35 Pre and Post Rig Workover Summary DATE SUMMARY 3/12/09 SET CATCHER ON PLUG @ 8~' RKB. JOB SUSPENDED DUE TO WIN 3/13/09 PULLED GLV FROM STA# 3, @ 6126' RKB, PULLED GLV FROM STA#1, @ 3161' RKB, ATTEMP TO PULL STA # 5 & 6, IN PROGRESS 3/14/09 SET 1" DMY'S @ 3161' AND 6126' RKB. IN PROGRESS. 3/15/09 PULL DMY @ 7120' RKB. IN PROGRESS. 3/16/09 UNSUCCESSFUL ATTEMPT TO PULL CATCHER @ 8126' RKB. BAIL FRAC SAND. IN PROGRESS. 3/17/09 PULL CATCHER @ 8111' SLM. BAIL FROM PLUG @ 8126' RKB. IN PROGRESS. 3/18/09 BAIL AND ATTEMPT TO PULL CA-2 PRONG @ 8113' SLM . JOB SUSPENDED FOR OTHER WORK NEAR WELL. 3/19/09 PULLED CA-2 PRONG. IN PROGRESS. 3/20/09 UNSUCCESSFUL ATTEMPT TO PULL CA-2 @ 8126' RKB. JOB SUSPENDED FOR OTHER WORK IN AREA OF WELL. 3/21/09 BAILED ON CA-2 PLUG @ 8126' RKB AND ATTEMPTED UNSUCCESSFUL PULL. PRONG HAS BEEN PULLED. JOB SUSPENDED FOR COIL. 3/22/09 PERFORMED CLEANOUT DOWN TO HARD TAG AT 8127' RKB PUMPING SLICK DIESEL AND DIESEL GEL AT 1.2-BPM. MAINTAINED 1:1 RETURNS SO AS NOT TO ALLOW PRODUCTION UP THROUGH EQUALIZED CA-2 PLUG. SEVERAL INSTANCES OF HEAVY GEL IN RETURNS WITH INDETERMINABLE SOLIDS CONTENT. LEFT WELL FREEZE-PROTECTED AND SHUT-IN. READY FOR SLICKLINE. 3/23/09 BAILED ON CA-2 PLUG AND ATTEMPTED TO PULL. UNSUCCESSFUL. JOB SUSPENDED. 3/23/09 TROUBLE SHOOT TTP (UNABLE TO OBTAIN PICTURE W/IMPRESSION BLOCK) AND UNABLE TO GET OVER FISH NECK W/ GAUGE RING. IN PROGRESS. 3/24/09 ATTEMPTED LATCH CA-2 PLUG BODY @ 8126' RKB. APPARENT PULVERIZED FRAC SAND PACKED AROUND FISHNECK. IN PROGRESS. 3/25/09 CONTINUED ATTEMPT TO REMOVE DEBRIS FROM AROUND F/N ON PLUG @ 8126' RKB. IN PROGRESS 3/26/09 CLEAR DEBRIS FROM CA-2 F/N @ 8726' WITH SERRATED G/R & BAILER, LATCH WITH RS TOOL, SHEARED, IN PROGRESS 3/27/09 CLEARED DEBRIS FROM CA-2 F/N. LATCHED PLUG @ 8126' RKB WITH BAITED 3" SS SPLIT SKIRT. IN PROGRESS. 3/28/09 LATCHED BAITED CA-2 @ 8126' RKB AND PULLED FREE. GAUGED TBG TO 2.73", TAGGED LINER TOP @ 8147' RKB, TD @ 8571' WLM. COMPLETE. 4/8/09 SET BAKER 255 QUIK-DRILL PLUG AT 8450' CORRELATED TO PERFORATING RECORD DATED 21-JULY-1997. TAGGED PLUG TO CONFIRM SET. TUBING AND IA PRESSURES DROPPED 400 PSI AFTER SETTING.HOT OIL BLED TBG TO ZERO TO CONFIRM NEGATIVE TEST AND FOLLOWED WITH 2000# PT. VALVE CREW INSTALLED BPV 4/12/09 STRINGSHOT THE 3.5", 9.3 PPF, L-80 TUBING FROM 8100'-8112'. CHEMICAL CUT THE TUBING AT 8110'. PIPE CUT BUT NOT FREE. MAKE SECOND STRING SHOT FROM 8104'-8116'. CHEMICAL CUT TUBING ON SECOND ATTEMPT AT 7263'. POSITIVE INDICATION OF PIPE CUT SEEN. 4/18/09 LRS CMIT TBG X IA TO 2500 PSI (PASSED ). PULLED BALL & ROD @ 8090' RKB. PULLED SHEARED SOV @ 7847' RKB. PULLED DGLVS @ 7388' AND 6337' RKB. (( IN PROGRESS )). 4/19/09 PULLED DV'S @ 3010' AND 5002' RKB. SET GLV'S @ 3010', 5002', 6335', AND 7386' RKB. SET OV @ 7845' RKB. BLED IA TO CONFIRM VALVES ARE SET. PULLED 3 1/2 RHC PLUG (2.75 PACKING BORE) @ 8089' RKB. TAGGED @ 8394' SLM (OBATINED SAMPLE) . (GL DESIGN IN PLACE AND READY FOR COIL TBG. ). 4/22/09 RIH AND USED A 2.60" OD JUNK MILL TO REMOVE A COMPOSITE PLUG SET @ 8475' CTMD / 8450' RKB. ABLE TO MILL AND PUSH PLUG BODY DOWN TO 8671' RKB LEAVING 33 FEET OF RAT HOLE BELOW THE LOWER SET OF PERF @ 8638' RKB.JOB COMPLETE. • ummary CortocoPhi~lips Time Log- & S u Weltvlew tNeb ReAOrttng Re p o r Well Name: 3K-35 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 4/11/2009 5:30:00 AM Rig Release: 4/17/2009 5:00:00 AM Time l.o~s Date From To Dur_ S. Depth E Depth Phase Code Subcode T Comment __ _ __ _ 4/10!2009 24 hr Summary Move Nordic Rig 3 from 2A-06 towards KCS/Oliktok Y 14:00 00:00 10.00 MIRU MOVE MOB P Move rig off of 2A-06 to KCS / Oliktok Y 4/11 /2009 Continue to Road rig from KCS/Oliktok Y to 3K-35. MIRU Nordic Rig 3 on 3K-35. Spot and set down, berm up. Spot auxillary equipment . Pull BPV. Circ and Kill well w/ KWF. ND Tree and BOPE. Test BOPE @ 250/3,500 si. 00:00 03:00 3.00 MIRU MOVE MOB P Continue to Move rig "KCS / Oliktok Y" to CPF3 03:00 05:30 2.50 MIRU MOVE MOB P Continue to Move rig from CPF 3 to 3K-35 05:30 07:00 1.50 COMPZ RPCOM PSIT P Acce t Nordic Ri 3 05:30 hrs on 4 -11-09. Spot rig over 3K-35 and set down. RU Handi berm and spot auxillary equipment. RU hardline from kill tank. 07:00 08:30 1.50 COMPZ RPCOM RURD P RU hardline and hoses to wellhead in cellar. Load its w/9.7+ brine. 08:30 11:00 2.50 COMPZ WELCTI KLWL P Pick u lubricator to ri floor and thaw with steam. MU and BPV. 11:00 11:30 0.50 COMPZ WELCTL KLWL P Pressure test lines 250/3500 psi. 11:30 14:00 2.50 COMPZ WELCTI KLWL P Open well, IA= 190 psi, tubing 50 psi. Bled pressure down to IA=80 psi Tubing= 0. Pumped 9.7+ ppg brine down tubing taking retums to kili tank. Pumped 300 bbls total before 9.7+ returns. SD monitor well. Well static. 14:00 20:00 6.00 COMPZ WELCTL NUND P RD hoses, set back pressure. ND tree, set blanking plug. NU BOPE re in for test. 20:00 00:00 4.00 COMPZ WELCTI BOPE P Test 13 5/8 BOPE @ 250 / 3,500 PSI. 24 hr Notice was to AOGCC @ 18:00 hrs. Witness of test was waived b Bob Noble 02:35 hrs. COMPZ WELCTL 4/12/2009 Continue to Test BOPE @ 250 / 3,500 psi. Circulate well, Pull BPV, MU landing jt and unland hanger, Pull to 200k, unable to pull and seals. RU Eline and Cut @ 8,110'. RD Eline. Attempt to circulate and work. Unable to ull free. RU Eline and attem t to cut 7,263', cutter ass failed. Pooh and check out ass . ~ ®_ e~ e k~~,> t €~f ~i i ~._.___~ • r~ Time Logs - -- - - _- Date From To Dur - S De th E. De th Phase Code Subcode T Comment - - 00:00 01:00 1.00 T COMPZ - WELCTL BOPE P - Continue to test 13 5/8 BOPE @ 250 / 3,500 psi. 24 hr Notice was to AOGCC @ 18:00 hrs. Witness of test was waived by Bob Noble @ 02:35 hrs. Koomey Drawdown: 3,000 psi, 1,600 psi after, 200 psi in 22 seconds, 3,000 psi in 2 minutes and 1 second., 4 bottles N2 2,300 si. 01:00 01:30 0.50 COMPZ WELCTL MPSP P Pull Blankin lu , RU to circulate down tb . 01:30 03:00 1.50 COMPZ WELCTL CIRC P Circulate 1 tbg vol. thru BPV @ 1 bpm @ 130 psi ICP, 30 psi @ choke and 100 si FCP. 03:00 04:00 1.00 COMPZ WELCTL MPSP P Pull BPV, MU Landing jt, check IA for flow, 30 si on IAand 0 si tb 04:00 05:30 1.50 COMPZ WELCTL CIRC P Circulate 1 hole vol. 2 bpm @ 270 si. Monitor well -static. 05:30 08:00 2.50 COMPZ RPCOM PULL P BOLDS, upland hanger @ 95k and pull up to 200k . Unable to pull seals from PBR. 08:00 15:00 7.00 COMPZ RPCOM ELNE P RU SLB E-line, RIH and shot string shot from 8100' to 8112'. POOH. With 5K overpull, RIH w/ 2 3/8" Chemical Cutter, on depth w/CCL and cut tubin 8110' in the middle of the 1st full jt above the PBR. POOH w/ cutter and LD tools. 15:00 16:30 1.50 COMPZ RPCOM PULL P PU on tubin attempting to pull loose fr Ln chemical cut Cc~ 8110', working up and down pulling max wt of 166 + Top Drive wt. 35K total 200K. Circulated while working pipe w/ 840 si 4 BPM. still not successful. 16:30 18:30 2.00 COMPZ RPCOM ELNE P RU E-line again and RIH and shot 2nd strip shot 8112' thru 8115'. POOH standing tools back to the side. 18:30 20:00 1.50 COMPZ RPCOM CIRC P MU Top Drive, Circulate @ 4 bpm @ 840 psi and work pipe. Blow down To Drive. 20:00 00:00 4.00 COMPZ RPCOM ELNE P PJSM w/ wireline, MU Chem. Cutter #2, Rih w/ chem. Cutter to WLM. Attem t to cut -misfired. Pooh w/ wire. SWS trouble sot chemical cutter in shed. COMPZ RPCOM 4!13/2009 MU new cutter assy and RIH and attempt to cut @ 7,263' -cutter assy failed again. Pooh and MU new cutter assy and Rih to 7,263'. Cut was good. POOH w/ 3 1/2 decompletion: Rack and Tally 230 jts 3 1/2 Work strip . 00:00 04:30 4.50 COMPZ RPCOM ELNE P Rih w/ them Cutter # 3 to cut @ 7,263' and Failed. POOH and inspect tools and decide to swap out to 2 5/8 cutter ass . ~.~ ~c;~ 2 ,~f ~~ n r~ Time Logs Date From To Dur S De th E. Depth Phase Code Subcode T Comment _ _ 04:30 09:00 4.50 COMPZ RPCOM ELNE P RIH w/ cutter #4 and cut pipe @ 7 263'. POOH w/ E-line getting stuck @ 4900'. Closed annular and pressured up to 2250 psi (max a-line packoff would hold) pulled tool loose, continued to POOH and LD chem cutter tools. RD SLB. 09:00 10:00 . 1.00 COMPZ RPCOM CIRC P PU on tubing to confirm good cut 7263'. U wt 87K, pulled hanger to rig floor. Circulated hole clean w/850 si 4 BPM. 10:00 10:30 0.50 COMPZ RPCOM PULL P LD space out pups and tubing han er. Blow down to drive. 10:30 17:30 7.00 COMPZ RPCOM PULL P POOH with 3 1/2" 8rd EUE tubin standin back first 50stands (150 jts), laying down remainder (76 1/2 j ts.). Examine chemical cut and found good cut w/OD of 3.52" no flare. 17:30 18:30 1.00 COMPZ RPCOM OTHR P Clean rig floor, Strap and kick out 3 1/2 Decom letion. 18:30 00:00 5.50 COMPZ RPCOM OTHR P PJSM, Rack and Tally 230 jts 3 1/2 PH-6 H dril Work strin . 4/14/2009 PU and RIH w/ 3 1/2 Fishing assy. Attempt to Circulate. Jar fish free. POOH laying down 3 1/2 workstring and fish. 00:00 00:30 0.50 COMPZ FISH OTHR P Finish rack and tallying 3 1/2 workstrin . 00:30 02:00 1.50 0 223 COMPZ FISH PULD P PU and MU 4 11/16 OS and RIH on 3 1 /2 DC's. 02:00 10:00 8.00 223 7,253 COMPZ FISH PULD P PU and RIH w/ 3 1/2 PH-6 hydril workstrin f/ 223' 10:00 12:30 2.50 7,253 7,263 COMPZ FISH FISH P RIH to 7253'. Up wt = 105 K#, down wt = 80 K#, rotating wt = 86 K#. Pumping 5 bpm @ 1380 psi. En a e tubin stub at 7263'. Apply 15 jar licks, pulled 250 K# and fish came free. Worked pipe 35' up and down while pumping 5 bpm @ 1650 psi. Pumped 20 bbl visc sweep, returns full of frac sand. 12:30 13:00 0.50 8,149 8,149 COMPZ FISH OWFF P Monitor well, Blow down TD. Well static 13:00 15:00 2.00 8,149 4,489 COMPZ FISH TRIP P POOH from 8,149 to 4,489' (if seals pulled free} standing back 38 stands of 3 1/2 PH-6 WS. 115k u wt. 15:00 19:00 4.00 4,489 1,109 COMPZ FISH PULD P Lay down remaining 3,380' of PH-6 H dril work strin . 19:00 21:00 2.00 1,109 876 COMPZ FISH PULD P Lay down fishing BHA and release Overshot. 21:00 22:00 1.00 876 876 COMPZ FISH OTHR P Change out floor equipment, kick out PH-6 TBG and Baker Fishin Tools. r~ • Time Logs _ _ _ Date From To Dur S De th E. De th Phase Code Subcode T Comment _ 22:00 00:00 2.00 876 0 COMPZ FISH PULL P POOH la in 3 1/2 Decom letion tubin and ~ewelr .Tubing had multiple holes through out. Carbolite was found to be packed around tubing 90' above last GLM and clean below. Strap and tally decompletion and kick out. Chemical cut #1 was a clean cut. Strin shot had s lit the tubin wall. 4/15/2009 MU Poorboy OS and RIH on Worksting, locate stub and shear out OS. Reverse CBU. POOH laying down workstrin . 00:00 07:00 7.00 0 8,115 COMPZ RPCOM TRIP P PJSM, Bring in OS and strap same. MU and RIH w/ 3 1/2 Workstring to 8,084'. Up wt = 100 K#, down wt = 78 K#. Circ press 880 psi @ 4 bpm. RIH to 8110' when wei ht indicated overshot at top of tubing stub and press increased to 1130 psi. RIH to 8113' when pins sheared in overshot and pressure started climbing. RIH and sit down 15K# at 8115'. 07:00 09:30 2.50 8,115 8,110 COMPZ RPCOM CIRC P Circulate BU at 5.5 bpm @ 1650 psi. returns. Reverse circa 20 bbl viscous Flowzan sweep 4 bpm @ 1400 psi. Minimal amount of frac sand in the returns. 09:30 12:00 2.50 8,110 8,110 COMPZ RPCOM PRTS P PJSM. RU to press test casing. Blow down top drive. Pressure test casin to 3000 si / 30 min. Pump down the tubing with the UPR closed. Pressure bled off 150 si in 30 min, steady pressure drop over the 30 min. Double blocked all valves, closed LPR and pressure tested casing to 3000 psi / 30 min. Pressure bled off 150 psi in 30 min, steady pressure drop over the 30 min. Visual inspection was done on BOPE/wellhead connections and valves, all surface lines and connection with no visual leaks identified. ** Plan to run completion to eliminate ossible downhole plug leak. If slow leak is still evident after new stacker packer completion a second packer will be run to straddle possible corroded casin section. ** 12:00 22:30 10.50 8,110 0 COMPZ RPCOM TRIP P PJSM. POOH with 3.5" workstring, la in down and kickin out. ~ ®_ ~ag€; ~ s~f ~ ~~..~..._._.__.~... r~ Time Logs _ - - _ _-_ - -. D~te_ From To___ ___ _ _ _ ~._ __ Dur_- S. De th E De th Phase Code Subcode T .Comment 22:30 23:30 1.00 0 0 COMPZ RPCOM PRTS P Close Blind rams and PT 5 1/2" 15.5# L-80 cs to 3 000 si and chart for 30 minutes. Lost 75 si over the 30 minute i 23:30 00:00 :0.50 0 0 COMPZ RPCOM OTHR P RU for 3 1/2 Completion run 4/16/2009 MU and RIH w/ 3 1/2 Recompletion string to 8,110' and spot corrosion inhiibited KWF. Set Packer and shear out of PBR. PT csg and Space out. Land hanger and RILDS. PT TBG and csg, Shear out SOV. Set BPV and ND BOPE and NU Tree. PT Tree. 00:00 10:30 10.50 0 8,115 COMPZ RPCOM RCST P PU and MU 3 1/2 Recompletion string and RIH to 8,100'. Up wt = 88 K#, down wt = 70 K#, pump 1.5 bpm @ 120 psi. RIH to 8110', observe pressure increase to 160 psi. RIH to 8112', shear screws in overshot with 6 K#. No oat 8115', sit down 20 K#. 10:30 12:00 1.50 8,115 8,109 COMPZ RPCOM CRIH P PUH to 8109'. RU to circulate corrosion inhibitor (1% CRW-132). Pump 20 bbl of inhibitor followed by 60 bbl of brine down the tubing at 2 bbl 300 si. 12:00 13:00 1.00 8,109 8,114 COMPZ RPCOM PACK P Drop ball and rod. RIH and sit down on tubing stub, pick up weight and space out overshot 1' above tubing stub. Pump down tubing, pressure up to 4500 psi for 15 min to set SABL-3 acker. 13:00 14:30 1.50 8,114 0 COMPZ RPCOM HOSO P Bleed tubing down to 2000 psi. Shear out of PBR with 60 K# of over pull. Space out seal assembly 2'. Land hanger RILDS. Prior to landing hanger up wt = 88 K#, down wt = 70 K#. 14:30 16:00 1.50 0 0 COMPZ RPCOM PRTS P Pressure test tubing to 2500 psi for 15 min. Bleed tubing down to 1800 psi, test IA to 3000 psi for 30 min. Bleed down IA and then tubing. Pressure up IA to 2300 psi, sheared SOV in GLM #5. 16:00 21:30 5.50 0 0 COMPZ RPCOM NUND P RD test lines and LD landing joint. Set 2 way check. ND BOPE. NU Tree. Pull TWC and Set Test Plu . 21:30 00:00 2.50 0 0 COMPZ RPCOM PRTS P Fill tree w/diesel and PT same to 5,000 psi. Tighten Blind flange on wing valve and replace seal ring on tree bonnet. - Re test -Good. 4/17/2009 RU and Freeze protect well, let swap. Set HBPV and dress tree. RDMO Nordic Rig 3. Clear and clean Well site. 00:00 01:30 1.50 0 COMPZ RPCOM FRZP P PJSM, RU Little Red Services and PT Lines @ 2,500 psi. Pump 60 bbls diesel @ 2 bpm @ 2,000 psi. down Tubin RD LRS. 01:30 02:30 1.00 COMPZ RPCOM OTHR P Open up well and allow TBG and IA to swa out. ~- - _ -- Y~c~ ~ of 6 ~~ Time Logs Date From 02:30 To __ 03:00 Dur 0.50 S. De th_E_Depth Phase Code Subcode COMPZ RPCOM OTHR T P __Comment ___ Blow down hoses, Kill and Choke Manifolds. 03:00 04:00 1.00 COMPZ RPCOM MPSP P Set 3" H-BPV and dress tree. 04:00 05:00 1.00 COMPZ RPCOM RURD P Jack up and back off 3K-35. Clear and clean well site. Release Nordic Ri as of 05:00 hrs. ~ ~_ i ~ ~® ~°ag~~ 5 ~a~ 3K-35 (PTD# 197-109) Repor~ Sustained Casing Pressure • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] 2p~~/ 4~16~ ZC~O Sent: Friday, April 03, 2009 3:32 PM _( To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Wetl Integrity Proj; CPF3 Prod Engrs; CPF3 DS Lead Techs; Glessner, Dana ~ Subject: 3K-35 (PTD# 197-109) Report of Sustained Casing Pressure Attachments: 3K-35 TIO Plot.pdf; 3K-35 Wellbore Schematic.pdf (~i~ Jim/Tom, Kuparuk gaslifted producer 3K-35 (PTD# 197-109) began experiencing sustained inner annulus pressure above 2000 psi upon pulling a tubing plug in preparation for a workover. The well was first reported to the AOGCC on ~`~z+~~ 9,.2~fe9 after a failed TIFL. Subsequent diagnostics indicated that the well condition was beyond repair using l through tubing methods. A positive plug was set on 121~/8~and remained in place until it was pulled on 3/19/09 .~ which resulted in elevated inner annulus pressure. ~ z(~~~ The well is currently scheduled for a workover in May 2009, so therefore CPAI does not plan to take any action unless, as per Rule 5 of C0494, the inner annulus exceeds 3150 psi (45% of the burst pressure). 3K-35 is equipped with 5-1/2", 15.5 ppf, L-80 production casing with a calculated internal yield pressure of 7000 psi. Attached is a 90 day TIO plot and Wellbore schematic. «3K-35 TIO Plot.pdf» «3K-35 Wellbore Schematic.pdf» =~` 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 4/16/2009 Well Name 3K-35 Notes: End Date 4/3/2009 Days 90 Start Date 1/3/2009 Annular Communicaton Surveillance 2500 2000 1500 .N Q. looo 500 ~~:~ C( .ilk - >~ r ~~~ (`l7`I~'~I 0 Jan-09 Feb-09 Mar-09 Apr-09 1 ~DGI ' os ~MGI ~ o.e ~PWI c o.~ ~SWI a 0.6 c o.s i~BLPD U 0.4 0.3 0.2 0.1 0 Jan-09 Feb-09 Mar-09 AprA9 45 40 35 30 25~ a 20 15 10 5 0 • • Date ~ , ConocoPhillips ~~ Alaska In ~ Comment HZS (ppm( Date Annotation End DaH K8-Grd (fi) Rip Raleaae Date .. SSSV: NIPPLE 160 7/1/2008 Last WO: 7/21/1 31 72 997 i,i well coon : -aKas tvnncoe a sa ~1?-F - --- -- - _ _ - _ . _ SehemaMC- _ _ ACn,a~. - -- - - A ota[ion Depth (fiNB( End Date Annotation End Data Last Tag: SLM 8.574.0 1 V24/2008 Rev Reason: TAG FILL. SET PLUG 12/27/2008 Casio Strin s ', String OD ~ string ID Set Depth Sel Depth (rv D) string Wt string Casing Description (in( (in( Top (ftK8) (ftK8( (ftKB) (Ibslfi) Grade Slring Top Thrd CONDUCTOR 1 6 15.062 0.0 ~ 21.0 121.0 62.58 H-40 coNDUCTOR. SURFACE 75/ 8 6.750 0.0 5,298.0 4,100.9 29.76 J-55 121 PRODUCTION 51/ 2 4.653 0.0 8,362.0 6,267.6 15.50 1-80 Liner 31/ 2 2.992 8,147.0 9.114.0 6,898.6 9.30 L-80 Tubin Strin s String O D String ID Sat Depth Set Depth (TV D) String Wt String NIPPLE 526 - Tubing Description (in) (in) Top (ftKB( (ftKB) (ftK8) (IbsRt) Grade String To p Thrd . TUBING 3 1/ 2 - 2.992 0.0', 8.148.0 6.106.5 9.30 L-80 EUE AB MOD Other In Hole A ll Jewel :Tubin Run 8 Retrievable Fish etc. ITop Depth (rvD( Top Incl Top (ftKB) (ftK8) (°) Description Comment Run Data ID (in) Gns uFT 3 1Gt 526.0 525.5 5.52 N IPPLE Camco'DS' NIPPLE 7/16/1997 2.812 3,161.0 2.597.2 43.34 G AS LIFT BST/AXT/1/GLV/T-1/.156/1290/ Comment: STA 1 7/10/2008 2.900 4,748.0 3,714.9 44.72 G AS LIFT BST/AXT/1/DMYlf-1/// Comment: STA 2 7/9/2008 2.900 6,126.0 4,664.8 47.61 G AS LIFT BST/AXT/1/GLV/T-1/.156/1290! Comment: STA 3 7/2/2008 2.900 7.102.0 5,339.0 44.01 G AS LIFT BST/AXT/1/DMYlT-1/// Comment: STA 4 7/3/2008 2.900 7 722.0 788.4 5 42.26 G AS LIFT BST/AXT/1/OV/T-11.251/ Comment: STA 5 7/12/2008 2.900 GAS LIFT, . . 4,]4B 8.073.0 6,050.0 41.28 G AS LIFT BST/AXT/1/DMY/T-1///Comment: STA 6 11/15/2005 2.900 - 8,126.0 6,089.9 41.04 N IPPLE CamCO'D' Nipple NO GO 7/16/1997 2.750 8.126.0 6.089.9 41.04 P LUG 2.75" CA-2 PLUG 12/26/2008 0.000 suRFAw. 8,133.0. 6,095.2 - 41.01 P BR Baker l0'stroke 7/16/1997 3.000 s zga 8.147.0 6.105.7' 40.94 P ACKER LINER TOP PACKER Baker KBH-22 w/ SABL-3 PACKER 7/16/1997 2.780 Perforations snot Top (rvD( aem (rvD( D.ne Gns uFT 6,126 Top (ftKB) B[m (ftKB( (ftKB) (ftKB) Zona Date (eh... Type Comment 8.580.0 8.600.0 6,436.3 6.452.1 A -3. 3K-35 7/21/1997 4.0 IPERF 2.5" HSD; 160 deg. CCW 8.616.0 8,638.0 6,464.9 6,482.6 A -2, 3K-35 2/28/2002 4.0 APERF 2.5" HSD, 180 phase GAS LIFT ] 102 GAS LIFT. ],]22 GAS LIFT. 6 Ol3 NIPPLE. 8,126 ~ PLUG. 8.126 -~- - PBR. 8.133 PACKER. a td]--- PRODUCTION _ _ 8 362 IPERF _ 8 580-8 600 APERF 0,616-8 638 Liner. 9 114- TD.0116 3K-35 (PTD 197-109) Report~Failed TIFL ~ Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Friday, September 12, 2008 1:28 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPF3 Prod Engrs; CPF3 DS Lead Techs Subject: 3K-35 (PTD 197-109) Report Of Failed TIFL Attachments: 3K-35 Wellbore Schematic.pdf; 3K-35 TIO Plot.ppt /" Tom/Jim, 1 ~ ~~-- Kuparuk gas lifted producer 3K-35 (PTD 197-109) failed a SI TIFL on 09/10/08 and has been added to the Weekly SCP report. The T/I/O pressures prior to the TIFL were 1550/1400/0. A leaking~_ GLV is suspected so slickline will troubleshoot the leak and repair if possible. The well is currently shut in and will be repaired or shut in by 10/08/08. Attached is a 90 day TIO plot and schematic. «3K-35 Wellbore Schematic.pdf» «3K-35 TIO Plot.ppt» 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 4/16/2009 IAP OP,P 1600 1400 1200 1000 a 800 600 400 200 0 TIIlO Plot - 3K-35 ~ ~`t~-I~ 200 150 a E as 100 Y O L V 50 0 01-Jul-08 01-Aug-08 01-Sep-D8 Date `. ~ KUP ~ 3K-35 Conocohhillips W?I_I Attributes AI'I""~ "I' _ - 3K 3s a 11 ., - wan cony° ~ W ellbore APIIUWI ', Field Name Well Status Maximum Inclination (°) Total Depth (kKB) 500292277500 ~KUPARUK RIVER UNIT PROD 48.47 I 9,114.0 __--_ -Comment H25 (ppm) Data Annotation End Date TKB-Grd (k) Rig Release Dale NIPPLE _ 760 7/1/2008 Last W0. I 31.72 7/2[/1997 . --_ _ Scheme[ A ~;,i Annotaton Last Tag. Depth (kKB) IEnd Data 8.585.0 6/25/2008 Annotation - Rev Reason: SHO DMY W End Data 8/11/2008 _ _ CasingStrin s Casing Description OD (in) ID (in) Top (kKB) Sat Depth Set Depth (TVD) Wt (kKB) (kKB) (IbsHt) Orade Top Thread CONDUCTOR 16 15.062 0.0 121.0 121.0 62.58 H-00 coNeucTOR SURFACE 7 5/8 6.750 0.0 5,298.0 4,100.9 29.76 J-55 121 _ PRODUCTION 51/2 4.653 0.0 8.362.0 6.267.6 15.50 1-80 Liner 3112 2.992 8.147.0 ' 9,174.0 6,898.6 9.30 L-80 Tubin Strin s NIPPLE 526 Tubing Description OD tin) ID (in) Top (kKB) Set Depth (kK8) Sef D th (TVD) (kKB) Wt (Ibs/k) e p Grade Top Thread . J TLIFINC; 3 1/2 2.992 0.0 _ _ __ 8.148.0 ~ 6.106.5 9.30 L-80 EUE AB MOD Other In Hole (All Jewelry: Tubing Run 8 Retrievable, Fish, etc. Top (ftK81 Description Comment ~ `i2[i 0 NIPPLE Camco'DS' NIPPLE ~ - - Run Date 7/16/7997 ID i 2.! cns uFT ' 3.161.O ~ GAS LIFT BST/AXT/1/GLVIT-1/.156~1290i ConvnenC STA 7 7/10/2008 2.! 3.16 4,748.O GAS LIFT BST/AXT/1/DMYlf-1/// Commenr: STA 2 -~ 7/9/2008 2 6,126.0 GAS LIFT BST/AXT/1/GLV/T-1/.156/12901 Comment: STA 3 7/2/2008 2.! 7,102.0 GAS LIFT BST/AXT/1/DMYlr-1///Comment: STA 4 7/312008 2.! 7,722.0 GAS LIFT BSTlAXT/1/OVlT-1/.25// Comment: STA 5 7/12/2008 2.! GAS LIFT 8.073.0 GAS LIFT BST/AXT/1/DMY(r-1///Comment: STA 6 17/15/2005 2.! 4.]4s _ 8.126.0 NIPPLE Camco'D' Nipple NO GO 7/16/1997 2.-~ 8.133.0 PBR Baker 10' stroke 7/16/1997 3.( 8,147.0'~I PACKER LINER TOP PACKER Baker KBH-22 w/ SABL-3 PACKER 7/16/1997 2.-~ suRFAGE, ~ Perforations -- - 5.290 ~ Top IttKB) Btm (ftKB) Top (ND) (kKB) Btm (TVD) (kKB) Type Zone Shot Dens (ahot_. Date Comment GAS LIFT, 8.128 GAS LIFT. 7.102 GAS LIFT, ],122 GAS LIFT, 8.0]3 NIPPLE 8.1 PBR. 8,133 PACKER. 9.147 IPERF B.SBD-e 600 APERF. 8.618-9.636 Liner. 9.114 TD. 9.114 • . V V~~~ +'l ~ T~,41'1~5/1'TAL w~ ~: j,__... _d__~.~____ ;. f __ i~, ProActive Diagnostic Services, Inc. To: ABC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTTJ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road ~ ~~~ ' ~~ ~~ -~ ~^ ~ ~ -' ~ ~ Suite C Anchorage, AK 99518 Fax (907) 245-8952 ~1) Caliper Report 12-Dec-0B 3K 35 1 Report / EDE 50-029-22775-00 2] Signed Caliper Report 13-Dec-0B 3K 30 1 Report / EDE 50-029-22777-00 Pant Name: I _ _ nn ~II ~ (( Date V~i~'~5t_,~ ~Qt,Gn.JC.~~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 89518 PHONE: (9071245-8951 FAX: (907)245-88952 --> E-WAIL : 3adsar~c~or~ge(a2memor,~log.cam WEBSITE : w+,v~v.msm©r~t9og.com __~ C:\DOCi¢nents and Set6ngslOwner\Desktop\Tiansmit_C~oco.docx i • Memory Multi-Finder Caliper Log Results summary Company: ConocoPhillips Alaska, Inc. Well: 3K-35 Log Date: December 12, 2008 Field: Kuparuk Log No.: 7285 State: Alaska Run No.: 1 API No.: 50-029-22775-00 Ripe Desc.: 3.5" 9.3 Ib. L-80 EUE AB MOD Top Log Intrrl.: Surface Pipe Use: Tubing Bot. Log Intvl.: 8,193 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS ' This log is tied info the Camco `D` Nipple NO GO @ 8,126' (Drille-'s Depfh). ' This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damage. The caliper recordings indicate that the interval of 3.5" tubing logged is in good to poor condition, with holes recorded in a line of pits (recorded on the low side of the tubing from 4,760' to 7,520') in joint 210 (6,707'), joint 224 (7,161') and joint 213 (6,788'). A 3-D log plot of the caliper recordings from 6,420' to 7,220' is ' included in this report. Other damage appears as isolated and scattered pitting, broadens into line corrosion and general corrosion below GLM 5. No significant areas of cross-sectional wall loss (> 10%) or I.D. restrictions are recorded throughou# the 3.5" tubing logged. MAXIMUM RECORDED WALL PENETRATIONS Hole (100%) Jt. 210 @ 6,707 Ft. (MD) Hole (100%) Jt. 224 @ 7,161 Ft. (MD) Hole (100%) Jt. 213 @ 6,788 Ft. (MD) Line of pits (76%) Jt. 203 @ 6,471 Ft. (MD) Line of pits (76%) Jt. 217 @ 6,910 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 10%) are recorded throughout the interval logged. MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded throughout the interval logged. Field Engineer: Wm. 119cCrossan Analyst: HY. Yang Witness: C. Fitzpatrick ProActi~.~e Diagnostic Services, Inc. % P.O. box 1369, Stafford, TX 7749'., Phone: (281) or (888; 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog,com Prudhoe bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ~ ~ ~--r c~ ~~3a ~ • • PDS Multifinger Caliper 3D Log Plot ~_, Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3K-35 Date : December 12, 2008 Description : Detail of Caliper Recordings Across Interval of Holes recorded in a Line of Pits I~ i • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (-1.7' - 8186.9') Well: 3K-35 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: December 12, 2008 ^ Approx. Tool De viation ^ A pprox. Boreho le Profil e 1 3 786 1564 2346 GL.M 1 3169 3944 c s Y Q <;I M 2 4760 ~ 5541 GLM 3 6362 GLM 4 7184 GLM 5 GLM 6 7995 254 8187 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degre es) Bottom of Survey = 254 25 50 75 100 `w ~ 125 ;` Z 150 175 200 I a° i ~ I I I - 225 i 250 i i • • PDS Report Overview ~,~. Body Region Analysis Well: 3K-35 Survey Date: December 12, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 21 1387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: _ HY. Yang Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 EUE AB MOD 2.992 ins 3.5 ins 6.0 ins 0.0 ins Penetration and Metal loss (% wall) ~ penetration body ~ metal loss body 200 150 - 100 i -- 50 i 0 to 1 to 1% 10% 10 to 20 to 40 to over 20% 40% 85% 85% Number of 'oints anal sed total = 271 pene loss . 0 181 153 117 42 13 32 3 1 0 0 0 Damage Configuration (body ) 80 60 4t) i 2U I_ I ~ isolated general line ring hole / poss pitting corrosion cortosion corrosion ihle hole Number of joints dama ed total = 77 64 6 4 0 3 Damage Profile (% wall) ~ penetration body metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 Bottom of Survey = 254 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE AB MOD Well: 3K-35 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: December 12, 2008 Joint No. Jt. Depth (Ft.) Peen. Ul~sc~t (Ins.) Pen. Body (Ins.) Pen. % Metal Loss %, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 -2 0 0.02 7 0 2.89 PUP 1 3 O 0.03 11 2 2.93 1.1 33 0 0.01 6 2 2.95 PUP 1.2 39 O 0.02 8 1 2.95 PUP 1.3 49 0 0.01 6 1 2.90 PUP 2 59 U 0.02 7 I 2.95 3 91 0 0.02 8 1 2.95 4 124 0 0.01 5 l) 2.95 5 155 (1 0.02 9 2 2.95 6 187 (1 0.02 8 1 2.96 7 218 t) 0.02 7 2 2.96 8 250 0 0.02 7 1 2.96 9 281 0 0.02 7 1 2.95 10 313 0 0.01 6 0 2.96 11 344 O 0.02 8 1 2.94 12 376 0 0.02 8 0 2.96 13 408 (1 0.02 e) 3 2.96 14 439 0 0.01 6 2 2.95 15 471 0 0.02 8 1 2.96 15.1 501 0 0 0 0 2.81 Camco DS Ni le 16 503 l) 0.02 7 1 2.96 17 535 O 0.02 7 1 2.96 18 565 0 0.02 7 1 2.94 19 597 0 0.02 7 1 2.95 20 628 0 0.01 6 2 2.94 21 660 O 0.02 8 1 2.95 22 691 O 0.02 7 1 2.96 23 723 O 0.02 8 1 2.96 24 754 0 0.02 9 1 2.94 25 786 0 0.02 7 1 2.96 26 815 0 0.02 7 1 2.96 27 847 0 0.02 7 1 2.96 28 878 0 0.02 7 2 2.97 29 910 O 0.02 7 2 2.96 30 941 t) 0.01 5 1 2.96 31 973 t) 0.02 7 0 2.96 32 1004 0 0.02 7 2 2.95 33 I 1035 O 0.02 7 1 2.95 34 1067 0 0.02 8 0 2.94 35 1096 0 0.01 5 1 2.95 36 1128 0 0.02 7 2 2.97 37 1158 l) 0.02 7 1 2.95 38 1190 (1 0.01 5 2 2.95 39 1221 0 0.02 8 2 2.95 40 1253 t) 0.02 7 1 2.95 41 1284 t) 0.01 6 1 2.95 42 1316 l) 0.01 6 1 2.96 43 1347 t) 0.02 7 2 _ 2.97 44 1379 O 0.02 7 1 2.94 45 1410 t) 0.02 7 2 _ 2.95 Penetration Body Metal Loss Body Page 1 • i PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE AB MOD Well: 3K-35 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: December 12, 2008 Joint No. Jt. Depth (Ft.) Pc~n. UI>tic~t (Ins.) Pen. Body (Ins.) Pen. % Metal Loss % Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 46 1441 () 0.02 7 1 2.95 47 1473 l) 0.02 7 1 2.96 48 1504 l) 0.02 7 1 2.95 49 1534 0 0.02 7 1 2.93 50 1564 O 0.02 7 1 2.95 51 1595 U 0.01 5 U 2.94 52 1626 t) 0.02 7 2 2.96 53 1658 0 0.02 7 2 2.95 54 1689 0 0.02 7 1 2.95 55 1721 0 0.01 6 1 2.97 56 1752 U 0.02 7 1 2.94 57 1784 0 0.02 7 1 2.94 58 1816 0 0.02 7 1 _2.94 _ 59 1847 0 0.02 7 1 2.95 60 1878 0 0.02 7 1 2.96 61 1908 0 0.02 7 1 2.95 62 1939 U 0.02 8 1 2.96 63 1971 l) 0.02 7 2 2.95 64 2001 O 0.02 7 1 2.95 65 2032 l) 0.02 8 1 2.95 66 2064 O 0.01 6 1 2.95 67 2095 U 0.02 9 1 2.95 68 2127 O 0.02 9 2 2.94 69 2158 U 0.01 6 1 2.96 70 2190 0 0.02 7 0 2.93 71 2221 l) 0.01 6 1 2.94 72 2253 0 0.01 6 1 2.95 73 2284 O 0.01 6 1 2.95 74 2315 0 0.02 7 1 2.95 75 2346 0 0.01 6 1 2.94 76 2378 U 0.02 7 1 2.97 77 2408 U 0.02 7 1 2.95 78 2440 (1 0.02 9 2 2.96 74 2471 U 0.02 8 1 2.95 80 2503 0 0.03 11 0 2.94 81 2535 O 0.01 6 1 2.94 82 2566 l) 0.02 8 2 2.94 83 2598 l) 0.01 6 0 2.94 84 2629 U 0.01 6 1 2.94 85 2661 l) 0.02 9 1 2.95 86 2693 l) 0.01 6 1 2.95 87 2724 t) 0.01 6 1 _ 2.94 88 2756 0 0.02 8 1 2.95 89 2787 0 0.02 7 1 2.94 90 2819 (1 0.01 6 1 2.95 91 2850 (1 0.02 7 1 2.96 92 2882 U 0.02 7 1 2.96 93 2911 U 0.02 9 1 2.96 94 2943 0 0.02 7 1 2.95 95 2974 l) 0.01 6 1 2.95 Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE AB MOD Well: 3K-35 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: December 12, 2008 Joint No. )t. Depth (Ft.) I'c~n. Ut>sc~t (Ins.) Pen. Body (Ins.) Pen. % Metal Loss %~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 96 3006 (1 0.02 8 ? 2.95 97 3037 O 0.02 7 2 2.95 98 _ 3069 ll 0.02 7 U 2.96 99 3101 l) 0.02 7 U 2.95 99.1 3132 l) 0.01 6 2 2.96 PUP 99.2 3147 O 0 0 O N A GLM 1 Latch ~ 5:00 99.3 3155 O 0.01 5 2 2.94 PUP 100 3169 l) 0.02 7 1 2.96 101 _ 3200 O 0.02 7 2 2.94 102 3230 (1 0.01 6 1 2.94 103 3261 O 0.01 6 1 2.95 104 3293 l) 0.02 7 1 2.95 105 _ ___ 3324 l) 0.02 7 1 2.94 106 3356 l) 0.02 7 1 2.94 107 3387 l) 0.02 7 1 2.95 108 3419 O 0.01 6 3 2.95 109 3450 O 0.02 7 1 2.96 110 3479 (i 0.01 6 Z 2.94 111 3511 O 0.02 i 1 2.95 112 3542 0 0.02 7 1 2.94 113 3574 O 0.02 1 2.95 114 3605 l1 0.02 7 1 2.95 115 3637 0 0.02 7 1 2.93 116 3667 0 0.02 7 1 2.94 117 3698 0 0.02 7 1 2.96 118 3727 0 0.02 7 1 2.95 119 3759 0 0.01 5 l) 2.95 120 3789 0 0.02 9 2 2.95 121 3819 0 0.02 9 2 2.96 122 3850 (1 0.02 7 1 2.96 123 3882 U 0.02 9 2 2.95 124 3913 l) 0.02 7 1 2.94 125 3944 U 0.02 7 1 2.95 126 3975 O O.OZ 8 2 2.96 127 4007 0 0.02 8 1 2.96 128 4038 0 0.02 7 2 2.95 129 4069 0 0.02 ,' 2 2.95 130 410_0 0 0.02 7 2 2.95 131 4131 0 0.02 7 1 2.96 132 4162 0 0.02 9 1 2.95 133 4194 O 0.01 6 2 2.96 134 4225 l) 0.02 8 1 2.94 135 4256 0 0.02 7 1 2.94 136 4286 () 0.02 i 2 2.95 137 4318 l) 0.02 7 1 2.94 138 4349 O 0.01 6 2 ___ 2.96 139 4380 U 0.02 7 1 2.95 140 4411 O 0.02 8 1 2.95 141 4442 O 0.02 7 1 2.96 142 4474 O 0.02 7 1 2.96 'Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE AB MOD Well: 3K-35 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: December 12, 2008 Joint No. Jt. Depth (FtJ Pc~n. UE»c~t (Ins.l Pen. Body (Ins.) Pen. % Metal Loss % Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 143 4505 a 0.02 9 1 2.96 144__ _ 4537 0 0.02 9 3 2.90 145 4569 0 0.02 7 2 2.94 146 4599 0 0.02 7 1 2.95 147 4631 () 0.02 7 2 2.94 148 4662 0 0.02 7 1 2.94 149 4692 0 0.03 10 1 2.96 149.1 4724 0 0.02 7 1 2.96 PUP 149.2 4738 0 0 0 0 N A GLM 2 Latch @ 1:00 149.3 4745 0 0.01 5 1 2.96 PUP 150 4760 0 0.02 8 2 2.96 151 4792 t) 0.02 9 1 2.93 152 4824 t) 0.03 11 1 2.95 153 4855 0 0.02 9 1 2.94 154 4886 0 0.02 9 2 2.96 155 4917 0 0.02 9 1 2.95 156 4949 U 0.02 9 1 2.94 157 4981 0 0.02 9 1 2.93 158 5012 U 0.01 6 2 2.94 159 5044 0 0.03 12 1 2.95 160 5075 0 0.02 7 1 2.95 161 5105 0 0.02 7 1 2.95 162 5136 0 0.02 7 0 2.96 163 5168 U 0.02 7 1 2.9 5 164 5200 0 0.03 12 1 _ 2.96 165 5231 0 0.04 14 1 2.95 Line of its. 166 5263 0 0.01 6 0 2.93 167 5294 0 0.02 8 2 2.94 168 5326 0 0.02 9 2 2.95 169 5354 U 0.02 7 1 2.93 170 5385 U 0.02 9 1 2.96 171 5416 0 0.03 11 2 2.94 172 5446 U 0.04 15 1 2.94 Line of its. 173 5477 0 0.03 11 1 2.94 174 5510 0 0.04 18 1 2.94 Line of its. 175 5541 0 0.03 11 1 2.93 176 5572 l) 0.02 8 1 2.92 177 5603 0 0.01 6 1 2.93 178 5636 0 0.01 6 2 2.94 179 5667 0 0.02 8 1 2.92 180 5698 0 0.03 11 2 2.93 181 5730 0 0.04 18 1 2.93 Line of its. 182 5762 0 0.03 12 1 2.94 183 5793 0 0.05 19 1 2.92 Line of its. 184 5824 0 0.05 19 1 2.94 Line of its. 185 5856 0 0.04 14 1 2.94 Line of its. 186 5888 l) 0.05 20 1 2.92 _ Line of its. 187 5919 0 0.06 25 2 2.94 Line of its. 188 5950 0 0.09 34 2 _ 2.95 Line of its. 189 5981 1).06 0.06 24 2 2.94 Line of its. Penetration Body Metal Loss Body Page 4 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE AB MOD Well: 3K-35 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhiflips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: December 12, 2008 Joint No. Jt. Depth (Ft.) I'en. UL>sc~t (In,.) Pen. Body (Ins.) Pen. % Metal Loss %, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 190 6013 U 0.07 27 2 2.95 Line of its. 191 6044 O.U ~ 0.07 28 2 2.91 Line of its. 192 6075 U 0.03 12 2 2.94 192.1 6107 0 0.04 17 2 2.95 PUP Line of its. 192.2 6120 U 0 0 0 N A GLM 3 Latch ~ 7:30 192.3 6127 l) 0.06 22 2 2.96 PUP Line of its. 193 6144 0 0.13 51 2 2.93 Line of its. 194 6174 0 0.05 20 2 2.94 Line of its. 195 6206 0.14 0.10 40 2 2.95 Line of its. 196 6236 0 0.15 58 3 2.94 Line of its. 197 6268 0 0.05 18 1 2.93 Line of its. 198 6299 0.07 0.18 69 3 2.94 Line of its. 199 6330 0.07 0.11 43 2 2.93 Line of its. 200 6362 0.1 1 0.08 33 2 2.93 Line of its. 201 6394 0.09 0.14 54 3 2.94 Line of its. 202 6425 0.05 0.19 76 :; 2.94 Line of its. 203 6457 0.1 "; 0.19 76 3 2.94 Line of its. 204 6488 O.U7 0.15 60 2 2.94 Line of its. 205 6518 0 0.16 63 3 2.93 Line of its. 206 6551 0.07 0.17 67 3 2.94 Line of its. 207 6582 0.10 0.18 69 3 2.93 Line of its. 208 6614 0.06 0.18 72 3 2.91 Line of its. 209 6645 U.16 0.19 73 3 2.96 Line of its. 210 6677 U.O6 0.47 100 4 2.95 Line of its. HOLE ! 21 1 6708 0 0.18 69 3 2.93 Line of its. 212 6740 0 0.18 70 3 2.93 Line of its. 213 6771 O 0.40 100 10 2.95 HOLE ! 214 6802 0.12 0.16 63 3 2.93 Line of its. 215 6834 U.10 0.15 59 3 2.94 Line of its. 216 6865 0.09 0.17 Ei7 ~ 2.93 _ Line of its. 217 6897 0 0.19 76 1 2.93 Line of pits. 218 6929 0 0.14 57 "3 _ 2.95 Line of its. 219 6960 0.07 0.02 8 2 2.93 Line of its. 220 6991 0 0.18 69 3 2.91 Line of its. 221 7022 0.1 1 0.18 72 3 2.92 Line of its. 222 7054 0.06 0.19 75 4 2.93 Line of its. 222.1 7085 1.).06 0.18 72 4 2.95 PUP Line of its. 222.2 7101 0 0 0 0 N A _ GLM 4 Latch ~ 7:00 222.3 7109 O 0.01 4 1 2.96 PUP De osits. 223 7122 0 0.13 49 2 2.94 Line of its. 224 7153 0.18 0.45 100 8 2.93 HOLE ! 225 7184 0.10 0.03 10 1 2.93 Line of its. 226 7216 0.1 1 0.14 54 4 2.93 Line of its. 227 7247 () 0.13 52 2 2.91 Line of its. lt. De osits. 228 7275 O 0.03 11 2 2.92 229 .7306 0 0.12 48 2 2.92 Line of its. 230 7337 0 0.02 9 2 _ 2.94 231 7368 0 0.06 23 2 2.93 Isolated ittin . 232 7399 () 0.04 17 2 2.94 Line of its. 233 7431 0 0.05 20 2 2.93 Line of its. Penetration Body Metal Loss Body Page 5 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE AB MOD Well: 3K-35 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: December 12, 2008 Joint No. Jt. Depth (Ft.) Pen. Ut>set (Ins.) Pen. Body (Ins.) Pen. % Metal Loss °/, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 234 7461 l) 0.04 17 1 2.93 Line of its. 235 7492 U 0.05 20 2 2.94 Line of its. 236 7521 O.U6 0.03 10 2 2.94 Pittin in u set. 237 7553 0 0.03 13 2 2.93 Shallow ittin . 238 7583 0 0.03 11 1 2.91 239 7615 0 0.04 14 2 2.93 Shallow ittin . 240 7646 0 0.04 15 2 2.93 Shallow ittin . 241 7677 0.06 0.06 25 2 2.94 Isolated ittin . 241.1 _7707 0.05 0.04 14 2 2.96 PUP Shallow ittin . 241.2 7722 0 0 0 0 N A GI_M 5 (Latch ~ 11:00) 241.3 7731 0 0.04 17 2 2.93 PUP Shallow ittin . 242 7743 0 0.06 22 2 2.91 Isolated ittin . 243 7775 (1 0.05 19 2 2.90 Shallow corrosion. Lt. De osits. 244 7806 () 0.05 20 1 2.91 Shallow corrosion. Lt. De osits. 245 7838 0 0.04 17 1 2.91 Shallow ittin . 246 7870 0 0.05 19 1 2.90 Shallow ittin Lt. De osits. 247 7900 0 0.05 20 4 2.91 Corrosion. 248 7932 0 0.03 12 4 2.90 Lt. De sits. 249 7963 0 0.04 17 4 2.90 Shallow corrosion. Lt. De osits. 250 7995 U 0.10 39 3 2.90 Line corrosion. Lt. De osits. 251 8026 0 0.14 56 :; 2.92 Line corrosion. 251.1 8058 0 0.08 32 3 2.96 PUP Line corrosion. 251.2 8072 U 0 0 U N A GLM 6 Latch ~ 8:30 251.3 8082 U.05 0.12 46 4 2.94 PUP Line corrosion. 252 8095 0.07 0.15 59 1 1 2.85 Corrosion. Lt. De sits. 252.1 8126 0 0 0 U 2.75 Camco D Ni le No Go 252.2 8129 0 0.04 17 5 2.85 PUP Shallow corrosion. Lt. De sits. 252.3 8133 0 0 0 0 3.00 Baker 10 Stroke PBR 252.4 8147 0 0 0 0 2.78 Baker KBH-22w SABL-3 Packer 253 8156 0.09 0.14 56 10 2.80 Corrosion. Lt. De osits. 254 8187 0.0& 0.04 17 2 2.84 Shallow corrosion. Lt. De osits. _ Penetration Body Metal Loss Body Page 6 ~c~ PDS Report Cross Sections Well: 3K-35 Survey Date: December 12, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 21 1387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No, of Fingers: 24 Tubin 3.5 ins 9.3 f L-80 EUE AB MOD Anal st: HY. Yan Cross Section for Joint 210 at depth 6707.173 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 94 Tool deviation = 57 ° finger 21 Penetration = 0.468 .,.., Hole 0.47 ins. = 100% Wall Penetration HIGH SIDE = UP • Cross Sections page 1 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ A ~~ PDS Report Cross Sections Well: 3K-35 Survey Date: December 12, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 ppf L-80 EUE AB MOD Anal st: HY. Yan Cross Section for Joint 224 at depth 7161.223 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 93 Tool deviation = 54 ° Finger 21 Penetration = 0.448 Hole 0.45 ins. = 100% Wall Penetration HIGH SIDE = UP • Cross Sections page 2 KRU 3K-35 ConocoPhillips Alaska, Inc. NIP {526-527, 00:3.500) ' TUBING (aalaa, 00:3.500, 10:2.992) Gas Lilt MandrelNaNe 1 (31613162. Gas LAt ' MandrelNaNe (a7a6~7as, Gas Lift MandrelNaNe 3 ' (6126-6127, Gas LiR ' MandrelNaNe 4 (7102-7103, Gas Lilt MandrelNaNe 5 ' (7722-7723. Gas Lift nndrel/Dummy Valve 6 (8073.8074. ' I 00:4.750) NIP (81265127, 00:3.500) ' PBR (81335147, 00:4.000) Pert (8580-8600> Pert (86165638) 3K-35 API: 500292277500 Well T : PROD An le TS: 39 d 8509 SSSV Type: Nipple Orig Com letion: 7/21/1997 Angle @ TD: 24 deg @ 9118 Annular Fluid: Last W/O: Rev Reason: TAG FILL, GLV C/0 Reference Log: Ref Lo Date: Last U date: 12/3/2005 Last Ta : 8687 TD: 9118 ftK6 Last Ta Date: 11/13/2005 Max Hole An le: 48 de 2550 Casing Strin -ALL STRINGS Descri lion . Size To Bottom ND Wt Grede Thread CONDUCTOR 16.000 0 121 121 62.58 H-40 SUR. CASING 7.625 0 5298 4101 29.76 J-55 PROD. CASING 5.500 0 8362 6268 15.50 1-80 _ LINER _ _ 3.500 8147 9114 6899 9.30 L-80 Tubin Strin -TUBING Size _ Top Bottom TVD Wt Grade Thread 3.500 _ 0 8148 6106 9.30 L-80 EUE AB MOD _ _ Pertorations Summa Interval TVD Zone Status Ft SPF Dete T e Comment 8580 - 8600 6436 - 6452 A-3 20 4 7/21!1997 IPERF 2.5" HSD; 160 de . CCW 8616 - 8638 6465 - 6483 A-2 22 4 2/28/2002 APERF 2.5" HSD, 180 hase Gas Lift MandrelsNalves St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3161 2598 BST AXT GLV 1.0 T-1 0.156 1324 7/28/1997 2 4748 3715 BST AXT GLV 1.0 T-1 0.188 1354 7/28/1997 3 6126 4665 BST AXT GLV 1.0 T-1 0.188 1347 5/16/2000 4 7102 5339 BST AXT GLV 1.0 T-1 0.250 1443 7/28/1997 5 7722 __ 5788 BST AXT OV 1.0 T-1 0.250 0 1%15/200 6 8073 . 6050 BST AXT DMY 1.0 T-1 0.000 0 1/15/200 Other lu s e ui .etc. -JEWELRY .Depth TVD T e Descxi lion ID 526 525 NIP _ _ Camco'DS' 2.812 8126 6090 NIP Camco'D' Ni le NO GO 2.750 8133 6095 PBR Baker 10' stroke 3.000 8147 6106 PKR Baker KBH-22 w/ SABL-3 PKR on T of Liner 2.780 L . . I"<'.~'I '".~~ ., \ Q.. E 0 ;'$.. ' ;t~ ;¡. ...._"1 \ ". C,'L~""'~' .... ~ ConocoPhillips Alaska ,JUL 0 3 2007 '·\h),')!tiì Oil 8t Gas COlì3, Commission Än¡;!1m,;1øB P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 2,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 1/\oQ \C\ Dear Mr. Maunder: SCANNED JUL 0 5 ,2007 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. 4¡~ M.J. Loveland ConocoPhillips Well Integrity Supervisor ~. . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Corrosion Initial top of Vol. of cement Final top of Cement top oft Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft na aal 1C-19 203-054 28" none 28" na 12 6/24/2007 1C-123 201-084 22" none 22" na 24 7/1/2007 1C-127 201-114 18" none 18" na 12 7/1/2007 1C-133 201-077 16" none 16" na 8.5 7/1/2007 3K-12 186-165 6" none 6" na 3 6/24/2007 3K-19 201-108 6" none 6" na 3 6/24/2007 3K-20 201-088 4" none 4" na 1 6/24/2007 3K-23 197-097 8" none 8" na 5 6/24/2007 3K-24 198-249 4" none 4" na 1 6/24/2007 3K-25 198-081 6" none 6" na 3 6/24/2007 3K-26 197-077 8" none 8" na 5 6/24/2007 3K-27 197-046 6" none 6" na 3 6/24/2007 3K-31 198-082 8" none 8" na 5 6/24/2007 3K-34 198-077 7" none 7" na 4 6/24/2007 3K-35 197-109 3" none 3" na 2 6/24/2007 Date 7/1/2007 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 March 27, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 3K-35 (19% 109) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operations on the KRU well 3K-35. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad RECEIVED APR 1 2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 66 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 4255' FNL, 4964' FEL, Sec. 35, T13N, R9E , UM (asp's 529304, 6008016) 3K-35 At top of productive interval 9. Permit number / approval number 1153' FSL, 1136' FWL, Sec. 1, T12N, R9E, UM 197-109/ At effective depth 10. APl number 50-029-22775 At total depth 11. Field / Pool 4379' FNL, 4052' FEL, Sec. 1, T12N, R9E, UM (asp's 530766, 6002620) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 9118 feet Plugs (measured) true vertical 6902 feet Effective depth: measured 8808 feet Junk (measured) true vertical 6625 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 4 cu yds High Eady 121' 121' SUR. CASING 5252' 7-5/8" 510 sx ASLW, 440 sx Class G, 50 5298' 4101' PROD. CASING 8312' 5-1/2" 120 sx Class G 8362' 6268' LINER 967' 3-1/2" 159 sx Class G 9114' 6899' LINER Perforation depth: measured 8580' - 8600', 8618'- 8638' true vertical 6436'- 6452', 6467' - 6483' RECEIVED Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 8148' MD. APR ~ ~00~ Packers & SSSV (type & measured depth) Baker KBH-22 w/SABL-3 pkr on top of liner @ 8147' MD. CAMCO 'DS' @ 526' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 174 1420 375 - 142 Subsequent to operation 150 1023 323 - 132 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ X Gas __ Suspended __ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Mooney 263-4574 Signed ~_ ..... ~.~~ Title: Wells Team Leader Date Michael Mooney Prepared by Sharon AIIsup-Drake 263-4612 ORIGINAL Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment 3K-35 Event History 02/24/02 02/25/02 O2/26/O2 02/28/02 PERFORMED A FCO TO 8950' CTMD. APROX 8978' RKB. RETURNS SPORATIC THROUGHOUT THE DAY. UTILIZED SLICK DIESEL PLUS DIESEL GEL. 1/2 YARD SAND IN TANKS AFTER FCO. WELL FREEZE PROTECTED TO 5000'. [FCO] ATTEMPTED DUMMY GUN DRIFT, IN PROGRESS. [PERF, TAG] DRIFTED TBG W/22' X 2.5" HOLLOW CARRIER TO 8800' RKB. [PERF, TAG] PERFORATED A-2 SAND INTERVAL 8618'-8638' W/2.5" HSD, 4 SPF, DP, 180 DEG PHASING. ALSO TAGGED TD @ 8808'. [PERF] Page 1 of 1 3/26/2002 MEMORANDUM- TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, ~%t~O~ Corr.'nissioner aun e , P. !. Supervisor -~'l ~'~' 0 N, FROM: John Crisp, SUBJECT: Petroleum Inspector DATE: May 18, 2001 Safety Valve Tests Kuparuk River Unit 3K Pad ..May 18,2001' I traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, SSV on 3K-27 would not pass the DP test. The valve was serviced & passed the re-test The AOGCC test report is attached for reference. I inspected 14 well houses on lQ Pad w/no problems witnessed. 'SUMMARY: I witnessed SVS testing in Kuparuk River Field. 14 wells, 28 components tested'. 1 failure witnessed. 3.57% failure rate. 14 well houses inspected. Attachments: SVS KRU 3K 5-18-01jc cc; NON-CONFIDENTIAL SVS KRU 3K 5-18-0ljc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Operator Rep: Emie Bamdt AOGCC Rep: John Crisp Submitted By: Date: Field/UniffPad: Kuparuk River Unit 3K Pad Separator psi: LPS 65 HPS 5/18/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed (;AS or CYCLE 3K-01 1861010 65 70 50 P P OIL , 3K-03 1861030 65 70 55 P P OIL , . 3K-06 1861240 65 70 50 P P OIL 3K-09A 1861740 65 60 54 P P OIL , , 3K-10 1861630, 65 70 52 P P OIL 3K-11 1861640! 65 70 50 P P OIL~ , 3K-14 1861370! 65 60 58 P P OIL 3K-16 1861390 65~ 70 70 P P OIL 3K-i7 1861520 65-: 60 35 P P OIL , , , 3K-23 1970970 65 70 58 P P OIL 3K-24 1982490 65 70 50 P P OIL , , 3K-27 1970460 65 701 52 P 4 OIL 3K-32 1970760 65 70i 55 P P OIL , , ~i~K~::~!''~::: :: 1971090 65 70 50! P P O!_L_ Wells: 14 Components: 28 Failures: 1 Failure Rate: 3.§7% I'-i 9o var Remarks: RJF 1/16/01 Page 1 ofl SVS KRU 3K 5-18-01jc THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03, 2 001. M p L E W ATE IA L U N u I= I< TH IS M ARK I~ ~ C:LORIYMFILM.DOC AOGCC Individual Well Geological Materials Inventory PERMIT DATA T DATA PLUS ......................... 97-109 8028 ~PERRY GR/ROP 97-109 MWD SRVY ~8362. 97-109 NGP-MD ~308-8362 97-109 NGP-TVD ~/4088-6235 97-109 PIL ~'~900-9118 97-109 7744 ~'E~dHLUM DITE/CNTG 97-109 DIR SR~ ~CO 0-9000 Page: 1 Date: 07/19/99 RUN RECVD ............. 2,3 07/23/97 07/24/97 FINAL 07/30/97 FINAL 07/30/97 FINAL 07/18/97 1 07/18/97 09/02/97 10-407 ~COMPLET~ON DATE DA~L¥ WELL OPS R * ~/ /~/9~/ TO Are dry ditch samples required? yes ~_~-received? Was the well cored? yes ~Analysis & description received? Are well tests required? /~es ~Received? Well is in compliance Initial COMMENTS yes no ~_~ T D BOX STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. BOX 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1022' FSL, 316' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1153' FSL, 1136' FWL, Sec. 1, T12N, R9E, UM At effective depth 945' FSL, 1748' FWL, Sec. 1, T12N, R9E, UM At total depth 900' FSL, 1756' FWL, Sec. 1, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 9118 6804 6. Datum elevation (DF or KB) RKB 32 7. Unit or Property name Kuparuk River Unit 8. Well number 3K-35 9. Permit number/approval number 97-109 10. APl number 50-029-22775-00 11. Field/Pool Kuparuk River Field/Oil Pool feet feet feet Plugs (measured) None Effective depth: measured 9 01 4 true vertical 6796 feet feet Junk (measured) None 13. 14. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 5252' 7-5/8" 8312' 966' measured 8580'-8600' true vertical 6436'-6452' Cemented Measured depth True vertical depth 4 CU yards HE 1 21 ' 510 Sx ASLW & 5298' 440 Sx Class G w/50 Sx AS I Top Job 120 Sx Class G 8 3 5 3' 159 Sx Class G 91 1 4' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 8148' Packers and SSSV (type and measured depth) Pkr: Baker SABL-3 Pkr/Liner hgr @ 8148'; SSSV: Stimulation or cement squeeze summary Fracture stimulate 'A' Sands on 7/24/97. Intervals treated (measured) 8580'-8600' Treatment description including volumes used and final pressure 121' 4101' 6261 ' 6802' None, Camco nipple @ 526' r.- Pumped 171.6 Mlbs of 20/.40, 12/18, and 10/14 ceramic proppant into formation, fp = 6300 psi. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 760 300 Subsecluent to operation 1 I 2 6 865 8 785 155 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed : ¢,,.%.r ~"-[~,-~¢ ~'~ Title Wells Superintendent Form '~ 0-404 Rev 06/,1~8 Date SUBMIT IN DUPLICATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Pull tubing Alter casing Stimulate Plugging Perforate X Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1022' FSL, 316' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1153' FSL, 1136' FWL, Sec. 1, T12N, R9E, UM At effective depth 945' FSL, 1748' FWL, Sec. 1, T12N, R9E, UM At total depth 900' FSL, 1756' FWL, Sec. 1, T12N, R9E, UM '12. Present well condition summary Total Depth: measured true vertical 9118 6804 6. Datum elevation (DF or KB) RKB 32 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3K-35 9. Permit numbedapproval number 97-109 10. APl number 50-029-22775-00 11. Field/Pool Kuparuk River Field/Oil Pool feet feet Plugs (measured) None Effective depth' measured 9 0 1 4 feet true vertical 6796 feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 5252' 7-5/8" 8312' 5.5" 966' 3.5" measured 8580'-8600' true vertical Cemented Measured depth True vertical depth 4 cu yards HE 1 21 ' 510 Sx ASLW & 5298' 440 Sx Class G w/50 Sx AS I Top Job 120 Sx Class G 8 3 5 3' 159 Sx Class G 91 1 4' 121' 4101' 6261 ' 6802' 6436'-6452' ~,-~ ~[ '"'.'.. Tubing (size, grade, and measured depth) ORIGihJ "AL 3.5", 9.3#/ft., L-80 @ 8148' Packers and SSSV (type and measured depth) Pkr: Baker SABL-3 Pkr/Liner hgr @ 8148'; SSSV: None, Camco nipple @ 5~6 13. Stimulation or cement squeeze summary Perforate 'A' Sands on 7/21/97. Intervals treated (measured) 8580'-8600' Treatment description including volumes used and final pressure Pedorate using 2-1/2" HSD guns w/ BH Charges, 4 SPF, fp = 1000 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 760 300 Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X I 1 2 6 865 8 785 155 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned, .~~/~¢~-~'~,,.. ,l~'-~(~ ~,~'~kc~Title Wells Superintendent Form '~10~-404 Rev 06/1..~8~, Date SUBMIT IN DUPLICATE KUPARUK RIVER UNIT Kl(3K-35(W4~6)) WELL SERVICE REPORT WELL JOri SCOPE JOB NUMBER 3K-35 PERFORATE, PERF SUPPORT 0718972248.9 DATE DAILY WORK UNIT NUMBER 07/21/97 GYRO DATA SURVEY~ PERFORATE 8293 DAY OPERATION COMPLETE [ SUCCESSFUL KEY PERSON SUPERVISOR 2 YESI YES SWS-JOHNSON CHANEY '-'"~" ~t?/i Tb~'-'P-ress Final Tbg Press Initi;ai Inner Ann Final Inner Ann Initial Outer Ann Final Outer Ann 0 PSI 900 PSI 0 PSI 0 PSI 200 PSI 200 PSI DAILY SUMMARY RAN GYRO & PERFD "A" SAND INTERVAL 8580' TO 8600' W/2- l f2" tlSD PERF GUN, 4 SPF, BIG HOLE CHARGES, ORIENTED 160 DEG I CCW. I TIME LOG ENTRY 13:3 0 WAIT FOR SURFACI~; PANEL INSTALATION 15:00 MIRU SWS UNIT 8293; ENG: JOHNSON 19:30 RIG DOWN GYRO DATA TOOL 15:4 0 Rill WITIt GYRO DATA DIRECFIONAL SURVEY T(X)L 20:3 0 PRESSURE TEST RISER/BOP TO 300~ 21:00 RIH WITH PGGT/20' 2-1/2" HSD PERF GUN4 SPF, BIG HOLE CHARGES, ORIENTED 160 DEG CCW 22:10 TAG TD AT 9011'RUN GR/CCI, PASS 8985' TO 8000' 22:50 LOG INTO SHOOTING POSISTIONPUMP TBG PRESS TO 1300~ WITH TRIPI.EX 23:05 SHOOT 8580' TO 8600'. TBG PRESSURE I)ROI>I>EI) DOWN 'FO 10(X) PSI 23:10 POOtt. ALL SHOTS FIRED. 00:3 0 RIG DOWN. WELL SECURED AND NOTIFIEI) IXSO OF STATUS. ARCO Alaska, Inc. Post Office Box !0036u Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 29, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3K-35 (Permit No. 97-109) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3K-35. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Development REC,. X V b 2 1997 4Ja~21 ~il .& 6as Cons. ~ ' .... gncIio, m~o.' WSI/skad ORIGINAL STATE OF ALASKA ALASI,,, OIL AND GAS CONSERVATION C,.,MMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 97-109 3. Address 8. APl Number P. O. Box 100360, Anchorage, Alaska 99510 50-029-22775 4. Location of well at surface ~ ............... ~ 9. Unit or Lease Name '; ,~(~?~-,~;L!.;!;,~i ; !~,~ Kuparuk River Unit 1022' FSL, 316' FWL, Sec.35, T13N, RSE,UM At top of productive i nter~al i ~;~---~ 10. Well Number 1153' FSL, 1136' FWL, Sec. 1, T12N, RSE, UM ' v,~i~:!,~:~l ~ 3K-35 At total depth i i ~,,~_..~'~__. 11. Field and Pool 900' FSL, 1756' FWL, Sec. 1, T12N, RSE, UM .........................~ Kuparuk River RigElevati°nRKB 32',in feetpad(indicate34, KB, DF, etc.) i6. LeaseADL 25629,Designati°nALK 2562and Serial No. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp., or Aband.115. Water depth, if offshore 116. No. of Completions 6/16/97 i 7/12/97 I 7/21/97 I N/A MSLI One Total Depth (MD+TV[~) 118. Plug BaCk Depth (MD+TVD)I19. Directional SUrveyl20. DePth Where SSSV se~'~l. Thickness of Permafrost 9118 6804 FT~ 9014 6796 FT~ [~Yes I-1No I N/A MD/ 1565' (Approx.) Type Electric or Other Logs Run . 22. i23. CASING SIZE VVT. PER FT. 16" 151.5# 7.625" 29.7# 5.5" 15.5# 3.5" 9.2# Perforations open to Production (MD+TVD of Top and bottom' CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH ' HOLE GRADE ToP BO-FrOM SIZE CEMENTING RECORD X-65 Surf. 121' 30" 4 cubic yards High Early L-80 Surf. 5289' 9.875" 510 sx ASLW, 440 sx Class G, 50 sx AS I L-80 Surf. 8353' 6.75" 20 sx Class G L-80 8148' 9114' 4.75" 59 sx Class G !25. AMOUNT PULLED and interval, size and number) MD TVD 8580'-8600' 6436'-6452' 4 spf M D TVD 26. TUBING RECORD S~ZE 3.5" DEPTH SET (MD) PACKER SET (MD) 8148' 8148' ACID FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8580'-8600' 171,619# proppant to 12.2 ppa, 10/14 at perfs, left 13,455# 10/14 proppant in pipe. 27. Date First Production 7/25/97 Date of TestiHours Tested 8/14/97 i 17.8 Flow TubingiCasing Pressure Press. 15&." 1035 PRODUCTION TEST iMethod of Operation (Flowing, gas lift, etc.) .... ~_ Gas_Li_!t___ -¢-¢~,-~- MCF PRODUCTION FOR J O~L-BBL . TEST PERIOD · I 1005 ~ 563 ! CALCULATED · ~OIL-BBL GAS- P_4-HOUR RATE I 1226 M5c~2 CORE DATA WATER-BBL 9 WATER-BBL 12 i-CHOKE 0SIZE I GAS-OIL RATIO i 418 'OIL. GRAviTYLAPI' (CORR) 24° Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Mar' 30. Formation Tests ~., Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top Kuparuk C 8509' 6381' Annulus left open - freeze protected with diesel. Bottom Kuparuk C 8509' 6381' Top Kuparuk A 8552' 6414' Bottom Kuparuk A 8711' 6542' I ~ List ~i ~ttachments Summary of Daily Drilling Reports, Surveys 321 i i-ler~by certify/t~-~a:t--~:-i~e f'oreg0i-r~--i~-~ru~ ar~-~J--~ie~ t~ t-~--~-St -of my--l~-~-I-esg~ ................................................... . S gned ~ ~ ..... ~....~"L ~ . ~ .,..~., ~_ Title ~"~,,~.~N ~ _ _. ~ 6.~.~ EER_ ...... Date_ Prepared By Name/Number: Sharon K. AIIsup-Drake 263-4612 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Date: 7/23/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:3K-35 RIG:NORDIC WI: 0% SECURITY:0 WELL ID: AK8789 TYPE: AFC:--AK8789 AFC EST/UL:$ 1250M/ 1500M STATE:ALASKA API NUMBER: 50-029-22775-00 AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:06/16/97 START COMP: FINAL:07/16/97 06/15/97 (D1} TD: 121' (121) SUPV: DCL DAILY: $ 06/16/97 (D2} TD: 3588' (3467) SUPV: DCL DAILY: $ 06/17/97 (D3} TD: 5308' (1720) SUPV: DCL DAILY: $ 06/18/97 (D4) TD: 5308' ( 0} SUPV: DCL DAILY: $ 06/19/97 (D5) TD: 6057' (749) SUPV: DCL DAILY: $ 06/20/97 (D6) TD: 8060' (2003} SUPV: DCL DAILY: $ 06/21/97 (D7) TD: 8362' (302) SUPV: DCL DAILY: $ 06/22/97 (D8) TD: 8362' ( 0) SUPV: DCL DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 DRILLING Move rig from 3K-23 to 3K-35. Accept rig at 2130 hrs. 6/15/97. NU diverter system. Function test diverter. 11,912 CUM'$ 11,912 ETD:$ 0 EFC:$ 1,261,912 MW' 9.2 VISC: 65 PV/YP: 18/19 APIWL: 6.8 WIPERTRIP @ 4047' Clean out conductor to 121'. Drilling from 121' to 3588' 139,702 CUM:$ 151,614 ETD:$ 261,871 EFC:$ 1,139,74~ MW: 9.5 VISC: 44 PV/YP: 12/10 APIWL' 6.8 PREP TO RUN CSG Drilling from 3588' to 5308' 77,449 CUM'$ 229,063 ETD:~ 367,149 EFC'$ 1,111,914 MW: 9.5 VISC: 42 PV/YP: 12/ 9 APIWL: 6.6 POH F/BHA Held prejob safety meeting. RIH w/7-5/8" casing. Pump cement. Test BOPE to 300/3000 psi. 149,307 CUM:$ 378,370 ETD:$ 367,149 EFC:$ 1,261,221 MW: 8.6 VISC: 34 PV/YP: 6/ 3 APIWL: 10.4 DRILLING Clean out cement from 4912' to 5133' Drill out cement, FE and 20' of new formation to 5328' Perform LOT, 13.8 ppg. Drilling from 5328' to 6057' 70,853 CUM:$ 449,223 ETD:~ 474,787 EFC'$ 1,224,436 MW' 9.2 VISC' 41 PV/YP: 11/10 APIWL' 4.6 WIPERTRIP TO RUN CSG Drilling from 6057' to 8060' 74,463 CUM:$ 523,686 ETD:~ 762,635 EFC:$ 1,011,051 MW' 9.3 VISC' 43 PV/YP: 12/ 9 APIWL: 6.2 ND BOPE Drilling from 8060' to 8362' Performed OH LOT. Held prejob safety meeting. RIH w/5.5" casing. 71,349 CUM:$ 595,035 ETD:$ 0 EFC:$ 1,845,035 MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Work last 4 joints to TD. Reciprocate pipe until circ at 5 bpm. Pump cement. Install packoff. Freeze protect annulus. Release rig at 16:00 hrs. 6/22/97. 100,519 CUM:$ 695,554 ETD:$ 0 EFC:$ 1,945,554 Date: 7/23/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 07/09/97 (D9) TD: 8353' ( 0) SUPV:DLW DAILY:$ 07/10/97 (D10) TD: 8353' ( 0) SUPV:DLW DAILY:$ 07/11/97 (Dll) TD: 8746' (393) SUPV:DLW DAILY:$ 07/12/97 (D12) TD: 9118' (372) SUPV:DLW DAILY:$ 07/13/97 (D13) TD: 9118' ( 0) SUPV:DLW DAILY:$ 07/14/97 (D14) TD: 9118' ( 0) SUPV:DLW DAILY:$ 07/15/97 (D15) TD: 9014' ( 0) SUPV: DLW DAILY:$ MW: 6.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIH P/U W/BHA %1 Turn key pad to pad move from iQ to 3K. Rig up. Accept rig @ 1200 hrs. 7/9/97. Test BOPE 250/3500 psi, OK. 51,300 CUM:$ 746,854 ETD:$ 0 EFC:$ 1,996,854 MW: 11.0 VISC: 69 PV/YP: 23/27 APIWL: 3.7 WORKING ON SWIVEL PACKING RIH w/BHA %1. Tag cement. Displace seawater with mud. Clean out cement, wiper plugs and float equipment from 8261' to 8326'. 71,043 CUM:$ 817,897 ETD:$ 0 EFC:$ 2,067,897 MW: 12.0 VISC: 56 PV/YP: 23/18 APIWL: 3.4 DRILLING 4.75" HOLE @ 8978' Continue to change out kelly swivel washpipe and packing. Continue to clean out float equipment from 8326' to 8353' Drilling 4.75" hole from 8353' to 8373', 20' of new hole. FIT, EMW 14.1 ppg. Drilling from 8373' to 8746' Shaker screens blinding off. Raise mud weight to 12.0 ppg. 40,602 CUM:$ 858,499 ETD:$ 0 EFC:$ 2,108,499 MW: 12.0 rISC: 52 PV/YP: 22/15 APIWL: 4.0 RUNNING 3.5" LINER Continue to circulate 12.0 ppg mud and clean Asphaltine off shaker screens. Continue drilling 4.75" hole from 8746' to 9118' TD. RIH w/E-logs. 44,906 CUM:$ 903,405 ETD:$ 0 EFC:$ 2,153,405 MW: 12.0 VISC: 71 PV/YP: 32/20 APIWL: 3.5 L/D 2-7/8" DP Continue E-logs. Run 3.5" liner. Pump cement. 87,315 CUM:$ 990,720 ETD:$ 0 EFC:$ 2,240,720 MW: 8.4 VISC: 26 PV/YP: 1/ 0 APIWL: 0.0 RUNNING 3.5" COMPLETION TBG Continue to reverse circulate and displace 12.0 ppg mud from 8140' Load pipe house with 3.5" tubing. 57,241 CUM:$ 1,047,961 ETD:$ 0 EFC:$ 2,297,961 MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RELEASE RIG Run 3.5" tubing. Freeze protect well. Test tubing to 3500 psi 15 min. OK. Test annulus to 3500 psi for 15 min. OK. Test tree to 250/5000 psi. Release rig @ 2400 hrs. 7/15/97. 120,712 CUM:$ 1,168,673 ETD:$ 0 EFC:$ 2,418,673 End of WellSummary for Well:AK8789 SPF~-z~SUN DRILLING SERVICES ANCHORAGE ALASKA ARCO ALASKA, INC. KUPARUK RIVER UNIT / 3K-35 500292277500 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/14/97 DATE OF SURVEY: 062297 MWD SURVEY JOB NUMBER: AK-MM-70179 KELLY BUSHING ELEV. = 75.30 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -75.30 121.00 121.00 45.70 170.00 170.00 94.70 266.00 265.99 190.69 352.00 351.96 276.66 0 0 0 0 0 45 0 45 2 0 N .00 E .00 .00N .00E N .00 E .00 .00N .00E N 36.00 W 1.53 .26N .19W N 10.00 E .61 1.39N .45W N 69.00 E 2.02 2.48N 1.05E .00 .00 -.30 -1.45 -2.14 444.00 443.81 368.51 562.04 561.35 486.05 654.47 652.96 577.66 746.43 743.44 668.14 837.91 832.38 757.08 4 3O 6 16 8 48 11 43 15 18 S 70.00 E 3.55 1.82N 5.94E S 38.22 E 2.89 4.84S 14.29E S 37.69 E 2.73 14.41S 21.74E S 41.38 E 3.26 26.99S 32.22E S 34.83 E 4.25 43.89S 45.27E - .27 8.28 19.41 34.22 53.86 929.86 920.36 845.06 1020.72 1005.53 930.23 1109.71 1087.06 1011.76 1202.90 1170.70 1095.40 1298.49 1254.62 1179.32 18 25 22 18 24 55 27 24 29 50 S 31.34 E 3.56 66.26S 59.77E S 26.94 E 4.60 93.91S 75.05E S 26.30 E 2.95 125.78S 91.01E S 22.51 E 3.22 163.21S 107.93E S 16.83 E 3.81 206.31S 123.24E 79.16 109.76 144.62 185.10 230.67 1391.27 1333.87 1258.57 1477.08 1405.72 1330.42 1571.57 1483.75 1408.45 1663.81 1557.66 1482.36 1750.73 1624.49 1549.19 32 48 33 27 35 10 38 18 41 10 S 15.54 E 3.28 252.63S 136.66E S 15.34 E .77 297.85S 149.15E S 14.86 E 1.84 349.28S 163.02E S 14.29 E 3.41 402.68S 176.90E S 13.83 E 3.31 456.58S 190.39E 278.88 325.78 379.04 434.22 489.78 1848.31 1695.95 1620.65 1937.33 1757.61 1682.31 2219.65 1950.65 1875.35 2495.35 2139.17 2063.87 2774.28 2327.79, 2252.49 44 39 47 39 46 3 47 39 47 15 S 13.90 E 3.57 521.07S 206.31E S 13.67 E 3.38 583.41S 221.60E S 11.06 E .88 784.54S 265.75E S 13.81 E .93 980.89S 309.12E S 13.48 E .17 1180.57S 357.59E 556.20 620.38 826.15 1027.09 1232.55 3052.33 2520.04 2444.74 3328.83 2709.28 2633.98 3604.49 2894.95 2819.65 3881.63 3086.44 3011.14 4160.26 3283.84 3208.54 45 15 48 21 46 57 45 37 44 8 S 14.34 E .75 1375.50S 405.84E S 13.79 E 1.13 1571.02S 454.80E S 13.55 E .52 1768.97S 502.95E S 13.05 E .49 1963.91S 549.04E S 13.83 E .57 2155.13S 594.72E 1433.35 1634.90 1838.60 2038.86 2235.43 4438.41 3482.21 3406.91 4804.82 3738.11 3662.81 5080.65 3931.26 3855.96 5228.20 4033.79 3958.49 5455.11 4188.41 4113.11 44 52 46 31 44 34 47 22 46 42 S 13.25 E .30 2344.68S 640.36E S 13.64 E .46 2599.68S 701.34E S 14.38 E .73 2790.69S 748.97E S 14.56 E 1.91 2893.40S 775.48E S 15.68 E .47 3053.72S 818.79E 2430.37 2692.50 2889.35 2995.43 3161.49 ORIGINAL JUL 4 · SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT / 3K-35 500292277500 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/14/97 DATE OF SURVEY: 062297 MWD SURVEY JOB NUMBER: AK-MM-70179 KELLY BUSHING ELEV. = 75.30 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 5731.92 4377.25 4301.95 47 15 6009.20 4564.11 4488.81 48 0 6284.65 4749.52 4674.22 47 22 6562.62 4937.55 4862.25 47 29 6839.94 5127.48 5052.18 46 4 S 15.90 E .21 3248.47S 873.87E 3363.83 S 15.81 E .27 3445.53S 929.83E 3568.63 S 13.59 E .64 3642.52S 981.53E 3772.29 S 16.83 E .86 3840.00S 1035.23E 3976.92 S 13.64 E .98 4034.91S 1088.38E 4178.94 7118.56 5323.63 5248.33 44 25 7397.68 5523.29 5447.99 44 14 7675.50 5724.55 5649.25 42 54 7947.18 5924.67 5849.37 42 12 8221.00 6128.84 6053.54 41 22 S 15.37 E .74 4226.43S 1137.88E 4376.76 S 13.47 E .48 4415.31S 1186.45E 4571.77 S 15.04 E .62 4600.89S 1233.57E 4763.24 S 11.79 E .85 4779.53S 1276.21E 4946.87 S 11.41 E .32 4958.25S 1312.91E 5129.08 8311.27 6196.68 6121.38 41 11 S 10.74 E .53 8362.00 6234.85 6159.55 41 11 S 10.74 E .04 5016.70S 1324.35E 5188.52 5049.52S 1330.57E 5221.85 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5221.88 FEET AT SOUTH 14 DEG. 45 MIN. EAST AT MD = 8362 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 165.44 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 8,362.00' MD · SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT / 3K-35 500292277500 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/14/97 DATE OF SURVEY: 062297 JOB NUMBER: AK-MM-70179 KELLY BUSHING ELEV. = 75.30 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTi~NGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -75.30 .00 N .00 E .00 1000.00 986.30 911.00 87.06 S 71.51 E 13.70 13.70 2000.00 1799.83 1724.53 628.42 S 232.55 E 200.17 186.48 3000.00 2483.20 2407.90 1339.50 S 396.64 E 516.80 316.63 4000.00 3169.21 3093.91 2046.34 S 568.15 E 830.79 313.98 5000.00 3873.81 3798.51 2735.86 S 734.92 E 6000.00 4557.95 4482.65 3438.96 S 927.97 E 7000.00 5238.95 5163.65 4146.42 S 1115.89 E 8000.00 5963.80 5888.50 4814.26 S 1283.46 E 8362.00 6234.85 6159.55 5049.52 S 1330.57 E 1126.19 295.41 1442.05 315.85 1761.05 319.00 2036.20 275.15 2127.15 90.95 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT / 3K-35 500292277500 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/14/97 DATE OF SURVEY: 062297 JOB NUMBER: AK-MM-70179 KELLY BUSHING ELEV. = 75.30 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVI) VERTICAL DIFFERENCE CORRECTION .00 .00 -75.30 75.30 75.30 .00 175.30 175.30 100.00 275.31 275.30 200.00 375.36 375.30 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .32 N .23 W .00 .00 1.51 N .43 W .01 .01 2.64 N 1.95 E .06 .05 475.59 475.30 400.00 576.07 575.30 500.00 677.10 675.30 600.00 779.05 775.30 700.00 882.58 875.30 800.00 .70 N 8.24 E 6.04 S 15.24 E 17.24 S 23.98 E 32.35 S 36.70 E 54.16 S 52.16 E .29 .23 .77 .48 1.80 1.03 3.75 1.95 7.28 3.54 988.22 975.30 900.00 1096.76 1075.30 1000.00 1208.09 1175.30 1100.00 1322.43 1275.30 1200.00 1440.61 1375.30 1300.00 83.34 S 69.51 E 120.94 S 88.62 E 165.45 S 108.82 E 217.87 S 126.70 E 278.46 S 143.83 E 12 21 32 47 65 .92 5.63 .46 8.55 .79 11.33 .13 14.34 .31 18.18 1561.23 1475.30 1400.00 1686.43 1575.30 1500.00 1819.54 1675.30 1600.00 1963.59 1775.30 1700.00 2111.05 1875.30 1800.00 343.52 S 161.49 E 85.93 20.62 416.40 S 180.37 E 111.13 25.20 501.63 S 201.50 E 144.24 33.11 602.27 S 226.19 E 188.29 44.05 707.79 S 250.75 E 235.76 47.47 2255.17 1975.30 1900.00 2400.53 2075.30 2000.00 2548.98 2175.30 2100.00 2696.95 2275.30 2200.00 2844.26 2375.30 2300.00 809.64 S 270.66 E 912.84 S 292.39 E 1019.37 S 318.58 E 1125.34 S 344.35 E 1230.54 S 369.57 E 279.87 325.23 373.68 421.65 468.96 44.11 45.37 48.44 47.97 47.32 2988.78 2475.30 2400.00 3131.46 2575.30 2500.00 3277.98 2675.30 2600.00 3428.19 2775.30 2700.00 3575.71 2875.30 2800.00 1331.78 S 394.66 E 1430.39 S 419.79 E 1534.29 S 445.75 E 1643.13 S 472.50 E 1748.52 S 498.02 E 513.48 556.16 602.68 652.89 700.41 44.52 42.68 46.53 50.21 47.52 3722.20 2975.30 2900.00 3865.70 3075.30 3000.00 4008.70 3175.30 3100.00 4148.36 3275.30 3200.00 4287.71 3375.30 3300.00 1852.59 S 523.10 E 1952.82 S 546.47 E 2052.40 S 569.55 E 2147.09 S 592.74 E 2241.32 S 615.94 E 746.90 790.40 833.40 873.06 912.41 46.49 43.50 43.00 39.66 39.35 S~ · SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT / 3K-35 500292277500 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/14/97 DATE OF SURVEY: 062297 JOB NUMBER: AK-MM-70179 KELLY BUSHING ELEV. = 75.30 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 4428.66 3475.30 3400.00 2337.99 S 638.79 E 953.36 40.95 4569.76 3575.30 3500.00 2434.89 S 661.60 E 994.46 41.10 4713.54 3675.30 3600.00 2535.31 S 685.72 E 1038.24 43.77 4858.87 3775.30 3700.00 2637.79 S 710.58 E 1083.57 45.33 5002.10 3875.30 3800.00 2737.29 S 735.28 E 1126.80 43.23 5143.12 3975.30 3900.00 2833.60 S 760.01 E 1167.82 41.02 5289.50 4075.30 4000.00 2937.06 S 786.82 E 1214.20 46.38 5435.99 4175.30 4100.00 3040.32 S 815.03 E 1260.69 46.49 5581.83 4275.30 4200.00 3142.53 S 843.72 E 1306.53 45.84 5729.05 4375.30 4300.00 3246.45 S 873.29 E 1353.75 47.22 5876.51 4475.30 4400.00 3350.67 S 902.97 E 1401.21 47.46 6025.93 4575.30 45.00.00 3457.50 S 933.22 E 1450.63 49.42 6175.04 4675.30 4600.00 3564.12 S 962.58 E 1499.74 49.11 6322.72 4775.30 4700.00 3669.75 S 988.11 E 1547.42 47.68 6470.50 4875.30 4800.00 3775.00 S 1015.56 E 1595.20 47.78 6618.33 4975.30 4900.00 3879.28 S 1046.87 E 1643.03 47.83 6764.47 5075.30 5000.00 3982.03 S 1075.11 E 1689.17 46.14 6908.87 5175.30 5100.00 4083.16 S 1100.09 E 1733.57 44.40 7050.90 5275.30 5200.00 4180.77 S 1125.33 E 1775.60 42.03 7190.91 5375.30 5300.00 4275.26 S 1151.31 E 1815.61 40.01 7330.70 5475.30 5400.00 4369.86 S 1175.57 E 1855.40 39.79 7470.28 5575.30 5500.00 4464.56 S 1198.25 E 1894.98 39.58 7608.26 5675.30 5600.00 4556.68 S 1221.69 E 1932.96 37.98 7744.79 5775.30 5700.00 4646.45 S 1245.81 E 1969.49 36.53 7880.53 5875.30 5800.00 4735.71 S 1267.07 E 2005.23 35.74 8015.52 5975.30 5900.00 4824.47 S 1285.59 E 2040.22 34.99 8149.66 6075.30 6000.00 4912.03 S 1303.58 E 2074.36 34.13 8282.86 6175.30 6100.00 4998.32 S 1320.86 E 2107.56 33.21 8362.00 6234.85 6159.55 5049.52 S 1330.57 E 2127.15 19.58 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS A Gyroda t a Di re c t i ona i Survey for ARCO ALASKA INC. DRILLSITE 3K, WELL NO. 3K-35 KUPARUK RIVER UNIT, ALASKA Job Number: SUB415 Run Date: 21-Jul-97 16:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.416600 deg. N Sub-sea Correction from Vertical Reference: 66 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 165.440 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyrodata ARCO ALASKA INC. DRILLSITE 3K, WELL NO. 3K-35 KUPARUK RIVER UNIT, ALASKA Job Number: A0797GCE415 Direct i o n a 1 MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. . 100. 200. 300. 400. 0.00 0.00 0.0 .39 345.82 100.0 .52 328.19 200.0 1 . 18 56 . 76 300 . 0 3.83 88.64 399.9 0.0 0.00 0.0 0.0 -.3 .39 .3 345.8 -1.1 .19 1.1 338.8 -1.9 1.28 2.0 6.3 -1.4 2.90 5.2 59.2 500. 600. 700. 801. 900. 4.86 116.05 499.6 7.40 134.35 599.0 9.84 140.53 697.9 13.65 144.19 796.8 17.54 147.65 892.1 2.1 10.4 23.6 42.6 67.7 2.29 11.6 85.8 3.17 20.7 105.4 2.61 34.3 118.9 3.84 53.8 127.8 4.04 79.5 133.8 950. 1000. 1050. 1100. 1150. 19.83 149.66 939.5 21.84 151.07 986.2 23.81 152.62 1032.3 24.99 153.59 1077.8 26.06 154.65 1122.9 83.0 100.2 119.0 139.2 160.3 4.75 95.0 136.3 4.15 112.4 138.5 4.12 131.3 140.5 2.48 151.5 142.2 2.33 172.7 143.7 1200. 1250. 1300. 1350. 1400. 27.55 157.26 1167.6 28.82 160.47 1211.6 30.09 162.07 1255.2 31.41 162.80 1298.1 32.72 162.98 1340.5 182.6 206.0 230.6 256.1 282.6 3.80 194.8 145.1 3.95 217.8 146.6 2.99 241.6 148.0 2.74 266.4 149,4 2.63 292.3 150.6 1450. 1500. 1550. 1600. 1650. 33.28 163.01 1382.4 33.77 163.07 1424.1 34.63 163.24 1465.5 36.06 163.37 1506.3 37.95 163.86 1546.2 309.8 337.4 365.5 394.4 424.5 1.11 319.0 151.7 .99 346.1 152.6 1.73 373.8 153.4 2.85 402.3 154.1 3.83 432.0 154.7 Survey Page HORIZONTAL COORDINATES feet 0.00 N 0.00 E .33 N .08 W 1.04 N .41 W 1.99 N .22 E 2.64 N 4.42 E .86 N 5.51 S 16.61 S 32.95 S 55.04 S 68.73 S 84.19 S 101.29 S 119.71 S 139.10 S 159.69 S 181.71 S 205.00 S 229.37 S 254.74 S 280.78 S 307.20 S 334.10 S 361.80 S 390.67 S 11.58 E 20.00 E 30.04 E 42.50 E 57 33 E 65 64 E 74.43 E 83 57 E 92.91 E 102 31 E 111 48 E 119.98 E 127 87 E 135.58 E 143.39 E 151.36 E 159.41 E 167.55 E 175.86 E 184.35 E ORIGIN/ £ A Gyroda t a Di r ec t i ona i Survey ARCO ALASKA INC. DRILLSITE 3K, WELL NO. 3K-35 KUPARUK RIVER UNIT, ALASKA Job Number: A0797GCE415 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 1700.0 39.57 164.24 1585.2 1750.0 41.27 164.45 1623.2 1800.0 43.07 164.51 1660.3 1850.0 45.18 164.33 1696.2 1900.0 46.45 164.74 1731.0 455.8 488.2 521.7 556.5 592.4 3.27 462.9 155.4 3.42 494.9 156.0 3.59 528.2 156.5 4.23 562.7 157.0 2.61 598.2 157.4 420.77 S 192.95 E 451.98 S 201.70 E 484.32 S 210.68 E 517.85 S 220.03 E 552.41 S 229.59 E 1950.0 48.18 165.65 1764.9 2000.0 48.41 166.49 1798.2 2050.0 48.17 167.10 1831.5 2100.0 47.96 167.13 1864.9 2150.0 47.46 167.23 1898.5 629.1 666.5 703.8 741.0 777.9 3.70 634.7 157.9 1.33 671.6 158.3 1.03 708.6 158.8 .43 745.4 159.2 1.02 782.0 159.6 587.94 S 238.97 E 624.17 S 247.96 E 660.51 S 256.49 E 696.77 S 264.78 E 732.83 S 272.99 E 2200.0 46.27 167.65 1932.7 2250.0 44.52 167.97 1967.8 2300.0 44.11 168.04 2003.6 2350.0 44.03 168.08 2039.5 2400.0 45.38 166.15 2075.1 814.4 850.0 884.9 919.6 954.7 2.44 818.2 159.9 3.54 853.5 160.2 .82 888.1 160.6 .17 922.6 160.8 3.82 957.5 161.1 768.45 S 280.93 E 803.24 S 288.44 E 837.41 S 295.70 E 871.43 S 302.90 E 905.72 S 310.75 E 2450.0 46.53 165.28 2109.8 2500.0 48.34 164.84 2143.6 2550.0 48.47 164.78 2176.8 2600.0 48.27 164.72 2210.0 2650.0 47.66 164.64 2243.5 990.7 1027.5 1064.9 1102.3 1139.4 2.62 993.4 161.2 3.67 1030.1 161.4 .28 1067.4 161.5 .41 1104.8 161.6 1.22 1141.8 161.7 940.54 S 319.62 E 976.12 S 329.11 E 1012.21 S 338.91 E 1048.26 S 348.74 E 1084.08 S 358.55 E 2700.0 47.56 164.75 2277.2 2750.0 47.11 164.73 2311.1 2800.0 46.68 164.77 2345.3 2850.0 46.44 164.66 2379.7 2900.0 45.99 164.43 2414.3 1176.3 1213.1 1249.6 1285.9 1322.0 .27 1178.7 161.8 .90 1215.4 161.9 .86 1251.9 162.0 .51 1288.2 162.0 .95 1324.2 162.1 1119.70 S 368.30 E 1155.17 S 377.98 E 1190.39 S 387.58 E 1225.41 S 397.15 E 1260.20 S 406.76 E A Gyr oda t a Di r e c t i ona i ARCO ALASKA INC. DRILLSITE 3K, WELL NO. 3K-35 KUPARUK RIVER UNIT, ALASKA Job Number: A0797GCE415 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEV}~RITY DIST. AZIMUTH de~t./ feet deg. 100 ft. 2950.0 45.82 164.27 2449.1 3000.0 45.35 164.12 2484.1 3050.0 45.13 163.97 2519.3 3100.0 45.10 164.19 2554.5 3150.0 44.79 164.27 2589.9 1357.9 1393.6 1429.1 1464.5 1499.8 .42 1360.1 162.2 .96 1395.8 162.2 · 49 1431.3 162.3 .32 1466.7 162.3 · 63 1502.0 162.4 3200.0 44.47 164.51 2625.5 3250.0 45.92 165.29 2660.8 3300.0 47.71 165.37 2695.0 3350.0 47.97 165.30 2728.5 3400.0 47.48 165.27 2762.2 1534.9 1570.4 1606.9 1643.9 1680.9 · 72 1537.1 162.4 3.10 1572.5 162.5 3.57 1608.9 162.5 · 54 1646.0 162.6 · 98 1682.9 162.6 3450.0 47.48 165.37 2796.0 3500.0 47.23 165.47 2829.8 3550.0 47.07 165.52 2863.8 3600.0 46.63 165.47 2898.0 3650.0 46.37 165.43 2932.5 1717.8 1754.6 1791.2 1827.7 1864.0 · 15 1719.7 162.7 · 51 1756.5 162.8 .34 1793.1 162.8 · 88 1829.5 162.9 .52 1865.8 162.9 3700.0 46.34 165.56 2967.0 3750.0 46.11 165.61 3001.6 3800.0 45.68 165.62 3036.4 3850.0 45.66 165.55 3071.3 3900.0 45.45 165.31 3106.3 1900.1 1936.2 1972.1 2007.9 2043.6 · 21 1901.9 163.0 .46 1938.0 163.0 .85 1973.8 163.1 .11 2009.6 163~1 · 53 2045.2 163.2 3950.0 44.96 165.09 3141.5 4000.0 44.80 164.89 3177.0 4050.0 44.43 164.92 3212.6 4100.0 44.33 165.08 3248.3 4150.0 43.96 165.24 3284.2 2079.1 2114.4 2149.5 2184.4 2219.3 1.04 2080.7 163.2 .41 2116.0 163.2 .75 2151.1 163.2 · 30 2186.0 163.3 .78 2220.8 163.3 Survey Page HORIZONTAL COORDINATES feet 1294.77 S 416.45 E 1329.14 S 426.18 E 1363.27 S 435.94 E 1397.34 S 445.65 E 1431.33 S 455.25 E 1465.17 S 1499.42 S 1534.68 S 1570.54 S 1606.32 S 1641.97 S 1677.56 S 1713.05 S 1748.37 S 1783.47 S 1818.49 S 1853.46 S 1888.24 S 1922.88 S 1957.42 S 1991.73 S 2025.81 S 2059.71 S 2093.49 S 2127.15 S 464.70 E 473.94 E 483.18 E 492.56 E 501.96 E 511.30 E 520.56 E 529.74 E 538.88 E 547.99 E 557.05 E 566.04 E 574.95 E 583.86 E 592.84 E 601.90 E 611.04 E 620.18 E 629.23 E 638.15 E A Gy r o d a t a ARCO ALASKA INC. DRILLSITE 3K, WELL NO. 3K-35 KUPARUK RIVER UNIT, ALASKA Job Number: A0797GCE415 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet de9. deg. feet VERTICAL SECTION feet 4200.0 43.60 165.13 3320.3 4250.0 43.42 165.17 3356.5 4300.0 43.58 164.98 3392.8 4350.0 44.68 164.90 3428.7 4400.0 44.76 165.26 3464.2 4450.0 44.39 165.44 3499.8 4500.0 44.13 165.68 3535.6 4550.0 43.73 165.87 3571.7 4600.0 43.70 165.95 3607.8 4650.0 43.52 166.09 3644.0 4700.0 43.16 165.91 3680.4 4750.0 44.78 ~ 165.50 3716.3 4800.0 46.06 165.11 3751.4 4850.0 45.91 165.03 3786.2 4900.0 45.37 165.03 3821.1 4950.0 45.23 164.95 3856.3 5000.0 44.85 164.69 3891.6 5050.0 44.45 164.64 3927.2 5100.0 44.46 164.86 3962.9 5150.0 44.31 164.55 3998.6 5200. ~ 46.18 5250 47.31 5300 46 5 3 5 0.'~ ,......'4 6. 5 4 0 0 . '.~, ' 4 6 2253.9 2288.3 2322.7 2357.5 2392.7 2427.8 2462.7 2497.4 2531.9 2566.4 2600.7 2635.4 2671.1 2707.0 2742.8 2778.3 2813.7 2848.8 2883.8 2918.8 164.05 4033.8 2954.3 163.89 4068.1 2990.7 163.78 4102.3 3027.2 163.82 4136.6 3063.5 163.71 4171.0 3099.8 Directional DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet de~. 100 ft. .74 2255.4 163.3 .36 2289.8 163.4 .42 2324.2 163.4 .19 2359.0 163.4 .54 2394.2 163.4 .79 2429.2 163.5 .61 2464.1 163.5 .84 2498.8 163.5 .13 2533.3 163.6 .40 2567.8 163.6 .77 2602.0 163.6 .29 2636.7 163.6 .62 2672.3 163.7 .33 2708.3 163.7 .07 2744.0 163.7 .30 2779.5 163.7 .84 2814.9 163.7 .80 2850.1 163.7 .31 2885.1 163.8 .53 2920.0 163.8 .81 2955.5 163.8 .26 2992.0 163.8 .67 3028.5 163.8 .38 3064.8 163.8 .48 3101.1 163.8 Survey HORIZONTAL COORDINATES feet 2160.60 S 646.99 E 2193.87 S 655.82 E 2227.13 S 664.68 E 2260.74 S 673.73 E 2294.74 S 682.78 E 2328.69 S 691.66 E 2362.48 S 700.36 E 2396.11 S 708.89 E 2429.62 S 717.30 E 2463.09 S 725.63 E 2496.39 S 733.94 E 2530.03 S 742.51 E 2564.48 S 751.54 E 2599.22 S 760.81 E 2633.75 S 770.04 E 2668.08 S 2702.23 S 2736.12 S 2769.90 S 2803.64 S 2837.82 S 2872.81 S 2907.87 S 2942.74 S 2977.59 S 779.25 E 788.51 E 797.81 E 807.02 E 816.25 E 825.86 E 835.92 E 846.08 E 856.21 E 866.36 E Page A Gyroda t a Di r e c t i ona i ARCO ALASKA INC. DRILLSITE 3K, WELL NO. 3K-35 KUPARUK RIVER UNIT, ALASKA Job Number: A0797GCE415 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. 5450.0 46.50 163.74 4205.5 5500.0 46.77 163.71 4239.8 5550.0 46.77 163.73 4274.0 5600.0 47.07 163.74 4308.2 5650.0 46.97 163.79 4342.3 3136.0 3172.3 3208.7 3245.2 3281.8 .13 3137.3 163.8 .53 3173.7 163.8 .02 3210.1 163.8 .60 3246.6 163.8 .20 3283.2 163.8 5700.0 46.99 163.86 4376.4 5750.0 47.07 163.97 4410.5 5800.0 47.05 164.17 4444.5 5850.0 47.29 164.26 4478.5 5900.0 47.18 164.45 4512.5 3318.3 3354.9 3391.5 3428.2 3464.9 .11 3319.7 163.8 .22 3356.3 163.8 .30 3392.9 163.8 .52 3429.6 163.8 .36 3466.3 163.8 5950.0 47.50 164.35 4546.4 6000.0 47.69 164.51 4580.1 6050.0 47.72 164.45 4613.7 6100.0 47.92 164.73 4647.3 6150.0 47.33 164.76 4681.0 3501.6 3538.6 3575.5 3612.6 3649.5 .66 3503.1 163.8 .45 3540.0 163.8 .12 3577.0 163.8 .58 3614.0 163.8 .18 3651.0 163.8 6200.0 47.44 165.03 4714.8 6250.0 47.07 165.16 4748.8 6300.0 47.20 165.25 4782.8 6350.0 47.45 165.26 4816.7 6400.0 47.13 165.33 4850.6 3686.3 3723.0 3759.7 3796.4 3833.2 .45 3687.8 163.8 .76 3724.5 163.9 .30 3761.1 163.9 .50 3797.8 163~9 .66 3834.6 163.9 6450.0 47.41 165.54 4884.5 6500.0 47.11 165.67 4918.5 6550.0 47.07 165.77 4952.5 6600.0 47.16 165.89 4986.5 6650.0 46.94 166.02 5020.6 3869.9 3906.6 3943.2 3979.9 4016.5 .66 3871.3 163.9 .64 3908.0 163.9 .16 3944.6 163.9 .24 3981.2 164.0 .47 4017.8 164.0 Survey Page HORIZONTAL COORDINATES feet 3012.39 S 876.52 E 3047.28 S 886.70 E 3082.25 S 896.91 E 3117.30 S 907.15 E 3152.42 S 917.37 E 3187.54 S 927.56 E 3222.69 S 937.69 E 3257.88 S 947.73 E 3293.17 S 957.71 E 3328.52 S 967.60 E 3363.94 S 977.49 E 3399.50 S 987.40 E 3435.14 S 997.30 E 3470.86 S 1007.15 E 3506.50 S 1016.86 E 3542.02 S 1026.45 E 3577.50 S 1035.90 E 3612.93 S 1045.25 E 3648.48 S 1054.61 E 3684.02 S 1063.94 E 3719.57 S 1073.17 E 3755.14'S 1082.30 E 3790.63 S 1091.33 E 3826.15 S 1100.30 E 3861.65 S 1109.18 E A Gyroda t a Di re c t i ona i ARCO ALASKA INC. DRILLSITE 3K, WELL NO. 3K-35 KUPARUK RIVER UNIT, ALASKA Job Number: A0797GCE415 MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. 6700 6750 6800 6850 6900 .0 45.95 166.81 5055.1 .0 45.62 166.77 5089.9 .0 45.82 167.04 5124.8 .0 45.88 166.96 5159.7 .0 45.70 166.81 5194.5 4052.7 4088.5 4124.3 4160.2 4196.0 .30 4054.0 164.0 .64 4089.8 164.0 .55 4125.5 164.0 .16 4161.4 164.1 .42 4197.2 164.1 6950 7O00 7050 7100 7150 .0 .0 .0 .0 .0 44.26 166.62 5229.9 43.90 166.76 5265.8 44.02 166.87 5301.8 44.31 166.77 5337.7 44.04 166.85 5373.5 4231.3 4266.1 4300.8 4335.6 4370.5 .90 4232.5 164.1 .75 4267.2 164.1 .29 4301.9 164.2 .59 4336.7 164.2 .56 4371.5 164.2 7200 7250 7300 7350 7400 .0 .0 .0 .0 .0 44.07 166.99 5409.5 44.02 167.20 5445.4 44.18 167.34 5481.3 44.08 167.32 5517.2 43.71 167.47 5553.2 4405.2 4440.0 4474.8 4509.6 4544.2 · 21 4406.2 164.2 .32 4440.9 164.2 .37 4475.7 164.3 .22 4510.5 164.3 .77 4545.1 164.3 7450 7500 7550 7600 7650 .0 .0 .0 .0 .0 43.77 167.66 5589.3 43.32 167.63 5625.6 43.24 167.86 5662.0 42.95 167.73 5698.5 42.55 167.63 5735.2 4578.7 4613.2 4647.4 4681.5 4715.5 · 30 4579.6 164.3 .90 4614.0 164.4 .35 4648.2 164.4 · 61 4682.3 164.4 .81 4716.2 164.4 7700.0 42.41 167.60 5772.1 7750.0 42.06 167.49 5809.1 7800.0 42.01 167.53 5846.2 7850.0 41.98 167.52 5883.4 7900.0 41.85 167.76 5920.6 4749.2 4782.8 4816.2 4849.7 4883.1 .28 4749.9 164.5 .71 4783.5 164.5 .12 4816.9 164.5 .05 4850.3 164.5 .42 4883.7 164.5 Survey Page HORIZONTAL COORDINATES feet 3896.87 S 3931.76 S 3966.63 S 4001.59 S 4036.50 S 4070.89 S 4104.74 S 4138.53 S 4172.45 S 4206.37 S 4240.24 S 4274.12 S 4308.07 S 4342.03 S 4375.86 S 4409.62 S 4443.26 S 4476.76 S 4510.15 S 4543.31 S 4576.29 S 4609.11 S 4641.80 S 4674.46 S 4707.09 S 1117.69 E 1125.88 E 1133.99 E 1142.06 E 1150.19 E 1158.31 E 1166.32 E 1174.24 E 1182.18 E 1190.14 E 1198.01 E 1205.77 E 1213.44 E 1221.07 E 1228.64 E 1236.08 E 1243.45 E 1250.73 E 1257.95 E 1265.19 E 1272.43 E 1279.68 E 1286.92 E 1294.15 E 1301.30 E A Gyrodata ARCO ALASKA INC. DRILLSITE 3K, WELL NO. 3K-35 KUPARUK RIVER UNIT, ALASKA Job Number: A0797GCE415 Direct i o n a 1 Survey MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 7950.0 41.95 167.78 5957.8 8000.0 41.45 167.64 5995.2 8050.0 41.29 167.86 6032.7 8100.0 41.16 168.07 6070.3 8150.0 40.93 168.30 6108.0 4916.4 .20 4917.0 164.6 4949.7 1.01 4950.2 164.6 4982.7 .43 4983.2 164.6 5015.6 .38 5016.1 164.6 5048.4 .55 5048.9 164.7 4739.72 S 1308.37 E 4772.22 S 1315.45 E 4804.51 S 1322.46 E 4836.74 S 1329.33 E 4868.87 S 1336.06 E 8200.0 41.14 168.32 6145.7 8250.0 41.19 168.20 6183.4 8300.0 41.24 168.64 6221.0 8350.0 40.99 168.83 6258.6 8400.0 39.95 168.70 6296.7 5081.2 .43 5081.6 164.7 5114.0 .19 5114.5 164.7 5146.9 .58 5147.3 164.7 5179.8 .56 5180.1 164.8 5212.2 2.07 5212.5 164.8 4901.02 S 1342.71 E 4933.24 S 1349.41 E 4965.52 S 1356.02 E 4997.76 S 1362.44 E 5029.59 S 1368.77 E 8450.0 39.72 168.61 6335.1 8500.0 39.54 168.72 6373.6 8550.0 38.14 168.93 6412.5 8600.0 37.13 168.63 6452.1 8650.0 35.91 168.55 6492.3 5244.1 .49 5244.5 164.8 5276.0 .39 5276.3 164.8 5307.3 2.80 5307.6 164.8 5337.8 2.06 5338.0 164.9 5367.5 2.44 5367.7 164.9 5060.99 S 1375.07 E 5092.26 S 1381.34 E 5123.02 S 1387.42 E 5152.97 S 1393.35 E 5182.14 S 1399.24 E 8700.0 34.30 168.86 6533.2 8750.0 32.39 169.05 6575.0 8800.0 30.64 169.02 6617.6 8850.0 29.11 169.24 6660.9 8900.0 27.48 169.54 6705.0 5396.2 3.23 5396.4 164.9 5423 . 6 3 . 83 5423 . 8 164 . 9 5449 . 7 3 . 49 5449 . 9 165 . 0 5474 . 5 3 . 07 5474 . 7 165 . 0 5498 . 2 3 . 28 5498 . 4 165 . 0 5210.33 S 1404.87 E 5237.30 S 1410.14 E 5262.96 S 1415.11 E 5287.42 S 1419.81 E 5310.72 S 1424.17 E 8950.0 26.12 169.77 6749.6 9000.0 24.67 169.90 6794.8 5520.7 2.73 5520.8 165.0 5542.1 2.90 5542.2 165.0 5332.90 S 5354.00 S 1428.22 E 1432.00 E Page Final Station Closure: Distance: 5542.20 ft Az: 165.03 deg. CI I:! I I--I-- I I~ G S IE I::! L/I C I:: S WELL LOG TRANSNHTTAL ._ To: State of'Alaska July 30,~ 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 3K-35, AK-MW-70179 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 3K-35: 2" x 5" MD Gamma Ray Logs: 50-029-22775-00 2" x 5" TVD Gamma Ray Logs: 50-029-22775-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia JUL 50 --_ 0il & ~s ~' r ~ .,~ i~~ 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company _ 7/22/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11175 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) Well Job # Log Description Date BL RF Sepia LIS Tape 3K-35 "7"7q~ I 97307 IDITE-GR 970713 1 *NOTE: THIS IS A REDO TAPE - MISSING CURVE WAS ADDED. PRINTS ARE CORREC'I', ... -"'7,4.?F--- -7'7 ~/ Y ~' ~ /-)lA ~ ,, Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECE V -m JUL. 2 5 ~997' Gas Cons_ Cor,~i~'fissicn Anchom§e sperry-sun CI I::! i I--I-- I I~1 G S I~ I~!~ I I-- I~ S July 17, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Dear Sir/Madam, Re: MWD Survey 3K-35 Enclosed is one hard copy of the above mentioned file(s). Well 3K-35 Tie in point 0.00', interpolated depth at 8,362.00' Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ARCO Alaska, Inc. .(UPARUK RIVER UNIT .4. WELL SERVICE REPORT '~ K1(3K-35(W4-6)) WELL JOB SCOPE JOB NUMBER 3K-35 FRAC, FRAC SUPPORT 0723970727.1 DATE DAILY WORK UNIT NUMBER 07/24/97; PUMP INITIAL "A" SANDS FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 (~) Yes- © NoI ® Yes C) No DS-GALLEGOS JOHNS ESTIMATE 998678 230DS36KG $88,1 31 $91,271~.. ,/~,~.C~'~-'~ ' Initial Tbq Press Final Tbcl Press Initial Inner Ann Final Inner Ann, Initial Outer Ar'~'//]~inal Out. nh_ _ 1 038 PSI 3200 PSI 700 PSI 1000 PSII 250 PSII 450 PSI DAILY SUMMARY IPUMPED "A" SANDS FRAC, WITH 171,619# PROPPANT TO, 12.2 PPA, 10/14 AT PERFS, LEFT 13,455# 10/14 PROPPANT IN PIPE. SCREENED OUT SHORTLY AFTER 10/14 HIT PERFS. TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP., APC DOWNHOLE PUMP AND VAC. TRUCK. 08:25 HELD ON SITE SAFETY MEETING. 08:45 SET TREESAVER. 09:30 09:34 09:41 10:36 12:26 12:35 13:24 PRESSURE TEST SURFACE PIPE TO 9091 PSI PUMP BREAKDOWN STAGE W/100 BBLS , 50#GEL , AT 23 8PM AND 7100 PSI. PUMP 2 PPA, SCOUR STAGE OF 20/40 PROPPANT 15 BPM AND 6980 PSI. PUMP FLUSH , 15 BPM AND 6140 PSI. SHUT DOWN FOR ISIP 2572 PSI AND PULSE TEST. PUMP DATA FRAC, 5 TO 15 BPM AND 5062 PSI. PUMP 2# STAGE W/20/40 PROPPANT , 15 BPM AND 4366 PSI. PUMP 2#TO 12# PPA 12/18 PROPPANT, 15 BPM AND 4966 PSI. PUMP 144¢ PPA, 10/14, WELL SCREENED OUT WITH 12.2# PPA 10/14 AT PERFS. LEFT 13,455# PROPPANT IN PIPE. SHUT DOWN. SERVICE COMPANY - SERVICE DAILY' COST ACCUM TOTAL $o.oo $o.oo APC $8,000.00 $8,000.00 DOWELL $80,131.00 $80,131.00 HALLIBURTON $0.00 $2,115.00 LI-1-FLE RED $0.00 $1,025.00 TOTAL FIELD ESTIMATE $88,131.00 $91,271.00 OF:IICI--lNG S ~: I:!~ I r' I:: S WELL LOG TRANSNHTTAL To: State of Alaska July 23, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 3K-35, AK-MW-70179 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22775-00 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 ° (907) 563-3256 · Fax (907) 563-7252 __ A Dresser Industries, Inc. Company ARCO Alaska, Inc. K:UPARUK RIVER UNIT '~, WELL SERVICE REPORT '~' - K1(3K-35(W4-6)) WELL JOB SCOPE JOB NUMBER 3K-35 PERFORATE, PERF SUPPORT 071 8972248.9 DATE DAILY WORK UNIT NUMBER 07/21/97i GYRO DATA SURVEY; PERFORATE 8293 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 (~ Yes' O NoI (~ Yes O No SWS-JOHNSON CHANEY FIELD AFC# CC# DAILY COST ACCUM COST signed ESTIMATE AK8789 230DS36KG $1 3,713 $26,921 Y.'~'f.; Initial Tb_q Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I 'Final Outer Ann 0 PSI 900 PSI 0 PSI 0 PSII 200 PSII 200 PSI DAILY SUMMARY I RAN GYRO & PERF'D "A" SAND INTERVAL 8580' TO 8600' W/ 2-1/2" HSD PERF GUN, 4 SPF, BIG HOLE CHARGES, ORIENTED 160 DEG CCW. TIME LOG ENTRY 13:30 WAIT FOR SURFACE PANEL INSTALATION 15:00 MIRU SWS UNIT 8293; ENG: JOHNSON 19:30 RIG DOWN GYRO DATA TOOL 15:40 ..... RIH WITH GYRO DATA D :-'-ZC'i-iONAL SURVEY TOOL PRESSURE TEST RISE;~/dj, P T'O 3000# 20:30 21:00 RIH WITH PGGT/20' 2-1/2" HSD PERF GUN 4 SPF, BIG HOLE CHARGES, ORIENTED 160 DEG CCW 22:10 TAG TD AT 9011' RUN GR/CCL PASS 8985' TO 8000' 22:50 LOG INTO SHOOTING POSlSTION PUMP TBG PRESS TO 1300# WITH TRIPLEX 23:05 SHOOT 8580' TO 8600'. TBG PRESSURE DROPPED DOWN TO 1000 PSI 23:10 POOH. ALL SHOTS FIRED. 00:30 RIG DOWN. WELL SECURED AND NOTIFIED DSO OF STATUS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $200.00 $6,200.00 DIESEL $0.00 $344.00 DOWELL $0.00 $6,018.00 GYRO DATA $6,000.00 $6,000.00 HALLIBURTON $0.00 $846.00 SCHLUMBERGER $7,513.00 $7,513.00 TOTAL FIELD ESTIMATE $1 3,71 3.00 $26,921.00 7/17/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11158 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) Well Job # Log Description Date BL RF Sepia LIS Tape 2F'-19PB1 ~-1(.¢ '" ~Ot "7"7~";~ 97146 .... DITE & CNTG 970330 1 2F-19PB1 97146 DITE 970330 1 1 2F-19PB1 97146 CNTG 970330 I I ~ 2F-19PB1 97146 BOREHOLE PROFILE LOG 970330 1 1 12F-19PB1 "''- 97146 SSTVD 970330 1 1 3K-35 ~:;~'?- I~ ~'~ -~?~Z_/ 97307 DITE-GR (PDC) 970713 1 3K-35 ,],,' 97307 DITE-GR 97071 3 1 1 ,. Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. JUL I TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 6, 1996 Michael Zanghi Drill Site Development Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re; Kuparuk River Uni 3K-35 ARCO Alaska. Inc. Permit No. 97-109 Surf Loc 1022'FSL. 316'FWL, Sec. 35, T13N, R9E. UM Btmhole Loc 789'FSL, 1245'FWL. Sec. 1, T12N. R9E. UM Dear Mr. Zanghi Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by laxv from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. This approval includes mmular disposal of drilling wastes and is contingent on obtaining a well cemented surface casing confirmed bv a valid Formation Integrity Test (FIT) - cementing records, FIT data, and anv CQLs are to be submitted to the Commission prior to the start of disposal operations. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission ma3' witness thc test. 9-1433. David W. Johnston ~ ~ Chairman ~ ~5 - BY ORDER OF THE MISSION dlf/encl Dept ofFish & Game. Ilabitat Section - w/o encl Dcpt of Environmental Conservation - w/o cncl STATE OF ALASKA ALAS, ~ OIL AND GAS CONSERVATION COMMISSk.. PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] I lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry [] Deepen []J Service ~ Development Gas [] Single Zone X Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. Ri~l RKB 41', Pad 34' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25629, ALK 2562 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1022' FSL, 316' FWL, Sec. 35, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1010' FSL, 1189' FWL, Sec. 1, T12N, R9E, UM 3K-35 #U-630610 At total depth 9. Approximate spud date Amount 789' FSL, 1245' FWL, Sec. 1, T12N, R9E, UM 6/9/97 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TV•) property line 3K-15 9067' MD 789 @ TD feet 5.5'@ 350' feet 2560 6743' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 46.2o Maxirnumsudace 241 8 psig At total depth (TV•) 3500 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sta~le dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 9.875" 7.625" 29.7# L-80 LTC 5238' 41' 41' 5279' 4084' 1510 Sx Arcticset III & - HF-ERW 340 Sx Class G 6.75" 5.5" 15.5# L-80 LTCMOD 8529' 41' 41' 8570' 6365' 130 Sx ClassG HF-ERW 6.75" 4.5" 12.8# L-80 EUE8rdM 497' ~'§-5-7-~0~ 6365' ,--~)'067'~-'),-- 6743' Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry. and Deepen Operations. Present well condition summary Total depth: true measured J~'' vertical ii k feet feet Plugs(measured) Effective depth: measured ? ~ feet Junk (measured) true vertical i i feet Casing Structural Length,i ~. iSize Cemented ?/~Mj~asure~dipth Conductor i ~ Surface Intermediate ~.~?? ~ .'~"' Production ,J~!r:J 5 1997 Liner ' ' Perforation depth: measured 4~c~8~,j~ 0il & true vertical 20. Attachments Filing fee X Property plat [-J BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis J--J Seabed report [] 20 AAC 25.050 requirements X 21. I hereby certify ~hat the foregoing is true and correct to the best of my knowledge [/I /~' . J Site Develop. Supv. _ ~? '/ F ["¢' '~%¢~ ~~ For questions, please call Denise Petrash · Commission Use Only Permit Number I/'API n~mber I Approval d~r,~' ~ I See cover letter for ~,,~,../,/<::~, ,c~ J'5~:~.."'c~-' '~-~--" ~ '~ v4" -' (¢~ ~ ~ other requirements Conditions of approval Samples required J-'J Yes ~J No Mud log required Yes 'j~ No Hydrogen sulfide measures J~] Yes J--1 No Directional survey required J~j Yes r-J No Required working pressure for BOPE J--J 2M J~J 3M J'-J 5M r"J 1OM E] 15M Other: by order of /c~ D~,vid W. Johnston Approved by Commissioner the commission Bate(,,_O ~::)~!' j Form 10-401 Rev. 7-24-89 Submit in triplicatt , 2, 3~ , , . . , , 10. 11. 12. 13. 14. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 3K-35 Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (5,279')according to directional plan. Run and cement 7-5/8" casing, using stage collar placed at least 200' below the base of the permafrost, and light weight lead cement. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test, maximum pressure allowed 16.0 ppg EMW. Drill 6-3/4" hole to total depth (9,067') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 5-1/2" x 4-1/2" tapered casing string with polished seal bore as part of XO. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test 5-1/2" x 4-1/2" casing to 3500 psi. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. ND BOPE. NU tubinghead & master valve and upper tree assembly. Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Shut in and secure well. Clean location and release rig in preparation for perforating. DRILLING FLUID PROGRAM Well KRU 3K-35 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators General Notes: Weight up to TD 11.0 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% 0',:'l -, ~ Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2418 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3K-35 is 3K-15. As designed, the minimum distance between the two wells would be 5.5' @ 350'. Drilling Area Risks: Risks in the 3K-35 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #2 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ANNULAR PUMPING OPERATIONS WELL KRU 3K-35 Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3K-35 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 3K-35 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The 3K surface casing shoes will be set _+200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 4048 psi The pressure is very conservative as frictional losses while pumping are not accounted for. The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst 7.625 29.7 L-80 3 LTC 4790 4072 6890 5857 5.500 15.5 L-80 3 LTC-M 4990 4242 7000 5950 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (g) (1) & (2). ARCO ALASKA, Inc. Pad 3K 35 Slot #35 Kuparuk River Unit North Slope, Ataska 3-D M I N ! M U M D I STANCE CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 35 Version #2 Our ref : prop1785 License : Date printed : 22-May-97 Date created : 22-Aug-96 Last revised : 20-May-97 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 25 48.667, w149 45 49.2 Slot location is nTO 25 58.718,w149 45 39.928 Slot Grid coordinates are N 6008015.725, E 529307.873 Slot local coordinates are 1022.00 N 316.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath Closest approach with 3-D Minimum Distance method Last revised Diverging from M.D. 200.0 H Version #2,,H,Pad 3K PGMS <0-9038'>,,16,Pad 3K PGMS <0-9584'>,,17,Pad 3K 30 Version #2,,30,Pad 3K PGMS <0-9843'>,,18,Pad 3K PGMS <0-9275'>,,15,Pad 3K PGMS <0-8960'>,,14,Pad 3K PGMS <0-8580'>,,13,Pad 3K PGMS <0-7770'>,,12,Pad 3K PGMS <0-7853'>,,11,Pad 3K PGMS <0-7300'>,,lO,Pad 3K PMSS <5275 - 7443'>,,9,Pad 3K PGMS <0-7580'>,,9A,Pad 3K PGMS <0-8500 PGMS <0-8500 PGMS <0-8100 PGMS <0-8140 PGMS <0-8980 PGMS <0-8900 PGMS <0-9960 PGMS <0-9150 >,,8,Pad 3K >,,7,Pad 3K >,,6,Pad 3K >,,5,Pad 3K >,,4,Pad 3K >,,3,Pad 3K >,,2,Pad 3K >,,1,Pa~ ~J~ PMSS (SS) <648-11180'>,,22,Pad 3K PMSS < 827 - 10944' >,,32,Pad 3K 23 Version #4,,23,Pad 3K 26 Version #2,,26,Pad 3K Distance M.D. 8-0ct-96 275.0 200.0 10-0ct-96 13.6 100.0 10-0ct-96 37.4 100.0 18-Mar-97 125.0 300.0 10-0ct-96 63.3 0.0 10-0ct-96 5.5 350.0 10-0ct-96 37.8 200.0 10-0ct-96 59.6 350.0 10-0ct-96 87.1 100.0 10-0ct-96 112.7 200.0 10-0ct-96 136.4 350.0 10-0ct-96 212.1 0.0 10-0ct-96 212.1 0.0 10-0ct-96 237.0 100.0 10-0ct-96 262.1 0.0 10-0ct-96 287.1 0.0 10-0ct-96 311.4 350.0 10-0ct-96 337.1 0.0 10-0ct-96 362.1 0.0 10-0ct-96 387.1 0.0 tO-Oct-~6 ~12.0 0.0 1S-May-97 348.1 375.0 19-May-97 74.7 325.0 9-May-97 325.0 300.0 7-Apr-97 250.0 300.0 9OOO 100 3OO 0 35O 20O 350 100 2OO 35O 0 0 100 0 325 35O 0.0 0.0 0.0 0.0 375.0 325.0 300.0 300.0 PMSS <834 - ????>,,26,Pa¢ PMSS <466 - 10456'>,,27,Pacl 5K 21-May-97 22-May-97 250.0 224.4 100.0 375.0 100.0 375.0 by finch For: D PETRASH1 Data plotted : 22-May-97 J Floe Reference is 35 V~rsion #2. J 400 C 0 ALAS KA Structure : Pad 5K Well: Field : Kuparuk River Unit Location : North Slope, A aska SURFACE LOCATION: 1022' FSL, 316' FWL SEC. 35, T15N, R9E East (feet) -> 500 0 500 1000 1500 I ~,0 Az ,~egm Turn To Torget 50O Base Permafrost EOC 500 0 RKB ELEVATION: 75' ' T k i oo0 ~ [ KOP TVD=300 TMD=3O0 DEP=O 400 ~ ~ 5.00 ! I BEGIN TURN TO TARGET WD=500 TMD=500 DEP=6 _~ 1~ 7.90 Top Ugnu Sands 1500 aooJ ~10.35 ~3.oo 165.44 AZIMUTH \. J '~.~,~ 5474' (TO TARGET) ~ 200° [ ~ 21.53 BLS: 3.00 de9 per 100 ft ***Plane of Pro osal*** / k 24.44 P Top West Sok Sands ~ L 2001 \ 2L % \ 1600~ ~ d~.z B/ PERMAFROST ~D=1640 TMD=1755 DEP=470 . ~,~ ~ ~ ~5.15 7 5/8 Casingz~ / ] ~ EOC WD=1771 TMD=1936 DEP=595 ~ ~5000 J ~ I 1010' FSL, 1189' FWL I ~, k ~5oo / UGNU SNDS ~D=2694 T~D=3270 DEP=1558 4000 2800 , SOUIH 5292 ~ MAXIMUM ANGLE ~ ~s¢ ,~o~ k ' ~ K- 1 Marker ~ J T/ '~D~7 ~=4300 DEP=2302~ ..... ~ b5000 Top nit C 3600 T~rget A5 Interval ~OD) / ~ Base Kuporuk~ 4000 [ 7 5/a~~MD:5279 DEP:3008 ~ ~ ~ L 6000 [ ~ I ~D LOCAl,ON: J / ouuu ~ 44.23 6400 ~ 40.23 ~oo] 40 DEG - / [ i I I i I i I i i i I i i i i I I L I I I II ~ I I I I r I I 0 400 800 1200 1600 2000 2400 2800 5200 3~00 4000 ~400 4800 5200 5600 6000 Verfical Secfion (feet) -~ Azimuth 165.44 with reference 0.00 N, 0.00 E from Slot #35 Cr~otcd by finch For: D PETRASH Co. rd;hales ore in ~eet reference Slot ~35. Tr~e Vcriical Dep~hs~~B (Parker ~245). 2O 4O 6O 80 100 120 140 160 ARCO ALASKA, l c. Structure : Pad bK Well : ,35 Field : Kuparuk River Unit Location : North Slope, Alosko 180 2OO 220 240 260 280 300 j 60 40 20 0 I I t I I I J 1 I i I I I I I t J I I I I I I I ~oo _~% ¢0 ~5oo ~-x 500/ ~' ~ '"'"% ~ 800 8oo % ~o k % 90{ 700 %,~ ~ 3400 ~900 70~ 900 'xx ~ ~ 800 x 1000 "~ 350'~ 0 ~ 3ooN, 1 O0 500 600~ 70{ 2OO 1 East' (feet) -> 20 40 60 80 100 120 140 160 180 200 220 60 40 20 0 2 0 11 O0 ',, ,, ',, , ',, oo ,,, ,,,'.. 3600 1200 ~, , · , , , 90C ", 1300 ,,, 3700 1 ¢00 11 O0 O0 1200 &tiC) I 6Jo I 810 I I I J I I I 1 O0 120 1 40 160 Eost (feet) -> 80( 60 40 20 0 20 40 60 160 180 200 220 240 260 28O , , , , 300 180 200 220 8O 100 12o 140 v J 7 , 6 5 4 I3 13 5/8" 5000 PS, BOP STACK ACCUMULATOR CAPACITY TEST, 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILLAND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2" TO 5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8"- 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR r,,UPARUK RIVER UNI, 20" DIVERTER SCHEMATIC I 5 4 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENAN(~E & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY, CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16"CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD, 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20"- 2000 PSI DRILLING SPOOLWITH ONE 16"OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 PROGRAM: expo dev~ redrlO servO wellbore segO ann disp para reqD ADMINISTRATION 1. 2 3 4 5 6 7 8 9 10 ll 12 13 Permit fee attached ................... YIY Lease number appropriate ................ ti Y Unique well name and number ............... Well located in a defined pool ............. Well located proper distance from drlg unit boundary. . Well located proper distance from other wells ...... Sufficient acreage available in drilling unit ...... .i YI If deviated, is wellbore plat included ........ Operator only affected party .............. Operator has appropriate bond in force ......... I.Y Permit can be issued without conservation order .... Permit can be issued without administrative approval. . __ Can permit be approved before 15-day wait ....... '\Y, ENGINEERING REMARKS GEOLOGY 14. Conductor string provided ............... Q~ N 15. Surface casing protects all known USDWs ........ .~ N 16. CMT vol adequate to circulate on conductor & surf cng. N 17. CMT vol adequate to tie-in long string to surf cng . . . Y 18. CMT will cover all known productive horizons ....... 19. Casing designs adequate C, T, & permafrost. . .'~-.~ 20. Adequate tankage or reserve pit ............ 21. If a re-drill, has a 10-403 for abndnmnt been approved.-~----N-~'/~ 22. Adequate wellbore separation proposed .......... ~N 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate i~y~ N 25. BOPEs adequate .................... N 26. BOPE press rating adequate; test to ~6~'t~ psig.~ N 27. Choke manifold complies w/aPI RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... N 29. Is presence of H2S gas probable ............ N 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... Y//'N ~ ~ //~ 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ....... ./ Y N 34. Contact name/phone for weekly progress reports . . ./. . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW/dlf- A'\FORMS\cheklist rev 01/97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER . ****************************** . ............................ * ....... SCHLUMBERGER ....... . ............................ ****************************** RECEIVED. ,JUL 2 5 i991 Alaska Oil & Gas Cons. Com~,Si0~ Anchorage COMPANY NAME : ARCO ALASKA, INC. WELL NAME : KRU 3K-35 FIELD NAME : KUPARUK RIVER UNIT BOROUGH 'NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22775-00 REFERENCE NO : 97307 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER COMPANY NAME : ARCO ALASKA, INC. WELL NAME : KRU 3K-35 FIELD NAME : KUPARUK RIVER UNIT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22775-00 REFERENCE NO : 97307 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JUL-1997 09:04 PAGE: **** REEL H~ER **** SERVICE NAME : EDIT DATE : 97/07/21 ORIGIN : FLIC REEL NAME : 97307 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, 3K-35, KUPARUK, API #50-029-22775-00 **** TAPE H~ER **** SERVICE NAME : EDIT DATE : 97/07/21 ORIGIN : FLIC TAPE NAME : 97307 CONTINUATION # : 1 PREVIOUS TAPE : CO~r~F~IT : ARCO ALASKA INC, 3K-35, KUPARUK, API #50-029-22775-00 TAPE HEADER Kuparuk River Unit OPEN HOLE WIRELINELOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION RUN1 97307 E. Bartz D. Wester SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING KRU 3K-35 500292277500 ARCO Alaska, Inc. SCHLUMBERGER WELL SERVICES 16-JUL-97 RUN 2 RUN 3 35 13 9E 1022 316 66.65 65.15 34.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.750 5.500 8353.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JUL-1997 09:04 3RD STRING PRODUCTION STRING REMARKS: No depth adjustments were made to this data because this DITE/GR data Is the depth control GR for all subsequent logging. Primary depth control, including the use of magnetic marks, was used by the field logging crew. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~BER: 1 EDITED OPEN HOLEMAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INGREDIENT: 0.5000 FILE SUMI4ARY LDWG TOOL CODE .............. DTE $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 9120.0 8346.0 BASELINE DEPTH .............. $ MERGED DATA SOURCE LDWG TOOL CODE .............. $ REMARKS: THIS FILE IS THE MAIN PASS OH DATA. NO DEPTH SHIFTS WERE APPLIED AS THIS IS THE PDC LOG FOR THIS WELL. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... DTE RUN NO. PASS NO. MERGE TOP MERGE BASE ................... LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JUL-1997 09:04 PAGE: 3 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022680 O0 000 O0 0 1 1 1 4 68 0000000000 IDPH DTE OH~M 1022680 O0 000 O0 0 1 1 1 4 68 0000000000 IMPH DTE OH~M 1022680 O0 000 O0 0 1 1 1 4 68 0000000000 ILD DTE OH~4M 1022680 O0 000 O0 0 1 1 1 4 68 0000000000 ILM DTE OH~f 1022680 O0 000 O0 0 1 1 1 4 68 0000000000 SFL DTE 1022680 O0 000 O0 0 1 1 1 4 68 0000000000 GR DTE GAPI 1022680 O0 000 O0 0 1 1 1 4 68 0000000000 TENS DTE LB 1022680 O0 000 O0 0 1 1 1 4 68 0000000000 SP DTE MV 1022680 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9120.000 IDPH.DTE -999.250 IMPH.DTE -999.250 ILD.DTE -999.250 ILM. DTE -999.250 SFL.DTE -999.250 GR.DTE -999.250 TENS.DTE 2741.000 SP.DTE -999.250 DEPT. 9000. 000 IDPH.DTE 2.140 IMPH.DTE ILM. DTE 2.149 SFL . DTE 2. 430 GR. DTE SP. DTE -2.938 2.160 ILD.DTE 2.115 111.909 TENS.DTE 3380.000 DEPT. 8500. 000 IDPH. DTE 2. 489 IMPH.DTE ILM. DTE 2. 423 SFL. DTE 2. 533 GR. DTE SP. DTE -32.125 2. 423 ILD. DTE 2. 451 132. 790 TENS.DTE 3203. 000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JUL-1997 09:04 PAGE: DEPT. 8346. 000 IDPH.DTE ILM.DTE O. 648 SFL.DTE SP. DTE -24. 625 0.320 IMPH. DTE 1.407 GR.DTE 1.797 130.194 ILD. DTE TENS. DTE 0.367 3006. 000 ** END OF DATA ** * * ** FILE TRAILER * * * * FILE NAME : EDIT .00I SERVICE : FLIC VERSION ' O01CO1 DATE : 97/07/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE i~J~IBER : 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH ......................... DTE 8346.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 7888.0 BASELINE DEPTH .......... EQUIVALENT UNSHIFTEDDEPTH .......... DTE ....... THIS FILE IS THE MAIN PASS CH DATA. NO DEPTH SHIFTS WERE APPLIED AS THIS IS THE PDC LOG FOR THIS WELL. LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JUL-1997 09:04 PAGE: LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 12 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 85 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022680 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH DTE GAPI 1022680 O0 000 O0 0 2 i 1 4 68 0000000000 TENS DTE LB 1022680 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 8346. 000 GRCH.DTE 130. 194 TENS.DTE 3006. 000 DEPT. 8000. 000 GRCH. DTE 159. 449 TENS.DTE 2974 . 000 DEPT. 7888.000 GRCH. DTE 106.159 TENS.DTE 2864.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JUL-1997 09:04 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 3 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE Str~4F~%RY VENDOR TOOL CODE START DEPTH STOP DEPTH 9120.0 8346.0 DITE $ LOG HEADER DATA DATE LOGGED: 13-JUL-97 SOFTWARE VERSION: 8C0 - 609 TIME CIRCULATION ENDED: 1600 12-JUL-97 TIME LOGGER ON BOTTOM: 100 13-JUL-97 TD DRILLER (FT) : 9118.0 TD LOGGER (FT) : 9116.0 TOP LOG INTERVAL (FT) : 7900.0 BOTTOM LOG INTERVAL (FT) : 9116.0 LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DITE INDUCTION SONDE DITE INDUCTION CART. TOOL NUMBER DIS-HB 261 DIC-EB 262 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JUL-1997 09:04 PAGE: GR GAM~A RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) '. LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : SGC - SA 4.750 8353.0 8345.0 Fresh Mud 12.00 56.0 159.0 2.480 2. 010 1.380 62.0 62.0 62.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: Log run on marked line. Stretch correction of 4' added @ TD. No standoffs run on Induction due to hole size = 4.75". Induction frequency used = 20 KHz. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JUL-1997 09:04 PAGE: 8 TYPE REPR CODE VALUE .............................. 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022680 O0 000 O0 0 3 1 1 4 68 0000000000 IDPH MOH 0Pi~1022680 O0 000 O0 0 3 1 1 4 68 0000000000 IMPH MOH O H~M1022680 O0 000 O0 0 3 1 1 4 68 0000000000 ILD MOH 0H14~41022680 O0 000 O0 0 3 1 1 4 68 0000000000 ILM MOH OPiUM lO22680 O0 000 O0 0 3 1 1 4 68 0000000000 SFL MOH 1022680 O0 000 O0 0 3 1 1 4 68 0000000000 GR MOH GAPI 1022680 O0 000 O0 0 3 1 1 4 68 0000000000 TENS MOH LB 1022680 O0 000 O0 0 3 1 1 4 68 0000000000 SP MOH MV 1022680 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9120.000 IDPH.MOH -999.250 IMPH.MOH -999.250 ILD.MOH -999.250 ILM. MOH -999.250 SFL.MOH -999.250 GR.MOH -999.250 TENS.MOH 2741.000 SP.MOH -999.250 DEPT. 9000.000 IDPH.MOH 2.140 IMPH.MOH ILM.MOH 2.149 SFL.MOH 2.430 GR.MOH SP.MOH -2.938 2.160 ILD.MOH 2.115 111.909 TENS.MOH 3380.000 DEPT. 8500.000 IDPH. MOH 2.489 IMPH.MOH ILM. MOH 2.423 SFL.MOH 2.533 GR.MOH SP.MOH -32.125 2.423 ILD.MOH 2.451 132.790 TENS.MOH 3203.000 DEPT. 8346.000 IDPH.MOH 0.320 IMPH.MOH iLM. MOH 0.648 SFL.MOH 1.407 GR.MOH SP.MOH -24.625 1.797 ILD.MOH 0.367 130.194 TENS.MOH 3006.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JUL-1997 09:04 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS lV--UM~ER : 2 DEPTH INCREMENT: 0. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 8750.0 8346.0 DITE $ LOG HEADER DATA DATE LOGGED: 13 -JUL- 97 SOFTWARE VERSION: 8C0- 609 TIME CIRCULATION ENDED: 1600 12-JUL-97 TIME LOGGER ON BOTTOM: 100 13-JUL-97 TD DRILLER (FT) : 9118.0 TD LOGGER (FT) : 9116.0 TOP LOG INTERVAL (FT) : 7900.0 BOTTOM LOG INTERVAL (FT) : 9116.0 LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DITE INDUCTION SONDE DITE INDUCTION CART. GR GAMMA RAY TOOL NUMBER DIS-HB 261 DIC-EB 262 SGC- SA LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JUL-1997 09:04 PAGE: 10 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 4.750 8353.0 8345.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~ff4) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT) '. MUD CAKE AT (BHT) : Fresh Mud 12.00 56.0 159.0 2.480 2. 010 1.380 62.0 62.0 62.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: Log run on marked line. Stretch correction of 4' added @ TD. No standoffs run on Induction due to hole size = 4.75". Induction frequency used = 20 KHz. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JUL-1997 09:04 PAGE: 11 TYPE REPR CODE VALUE 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022680 O0 000 O0 0 4 1 1 4 68 0000000000 IDPH ROH OH~M1022680 O0 000 O0 0 4 1 1 4 68 0000000000 IMPH ROH OH~4M1022680 O0 000 O0 0 4 1 1 4 68 0000000000 ILD ROH OH~4M1022680 O0 000 O0 0 4 1 1 4 68 0000000000 ILM ROH OHMM1022680 O0 000 O0 0 4 1 1 4 68 0000000000 SFL ROH 1022680 O0 000 O0 0 4 1 1 4 68 0000000000 GR ROH GAPI 1022680 O0 000 O0 0 4 1 1 4 68 0000000000 TENS ROH LB 1022680 O0 000 O0 0 4 1 1 4 68 0000000000 SP ROH MV 1022680 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 8749.500 IDPH. ROH -999.250 IMPH. ROH -999.250 ILD.ROH -999.250 ILM. ROH -999.250 SFL.ROH -999.250 GR.ROH -999.250 TENS.ROH 1378.000 SP.ROH -999.250 DEPT. 8500.000 IDPH. ROH 2.466 IMPH.ROH ILM. ROH 2.454 SFL.ROH 2.565 GR.ROH SP.ROH -3.625 2.406 ILD,ROH 2.426 129.842 TENS.ROH 3079.000 DEPT. 8346.000 IDPH. ROH 0.314 IMPH.ROH ILM. ROH 0.657 SFL.ROH 1.464 GR.ROH SP.ROH 6.563 0.793 ILD.ROH 0.366 133.873 TENS.ROH 2991.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JUL-1997 09:04 PAGE: 12 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE · 97/07/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : DITE $ LOG HEADER DATA FILE HEADER FILE ~ER 5 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NTJM~ER : 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 8346.0 7888.0 DATE LOGGED: 13-JUL-97 SOFTWARE VERSION: 8C0 - 609 TIME CIRCULATION ENDED: 1600 12-JUL-97 TIME LOGGER ON BOTTOM: 100 13-JUL-97 TD DRILLER (FT) : 9118.0 TD LOGGER (FT) .. 9116.0 TOP LOG INTERVAL (?T): 7900.0 BOTTOM LOG INTERVAL (FT) '. 9116.0 LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DITE INDUCTION SONDE DIS-HB 261 DITE INDUCTION CART. DIC-EB 262 GR GAM~A RAY SGC-SA $ BOREHOLE AND CASING DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JUL-1997 09:04 PAGE: 13 OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OB?4M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : 4.750 8353.0 8345.0 Fresh Mud 12.00 56.0 159.0 2.480 2. 010 1.380 62.0 62.0 62.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: Log run on marked line. Stretch correction of 4' added @ TD. No standoffs run on Induction due to hole size = 4.75". Induction frequency used = 20 KHz. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 12 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 85 12 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JUL-1997 09:04 PAGE: 14 TYPE REPR CODE VALUE 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NOWB SAMP ELEM CODE (HEX) DEPT FT 1022680 O0 000 O0 0 5 1 1 4 68 0000000000 GR MCH GAPI 1022680 O0 000 O0 0 5 1 1 4 68 0000000000 TENS MCH LB 1022680 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 8346.000 GR.MCH 130.194 TENS.MCH 3006.000 DEPT. 8000.000 GR.MCH 159.449 TENS.MCH 2974.000 DEPT. 7888.000 GR.MCH 106.159 TENS.MCH 2864.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JUL-1997 09:04 PAGE: 15 FILE HEADER FILE 1VUM~ER 6 RAW CASED HOLE REPEAT PASSES Curves and log header data for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH DITE 8346.0 8290.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~ CIRCULATION ENDED .. TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 13 -JUL-97 8C0- 609 1600 12-JUL-97 100 13 -JUL-97 9118.0 9116.0 7900.0 9116.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ......................... DITE INDUCTION SONDE DIS-HB 261 DITE INDUCTION CART. DIC-EB 262 GR GAi~4A RAY SGC-SA $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 4.750 8353.0 8345.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT S~EASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : Fresh Mud 12.00 56.0 159.0 2.480 2. 010 1.380 62.0 62.0 62.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX .. LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JUL-1997 09:04 PAGE: 16 MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: Log run on marked line. Stretch correction of 4' added @ TD. No standoffs run on Induction due to hole size = 4.75". Induction frequency used = 20 KHz. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 12 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 85 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022680 O0 000 O0 0 6 1 1 4 68 0000000000 GR RCH GAPI 1022680 O0 000 O0 0 6 1 1 4 68 0000000000 TENS RCH LB 1022680 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JUL-1997 09:04 PAGE: 17 DEPT. 8346.000 GR.RCH DEPT. 8290.000 GR.RCH 133.873 TENS.RCH 94.972 TENS.RCH 2991.000 3010. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION · O01CO1 DATE : 97/07/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/07/21 ORIGIN : FLIC TAPE NAME : 97307 CONTINUATION # : 1 PREVIOUS TAPE : COf~ENT : ARCO ALASKA INC, 3K-35, KUPARUK, API #50-029-22775-00 **** REEL TRAILER **** SERVICE NA~CE : EDIT DATE : 97/07/21 ORIGIN : FLIC REEL NA~E : 97307 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, 3K-35, KUPARUK, API #50-029-22775-00 Sperry-Sun Drilling Services LIS Scan Utility Thu Jul 17 10:15:24 1997 Reel Header Service name ............. LISTPE Date ..................... 97/07/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 97/07/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 2 AKLMW-70179 PAUL SMITH DONNIE LUTRI OPEN HOLE 03K-35 500292277500 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 17-JUL-97 MWD RUN 3 AK-MW-70179 PAUL SMITH DONNIE LUTRI 35 13N 9E 1022 CASING 316 .00 75.80 34.30 DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9. 875 7. 625 5298.0 6. 750 8362.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 3. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUNS 2 AND 3 ARE DIRECTIONAL WITH SCINTILLATION DETECTOR/GAMMA RAY (NGP). 5. THIS WELL REACHED A TOTAL DEPTH OF 8362'MD, 6235'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 5242.5 8295.0 ROP 5294.5 8348.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 5242.5 5257.0 7897.0 7911.5 7911.0 7925.5 7937.0 7950.0 7978.5 7992.0 7987.0 8001.0 7991.5 8006.0 8007.0 8020.0 8010.5 8023.5 8013.5 8026.5 8015.5 8028.5 8017.0 8030.0 8025.0 8038.5 8044.5 8060.0 8067.0 8080.5 8069.0 8082.5 8076.0 8089.5 - EQUIVALENT UNSHIFTED DEPTH - 8092.5 8109.5 8169.5 8190.5 8200.0 8203.0 8243.5 8248.0 8258.5 8261.5 8263.5 8281.0 8348.0 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: 8101.5 8118.0 8183.0 8204.0 8213.0 8216.0 8251.0 8257.0 8272.5 8275.0 8276.5 8295.0 8362.0 BIT RUN NO MERGE TOP MERGE BASE 2 5308.0 6057.0 3 6057.0 8362.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 5242.5 8348 6795.25 6212 5242.5 ROP 5.2094 4387.5 227.308 6108 5294.5 GR 25.9155 576.471 107.232 6106 5242.5 Last Reading 8348 8348 8295 First Reading For Entire File .......... 5242.5 Last Reading For Entire File ........... 8348 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/17 Maximum Physical Record..65535 File T~e ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5257.0 6003.5 ROP 5309.0 6057.0 $ LOG HEADER DATA DATE LOGGED: 19-JUN-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 46.7 MAXIMUM ANGLE: 48.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): ISC 5.06 CIM 5.46/DEP 2.042/SPC 5.74 MEMORY 6057.0 5308.0 6057.0 TOOL NUMBER NGP 74 6.750 6.8 LSND 180.80 60.0 8.5 600 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 .000 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 32.8 First Name Min Max Mean Nsam Reading DEPT 5257 6057 5657 1601 5257 GR 25.9155 117.549 75.6846 1494 5257 ROP 8.375 599.021 304.987 1497 5309 Last Reading 6057 6003.5 6057 First Reading For Entire File .......... 5257 Last Reading For Entire File ........... 6057 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 6006.0 ROP 6059.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMU-MANGLE: MAXIMUM ANGLE: STOP DEPTH 8309.0 8362.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL 21-JUN-97 ISC 5.06 CIM 5.46/DEP 2.042/SPC 5.74 MEMORY 8362.0 6057.0 8362.0 41.2 47.5 TOOL NUMBER NGP 320 6.750 6.8 LSND 175.00 39.0 9.0 450 5.6 .000 .000 .000 .000 46.7 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 3 AAPI 4 1 68 ROP MWD 3 FT/H 4 1 68 Code Offset 0 4 8 .0 Channel 1 2 3 Name Min Max Mean DEPT 6006 8362 7184 GR 48.9863 576.471 117.416 ROP 5.2094 4387.5 202.027 Nsam 4713 4607 4607 First Reading 6006 6006 6059 Last Reading 8362 8309 8362 First Reading For Entire File .......... 6006 Last Reading For Entire File ........... 8362 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/07/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 97/07/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File
