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M M M co O O M a) T O ch W 6) O O ' a) v1 R O O O O N N ONNNNNNNN ' � • Q1 r r r r O O r 0 O O O O O O O _ O O O O O O O O O O O O O O O +.� L C I) 1n v) u) u) )n )n to )n )n )n sn u) )n 4t) a U _ v C O7 al `0 _ v a CIDU Q O LN a' C C +-+ a I- v ai Q ,- co 0) o r` 0) co o ,- ,- In r- ,- �, o Y a vd N Z ++ hD r41 Z N N N M r 0 000 0i- r a+ _ E a) p- 4" = a n _a 2 2 '2 J r C9x6 ± ± ± ±U m m E r6 a C = a Q O N -.) co N N N N M M r 40, -......00z N Y 00 rat U n 3 C RSrn ® d a Q R •L v m _ H a a Q TATE OF ALASKA • TARNDB 2L-325 , SKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations 1— Fracture Stimulate fi Pull Tubing Operations Shutdown Performed: Suspend Perforate F Other Stimulate 1— Alter Casing f- Change Approved Program Plug for Redrill r Perforate New Pool 1— Repair Well fi Re-enter Susp Well r 1- 1 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: – ConocoPhillips Alaska, Inc. Development F Exploratory r 198-209 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic f-' Service 50-103-20275-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380053 KRU 2L-325 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 9200 feet Plugs(measured) None true vertical 5695 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) N/A true vertical 0 feet (true vertical) N/A Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 108 108 SURFACE 2771 7 5/8 2799 2313 PRODUCTION 9151 51/2 9176 5682 c-r op DEC g 8 2016, Perforation depth: Measured depth: 8550-8590, 8690-8710 13 True Vertical Depth: 5340-5362, 5416-5427 .I 'i.i "? 7r11r, Tubing(size,grade,MD,and TVD) 3.5, L-80, 8360 MD,5233 TVD : (-) r' Packers&SSSV(type,MD,and TVD) N/A SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): NONE 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 190 113 282 1200 1350 Subsequent to operation 172 205 256 1200 1350 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory - Development F Service IT Stratigraphic IT Copies of Logs and Surveys Run 16.Well Status after work: Oil F Gas IT WDSPL f.�.�••••••.. Printed and Electronic Fracture Stimulation Data IT GSTOR WINJ WAG n GINJ IT SUSP IT SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Elan Manoppo ta'�.263-4323 Email Elan.R.Manoppo@conocophillips.com Printed Name Elan Mano•• Title Tarn Dev. Team Lead Signature I� •, Illfp/Z:51/C, Phone:263-4323 Date v 1, ' -//ifn Form 10-404 Revised 5/2015 A 7-//,4.6 RBDMS Lk/ J! 2 8 2016 Submit Original Only • 2L-325 DTTM JOBTYP SUMMARYOPS START 3/21/16 PERFORATIONS- CUT HEAVY PARAFFIN FROM SURFACE TO 1100' SLM. TBG OPEN ELINE 2.76"TO 4000' SLM. IN PROGRESS. 3/22/16 PERFORATIONS- PULLED 2.81 CS LOCK& POGLM @ 8232' RKB, DRIFT WITH 1.69"X ELINE 110" DUMMY PERF DRIFT, TAG @ 8953' SLM EST. 363' RATHOLE. READY FOR E-LINE. 3/23/16 PERFORATIONS- ATTEMPTED TO PERFORATE WITH DEEPSTAR PENTAPHASE STRIP ELINE GUN. STRIP GUN MISSFIRED. WILL ATTEMPT TO PERFORATE AGAIN TOMORROW. 3/25/16 PERFORATIONS- PERFORATE PURPLE FORMATION FROM 8690'TO 8710' WITH 1 ELINE 11/16" 8SPF PENTAPHASE DEEPSTAR CHARGES. CCL TO TOP SHOT 10' CCL STOP AT 8680'. READY FOR SLICKLINE 3/26/16 PERFORATIONS- SET CONCENTRIC GLM (.25" OV INSTALLED) IN CMU @ 8232' RKB, ELINE JOB COMPLETE. Ir'' KUP OD 2L-325 Con(acoPhiHips ...i.,•&' l l fo''' ,¢. Well Attri s Max Angle&MD TD • Alaska inc Wellbore APUUWI Field Name Wellbore Status ncl(') MD(ftKB) Act Btm(ftKB) • CorvxoPhlllfps 501032027500 TARN PARTICIPATING AREA PROD 62.59 7,152.99 9,200.0 -.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2L-325,6/2312016 6123120161110.41 AM SSSV:NIPPLE Last WO: 36.49 11/12/1998 Vertical scnpmaam{achw0 Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,955.0 12/23/2015 Rev Reason:TAG,PERFORATE,RESET C- pproven 3/28/2016 LOCK HANGER;17.7 a Casing.Sings. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 29.0 108.0 108.0 62.58 H-40 WELDED Casing Description 'OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(TVD)... Wt/Len II...Grade Top Thread SURFACE 7 5/8 6.875 28.2 2,799.3 2,313.1 29.70 L-80 BTC-MOD Casing Description 'OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 51/2 4.950 25.6 9,176.3 5,682.0 15.50 L-80 LTC-MOD 55x35"@8363' 1i Ill Tubing Strings Tubing Description string Ma... ID(in) Top(ftKB) Set Depth(ft..ISet Depth(TVD)(...Wt(IbHt) Grade Top Connection TUBING 31/2 2.992 17.7 8,359.6 5,233.1 9.30 L-80 EUE8RDMOD Completion Details �ti CONDUCTOR;280-108.0 _ ' 11 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Com (in) 17.7 17.7 0.00 HANGER FMC GEN V TUBING HANGER 3.500 NIPPLE 4sss 466.6 466.5 0.65 NIPPLE CAMCO DS NIPPLE 2.875 8,232.1 5,160.6 55.55 SLEEVE-0 BAKER CMU SLIDING SLEEVE w/CAMCO PROFILE 2.813 (OPEN 2/23/09) 8,334.6 5,218.9 55.38 NIPPLE CAMCO D NIPPLE 2.750 i 8,341.6 5,222.9 55.41 LOCATOR BAKER LOCATOR 2.985 i 111 8.342.3 5,223.3 55.41 SEAL ASSY SEAL ASSEMBLY-15'EFFECTIVE SEAL"STROKE 2.985 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (") Des Com Run Date ID(in) 8,232.0 5,160.5 55.55 POGLM 2.81"Concentric/1.25"OV 3/26/2016 0.250 MANDREL 8,273.0 5,183.8 55.25 PATCH 3.5"WEATHERFORD ER PACKER WITH MID- 2/23/2009 1.750 ELEMENT AT 8294',MIDDLE OF THE FIFTEEN FOOT JOINT BELOW GLM(STATION 2)@ 8297.79'. SET UPPER ER PACKER,SPACER SURFACE,28.2-2,799.3^ PIPE 8 SNAP LATCH ASS'Y(20.83'OAL W/MIN. ID OF 1.75")@ 8294'RKB(TOP OF UPPER PACKER @ 8273'RKB). I Perforations&Slots GAS LIFT;5,024.3 111 Shot I Dens Top(TVD) Btm(TVD) (shots) Top(RKB) BM(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com I 8,550.0 8,590.0 5,340.3 5,362.5 S-5,S-3,T-2, 11/21/1998 4.0 IPERF 180 deg phased, 2L-325 oriented 170 deg CCW from high side of hole POGLM MANDREL 8,2320ii w/2.5"HC BH POGLM MANDREL 8,232.0 ) SLEEVE-O;8,232.1 ` If 8,690.0 8,710.0 5,416.7 5,427.5 S-5,S-3,T-2, 3/25/2016 8.0 APERF 1 11/16"DEEPSTAR 'II 2L-325 GUNS 11 Mandrel Inserts st aoi nTop(TVD) Valve Latch Port Size TRO Run N NTop(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com GAS LIFT,8,281 8 1 5,024.3 3,498.9 CAMCO KBG 2- 1 GAS LIFT DMY INT 0.000 0.0 12/4/1998 PATCH,8,2730, 9 III 2 8,281.8 5,188.8 CAMCO KBG 2- 1 GAS LIFT PATC INT 0.000 0.0 2/24/2009 9 H Notes:General&Safety End Date Annotation 12/26/2008 NOTE: HIGH SEALABILITY PACKAGE SET IN GLM#2 11/9/2010 NOTE:View Schematic w/Alaska Schematic9.0 NIPPLE;8,334.6 LOCATOR;8,341 6 0 SEAL ASSY,8942.3 S 4 (PERF;8,550.0-8,590.0 APERF;9690.0-8,710 0 PRODUCTION 5.5"03.5"W 8363',25.6-9,176.3 1:1ldll iY1021 WELL LOG TRANSMITTAL#903201990 40GCC To: Alaska as a Oil and Gas Conservation Comm. May 5, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchora e Alaska 99501 5 «i2 g + ivl. K. BENDER RE: Perforation Record: 2L-325 Run Date: 3/25/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2L-325 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20275-00 Perforation Record (Field Print) 1 color log 50-103-20275-00 %MO PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / / Ag .0-tov / `E,,p"_""( Pages NOT Scanned in this Well History File XHVZE 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. File Number of Well History File PAGES TO DELETE Complete RESCAN ,~ Color items - Pages: ~-~, Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Mildred Daretha~Lowell Date: ..~.//Y Is, ,~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: ~si ~ ~~~ STATE OF ALASKA APB () ~~ 1_`'4'~~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OP~I~~'~~ i'~' ~rr~t3 1. operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^ set patch & Concentriic GLM Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ 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 ^ 198-209 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20275-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 146' 2L-325 8. Property Designation: 10, Fieid~'Pool(s): ADL 380053 • Kuparuk River Field 1 Tarn Oil Pool . 11. Present Well Condition Summary: Total Depth measured 9200' feet true vertical 5695' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 108' 16" 108' -- - 108' 1640' 630' SURFACE 2653' 7-5/8" 2799' 2313' 6890' 4790' PRODUCTION 8214' 5-1 /2" 8360' 5233' 7000' 4990' PRODUCTION 816' 3-1 /2" 9176' 5682' 10159' 10533' Pertoration depth: Measured depth: 8550' - 8590' _ ~~ ~ ~ ~, ~`~~,` t ~: ~ ~ ~ ~% true vertical depth: 5340' - 5364' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8360' MD. Weathertord ER Patch from 8273' - 8294' (1.75" ID) JMI Concentric Gaslift Manrel at 8232' Packers &SSSV (type & measured depth) Baker Casing Seal Receptacle (CSR) 8344' SSSV= NIPPLE 467' 12. Stimulation or cement squeeze summary: '~"-CL~~.S~, `Jr~`®g Intervals treated (measured) not applicable i((d fQ'Y 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 NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14. Attachments 15. Well Glass after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ °Service ^ Dairy 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 N/A if C.o. Exempt: N/A Contact Martin Walters @ 659-7224 Printed Name Martin Wafters Title Problem Wells Supervisor Signature ~ ~2~~C~ ~ Phone: 659-7224 Date / Pre ared b Martin Walters 659-7224 Form 10-404 Revised 04/2006!, - lll"1~~~ Submit Ori final Onl s 9 Y '~ • 2L-325 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary SET 3.5" WEATHERFORD ER PACKER WITH MID-ELEMENT AT 8294', MIDDLE OF THE FIFTEEN FOOT JOINT BELOW GLM (STATION 2). [LOWER PACKER FOR WEATHERFORD ER (RETREIVABLE) PATCH.] READY FOR SL TO STING UPPER ASSEMBLY AND SET UPPER PACKER. 2/19/200 SET UPPER ER PACKER SPACER PIPE AND SNAP LATCH ASSEMBLY (20.83' OAL W/ MIN. ID OF 1.75) @ 8294' RKB (TOP OF ER PACKER Cc~ 8274' RKB ). IN PROGRESS. TTEMPT TO MITIA FAILED (APPEARS STINGER OR LOWER PACKER LEAKING) SET EST TOOL IN UPPER ER PACKER @ 8274' RKB AND OBTAIN GOOD TUBING TEST. PULL TEST TOOL. (IN P LLED 2 ' E AC ER SPACER PIPE AND SNAP LATCH ASSEMBLY (ALL PARTS 2/21/2009 ACCOUNTED FOR AND ALL SEALS DAMAGED ON SNAP LATCH ASSEMBBY) FROM 8274' RKB.WILL TEST LOWER PACKER AT LATER DATE. AN TEST TOOL DOWN TO ER PACKER (c~ 8294' RKB AND CMIT TBG X IA TO 2500 PSI PASSED ). WILL RETURN LATER TO SET UPPER PORTION OF PATCH ' (20.83' OAL W/MIN. ID OF 1:75") @ 8294' RKB (TOP OF UPPER PACKER @ 8273' RKB ). MITIA TO 2500 PSI PASSED ). SET TEST TOOL @ 8273' RKB ,SHIFTED CM , PULLED TEST TOOL. IN PROGRESS 3/19/20091 BRUSH & FLUSHED TBG TO 8250' SLM, RAN 42B0 TO CMU @ 8232' RKB, MADE SURE CMU WAS OPEN. SET 3 1/2"POGLM ~ 8232' RKB. COMPLETE RE-TIFL -PASSED. Initial T/I/O = 140/550/330. Shut in WH and GL upon arrival.. Attempted to shoot FL with no results. Stacked out TBG with LG. T/I/O = 650/650/330. Bled IA down. T/I/O = 650/250/330. 1hour T/I/O = 675/250/330. Final T/I/O = 675/250/330. Summary Set atch and concentric aslift mandrel and conducted assin TIFL KRU 2L-325 (PTD# 198-209) ~ort Of TxIA Communication • Page 1 of 1 Regg, James 6 (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] -~ ~~~lIc' 7 ~~2~=~ Sent: Tuesday, March 03, 2009 2:06 PM ( ~ To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Braun, Michael Subject: KRU 2L-325 (PTD# 198-209) Report Of TxIA Communication Attachments: 2L-325 Wellbore Schematic.pdf; 2L-325 TIO Plot.ppt Jim/Tom, Kuparuk gaslifted producer 2L-325 (PTD# 198-209) is suspected of having TxIA communication based upon a failed TIFL after installation of a tubing patch and concentric gaslift mandrel. A leaking concentric gaslift mandrel is f~Tikely source of communication, so slickline will troubleshoot and repair by 03/26/09 or the well will be shut ~ in. CPAI will add 2L-325 to the SCP Report and will submit paperwork as necessary to restore production. Attached is a 90 day TIO plot and a Wellbore schematic. «2L-325 Wellbore Schematic.pdf» «2L-325 TIO Plot.ppt» Please contact me at your convenience if you have questions or comments. Martin Martin Waiters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 3/9/2009 l~ ?.~..-3~z7 T/i/0 Plot - 2 L-325 1500 a 1000 500 3~3~ ~`i 1) ! ~'o -Zac 200 ___.. ___ -jr t ~ 154 ~~i I ~ ~'.,..i~~ ~,~~ ~ ~~ j'i ~ -~. ,_ ... , , ..ICI=-.. ' .. I .. ................................ ~~. ~~ ~,..................................... ~~ ..j~.... ~~ .... ~.~~.^ ........ 1tiit . `t.:. .... . _ I ~. .. t'I i. 1 .~..~. 150 a as 100 ~ Y O .C V 50 0 -}~-~+~ 03-Dec-O~ 1 fi-Dec-08 ~9-Dec-O$ 11-Jan-09 24-Jan-09 05-Feb-09 19-Feb-09 Date 0 --,~ CortocoPhiliips ~~~~ _ ~~.~.. NbN CoM10: -3+'tt5 7/2S2w+'-' 1~ a0 PM _ _ _ _.._ 9clurrletb-AGuel __ • KUP 2L-325 tributes ~PUUWI -Fieltl Name _ __ __ ____ Max Angle 6 MD Well Status Prod/lnj Type ~Incl I°) ~MD (RKB) _TD_ ~'.~ Aet Btm (RKB1 )?7500 TARN PART ICIPATING AREA PROD 62 59 7,153 9 200 R25 (ppm) Drte Annotation End Date KB-0b (R) Rig Release Drte ~ple 30 1/1/2009 Last WO'. 36.49 ~ 1111211998 i Depth (R1(B) End Dale A nnotrt on End Drte SLM 8,953 2l1 /2009 Rev Reason SET PATCH OPEN CMU. GLV C/0 2/25/200 Strings Stnnq OD ~ Strlrrg ID ~~ Sel Depth Set Depth ITVD) String VYt String ~ - --~ ~_ I lescrlptbn IIn1 Ilnl Top (RKB) (RKB) (RKB) (IM/R) Orad e String Top TOR ~ 16 15.062 0 108 108.0 62.58 H-00 WELDED 75/8 6.750 0 2,799 2.312.9 29.70 L-80 BTC-MOD I TION 5 1/2 4 950 0 8.360 5.233.3 15 50 L-80 EUE Brd y I TION 3 v2 2 992 6,360 9.176 5,681 9 9 30 L-80 EUE Brd Stringg __ String OD String ID _ _ - Set Depth Set Depth (ND) String Wt Sf q )escripoon hnl (in) Top IRKS) (RK8) (RKB) (IDSIR) Ored ~ e~_String Top Ttud 3 vz 2 992 L~0 0 8,360 5,233 9.30 IEUE Srd n Hole ( Top DaPth. All Jewelry: Tubin . g Run 8 Retrievable,_Flsh, ete.) _.___ -_. (ND) Top Incl (RKB) (°) Description Comment '~ Run Dab ID (ln) 466.9 0.65 NIPPLE CAMCO'DS' NIPPLE 11/12/1998 2.8751 3,498.8 59.21 GAS LIFT ~CAMCOIKBG29I1IDMY/INTI//Comment: STA1 12/4/1998 ~' 2.900~'~ 5,160.2 54.96 GAS LIFT CAMCO/ConcentridOV on CR LOCK (55" OAL) 2/24/2009 5,160.2 54.96 SLEEVE-O BAKER CMU w/CAMCO profile; OPENED 2/23/2009 11/12/1998 2.813 5.183.8 55.12 PATCH 3.5" WEATHERFORD ER PACKER WITH MID-ELEMENT ~2/23I2009 1.750 AT 8294', MIDDLE OF THE FIFTEEN FOOT JOINT BELOW GLM (STATION 2) @ 8297.79'. SET UPPER ER PACKER, SPACER PIPE & SNAP LATCH ASS'Y (20.83' OAL W/ MIN. ID OF 1.75") @ 8294' RKB (TOP OF UPPER PACKER @ 8273' RKB ). '. 5,188.9 55.16 GAS LIFT CAMCO/KBG29I/IPatchllNT//I Comment: STA2 2/24/2009 2.900 5,218.5 55.38 NIPPLE CAMCO.'D' 11/12/1998 2.750 5,222.5 55.41 SEAL BAKER 5.5", 80-40 SEAL ASSEMBLY 11/12/1998 2.985. Top ITVD) BIm IND) D^ns etm (RKB( (RKB) (RKB) Zone _DaOe Ish... Type Commerrt _ i 8,590 5,340.3 5.363.7 - 11121/1998 ~ 4.0 IPERF ~' 180 deg phased, oriented 170 deg CCW from high side of hole w12.5" i HC BH General & Safety _ _~_ - - -- -Annotation -- J 8 NOTE HIGH SEALABILITY PACKAGE SET IN GLM d2 ..~-7 ~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # C-~ ~'^~~ ~' 'LL.~_ i _~v.~~ s Log Description - ~, k~ 01 /23/09 ~~-~;`Ire NO. 5056 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 16-05 2L-325 ANHY-0030 ANHY-00031 INJECTION PROFILE Q LDL 01/09/09 01/10/09 1 1 1 1 3M-03A AZJZ-00011 SFRT - (~. 01/11/09 1 1 2T-10 ANHY-00033 INJECTION PROFILE - 01/11/09 1 1 2L-301 AZJZ-00013 USIT 01/12/09 1 1 2A-26 AZJZ-00010 SONIC SCANNER _ - 01/15/09 1 1 2A-26 AZJZ-00010 SFRT Cj / 01/17/09 1 1 18-18 ANHY-00039 INJECTION PROFILE ~~ 01/19/09 1 1 2V-04 ANHY-00040 INJECTION PROFILE ~ 01/20/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • l~ • SEP ~ 0 ~(l~8 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM~~I~jj~ ~ ~3:~ ~~~'~`~~ ~~fYT`,i~1"x'00 REPORT OF SUNDRY WELL OPERATIOMS~ ~ '" 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ~ SPJP to Gaslift Alter Casin Pull Tubin g ^ g ^ Perforate New Pool ^ Waiver ^ Conversion ^ Time Extension Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5: Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 198-209 3. Address: Stratigraphic ^ .Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20275-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 146' 2L-325 8. Property Designation: 10..Field/Pool(s): ADL 380053; ALK 4601 Kuparuk River / Tarn Oil Pool 11. Present Well Condition Summary: Total Depth measured 9200' feet true vertical 5695' ~ feet Plugs (measured) Effective Depth measured 9049 feet Junk (measured) true vertical 5614 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 108' 16" t os' 108' SURFACE 2653' 7-5/8" 2799' 2313' PRODUCTION 8214' S-1/2" 8360' ~ 5233' PRODUCTION 816' 3-1/2" 9176' 5682' Perforation depth: Measured depth: 8550'-8590' ~~~ s~~ ~ ~ ~~u~ true vertical depth: 5340'-5364' Tubing (size, grade, and measured depth) L-80, L-80, 8360' MD. Packers &SSSV (type & measured depth) Packer =Baker 80-40 Csg Seal Assy. Packer = 8341' SSSV =Nipple SSSV = 467 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 266 306 360 2162 212 Subsequent to operation 101 380 49 818 219 14. Attachments 15. Well Class after proposed work:. . Copies of Logs and Surveys run X Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _ 16. Well Status after proposed work: Oi10 Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 7 7. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A contact Bob Christensen/Vacant ~ ~ Printed Name Ro ert D. hristen n Title ~ Production Engineering Technician Signature °`--_ Phone: 659-7535 Date Cy ~ ~ ~+~ 6 lj . ~"4. a~'F ~ ~. X00$ ` ~ g.i~•~ Form 10-404 Revised 0412004 bmit Ori final Onl OR~GI~fAL ~ ~~~~~~ g y, • 2L-325 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/18/08 PULLED JET PUMP (S/N: PH-1103) @ 8232' RKB. IN PROGRESS. 08/19/08 TAGGED @ 8958' RKB. MEASURED SBHP @ 8570' RKB (1294 PSI) GRADIENT @ 8392' RKB (1263 PSI) CLOSED CMU @ 8232' RKB. SET 2.75 CAT STANDING VALVE @ 8334' RKB. MITIA TO 3500 PSI (PASSED ). PULLED DV FROM STA # 2 @ 8282' RKB AND SET 5/16 OV. PULLED CAT SV @ 8334' RKB. COMPLETE. 08/21/08 Well Opened -Returned to Service . . WELL LOG TRANSMITTAL ProActive Diagnostic Services; Inc. To: AOOCC 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 / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 Report / EDE2L - 325 Caliper Report & MTT 23-Aug-07 1) 2) 3) 4) 5) 6) 7) SCANNED SEP 1 12007 It:) ~ '-dD~ ff ¡q<)!r---- RECEIVED Signed: /! }i-- SEP 1 0 ZOO 1 Print Name: ~l.. £. f., f¡ IA e. 11I/1 o../A IA fJ.. e fA Date : 6eFf\¡:¡Ji",,¡on AlaSKa VII ÕI Gas CUllS. Anchorage PRoAcTIVE DIAGNOSTIC SERVICES, INc., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (901)245-8951 FAX: (9011245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE: ~.MEMORYLOG.cQ.M D:IMastcr _Copy _ OO]DSANC-2OxxIZ _ W ordlJ)jstributionITransmit"''- Sbc:c"'ll'ransmjUJri~inal.doc I I I I I I I I I I I I I I I I I I I Company: Log Date: Log No. : Run No.: Pipe1Desc.: Pipe1 Use: Pipe2 Desc.: Pipe2 Use: . . Memory Multi-Finger Caliper & Magnetic Thickness Tool Log Results Summary ConocoPhilllps Alaska, Inc. August 23, 2007 7184 1 3.5" 9.3 lb. L-80 Tubing 5.5" 15.51b EUE Production Casing Well: 2L-325 Field: Kuparuk state: Alaska API No.: 50-103-20275-00 Top Log Intvl1.: Surface Bot. Log IntvI1.: 8,441 Ft. (MD) Top Log Intvl1.: 2,790 Ft. (MD) (MTT only) Bot. Log Intvl1.: 8,434 Ft. (MD) (MTT only) Inspection Type : COMMENTS: Corrosive & Mechanical Damage Inspection This CaliperlMTT data is tied into the DS Nipple @ 8,334' (Drillers Depth). This is the first log of this well to be made with the PDS 24-Arm Multi-finger Caliper (MFC) and 12 Arm Magnetic Thickness Tool (MTT). The caliper records the features of the internal surface of the 3.5" tubing in this well while the Magnetic Thickness Tool responds to the total thickness of metal of the 3.5" tubing, and 5.5" production casing within the logged interval. The MTT portion of this log covers 2,790' to 8,434'. The additional metal volume added by the 7.625" surface casing above this interval exceeds the MTT's capability to record accurately. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not positively distinguishing in which pipe string the change in metal thickness occurs. Generally, intermittent high-frequency metal loss indications are attributed to metal loss of the tubing or inner-most string, and metal loss to outer concentric strings will be denoted by lower frequency shifts in the average metal loss of all twelve sensors combined. In this log, the MTT was calibrated down hole (6,005'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 3.5" tubing and 5.5" production casing. INTERPRETATION OF CALIPER LOG RESU~TS FOR 3.5" TUBING: This log was run to assess the condition of the tUbing with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the 3.5" tubing logged Is in good condition. There are no significant Wall Penetrations, areas of Cross Sectional Wall loss or 1.0. restrictions recorded throughout the interval of tubing logged. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRA 110NS : No significant wall penetrations (>20%) are recorded. RECE\VED SEP 1 0 Z007 ProActive Diagnostic Senlices, Inc. I P.O. Box 1369. Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.ço~ 0"\ & Gas Cons. commission Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Alas I A h age ne or , ¡Cit-{)oo, :it 1S-3'91S I I I I I I I I I I I I I I I I I I I . . MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall loss (>12%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant J.D. restrictions are recorded. INTERPRETATION OF MTT LOG RESUL T5 : A graph of the average metal thickness assessed from the MTT data on a joint~by-joint basis is included in this report. The MTT log results indicate no intervals of significant overall metal thinning (>6%) throughout the interval logged below the 7.625" surface casing. Accurate interpretation of possible minor isolated damage in this MTT data is not possible due to unsteady tool string speed. The tool string appears to be surging or jumping over approximately 2 ft. intervals throughout the logged interval. While this impairs the ability to accurately identify potential smaller isolated areas of metal loss, it does not preclude the identification of areas of significant tubing and/or casing metal loss that would be sufficient to shift the overall average metal thickness curve over an extended (more than 2') interval. No extended intervals of a significant downward shift in the overall metal thickness curve are indicated in the MTT log of this well. An increase in overall metal thickness is indicated by the MTT over the bottom of the tubing interval, from 6,600' to 8,360'. Larger increases indicated atthe very bottom ofthe tubing string are associated with the pump sleeve (@ 8,230') and other jewelry below this point. The source ofthe slight increase in metal thickness indicated between 6,600' and 8.230' is uncertain, but may be related to the content of the IA fluid column over this interval or the characteristics of materials on the outside of the 5.5" production casing over this interval. A log plot of the data recorded over the interval 4.200' - 4,370' is included in this report to illustrate the impairment of the data due to tool string surge that is typical to the entire logged interval. A log plot of the data recorded over the interval 8,215' - 8,385' is included to illustrate the MTT's response through the jewelry at the bottom of the tubing and into the mono-bore 3.5" liner section below the tubing. The recordings over this interval support the assumption that any extended intervals of significant metal loss would be apparent in the data, in spite of the tool string surging that masks potential small metal loss features. I Field Engineer: lM'n McCrossan Analyst: J. Thompson / J. Burton Witness: II. Yoakam I ProActive Diagnostic Services, Inc. / P.O. Box 1369} Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Pr'udhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 I to I 3.5 in Well: 2L-325 Field: Kuparuk I Alaska, loG. USA 23, 2007 I I Too! Deviation Approx. Borehole Profile 4 I 764 I 1553 I 2343 I 3132 I 3925 .... lI- .5 I 4716 GlM 1 I 5544 I 6333 I 7125 7915 I GLM 2 8435 I 50 100 Damage Profile (% IT 001 Deviation Bottom of ""264 I I I I I Well: Field: Company: Country: 2L-325 Alaska, ¡IlCo USA I I 9.3 Grade & Thread l-80 Nom.OD 3.5 ins Penetration and Metallo!!!! I metal loss 250 200 150 100 50 0 o to 1 10 to 20 to 40 to to over 1% 10% 20% 40"/" 85% 85% I I I Number of pene. 0 105 loss 37 230 166 4 I I Damage (body) 60 I 40 I 20 I o isolated gener¡¡J line ring pitting corrosion corrosion corrosion I o I I I I DS Report Overview NomJD 2.992 ins o o August 23, 2007 UW MFC 24 No. 212330 i.69 24 j. Thom soo Nom. 3.5 ins Damage Profile wall) metal loss 50 100 GlM 1 GlM2 Bottom of Survey = 264 Overview page 2 I JOINT LA TION I I I Wali: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf l-80 0.254 in 0.254 in 2.992 in Well: 21.-325 field: ¡ne. Country: USA Survey Date: August 23, 2007 I Joint Jt. Depth Pen, Pen. PelL ¡\Aetal Min. Profile No. \~ ;~:i~ t 1.0. Comments 0 50 100 1 4 2 36 3 68 4 100 0,03 5 131 0.114 6 163 0.03 Shallow corrosion 7 94 0.02 2. 8 1:~ 2.91 I 9 10 11 321 0.04 corrosion. It Deoos-its. 1/ 353 O. 13 383 3 Shallow nittirnI. It Del:'JOSits. 14 415 1,{f 446 SSSV 15 Shallow oitûmz. 16 480 9 9 17 511 =w 18 543 n 9 2.4 . th ¡i~ht deDosits. 19 575 2.93 Shaifow corrosion. 20 606 0.04 2.93 Shallow corrosion. 21 63 0.03 vn ¡ t. DenŒits. 12 67 004 Shallow corrosioo. 23 70 0 0.Q3 Shallowoittimz. 24 733 n 25 764 0 0.04 26 795 0 ¡7 826 W 2. Shallow corrosion. 8 R58 2.2 Shallow corrosion. ¡e¡ 889 14- 2.92 Shallow oiUjml. It Deoosits. 0 - ¡ ') 2.94 Shallow corrosion. 31 I 2.91 32 984 2.92 Shallow Pitl:Ïrnz. 33 1016 ) 2.94 Shallow DiWnlI. 34 1047 2.91 Shallow corrosion. U. Dermsits. 35 1079 0 2.94 Corrosion. % 1111 IT Shallow nitting:. 37 1142 38 m 1174 39 ) 0.03 2.92 Shallow oitl:Ïml. 40 ~ 0.0 e 2.92 41 1268 o. 'm 4J 1300 11 J.9 43 1331 1 2.9 Shallow oiWm¡. 44 1363 I ! .0 1 "hallow nitting. 45 1395 ~ 46 14 6 47 14. ,8 Shallow corrosion. 48 14' if! 1 9 2.93 49 15 2 { 10m 112 I 9 2.93 I I I I I I I I Body Meta! Loss Body I I LA TION I I Wall: Upset Wal!: NominaIID.: 3.5 in 9.3 ppf l-80 0.254 in 0.254 in 2.992 in Well: Field: 2l-325 Alaska, Ine. USA 2007 I Join t Jt Depth Pen Pen. Pen. !\llelal Min. -v Profiie No. l.Jpsel 1.0. Commen5 "" - '" \ '0 vv.....¡ (ins.) (Ins.) 0 50 100 ~14 2.93 Shallow corrosion. 51 1585 9 2.92 52 1616 0 0 03 2.94 Shallow c:orroSÎol1. 53 1648 0.02 ¡ 2 54 1680 Shallow corrosion. 55 1712 0.04 I Shallow corrosion. ~- 2 57 1775 corrosion. 59 1839 ( 0.03 2. 60 Hi71 0.03! 2.G3 61 1902 0.02 :.¡ 2.91 62 1934 0.03 1 Shallow oiWnlI. 63 1966 004 h Shallow corrosion. I 64 1997 . . 65 2027 66 20<¡Q 67 2089 l 0.2 ß ß 68 2121 0.02 9 69 2153 [) 0.03 I 3 2.92 Shallow corrosion. 70 2 184 0 æfl :t93 Shallow nittinll. Lt Denosits. 71 2 17 0 =HH 72 2. 48 73 2279 I 11 (n I 74 :nn lo,£n II ¡ t. n",nnS;h:. 75 2343 76 2175 [) I 77 2407 78 79 2470 O. 80 2502 [) 0.03 81 2534 0 Shallow DiUinl:!.. 82 2566 0 - Shallow niWnll. 83 2596 0.02 9 - 84 2628 0.03 11 85 2658 0.03 II ~2690 0.03 2.92 Shallow oiuirnz. 87 2722 0.03 I 2.95 88 2753 l' 2.93 Shallow DiUirnz. 89 2785 l !J 2.97 90 2817 [) 1 ') 293 91 2849 0 7 10 2.98 q2 2880 q ;¡ 2_q3 93 2912 VB Shallow Oìttil12. 94 ~I ~oo: . Shallow oitlil12_ 95 9fi 2.9 Shallow cono<åol1. 97 3037 I) 2.91 Shallow corrosion. 98 '1069 I) Vß Shallow nìttíml. 99 3101 0 0.03 iO 11 I 2.98 I I I I I I I I I I I I Body Metal loss Body 2 I I I PDS INT lATION SH I Pipe: Body Wall: Upset Wall: Nomina! 1.0.: 3.5 in 9.3 ppf L.oo 0.254 in 0.254 in 2. 992 in Well: field: 2L-325 I Inc. USA August 2007 I Joint Jt Depth PerL Pen. Pen. :'vletal Min. v Profile No. (Fl) LD. Comments wall) (Ins.) (Ins. ) (Ins.) 0 50 100 100 3132 0.03 Shallow corrosion. 101 3165 0.03 ¡ L Opoosits. 102 3196 K031: ') Shallow oìttimz. 103 3228 I 104 105 3 Î 0 ( 2.98 ti±~3 11 2.96 1 3355 2.93 108 ~ 294 109 I 3419 9 Ii 2.99 110 3450 H ~ ,'" 12.9~ 111 3482 .04 I Shallow corrosion. 112 3513 0.03 1( 113 3545 0.04 ¡ Shallow corrosion. Lt Deoosits. 114 3577 n . 2.98 115 3608 7.93 Shallow corrosion. 116 I ~~40 1= (t=Y1ì Shallow corrosion. 117 118 3703 119 3734 I 0.02 2.98 120 3766 ) ¡ f3 2.93 Shallow corrosinn. 121 3798 0 ;1 2.92 122 ~830 n O. ) 2.94 123 3862 :t=%== O. 2.98 124 3893 O. II 2.92 Shallow corrosion. 125 3925 O. 2.91 126 3957 0 O. 2.98 127 3988 0 0.02 j 2.93 Pitting. 128 4020 0.02 ! 129 4051 !=t 130 4084 2.94 131 4115 2.99 132 4146 O.OJ ¡ 1 2.94 133 4178 0.04 ß 2.93 Shallow corrosion. 134 4210 0.02 2.98 135 4242 0 0.02 2.96 136 4273 n 005 7.92 Shallow corrosion. 137 4305 0 0.02 2.98 138 4316 0.03 ±± 2.97 139 4368 0.04 4 2.92 Shallow pitting. It. Deoosits. 140 4400 0.02 9 I) 2.96 141 4431 g02 :i 1 2.94 Shallow corrosion. 142 4461 2.98 143 4495 2.97 144 4527 0.03 n 796 I 145 4559 0.04 1 2.93 Shallow corrosion. 146 4591 ) 0.02 2.98 147 4622 + 0.03 ") 2.97 148 4654 0.02 7.96 149 4685 {J 0.02 2.98 I I I I I I I I I I I I I I Body Meta! loss Body 3 I I PDS JOINT LATION I Pipe: BodyWa": Upset Wall: Nominal I.D.: 3.5 in 9.3 ppi l-OO 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2l-325 Kuparuk I I Alaska, ¡nc. USA August 23, 2007 I Joint Jt. Depth Pen. Pen. Pen. "vlelal Min. n. ,./. ,~...~ No. (Fl.) 1.0. Comments wall) (Ins) (Ins.) (Ins.) 0 50 100 150 A71h ill ~ Shallow corrosion. 151 4748 003 13 1 Shallow Dittillll:. 152 4781 0.03 13 9 2.93 Sh;¡lIow nittinQ. 153 4813 0.02 9 2.97 154 4844 0.04 m 2.94 Shallow corro<;Íon. 155 4876 0.0'1 2.91 It Oenosits 156 4907 0.03 2.93 Shallow oittillll:. 157 4940 0.02 2.99 158 4971 0.04 ¥= 9 2.94 Shallow oittim!. 158.1 5003 0.03 2 297 PUP 158.2 5017 J 0 11 NJA C.lM 1 158.3 5026 J 0.01 i pup 159 5039 ) 0.02 160 S070 ¡ 0.04 f\ Shallow corrosion. 161 5133 ++ ~ 162 ¡ 2.91 163 5165 0.03 2.93 Sh;¡lInw rorm<:Ïon. 164 5196 0.04 7 2.Q2 Sn;:¡ilow corro..ion. 165 5228 0.03 q 291 166 5260 0.02 2.97 167 5290 0.03 .2 93 168 5322 0.04 corrosion. 169 5355 0.02 .2 98 170 5386 0 0.02 ¡ 2.99 171 <;417 0.04 :\ " 2.93 Shallow corrosion. I t. DenosÎts. 172 5449 0.02 2.97 17i 5480 0 Ii 2.96 174 5513 O. 13 mil SfrnJlowoiffi"", 175 5544 o 4 Shallow oittin£. 176 5576 ( 0.02 i77 5607 0.03 178 5638 0 0.02 2.93 179 5670 0.02 2.98 180 5701 0.02 2.98 . 181 5732 004 2.90 Shallow corrosion. 182 5764 0.03 2.93 183 2.94 184 5828 0.02 [ i 2.96 185 5860 0.02 2.93 186 5892 0.04 14 2.93 Shallow pitting. 187 5924 0.03 u 1 2.93 188 t¡= 0.02 - 189 190 O. )3 191 6049 O. )4 2.92 Shallow oittim!:. 192 6080 0.02 2.93 193 6111 0.03 2.91 Sh;;¡Uow nittil1Q. 194 6143 0.03 m Shallow corrosion. 195 6175 0.04 I a Shallow mrroskm. 196 6208 0.03 i 9 I 2.97 ShallQwoittíntt. I I I I I I I I I I I I Body Meta! loss Body Page 4 I I JOINT lATION EET I I I Wall: Upset Wail: Nominal 1.0.: 3.5 in 9.3 ppf L·80 0.254 in 0.254 in 2.992 in Well: Field: 2L-325 Kuparuk Inc. Country: Date: USA August 23, 2007 I joint jt ~~fth PerL Pen. Pen. Ivletal Min. ,I;~'''''''' No. \~:)SE;I 1.0. Comments ¡Of - \ 'V""", (Ins. ) i 0 50 100 7 a 7 112 I 7 296 20 } '.91 Shallow corrosion. 02 I 2.98 203 1 204 Shallow nitìÍn2. Lt Deoosits. 205 6490 n 0.04 " 1aliow c.orrosion. 206 6522 ì 0.04 I S )aI/ow corrosion. 207 6553 ) It Denosits. 208 6586 ) 2.92 Lt. DeoosÎ ts. 209 6618 2.97 210 6649 ~ Shallow nittimz. 211 6680 0.03 Shallow corrosion. 212 6711 0.3 213 6744 O. 4 4 2.91 Shallow corrosion. 214 6776 O. 2 2.98 215 6807 ill ') 216 6839 0 0.02 ~ - 217 6871 ) 0.04 ) :...- "hallow c.orrosion. 218 6903 (10'; :...- Shallow r.orrosion. 219 69:1'; 0: ne; ~ Pitum¡- in !1r:JSet. 220 :1 70ig ) 221 ! ¡ Shall ''''' I 222 223 7061 I Shallow oittilî2. 224 7094 225 7125 226 7157 Deno¡¡its. 227 7188 228 1 Shallow oiWnSL 0.12 0.04 II' Shallow corro¡¡ion. o I 0.04 ¡ H Shallow corrosion. 233 234 235 7440 0 0.03 10 236 7472 0 237 0 0.03 --'- 238 n O.D5 0.03 2.94 231} 7' 003 2.% 240 7< ì ~ 0.02 'I Shallow corrosion. 241 'f 1 242 7662 243 7693 2.91 244- 7726 ii 245 7758 0.02 a 246 7790 ) 0.03 III I I I I I I I I I I I I Page 5 I NT LATION Well: Field: 3.5 in 93 0.254 in 0.254 in 2.992 in 2l-325 Kuparuk l-80 I Wall: Upset Wall: NominaILD.: USA 23, 2007 Joint No. Cömrnents I I I I I Page 6 I I Inc. o 50 100 I I Calibration 3.5 in 7.2' - Well: Field: 2L-325 I Alaska, Inc. USA August 23,2007 I I Decrease Increase 100 3132 I 125 3925 I I 150 4716 GLM 1 I "- IV ..... ..0 175 5544 E u.. ::¡ .S z I 200 6333 I I 225 7125 I 250 7915 I GLM 2 264 8435 I -50% 0 50% in Metal Thickness Bottom of Survey"" 264 I I I I cIas. . MTT 10 H ~ " . - (T~pk,ci: . " -'I J " p~ DIAq...:ílSJlc: !k1Me.... I..." ....v. ,,""!} "I 'J ....."" Database File: d:\warrior\data\21-325\21-325. db Data$et Pathname: 1/1/1/mtt Presentation Format: mtt Dataset ¡ Fri 24 20:00:34 2007 Charted Feet scaled 1 :120 ~!!~_~_~_~!~~~l!~L~~~ - .. 0 MTTPD1 (rad) 100 o Une Speed (ft/min) -200 -92.3 MTTP12 (rad) 7.6 3.2 M!T Finger 02 (in) 1.2 4200 - TL bin! Cc .. _._~ ---- -- - - ~ ¡,. f - 4220 .. %q.' -- P~~¡bie ~¡norr.; ;". , ~;. Jt 134 .~. .,. Due to J .~~, "'...,-~ Motion , ..., .-d' . -. - -' ..., I) - 4240 ~- ? Jt. 135 -,,- "- c_ -" . as¡n~ Collar 4260 0;:;0- --'- r-- ." ,.. "" -- I !- ~ Tubin( Collar I I I -- ìI I r I I I I I I I I I I I I I I I I 4280 00 tit != ---- -~ -- f---- .--- - -~- ~ -. ~. Jt. 136 iiI'- ""- ,--- I ~~=f < rç- ~ar 4300 ïUDln Co!lar~ =~ .. ~ I I ~ I Jt. 137 -= !± 4320 ~ .~ -- --- ..~---- ---I -- , I tl Jerl ~T(jo --. )ue to M . ""' , I .... ".~ I Tubir Collar ....... I Collar 4340 .. Ca.sin ~"'- 'm -- 11 I '"' ........ Jt. 138 I " "" I -- c-- -' 4360 - I -- ~ I Ita Metal Thickness (%) 100 0 MTTP01 (rad) 0 Line Speed (ft/min) -200 -92.3 MTTP12 (fad) 7"6 I 3.2 MIT Finger 02 (in) 1.2 I I I I <!as. . MTT 10 H ...... ". ,... · 1h ~L BY;:) - .. p~ D~"" Sell."'" I...,. f Y II ,,"'. ...... WI _. .J., .J Metal Volume :"" Database File: d: \warrior\data\21-325\21-325. db Dataset Pathname: 1/1/1/mtt Presentation Format: mtt Dataset Creation: Fri 2420:00:34 2007 Charted in Feet scaled 1 :120 ~ 0 MTIP01 (rad) 100 0 Une Speed (ft/min) -200 -92.3 MTIP12 (fad) 7.6 3.2 MIT Finger 02 {in) 1.2 ~ 8220 1- I I ~IT 02-=~ Jt. - 11 ~. [11- lineS l I} I ~ .- - ump Sleev 8240 I 1 '" ~-- - ~. '- Jt. ¡.. -= ~ ;tt S ,~ - 8260 " f I ) ~ -- ~. ¡ I~ f" .. í- " ~ .-- ~-- r-- - ¡....... - -... - !~I ~ r Jt I ~ 8280 r- GLM2 ,. I I""- ~ "" I i· --{ti-- I Pup Jt ,- I I I I I I I I I I i I Iii il I I I ~8~ Jöü, ~ I , I F- '--; I f----- --, , \ . , ~. - I, i - Below GlM :'2 ;:.. ~ c.- Jt:. 261 - c-- . ..- - . f---- -. - - -- -- 8320 - I r -- --... ¡ .. - Jt ¡JJ;, ':'?1? =E and - Seal - 8360 I t .- ~ - i1 3 6" Liner 1-- f--- 1-- . !--- - 'U~~~ + 1-3 5" ( ~ lit ... - >-- -. ~ --'- ~¡i·f¡ng~fo",,~ J-- 8380 !U~ I I 3b~e< 100 Delta Metal Thickness (%) 100 0 MTTP01 (fad) 0 Une Speed (ft/min) ~200 -92.3 MTTP12 (rad) 7.6 3.2 MIT Finger 02 (in) 1.2 I I I I I I I I I I I I I I KRU I I I I i . il I I I I I I . Conoc;Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 20, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK. 99501 SCANNED SEP 06 2007 Dear Mr. Maunder: . RECEIVED AUG 2 9 2007 Alaska Oil & Gas Cons. Commission Anchorage \<\q¡~~O~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was· found to h~we a void in the còÍÏduêtor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped between August 12-13,2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. 7¥~¿ MJ. Eoveland ConocoPhillips Well futegrity Projects Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/13/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement DumDed cement date inhibitor sealant date ft bbls ft gal 2L-305 198-240 SF N/A N/A N/A 1.7 8/13/2007 2L-307 198-256 10" N/A N/A N/A 8 8/13/2007 2L-311 203-155 15" N/A N/A N/A 9 8/13/2007 2L-313 198-219 15" N/A N/A N/A 5.9 8/12/2007 2L-315 198-218 23" N/A N/A N/A 5.9 8/12/2007 2L-317 200-210 SF N/A N/A N/A 4.2 8/12/2007 2L-323 198-251 9" N/A N/A N/A 3.4 8/12/2007 21:.-325 198-209 24" N/A N/A N/A 9.3 8/12/2007 2L-327 207-008 20" N/A N/A. N/A 6.8 8/12/2007 2L-329 198-225 24" N/A N/A N/A 6.8 8/12/2007 Re: Jet Pumped Wells Subject: Re: Jet Pu01ped Wells From: "NSK Problem Well Supv" <01617@'conoeophillips.eo01> Date: Sat, 7 Dee 2002 14:07:01 -0900 To: TOJ11l\1aunder <tom_01aunder@!.admin.state.ak.us> CC: "01617" <nI617@conoeophillips.eo01> Tom: I requested a list of surface powered jet pump wells from our PEls. The following should be the current total for the Kuparuk area: West Sak \oJells: 1C-123 (PTD 2010840) was recently S1 for high watercut 1C-135 (PTD 2012200) is a huff and puff well and was recently put on water injection cycle CPF 2 are as follows: 2L-307 (PTD 1982560) 2L- 313 (PTD 1982190) 2L-315 (PTD 1982180) 2L-321 (PTD 1982620) ~2L-325 (PTD 1982090) 2N-303 (PTD 2001690) 2N-304 (PTD 2011300) 2N-305 (PTD 2001350) 2N-318 (PTD 2001000) 2N-319 (PTD 1981970) 2N-332 (PTD 2000790) 2N-337 (PTD 1981220) 2N-339 (PTD 1981000) 2P-415 (PTD 2012260) There are no surface powered jet pump wells at CPF3. I hope this answers your question. Let me know if you need more information. Jerry Dethlefs ConocoPhillips Problem Well Supervisor Tom Maunder < tom maundëpg'admin. state. ¿.¡k. iJS> 12/06/2002 09:00 AM To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: Jet Pumped Wells Pete and or Jerry, I have some emails f h'l b rom aWl e ack regarding the wells out there on Jet pumps. Would you please provide an updatEd listing of the ~ells presently on jet pumps in greater KRU?? Thanks in advance. To Casing Detail 7.625" Surface Casino 11g- XJ9 WELL: TARN 2L-325 DATE: 11/5/98 1 OF 1 PAGES ARca Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RKB to LR = 28.00' TOPS Above RKB 7 5/8" Landing Joint 28.20 FMC GEN V- Prudhoe 7 5/8" Csg Hgr 2.02 28.20 jts. 42-63 7 5/8", 29.7#, L-80 BTC-mod(22 jts) 929.13 30.22 jt. 78 7 5/8", 29.7#, L-80 BTC-mod (Thread Locked Collar) 41.91 959.35 TAM 7 5/8" Port Collar (BAKERLOK) 2.45 1001.26 jt. 77 7 5/8", 29.7#, L-80 BTC-mod (Thread Locked Collar) 43.03 1003.71 jts. 3-41 7 5/8", 29.7#, L-80 BTC-mod (39 jts) 1665.67 1046.74 Gemeco Float Collar 1.31 2712.41 jts 1-2 75/8",29.7#, L-80 BTC-mod 84.14 2713.72 Gemeco Float Shoe 1.48 2797.86 Casing shoe..@ 2799.34 T.D. @ 2815' leaving 15.66' of rathole 31 Gemeco Bow Spring CENTRALIZERS Run centralizers in center of Jts. 1,2, 77, 78, over stop collars and over casing collars on Jts. 3-14 and over collars of jts. 17,20,23,26,29,32,36,39,42,45,48,51,54,57,60. Joints 64-76 (13 joints) will remain in the pipe shed. . Remarks: String Weights with Blocks: 80K Up,65K Dn,12k Blocks. Ran 65 joints of casing. Drifted casing with 6.750" plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections. Casing is non-coated. Doyon 141 Drilling Supervisor:G.R. Whitlock 5CANNEf) MAR 1 5 2004 ..~' .~" ARCO Alaska, Inc. Well Name: 2L-32S Rig Name: DOYON 141 Cementing Details Report Date: 11/06198 AFC No.: AK948S Report Number: 4 Field: Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: I LC Depth: % washout 7.62S 9.87S S9.3ð 2799 2712 Centralizers State type used, intervals covered and spacing Comments: Bow spring centralizers on jts 1,2,77 & 78 on stop collars 1/jt. Centralizers 1/jt on casing collars on jts 17, 20,23,26,29,32,36, 39,42, 4S, 48, S1, S4, S7,60 Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: 10.2 28 22 24 is Gels before: Gels after: Total Volume Circulated: 1S127 8/12 1105 Wash 0 Type: Volume: Weight: Comments: ARCO Wash 20 8.4 Spacer 0 Type: Volume: ~\ Weight: Comments: ARCO 40 10.5 Lead Cement 0 Type: Mix wtr temp: t of sac~ I Weight: Yield: Comments: ASIII 70 371 10.7 4.43 Additives: "'-./. 50% D124, 9% 044, .4% 046, 30% D53, 1.5% 51, 1.5% D79 .\ Tall Cement 0 Type: Mix wtr temp: Nt of saCkS) I Weight Yield: Comments: G 70 235 15.8 1.17 /' Additives: \\...._......~.../i' 1% 51, .2% 046, .3% D65 Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 6.9 6.1 80 Reciprocation length: Reciprocation speed: Str. Wt. Down: 10 10 fpm 65 Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 124.5 125.9 Calculated top of cement: ""~rp: Bumped plug: I Floats held: Surface te: 1116/98 yes yes r TI e:09:19 Rem.rt<s,".. full ""ms !hm.o.o.. Job. CI"'"',\". bbl cj'" to ,,"'c.. Cement Company: "Ri9 Contractor: I Approved By: DS DOYON G.R. Whitlock .~~ ~" ARCO Alaska, Inc. Daily Drilling Report AFC No. ¡Date RptNo I Rig Accept. hrs Days Since AccepVEst: 3.33 / Rig Relase . hrs: AK9485 11/06198 4 11/03198 08:00:00 PM Well: 2L-325 Depth (MDrrVD) 2815/2321 Prev Depth MD: 2815 Progress: 0 Contractor. DOYON Dailv Cost $ 247312 Cum Cost $ 523083 Est Cost To Date $ Rig Name: DOYON 141 Last Csg: 7-518" @ 2799" Next Csg: 5-112" x 3-112" @ 9172' Shoe Test: 16.6 Operation At 0600: Drilling 2860' Camp/rig on high line 24 hrs Upcoming Operations: Drill ahead MUD DATA DRILLING DATA BIT DATA EH&S DRILLSlBOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LSND 2R1 N TST 11/04/98 11/07/98 WEIGHT ROT wr SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.1ppa 6.75 10128/98 11/02198 VISCOSITY puwr MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 46sqc HTC N SPACE 10131/98 PV/yP sowr TYPE TYPE TYPE FUEL & WATER 14/15 STR554 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 1500 5/6/ 1901317 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED. 900 8.8 11/06198 BBlS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 107 ml/30 min 2815 INJECTION USED. BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER& 4.0% 0 2L-329 PËRSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of 0 110bbl 0 II I 0/ / 2L-325 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 0 10.0 1121 1 3.2 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 0 8.5 6161 I 625 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 0.00 2.2% 0 I 0 II Fresh Water 200 PIT VOL GPM2 JETS JETS Diesel ARCO PERSONNEL 1 500 0 I 0 II IIIII 11111 30 0 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $7045 III 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $51588 III III III 230 COMPANY MUD wr GRADE GRADE TOT FOR WELL (bbl) SERVICE 10 BAROID III III III 230 PERSONNEL TOTAL 43 TIME I.. END HOURS.. J OPS CODE I HOLE SECT. .....lpHASeÖPS. I ÖPERATIONSFROMÒboo "°000. ..... ,. ... .... ... 12:00 AM 02:00 AM 2.00 CASG SURF Casing and Hold pre-Job safety meeting. Run 7-5/8" casing to 1650' Cementing 02:00 AM 02:30 AM 0.50 CIRC SURF Casing and Clrc casing volume Cementing 02:30 AM 04:30 AM 2.00 CASG SURF Casing and Run 7-5/8" casing to 2799' Cementing 04:30 AM 07:30 AM 3.00 CIRC SURF Casing and Clrc hole clean. Cementing 07:30 AM 09:30 AM 2.00 CEMENT SURF Casing and Cement w/371 sx. Lead @ 10.7 ppg and 235 sx Tall @ 15.8 Cementing ppg. Displace w/24.5 bbl h20 and 100 bbl mud. Bump plug and check floats. CIP @ 09:19 09:30 AM 02:30 PM 5.00 NU_ND SURF Casing and UD landing Jt. Flush stack NID dlverter system. Cementing 02:30 PM 05:00 PM 2.50 NU_ND SURF Casing and N/U speed head, tubing head and BOPE Cementing 05:00 PM 08:00 PM 3.00 BOPE SURF Casing and Test all BOPE components to 250/3500 psi. Install wear Cementing ring 08:00 PM 11:00 PM 3.00 BHA PROD Making Hole MIU directional MWD. Test MWD. 11:00 PM 12:00 AM 1.00 TRiP_IN PROD Making Hole RIH to 2670' tag cmt Daily Drilling Report: 2L-325 11/06/98 Page 17 CASING TEST and FORMATION INTEGRITY TEST Well Name: 2L-325 Date: 11nl1998 Supervisor: G.R. Whitlock Casing Size and Description: 75/8", 29.7 ppf, L-80, BMTC Casing Setting Depth: 2,799' TMD 2,300' TVD Mud Weight: 9.1 ppg EMW = Leak-off Press. + MW 0.052 x TVD Hole Depth: 2,330' TVD 830 psi + 9.1 ppg LOT = (0.052 x 2,300') EMW = 16.0 ppg Fluid Pumped = 0.8 bbl Pump output = 0.1000 bps ~TIME LINE ¡I I I I I 1 I - lONE MlNlITE TICKS I I I ~ -'- L J ! I . J ! ¡ . I j ';boo-x. I i I I I I II I -1- - I ! I ! I I I I I I I i I i I ! I I I I ¡ ¡ I I! I I I II ! I I , ¡ I I ¡ II : I I I ! ! I I I I I I I ! 0 I I I I I J I JI ¡ I I I I ! ! ......... LEAK-OFF TEST r-~-- I ! I I I ! -'-CASING TEST r-i I I " I JJ I I "up. LOT SHUT IN TIME I~ I !. \ I I I I I -*- CASING TEST SHUT IN TIME q= q= 16 ! I I I I -+- TIME LINE ! ! , II ~ I I I , kL J I ~, I I .."""" I I 1.1 I I I I 'I I I I I ¡ I I I. I I I I I ! 2,300 psi 2,200 psi 2,100 psi 2.000 psi 1,900 psi 1,800 psi 1,700 psi 1,600 psi 1,500 psi W 1,400 psi a: 1.300 psi ~ 1,200psi ffi 1,100 psi a: 1,000 psi a.. 900psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64 66 66 70 72 74 76 78 80 82 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA CASING TEST DATA' MINUTES MINUTES FOR FOR FIT STROKES PRESSURE CSG TEST STROKES PRESSURE ,.-------------,------------,-------------, (--------------,------------------,------------------, I I 0 stks I 0 nsi I I I I I r---------t--:¡ stks---r--4"õpsr--"h. d;----------------t-----Õ-stkš----t----opš¡---l [=~~=~===I~=~~_!!~~_=l=J!Q~~~~=~ \ Q}~=~~=~~==~=r~~~~=~~~~~~~r~~~~~~fp.~r~J ~---------!--~!~~----i--~~-Q_.P~---~ \ ~þ----------------¡----~- st~~----~---~-?Q_J?..~~---j L--------L---~-~~~!----l---~Q_Q..p_~L_.Þ- \ q)----------------1-----~_!~-~~----}----~-~.Q_.P_~~--.1 L__-V_.J._-'§ s~~..l_!~.Q ps!-.J\ ~----------_L_--~_!!~!...___L_!!~_~Q-p'~-j I A) ~ -~-~_~~..L_l~Q..P~~_-j ~<&--------------!----_1~_!~~~--i-!!?-~Q psi ~ ~--- 0 -----+ 7 stk!____}---~~Q_.P~!_~ ~--------------t-____1!!~~~_---}--~~Q_p.~1_~ L----------j-----------l.----------~ L---------..-______l______-----_____-l-____-----------j I I I I I I I I t==~-=~==~t=~-====-~=+==-~~-=~==~=~ ~==~~~~~~~~===t=~~--=---~=~~~~=+~=~~~~=~~~~~~-=~~ r------i-------r--------i t----------------t-------------------t--------------1 t---------;-------------;--------------1 t----------------t-----------------1-----------------1 ~:- =~=-=-=~-:!:=--=~-=~j [==:==!:====-=-=t==::j I I I I I I I I ...------------i------------+-------------~ ~-----------------i------------------i------------------~ i ! ! i ! ¡ ! ! [----------,-------------¡---------"----, r-----.._----------t-----------------r--------------, I I I I I I I I r------------1---------------r------"-------1 ¡---------------t----..------------ I I t------------i------------+--------------~ ¡ ¡ ----------------- i ¡ ! ! ! ! ! SHUT IN TIME! I i [==~~=~~~~J~===~=I~~~=~~~==~] [=~Q~Q~!!!~~=J~=~~~~~~~===~~~~L~~?~~Qgg~~f] i ! ! ¡ ¡ 1.0 min i ¡ 1,930 psi ¡ t----------------1-----------+-------------1 t----------~----t----------------r-----"--------.-"1 I I : : I 2.0 mln I : 1,910 pSI: . . . . .----------------J-----------------'-------------------f ! 3.0 min ! ! 1,910 psi! ~~~=§~g~!!![~~~~l~~~=~~~~~~~~~~~~~r1~~~~~R~!~~~ ~---_!.Q;Q_I!!!!l----¡-----------------~--_!!~~~ ps.!_~ ! 15.0 min i i 1,870 psi! r--2õ~õ-ñifn-T------------T--i~ã6õpsi-l r--2S:-õ-ñïfn-T----------------r-1~ã6õpsr-l t=~Q~Q~!!!~~~~~r~=~~=~~~~~~~==t=1~~~~£~CJ L---------------..-..l....------..............-----1..-------------J ¡ ¡ ! ¡ I--------------f--------------'l----------------; , , I ' ~------------------~------------------.--------------~ t~=~~~===~~~~=~I=~~~~~~==~=~~~[~=-~~=~~~=~~~~] ~HU!-~.!.~~L-------------~-'il!..!_!~-~~~~~Y-~E L_i>J!..!!l'!~--j-------______l__~~Q.p.~L_J ! 1.0 min i ! 430 psi! }--------+-----------+--------------I L-~Q.!n~--L--------l--_~~QJ?~L_-J L--~:P ~~--J------------L-_i~Q_.p~~---J ! 4.0 min ! ! 400 psi! r-------:----f------------+-----------.----I ~---~Q..I!l~--J-------------!----~Q.QJ?~---~ L--~~_rn~~_-J-----------.l--_!~_Q_.p~L_j 1 7.0 min .J.._____L__~!O psi___J ! 8.0 min ! ! 380 psi i .----------+---------+-------------1 ! 9.0 min ! ! 380 psi! [~~~~~!!!I~_J~=~~==~=~=I~=!?2~r] NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY .~~ ~~ ARCO Alaska, Inc. Daily Drilling Report AFC No. ¡Date RptNo I Rig Accept. hrs Days Since AccepVEst: 4.33 I Rig Relase . hrs: AK9485 11/07/98 5 11/03198 08:00:00 PM Well: 2L-325 Depth (MDrrvD) 500213486 Prev Depth MD: 2815 Progress: 2187 Contractor. DOYON Daily Cost $ 124889 Cum Cost $ 647972 Est Cost To Date $ Rig Name: DOYON 141 Last Csg: 7-518" @ 2799" Next Csg: 5-1/2" x 3-112" @ 9172' Shoe Test: 16.6 Operation At 0600: Drilling @ 5700' Camp/rig on hlghllne 24 hrs Upcoming Operations: Drill to td MUD DATA DRILLING DATA BIT DATA EH&S DRILLSfBOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOPIDRILL LSND 5002 2R1 N TST 11/04/98 11/07/98 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.1 PDQ 70 6.75 10128198 11/02/98 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 50sqc 90 HTC N SPACE 10/31/98 PV/yP SOWT TYPE TYPE TYPE FUEL & WATER 17 I 17 60 STR554 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 1000 6/81 1901317 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 1200 5.6 11/07/98 BBLS HTHP WL TRO BTM DEPTH IN DEPTH IN POTABLE WATER 97 ml/30 min 3000 2815 INJECTION USED - BBLS SOLIDS TRO OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER,& 6.0% 2187 2L-329 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADTIAST SOURCE WELL TEMP of 0 199bbl 2450 III 8.3 I .25 I 2L-325 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 0 12.5 1121 I 5 -15 3.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION ° 9.5 61611 60- 90 600 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR OF 0.00 6.0% 0170 I 1 Water Base Muds 1032 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 1 600 012961 I 131131131131 1 I I I 1 1 135 Diesel 160 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $13829 201401 1 0 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $65417 52511200 1 I I I 1 I 1 I 1327 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 10 BAROID 9.1 I I I I I I I 1 1 1557 PERSONNEL TOTAL 43 ¡fIM~ '.li';":SNP HØUB$ I. (Dpšcitit?é 1. FïØ8Sš~Øm ..'1 pjH!ss aÞs iF . '. .. ØâEß@1íI<>N~.¡R8ÖIýj.dÞöÖ.AQÖÔÖ 12:00 AM 01:00 AM 1.00 CIRC PROD Making Hole Clrc hole clean 01 :00 AM 02:00 AM 1.00 CASG PROD Making Hole R/U and test casing to 2000 psi for 30 min. 02:00 AM 04:00 AM 2.00 CLN_OUT PROD Making Hole Drill cmt, float equipment, and 20' new hole from 2670' -2835' 04:00 AM 04:30 AM 0.50 CIRC PROD Making Hole Displace contaminated mud wi new LSND mud 04:30 AM 05:00 AM 0.50 TEST PROD Making Hole Peñorm FIT to 16.6 ppg EMW@ 2835' md 2332' TVD. 05:00 AM 05:30 PM 12.50 DRIL PROD Making Hole Drill from 2835' to 4502' (3218' TVD) 05:30 PM 06:30 PM 1.00 CIRC PROD Making Hole Pump sweep-monitor well 06:30 PM 07:00 PM 0.50 WIPERTRP PROD Making Hole POOH to 2760' 07:00 PM 07:30 PM 0.50 CIRC PROD Making Hole Clrc slug out of hole 07:30 PM 08:00 PM 0.50 TEST PROD Making Hole Peñorm LOTto 14.5 ppg EMW 08:00 PM 08:30 PM 0.50 WIPERTRP PROD MakIng Hole RIH 08:30 PM 12:00 AM 3.50 DRIL PROD Making Hole Drill from 4502' to 5002' 24.00 Supervisor: G.R WHITLOCK Daily Drilling Report: 2L-325 11/07/98 Page 22 Casing Detajl 5-1/2" X 3-1/2" Production Casino WELL: TARN 2L-32S DATE: 11/11/98 1 OF 1 PAGES ARca Alaska, Inc. Su¡'sldlary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RT to LDS = 25.60 TOPS 5 1/2", LANDING JT. 34.0' OVERALL LENGTH 25.60 Casing landed with emergency slips 25.60 Jts. 1-202 5-1/2", 15.5# L-80, LTC MOD (202 joints) 8307.13 25.60 PUP 5-1/2", 15.5# L-80, LTC MOD 11.07 8332.73 Baker Csg Seal Receptacle (CSR), SIZE 80-40,5-1/2" x 4" 19.01 8343.80 XO 3-1/2" 9.3# L-80 8rd EUE X 5 1/2" EUE 8rd (XO) 1.00 8362.81 pup 3-1/2" 9.3# L-80 8rd EUE 10.06 8363.81 Jts.20-25 3-1/2" 9.3# L-80 8rd EUE (6 joints) 189.24 8373.87 pup 3-1/2" 9.3# L-80 8rd EUE (marker) 9.93 8563.11 Jts.4-19 3-1/2" 9.3# L-80 8rd EUE (16 joints) 505.00 8573.04 Weatherford Gemoco Float Collar 1.17 9078.04 Jts.1-3 3-1/2" 9.3# L-80 8rd EUE (3 joints) 94.94 9079.21 Weatherford Gemoco Float Shoe 2.13 9174.15 Bottom of Shoe @ 9176.28 ACTUAL TD= (9200') 24' RA THOLE. Bypass plug latch in receptical @ 9046.40'. (top of jt. #4) (25) 3-1/2" x 6-1/2" straight blade centralizers(Jts.1-25) (12) 5 1/2" x 63/4" bow spring centralizers (Jts.1-12) . (16) 5-1/2" x 8-1/4" centering guidess on jts Jts.146,149,152 155,158,161,164,167,170,173,176,176,182,185,188, 191,194,197 Remarks: Strjßq]Veights with Blocks: 125k Up, 60K Dn, 8K Blocks. Ran 25 Joints 3-1/2" and,;!(J2 Joints of 5-1/2" casing. Drifted 5.5" (4.75")& 3.5" (2.867") casing with plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections. .'Casing is non-coated. Doyon 141 Drilling Supervisor: D.P.BURLEY ~~ .~" ARCO AI k C f D t 1 as a, nc. ernen Ing e als Well Name: 2L-325 Report Dale: 11/12/98 Report Number: 10 Rig Name: DOYON 141 AFC No.: AK9485 Field: Casing Size Hole Diameler: Angle Ihru KRU: Shoe Deplh: LC Deplh: % washout: 5-112" x 3-112" 6.75 9176 9049 Centralizers State type used, intervals covered and spacing Comments: Detailed on casing tally. Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 9.8 20 16 18 14 Gels before: Gels after. Tolal Volume Circulated: 7/9 4/5 550 Wash 0 Type: Volume: Weight: Commenls: ARCO Wash 20 8.5 Spacer 0 Type: Volume: Weight: Comments: ARCO 40 11.5 Lead Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Commenls: Additives: Tall Cement 0 Type: Mix wtr lemp: No. of Sacks: Weight: Yield: Commenls: G 70 240 15.8 1.2 Batch mixed Additives: 2 gps D600, 0.1 gps D135, 0.1 gps D47, 3% D53, 0.8% D65, 0.12% D800 Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): SIr. WI. Up: Comments: 4.5 4.0 125 Reciprocation length: Reciprocalion speed: SIr. WI. Down: 25 15 fpm 60 Theorelical Displacement: Actual Displacement: SIr. WI. in mud: 205.1 207.5 Calculated top of cement: CP: Bumped plug: Floals held: 7863 Date:11-11-98 yes yes Time:1828 hrs. Remarks:Staged up pumps until! full returns @ 4 bpm, pumped 5 bbls of fresh water, 20 bbls of wash, 40 bbls of spacer and 51 bbls of cement. Flushed lines clean with 7 bbls of fresh water, displaced with 10 bbls of fresh water and 197.5 bbls of seawater. Used newly modified Weatherford wiper plugs.(flrst time) Reciprocated pipe unUII spacer at shoe, pipe stuck suddenly, 3' off bottom. Cement Company: Rig Contractor: Approved By: DS DOYON D.BURLEY ~~ ~" ARCO Alaska, Inc. Daily Drilling Report AFC No. I Date RptNo I ;i9 Accept - hrs Days Since Accept/Est: 8.33 / 8.2 Rig Relase - hrs: AK9485 11/11/98 9 11/03198 08:00:00 PM Well: 2L-325 Depth (MDrrvD) 9200/5598 Prev Depth MD: 9200 Progress: 0 Contractor. DOYON Dailv Cost $ 224033 Cum Cost $1244343 Est Cost To Date $ 1100000 Rig Name: DOYON 141 Last Csg: 5-112 x 3-112" @9176 Next Csg: Shoe Test: 16.6 Operation At 0600: Running 3-112" Completion. Upcoming Operations: Finish completion, move rig. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LSND R3 N TST 11/10198 11/07/98 WEIGHT ROTWT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.8DDO 6.75 1 <V28198 11/09/98 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 45sqc STC N SPACE 10131/98 PV/yP SOWT TYPE TYPE TYPE FUEL & WATER 16/14 FDS GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 1600 4/5/ LP9142 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 210 5.2 9200 11/11/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 111 ml/30 min 9200 INJECTION USED. BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 9.0% 0 2L-329 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of 0 207bbl 2300 III % / 2L-325 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 0 12.5 1121 I 0- 2.3 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 0 9.0 61611 80 - 475 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 0.00 6.8% 01 I I open Water Base Muds 1053 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 1 0 1 I I I I 1 I I I I I 1 1 45 Diesel 30 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $875 I I I 0 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $110469 I I I 2121WTG I 1 I 1128 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 11 BAROID I I I E 11 1 ER I TD I 1 I 5733 PERSONNEL TOTAL 44 . TIME ....1...".........,'."6&0 HØ1J!i!S. . (I øeS:êøPà. I . H(¡)lliS$~cm. .'.'IRHAŠS"\1:)§s T .. '!5.¡¡¡Sa@ÎlÍIi:!mSI8i3!ÞMIöØÖÖ'P'OÖÖQ 12:00 AM 02:00 AM 2.00 TRIP_OUT PROD Making Hole PJSM. Laid down 4" drill pipe, hwdp and dc's. 02:00 AM 03:30 AM 1.50 RUN_CSG PROD Casing and Pulled wear bushing, rig up casers, held safety meeting Cementing with GBR and rig crew. 03:30 AM 07:30 AM 4.00 RUN_CSG PROD Casing and Run 3-1/2" and 5-1/2" casing to 3500'. Cementing 07:30 AM 08:00 AM 0.50 CIRC PROD Casing and Circ BU @ 5 bpm, full returns. Cementing 08:00 AM 10:15 AM 2.25 RUN_CSG PROD Casing and Run 5-1/2" casIng to 6377'. Cementing 10:15 AM 11:30 AM 1.25 CIRC PROD Casing and Clrc BU @ 2.5 bpm, 80% returns. Cementing 11:30 AM 02:00 PM 2.50 RUN_CSG PROD Casing and Run 5-1/2" casing, MU landing jt. and cement head. Cementing 02:00 PM 04:45 PM 2.75 CIRC PROD Casing and Circ and cond mud, Initial rate 2.2 bpm @ 380 psi, 70% Cementing returns, final rate 4 bpm @ 580 psi, full returns. Held safety meeting with cementers and rig crew. 04:45 PM 07:00 PM 2.25 CMT_CSG PROD Casing and Cemented casing as per program Cementing displaced with seawater. Plugs bumped; floats held. Casing stuck 3' high during displacement. Daily Drilling Report: 2L-325 11/11/98 Page 37 .107:00 PM 08:30 PM 1.50 CASG 08:30 PM 12:00 AM 3.50 CASG 24.00 PROD PROD Casing and Cementing Casing and Cementing MonItor slight flowback from well RD cement head and flushed surface lines and equipment. ND BOPE & removed tubing head spool. Prep to set slips on casing. Daily Drilling Report: 2L -325 11/11/98 Supervisor: D.P.BURLEY Page 38 CASING TEST and FORMATION INTEGRITY TEST Well Name: Date: 11n/1998 2L-325 Supervisor: G.R. Whitlock Casing Size and Description: 75/8",29.7 ppf, L-80, BMTC Casing Setting Depth: 2,300' TVD 2,799' TMD Mud Weight: 9.1 ppg EMW = Leak-off Press. + MW 0.052 x TVD Hole Depth: 3,218' TVD 650 psi + 9.1 ppg EMW LOT= (0.052 x 2,300') = 14.5 ppg Fluid Pumped = 0.8 bbl Pump output = 0.1000 bps ------ ~TIME LINE 2,300 psi ! I ! - lONE MINUTE 2,200 psi I I 2 100 psi ! l.1. ... I '- ! r I I 2,OOO~ I ~- : 1,900~ I II "'~.¡~ i 1.800~ i I Ii' 1,700~ I I i I I I 1,600~ i 8. I I 1,500 psi I I ! W 1.400psi 'I: I ~ 1.300~ I . i ! tJ) 1,200 psi ,; ! æ 1,100~ II ¡ I ; a: 1,OOOpsl i'I' I L ¡ i~, ---- -+-LEAK-OFF TEST l-----j Q, 900psi . .1 ..., -, - '/ -'-CASING TEST ' - , I I I ' .;l ~ 1)~-+,- LOT SHUT IN TIME ¡r-- 8OO~ Ii/, I .ð -ok-CASING TEST SHUT IN TIME ~ 700~ ,! 81t I V -+-TIME LINE - :: 'I Ll ¿¡.. 400 psi " I I 300 psi I I I '"'#", 200' Ð I I!! I 100: .P I I i I I Opsi !.II I I i I ! 0 sll< 6 sll< 13 sll< 19 sll< 26 sll< 32 sll< 38 sll< 45 sll< 51 sll< 58 sll< 64 sll< 70 sll< 77 sll< 83 sll< 90 sll< STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR FIT STROKES PRESSURE CSG TEST STROKES PRESSURE [~~--==~~-=J~~___Qi~~~-=I=--=Q~R~I~=~] C=~~=~~~~=~~~~~[~~~=~~~~=~==~I=~~==~=~~~~~J ! i 1 stks i 30 psi! ! ! 0 stks ! 0 psi ! [~==~:-==[=!!~kS _~I=~2~iC~] [~~~~~~~~~~~~~~~~J~~=I!~!=~~~[~~=~~~r=J ~----------~---~!k.!_--!-..1!.QJ?_~L_j L--------------l-----!!_~!~~----+-_.i?'QJ?_~~--J ! i 4 stks ! 270 psi! ! i 6 stks I 850 psi! r---""-----'--------i--"----.---' i--------..--..----t----------------"""-----------"-:--' I I 5 stks I 380 pSI I I I 8 stks I 1 ,250 pSI I ¡---------¡---6Stkš--r-4sõ-pšT--1 !------------------r---fosiks-.-!--:¡~54õ-PšT-1 .-------------1--------------+---------------1 r-----------------i-----------------'¡---------------- L----------.J--_..?_!.~~!_--1-~~Q_P~----Jl 0 fð---------------L-___1~_~~~!.---L-~!~--~~_e~L-1 ! ! 8 stks i 630 psi ¡,! ! ! t-------------1-------------t"'---------.----1 -3--tP---------------t-------------------r----------------1 I : 9 stks I 650 pSI I I I I I [-===F~~:t;:=:t~~~Ji ~====:==E:=~~=:~E=:==:] ! ! 20 stks ! 470 psi ¡ ! ! I ¡ C---=~==-~l=~I[ši-k~=t---~~Ë~---J C=~~~~~~~~~=~~=t~~~~~=~~~~~~~=~~t~=~=~~~~=~~=J ! ! 30 stks ! 450 psi! ! ! ! i [==--==-_~-=I=~!š-š~k~_Li~~~~T=J [=~~~~~~=~~~~~~~[~~~~~=~=~~~~=~[~~~~=~~~~=~~=] ! ! 40 stks ! 390 psi! ! ! ! ! t----------t--------------t-----------i t------------------t---------------t----------------- I I I I I I I I r----""---------'-------""-----¡-------------' r-----------------T"--------------"-"-~------------------, I I I I I I I I t-------------1----------------t"'------------------1 t------------------t------------------- . I ~--------~------------¡.-------------~ i 1------------------1 i r----===-~=~J==~~~--==~=t--===~~~~~~~j [==~~~~I~==f~~=~=~~~~~=~=~~~t~~~~~Q22~P'~[~j ! ! ! ! ¡ 1.0 min ¡ i 1,930 psi! t--------i---------+---------------t t------------:------t------------------t---------------:---f I I I I I 2.0mln I I 1,910 pSI : I I ~--------------i-------------'¡-----------------I i SHU!J~.!)-~~L---~~(}_!J~ P~~~~~~E L.--~Q_!!!~~----L------__m_------L-1!~~_~_e~1.J ! 0.0 min ! i 390 psi! i 5.0 min ! ! 1,890 psi! r--"1-:-Õ- min---r---------¡--36õ-pšT--1 !--1Õ~Õ-miñ--¡------------!-:¡~ã-ãõ-pši-1 .------i-------------+---------------I ~------------------I---------------'¡------------------ ! 2.0 min ! ¡ 340 psi! ! 15.0 min ¡ ! 1,870 psi! r-S:-õ-ñiiñ---r----------¡----340-pš-r--l r---2õ~õ-ñ'-fñ----I------------------T--:¡~ã6õr)šr-l r---¡:oñïinl------------!33Õ--pš-i-1 r--25:õ-miñ--T----------m--1--:¡~ä6Õr)-šr-1 r---Š-.Oñiin-r-------------r---33Õ--Pš-r--1 t---:3õ:õ-ñifñ--r-----------------r--:¡~ã6õ-pši-1 C~fQ~mTñ-]=-~~==--==r=-33~Ë~~r] [~=~~~=~~~~~~~=]~~=~~~~~~~~=~~=~~[~=~~~=~=~~~~] I 7.0 min ! ! 330 psi! ¡ I I ¡ '--------1----------------""----------------_"& ---------------------t-----------------+-----------------' ¡ 8.0 min I ¡ 320 psi! ! I : ¡ }------i--------------+--------------I ~----------------i----------------'¡--_._----------I ! 9.0 min ! ! 320 psi! I ! ¡ ! [J_O'O_!!1~---[~~~===~~I___1?:Q~Ë~I~] t==~~~=~~~~=]~~~~~~~=~~~=~~~~~~[~~~~~~~~~~~~~~~~~~] NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount, Commissioner Blair Wondzell, P. I. Supervisor FROM: John Crisp,~//,/u~ C,, SUBJECT: Petroleum I~pector DATE: July 20, 2000 Safety Valve Tests Kuparuk River Unit Tarn Field 2N & 2L Pads July 20, 2000: I traveled to Phillips Alaska's Kuparuk River Unit Tarn Field to' witness the semi-annual Safety Valve System tests on Pads 2N & 2L. Testing went well with only one failure on 2L Pad witnessed. No failures were witnessed on 2N Pad. The AOGCC test report is attached for reference. SUMMARY: I witnessed the semi-annual SVS tests on KRU's Tarn Pads 2N & 2L. 2N Pad, 9 wells, 18 components tested. No failures. 2L Pad, 6 wells, 12 components tested. I failure. 8% failure rate. Attachments: SVS Tarn KRU 2N & 2L 7-20-00jc CC,; NON-CONFIDENTIAL SVS Tarn KRU 2N & 2L 7-20-00jc.doc Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: Ernie Bamdt AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Tam, Kupamk River, 2N Separator psi: LPS 94 HPS 7/20/00 Well Permit Separ Set L~ Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GASor i 2N-307 1990170 2N-308 1990100 94 70 65 P P OIL 2N-309 1990210 2N-313 1980910 94 70 70 P P OIL 2N-315 1981900 2N-317 1981430~ 94 70 70 P P OIL 2N-319 1981970 2N-320 1990010 94 70 65 P P O~ 2N-321A 1981730 2N-323 1980710 94 70 70 P P OIL 2N-325 1981630 2N-329 1980670 94 701 70 p p OIL 2N-331 1981170 2N-335 1982040 94 70 70 P P OIL 2N-337A 1981220 2N-339 1981000: 2N-341 1981030 94 70 65 P P OIL 2N-343 1980920 2N-345 1981130 2N-347 2000630 94 70 60 P P OIL Wells: 9 Components: 18 Failures: 0 Failure Rate: 0.0% [] 90 Day Remarks: Page 1 of 1 SVS Tam KRU 2N 7-20-00jc.xls Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: Emie Barndt AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Tam, Kupamk River, 2L Separator psi: LPS 94 HPS 7/20/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 2L-305 1982400 94 70 60 P 4 OIL ,2L-307 1982560 94 70 70 P P OIL 2L-313 1982190 94 70 65 P P OIL 2L-315 1982180 94 70 70 P P OIL 2L-321 1982620 2L-323 1982510 ~3~5-.ii ~'', 1982090 94 70 65 P P OIL 2L-329A 1982250 800 700 700 P P GAS Wells: 6 Components: 12 Failures: 1 Failure Rate: 8.0% Remarks: 7/27/00 Page 1 of 1 SVS Tam KRU 2L 7-20-00jc.xls ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 24, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Revised Kuparuk Area Annular Injection, Fourth Quarter, 1999 Dear Ms. Mahan: RECEIVED Oil & C~a$ ," ,, ~chorage Please find reported below the volumes injected into surface casing by production casing annuli during the fourth quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the fourth quarter of 1999. Annular bzjection during the fourth quarter of 1999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CD1-37 15214 100 0 15314 17273 32587 CD1-39 27391 100 0 27491 4017 31508 1D-12 27089 100 0 27189 5702 32891 CDI-16 28925 100 0 29025 0 29025 CD1-32 7449 100 0 7549 0 7549 CD1-03 285 100 0 385 0 385 CD1-42 287 100 0 387 0 387 CD1-40 20 0 0 20 32649 , 32669 CD1-45 274 100 0 374 0 374 CD1-36 293 100 0 393 0 393 CD1-35 217 100 0 317 I 0 317 CD1-23 20 0 0 20t 17085 [ 17105 CDI-13 89 100 0 189 0 . 189 CD1-01 20 0 0 20 5201 t 5221 I Total Volumes into AnnuIi for which Injection Authorization Expired during the fourth quarter I Total I Total h(1) Total h(2) Total h(3) [ Volume Well Name Volume Volume Volume , Injected Status of Annulus I 2N-315 25326 100 0 25426 Open, Freeze Protected 2L-329A 33971 100 0 i 34071 Open, Freeze Protected 2L-325 20280 100 0 I 20380 Open, Freeze Protected I 2L-313 12433 100 0 [ 12533 Open, Freeze Protected Ms. Wendy Mahan AOGCC Fourth Quarter 1999 Annular Injection Report Page Two Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Momson and Winfree Sharon Allsup-Drake Well Files ARCO Alaska, Inc. Post Office Box-~-.~0360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 April 9, 1999 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, First Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the first quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the first quarter of 1999. Annular Injection during the first quarter of ! 999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-315 25326 100 0 25426 See Note #~ belo,; 25426 2L-325 8397 100 0 8497 11883 20380 2N-321A 27507 100 0 27607 0 27607 3K-23 15 0 [ 0 15 0 15 3K-25 4202 100 0 4302 0 4302 1 C- 15 16695 100I 0 16795 0 16795 2L-313 8554 100 ] 0 8654 0 8654 .Vote #1: Well # 2N-315. The previously regorted volume of 220 barrels was pumped into this annulus during the drilling of the well. This was the vtdutne required to Jlttsh and freeze protect the atmulus during initial drilling operations, not a w~lume of disposal fluids injected prior to the receipt of authorization .[?~r annular injection. Total Volumes into Annuli for which bzjection Authorization Expired during the quarter Total I Total h(1) Total h(2) Total h(3) Volume I Well Name Volume Volume Volume Injected , Status of Annulus 1C-12 34995 100 0 35095 I Open, Freeze Protected 1 C- 13 26800 100 0 26900 I Open, Freeze Protected Additionally, to prevent any possible confusion regarding previous reports of volumes injected, and to insure that the State's records are in agreement with ARCO's, we would like to repeat and supplement information we provided with our letter of February 26,1999. The information below is only for those wells for which injection volumes may not have been properly reported at the time of injection. Again, these volumes are the same as those reported with our February 26th letter, and are only reported here again for the sake of clarity. ARCO Alaska. inc. ts a Subsidiary of Atlantic Richfield Company AR3B-6003-C Ms. Wendy Mahan AOGCC First Quarter 1999 Annular Injection Report Page Two . Total Total h(1) Total h(2) Total h(3) Volume Current Status of Well Name Volume Volume , Volume Injected Annulus 2A-22 16749 100 i 0 16849 Open, Freeze Protected 2F-19 20725 100 0 20825 ] Open. Freeze Protected 3K-27 37173 100 I 0 37273 Open, Freeze Protected 3K-26 33970 100 0 34070 Open, Freeze Protected 1E-31 33645 100 0 33745 [ Open, Freeze Protected 1E-32 45205 100 0 45305 Open, Freeze Protected 3Q-22 6245 100 ] 0 6345 Open, Freeze Protected 1Q-24 23158 100 [ 0 23258 Open, Freeze Protected [ 1Q-26 25931 [ 100 ] 0 26031 Open. Freeze Protected Please call me at 263-4603 should you have any questions. Sincerelv. Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Morrison and Winfree Sharon Allsup-Drake Steve McKeever Well Files ARCO Alaska, Inc. ..._l Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 20, 1999 RECEIVED J'AN 22 19.99 /~aska Oil & Gas Cons. Commission Anchorage Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2L-325 (Permit No. 98-209) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 2L-325. If there are any questions, please call 263-4603. Sincerely, Drilling Team Leader AAI Drilling PM/skad STATE OF ALASKA . ~_ASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL E~] GAS E~ SUSPENDED [~ ABANDONED--] SERVICE r~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-209 3Address 100360, Anchorage,~ L~ ~.~ ~ V .. .¢= ¢.~ ,,_ ,. __~.~. 8 APlNumber P.O. Box AK 99510-0360 ~. 50-103-20275 4 Location of well at surface. . : ¢ ~ ~ ~ -~ 9 Unit-or Lease Name 218' FNL, 865' FEL, Sec. 22, T10N, R7E, UM ~/'~'~'i "~"~'' ~ '~~] Kuparuk River Unit At Top Producing Interval i 10 Well Number :7 ~ o~ ~ 2L-325 At Total Depth 0~f~ ~8 i~11 Field and Pool 232' FNL, 2287' FEL, Sec. 26, T10N, RTE, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. Tarn Oil Pool RKB 28', Pad 117' ADL 380055 ALK4601 12 Date04_Nov_gsSpUdded 13 Date10-Nov-98T'D' Reached ~4 Date12-Nov-98Comp', Susp. or Aband. 15 WaterNADepth, i~ offshorefeet MSL 16 No. l°f Completions 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 9200' MD & 5695' TVD 9049' MD & 5614' TVD YES M NO U N/A feet MD 1050 APPROX 22 Type Electric or Other Logs Run GR/Res, CCL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF. 108' 24" 9 CY High Eady 7.625" 29.7# L-80 SURF. 2799' 9.875" 371 sx ASIII & 235 sx Class G 5.5" x 15.5# L-80 SURF. 8363' 6.75" 240 sx Class G 3.5" 9.3# L-80 8363' 9176' 6.75" (included above) 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 8360' 8344' (CSR) 8550'-8590' MD 5340'-5363' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8550-8590' Pumped 229,294# prop (18000# 20/40 & 211,294# 12/18) w/10.4# ppa in perfs, 224,676# behind pipe 27 PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) ~ ~J8/98I Flowing Date of Test Hours Tested PRODUCTION FOI~OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO ~2J20/98 11.00 TEST PERIOD 617 863 0 176 1398 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 300 0 24-HOUR RATE: 1346 1882 0 38° 28 CORE DATA .Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ORIGINAL 9. " -' 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T-3 8510' 5318' T-2 8727' 5437' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ' - "/ ' ~J~-'~ Prepared by Name~umber Sharon 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 12/7/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2L-325 WELL ID: AK9453 TYPE: -- AFC: AK9453 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:il/04/98 START COMP: RIG:RIG % 141 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20275-00 11/03/98 (D1) TD: 108' (108) SUPV:G.R WHITLOCK 11/04/98 (D2) TD: 1513' (1405) SUPV:G.R WHITLOCK 11/05/98 (D3) TD: 2815' (1302) SUPV:G.R WHITLOCK 11/06/98 (D4) TD: 2815' ( 0) SUPV:G.R WHITLOCK 11/07/98 (D5) TD: 5002' (2187) SUPV:G.R WHITLOCK 11/08/98 (D6) TD: 7261' (2259) SUPV:G.R WHITLOCK 11/09/98 (D7) TD: 9200' (1939) SUPV:G.R WHITLOCK MW: 8.3 rISC: 28 PV/YP: 0/ 0 DRILLING CAMP/RIG ON HIGHLINE 4-1/2 HRS APIWL: 0.0 Move rig from 2L-329 to 2L-325. Accept rig at 2000 hrs. 11/3/98. N/U diverter system. MW: 10.0 VISC: 79 PV/YP: 25/34 APIWL: 4.8 DRILLING @ 2010' CAMP/RIG ON HIGHLINE 24 HRS Function test diverter. Drill' from 108' to 1513' MW: 10.2 rISC: 62 PV/YP: 28/26 APIWL: 5.2 CEMENTING SURFACE CASING CAMP/RIG ON HIGHLINE 24 HRS Drill from 1513' to 2815' Run 7-5/8" casing. MW: 9.1 VISC: 46 PV/YP: 14/15 APIWL: 8.8 DRILLING 2860' CAMP/RIG ON HIGHLINE 24 HRS Run 7-5/8" casing. Pump cement. Test BOPE to 250/3500 psi. MW: 9.1 VISC: 50 PV/YP: 17/17 APIWL: 5.6 DRILLING @ 5700' CAMP/RIG ON HIGHLINE 24 HRS Drill cement, float equipment, and 20' new hole from 2670' to 2835' Perform FIT to 16.6 ppg EMW. Drill from 2835' to 4502'. Perform LOT to 14.5 ppg EMW. Drill from 4502' to 5002' MW: 9.1 VISC: 48 PV/YP: 15/16 APIWL: 6.4 DRILLING @ 6750' CAMP/RIG ON HIGHLINE 24 HRS Drill from 5002'-7261' MW: 9.8 VISC: 48 PV/YP: 17/17 APIWL: 4.8 WIPER TRIP 9200' CAMP/RIG ON HIGHLINE 24 HRS Drill from 7261' to 9019' Date: 12/7/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 11/10/98 (D8) TD: 9200'( 0) SUPV:D.P.BURLEY 11/11/98 (D9) TD: 9200' ( 0) SUPV:D.?.BURLEY 11/12/98 (D10) TD: 9200' ( 0) SUPV:D.P.BURLEY MW: 9.8 VISC: 50 PV/YP: 18/18 RUNNING 3-1/2" X 5-1/2" PRODUCTION CASING. APIWL: 4.4 Drill from 9019' to 9200' TD. MW: 9.8 VISC: 45 PV/YP: 16/14 RUNNING 3-1/2" COMPLETION. APIWL: 5.2 Run 3.5" and 5.5" casing. Cement casing. Casing stuck 3' high during displacement. Monitor slight flowback from well. MW: 8.5 VISC: 28 PV/YP: 0/ 0 RELEASED RIG @ 1800 HRS. APIWL: 0.0 NU BOPE and test to 250-3500 psi. Run 3.5" completion. Freeze protect well. ND BOPE and install master valve and test to 5000 psi. Release rig @ 1800 hrs. 11/12/98 ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~, WELL SERVICE REPORT '~ K1(2L-325(W4-6)) WELL JOB SCOPE JOB NUI~IBER " 2L-325 FRAC, FRAC SUPPORT 1116980847.14 DATE DAILY WORK UNIT NUMBER 11/25/98 FRAC DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 2 YES YES DS-YOKUM KRALICK FIELD AFC# CC# Signed ESTI MATE K85109 180KN U2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 40 PSI 50 PSI 0 PSI 500 PSI 0 PSII 0 PSI DAILY SUMMARY PUMPED BRACKET FRAC AND 229,294# PROP (18,000# 20/40 & 211,294# 12/18) W/10.4# PPA IN PERFS - 224,676# BEHIND PIPE AFTER 64.5 BBL DIESEL FLUSH W/SAND LEVEL @ 8033' - 2620 PSI CALCULATED BHP - DATAFRAC ISlP 920 PSI - 3074 PSI CLOSURE PRESSURE - MAX PRESS 7200 PSI DURING BREAKDOWN[Frac-Refrac] TIME LOG ENTRY 08:00 MIRU DS - TGSM BLOWING SNOW 09:30 PFF HARD LINE AND SURFACE EQUIP TO 10,000 PSI 09:32 BREAKDOWN 100 BBLS WATER W/MAX PRESSURE @ 7200 PSI - PUMPED JOB PER A~-FACHED DETAIL REPORT 10:07 SCOUR STAGES @ 1 PPA AND 2 PPA 20/40 SAND USING X-LINKED GEL 11:40 13:06 13:44 15:09 DATAFRAC AND FLUSH ISIP 920 PSI - REDESIGN JOB AND ADD PAD (12.5 MIN CLOSURE TIME) BRACKET FRAC 332 BBLS USING WF-20 PRE PAD WATER AND PAD (WF-20) 800 BBLS TOTAL PUMPED SAND FROM 2 PPA (20/40) TO 10.4 PPA (12/18 FROM 2# UNTIL 10#) - CONTINUED TO PUMP UNTIL OUT OF PROP ON LOCATION - 229,294# W/224,676 IN PERFS - 4618# IN PIPE W/SAND LEVEL APPROX. 8033' 16:29 FLUSH W/64.5 BBLS DIESEL AND SHUTDOWN @ 6000 PSI 18:00 RDMO DS - INFORMED OPERATOR- ALL TREE SAVER RUBBERS RETURNED ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '' K1(2L-325(W4-6)) WELL JOB SCOPE JOB NUI~IBER ' " 2L-325 PERFORATE, PERF SUPPORT 1119981544.5 DATE DAILY WORK UNIT NUMBER 11/21/98 PERFORATE 2128 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 YES YES SWS-ELMORE LIGENZA FIELD AFC# CC# Signed ESTIMATE K85109 180KNU2TL Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY I PERFORATED FROM 8550' TO 8590', 180 DEG PHASED, ORIENTED 170 DEG CCW FROM HIGH SIDE OF HOLE W, 2-1/2' HC, BH, 4 SPF.[Perf] TIME LOG ENTRY 10:00 MIRU SWS/HOT OIL.. TGSM DISCUSS SIMULTANEOUS OPERATIONS W/RIG. LATEST SAFETY BULLETINS. 11:00 PT LUBE / BOPS TO 3000 PSI. WAIT ON DSO TO PUMP OPEN SSV. 11:45 PT TUBING / SHOE TO 2500 PSI. 12:15 THIRTY MINUTE TEST. ZERO PRESSURE LOSS. RIH W/CCL/GR/WT BAR TO LOG PERF INTERVAL. 13:00 LOG FROM TD AT 9011' TO 8150'TIE IN. POH. 15:20 RIH W / ROLLERS, CCL, MPT SET AT 170 DEG CCW FROM TOP. 20' X 2-1/2" HC 180 DEG PHASE. CCL 6.7' FROM TOP SHOT. LOST CCL SIGNAL AT APPROX. 7,000'. POH. 17:00 REPAIRED CCL. RIH W/SAME LESS SWVL. 5.5' FROM CCL TO TOP SHOT. 18:10 LOCATE AT 8564.5' TO PLACE TOP SHOT AT 8570. CHECK WELL HEAD PRESSURE. BUMP UP TO 200 PSI. NO INDICATION OF SHOT FIRED. 2 ATTEMPTS, POH 20:00 REPLACED HEAD. RIH W / CCL. 4.5' FROM CCL TO TOP SHOT. 21:00 LOCATE AT 8565.5' TO PLACE TOP SHOT AT 8570'. BUMP UP WH PRESSURE TO 200 PSI. INDICATION SHOTS FIRED. PRESSURE DROPPED TO 100 PSI. LOG UP. POH. 22:00 RIH W / SAME. 4.5' FROM CCL TO TOP SHOT. LOCATE AT 8545.5 TO PLACE TOP SHOT AT 8550'. TUBING PRESSURE 0 PSI. INDICATION SHOTS FIRED. LOG UP, POH. 23:00 ON SURFACE, ALL SHOTS FIRED. RDMO SWS. FINAL TUBING PRESSURE 0 PSI. SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-02024 Sidetrack No. Page 1 of 5 I Company ARCO ALASKA, INC. Rig Contractor & No. DOYON - #141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2L/325 Survey Section Name Definitive Survey BHI Rep. L. HENSLEY/K. CHRISTENSEN ~Jlllrr~=~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -218.46 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SSO Target Description Target Coord. E/W Slot Coord. E/W -864.82 Magn. Declination 26.810 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft~[ 30m~ 1Omo Vert, Sec. Azim. 143.68 Magn. to Map Corr. 26.810 Map North to: OTHER · SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FO (DD) (DD) (FT) (FO (F'r) (FI') (Per 100 F'r) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT -- 04-NOV-98 MWD 127.36 0.91 222.20 127.36 127.35 0.20 -0.75 -0.68 0.71 0.71 04- N 0V-98 MWD 218.21 1.21 218.98 90.85 218.19 0.59 -2.03 -1.77 0.34 0.33 04-NOV-98 MWD 309.27 1.32 220.95 91.06 309.23 1.06 -3.57 -3.06 O. 13 O. 12 04-NOV-98 MWD 402.75 0.97 210.50 93.48 402.69 1.61 -5.06 -4.17 0.43 -0.37 04-NOV-98 MWD 498.09 0.49 200.99 95.34 498.02 2.15 -6.14 -4.72 0.52 -0.50 04-NOV-98 MWD 583.29 0.72 208.35 85.20 583.22 2.58 -6.95 -5.11 0.28 0.27 04-NOV-98 MWD 673.99 0.59 204.81 90.70 673.91 3.05 -7.88 -5.57 0.15 -0.14 04-NOV-98 MWD 763.61 1.52 174.05 89.62 763.51 4.29 -9.48 -5.64 1.18 1.04 04-NOV-98 MWD 854.63 6.10 147.18 91.02 854.31 10.17 -14.75 -2.90 5.27 5.03 -29.52 04-NOV-98 MWD 943.97 9.04 146.08 89.34 942.86 21.92 -24.56 3.59 3.29 3.29 -1.23 04-NOV-98 MWD 1035.78 11.62 150.32 91.81 1033.18 38.31 -38.58 12.20 2.93 2.81 4.62 04-NOV-98 MWD 1126.68 13.62 152.73 90.90 1121.88 57.98 -56.05 21.64 2.27 2.20 2.65 04-NOv-98 MWD 1215.80 16.11 153.62 89.12 1208.01 80.52 -76.46 31.94 2.81 2,79 1.00 ~!' ,, -- · 04-NOV-98 MWD 1308.66 18.28 154.74 92.86 1296.72 107.51 -101.17 43.88 2.36 2.34 1.21 04-NOV-98 MWD 1401.20 20.34 157.02 92.54 1384.05 137.40 -129.11 56.35 2.37 2.23 2.46 04-NOV-98 MWD 1500.22 22.51 155.62 99.02 1476.22 172.70 -162.22 70.90 2.25 2.19 -1.41 05- NOV-98 MWD 1591.99 24.86 152.69 91.77 1560.26 208.94 -195.37 87.00' 2.86 2.56 -3.19 05- N 0V-98 MWD 1685.89 28.85 148.46 93.90 1644.02 251.03 -232.23 107,92 4.71 4.25 -4.50 -- 05-NOV-98 MWD 1779.36 33.28 145.44 93.47 1724.07 299.17 -272.59 134.28 5.02 4.74 -3.23 -- 05-N 0V~98 MWD 1873.19 39.61 143.71 93.83 1799.51 354.87 -317.95 166.62 6.83 6.75 -1.84 05-NOV-98 MWD 1967.85 46.91 143.91 94.66 1868.40 419.69 -370.27 204.89 7.71 7.71 0.21 05- N 0V-98 MWD 2056.55 51.43 144.09 88.70 1926.38 486.79 -424.56 244.33 5.10 5.10 0.20 05- N 0V-98 MWD 2151.37 56.70 142.76 94.82 1982.01 563.53 -486.17 290.08 5.67 5.56 -1.40 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-02024 Sidetrack No. Page 2 of 5 Company ARCO ALASKA, INC. Rig Contractor & No. DOYON - #141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2L/325 Survey Section Name Definitive Survey BHI Rep. L. HENSLEY/K. CHRISTENSEN jrjllllrr~~ WELL DATA Target TVD (F'r) Target Coord. N/S Slot Coord. N/S -218.46 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~- Target Description Target Coord. E/W Slot Coord. E/W -864.82 Magn. Declination 26.810 Calculation Method MINIMUM CURVATURE Target Direction (DE)) Build\Walk\DL per: 100ft~ 30mD 10mQ Vert. Sec. Azim. 143.68 Magn. to Map Corr. 26.810 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (-I-) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 05-NOV-98 MWD 2244.56 59.29 143.61 93.19 2031.40 642.55 -549.44 337.42 2.88 2.78 0.91 . 05-NOV-98 MWD 2339.21 59.67 142.97 94.65 2079.46 724.08 -614.80 386.16 0.71 0.40 -0.68 05-NOV-98 MWD 2432.64 59.82 143.51 93.43 2126.54 804.78 -679.46 434.46 0.52 0.16 0.58 05-NOV-98 MWD 2522.01 59.25 143.77 89.37 2171.85 881.81 -741.49 480.13 0.69 -0.64 0.29 05-NOV-98 MWD 2708.61 59.35 143.90 186.60 2267.12 1042.26 -871.02 574.81 0.08 0.05 0.07 07-NOV-98 MWD 2826.91 59.73 143.12 118.30 2327.09 1144.23 -953.00 635.46 0.65 0.32 -0.66 07-NO¥-98 MWD 2919.49 60.38 143.05 92.58 2373.30 1224.45 -1017.14 683.64 0.71 0.70 -0.08 07-NOV-98 MWD 3015.13 58.81 142.78 95.64 2421.70 1306.93 -1082.94 733.38 1.66 -1.64 -0.28 07-NOV-98 MWD 3109.77 58.87 141.66 94.64 2470.67 1387.88 -1146.95 782.99 1.01 0.06 -1.18 07-NO¥-98 MWD 3202.66 58.68 142.56 92.89 2518.83 1467.29 -1209.64 831.77 0.85 -0.20 0.97 07-NOV-98 MWD 3297.51 58.84 142.50 94.85 2568.02 1548.37 -1274.00 881.11 0.18 0.17 -0.06 07-NOV-98 MWD 3392.01 58.83 142.30 94.50 2616.92 1629.21 -1338.07 930.44 0.18 -0.01 -0.21 07-NOV-98 MWD 3486.58 59.22 142.24 94.57 2665.60 1710.27 -1402.20 980.06 0.42 0.41 -0.06 07-NOV-98 MWD 3580.64 57.54 142.23 94.06 2714.91 1790.33 -1465.51 1029.11 1.79 -1.79 -0.01 07-NOV-98 MWD 3672.47 57.42 141.66 91.83 2764.28 1867.73 -1526.48 1076.84 0.54 -0.13 -0.62 07-NOV-98 MWD 3765.47 57.45 143.20 93.00 2814.34 1946.09 -1588.61 1124.63 1.40 0.03 1.66 07-NOV-98 MWD 3859.62 57.46 141.67 94.15 2864.99 2025.43 -1651.51 1173.02 1.37 0.01 -1.63 07-Nov-98 MWD 3953.75 56.62 142.72 94.13 2916.20 2104.38 -1713.91 1221.43 1.29 -0.89 1.1 2 07-NOV-98 MWD 4048.40 56.99 143.41 94.65 2968.02 2183.58 -1777.22 1269.02 0.72 0.39 0.73 07-NOV-98 MWD 4140.48 56~99 142.80 92.08 3018.18 2260.79 -1838.97 1315.38 0.56 0.00 -0.66 07-N OV-98 MWD 4237.07 56.48 142.98 96.59 3071.16 2341.55 -1903.38 1364.11 0.55 -0.53 0.19 08-NOV-98 MWD 4331.70 56.29 143.43 94.63 3123.55 2420.35 -1966.48 1411.31 0.44 -0.20 0.48 07-NOV-98 MWD 4422.47 55.90 142.30 90.77 3174.19 2495.67 -2026.54 1456.79 1.12 -0.43 -1.24 -. 07-NOV-98 MWD 4517.54 56.88 143.38 95.07 3226.81 2574.84 -2089.64 1504.61 1.40 1.03 1.14 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-02024 Sidetrack No. Page 1 of 5 [-- J-~[~-' I Company ARC~ ALASKA, INC. Rig Contractor & No. DOYON - #141 Field TARN DEVELOPMENT FIELD [ ! I Well Name & No. TARN DRILLSITE 21_/325 Survey Section Name Definitive Survey BHI Rep. L. HENSLEY/K. CHRISTENSEN j~N~"~l~ WELL DATA Target TVD (FO Target Coord. N/S Slot Coord. N/S -218.46 Grid Correction 0.000 Depths Measured From: RKB ~] MSLr-1 SS[-] Target Description Target Coord. E/W Slot Coord. E/W -864.82 Magn. Declination 26.810 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m~ 10m~ Vert. Sec. Azim. 143.68 Magn. to Map Corr. 26.810 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F-r) (DD) (DD) (FO (F-r) (FT) (FT) (Per 100 FT Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT .L_ 04-NOV-98 MWD 127.36 0.91 222.20 127.36 127.35 0.20 -0.75 -0.68 0.71 0.71 ' 04-NOV-98 MWD 218.21 1.21 218.98 90.85 218.19 0.59 -2.03 -1.77 0.34 0.33 04-NOV-98 MWD 309.27 1.32 220.95 91.06 309.23 1.06 -3.57 -3.06 0.13 0.12 04-NOV-98 MWD 402.75 0.97 210.50 93.48 402.69 1.61 -5.06 -4.17 0.43 -0.37 04-NOV-98 MWD 498.09 0.49 200.99 95.34 498.02 2.15 -6.14 -4.72 0.52 -0.50 04-NOV-98 MWD 583.29 0.72 208.35 85.20 583.22 2.58 -6.95 -5.11 0.28 0.27 04-NOV-98 MWD 673.99 0.59 204.81 90.70 673.91 3.05 -7.88 -5.57 0.15 -0.14 04-NOV-98 MWD 763.61 1.52 174.05 89.62 763.51 4.29 -9.48 -5.64 1.18 1.04 04-NOV-98 MWD 854.63 6.10 147.18 91.02 854.31 10.17 -14.75 -2.90 5.27 5.03 -29.52 04-NOV-98 MWD 943.97 9.04 146.08 89.34 942.86 21.92 -24.56 3.59 ;3.29 3.29 -1.23 04-NOV-98 MWD 1035.78 11.62 150.32 91.81 1033.18 38.31 -38.58 12.20 2.93 2.81 4.62 04-NOV-98 MWD 1126.68 13.62 152.73 90.90 1121.88 57.98 -56.05 21.64 2.27 2.20 2.65 04-NOV-98 MWD 1215.80 16.11 153.62 89.12 1208.01 80.52 -76.46 31.94 2.81 2.79 1.00 04-NOV-98 MWD 1308.66 18.28 154.74 92.86 1296.72 107.51 -101.17 43.88 2.36 2.34 1.21 04-N OV-98 MWD 1401.20 20.34 157.02 92.54 1384.05 137.40 -129.11 56.35 2.37 2.23 2.46 04-NOV-98 MWD 1500.22 22..51 155.62 99.02 1476.22 172.70 -162.22 70.90 2.25 2.19 -1.41 05-N OV-98 MWD 1591.99 24.86 152.69 91.77 1560.26 208.94 -195.37 87.00 2.86 2.56 -3.19 05-NOV-98 MWD 1685.89 28.85 148.46 93.90 1644.02 251.03 -232.23 107.92 4.71 4.25 -4.50 05- NOV-98 MWD 1779.36 33.28 145.44 93.47 1724.07 299.17 -272.59 134.28 5.02 4.74 -3.23 05-N OV-98 MWD 1873.19 39.61 143.71 93.83 1799.51 354.87 -317.95 166.62 6.83 6.75 -1.84 05-NOV-98 MWD 1967.85 46.91 143.91 94.66 1868.40 419.69 -370.27 204.89 7.71 7.71 0.21 05-N OV-98 MWD 2056.55 51.43 144.09 88.70 1926.38 486.79 -424.56 244.33 5.10 5.10 0.20 05-NOV-98 MWD 2151.37 56.70 142.76 94.82 1982.01 563.53 -486.17 290.08 5.67 5.56 -1.40 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-02024 Sidetrack No. Page 3 of 5 i Company ARCO ALASKA, INC. Rig Contractor & No. DOYON - #141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 21./325 Survey Section Name Definitive Survey BHI Rep. L. HENSLEY/K. CHRISTENSEN jl'j~~~ WELL DATA Target'l'VD (ET) Target Coord. N/S Slot Coord. N/S -218.46 Grid Correction 0.000 Depths Measured From: RKB ~ MSL0 SS~ Target Description Target Coord. E/W Slot Coord. E/W -864.82 Magn. Declination 26.810 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build~Walk\DL per: 100ft[~ 30m~ 10m0 Vert. Sec. Azim. 143.68 Magn. to Map Corr. 26.810 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (F'r) (F'I~ (FT) (F-T) (Per 100 FT) Drop (-) Left (-) -- 07-NOV-98 MWD 4611.86 56.59 142.25 94.32 3278.55 2653.69 -2152.47 1552.27 1.05 -0.31 -1.20 07-NOV-98 MWD 4706.68 56.62 144.14 94.82 3330.74 2732.85 -2215.85 1599.69 1.66 0.03 1,99 -- 07-NOV-98 MWD 4801.04 58.00 143.23 94.36 3381.70 2812.26 -2279.84 1646.73 1.67 1.46 -0,96 07-NOV-98 MWD 4892.63 58.08 144.99 91.59 3430.19 2889.96 -2342.79 1692.28 1.63 0.09 1.92 07-NOV-98 MWD 4989.29 58.75 144.73 96.66 3480.81 2972.28 -2410.12 1739.67 0.73 0.69 -0,27 07-NOV-98 MWD 5082.89 59.27 143.60 93.60 3529.01 3052.52 -2475.17 1786.65 1.17 0.56 -1.21 08-NOV-98 MWD 5177.49 59.36 141.85 94.60 3577.29 3133.86 -2539.90 1835.92 1.59 0.10 -1.85 08-NOV-98 MWD 5270.61 59.36 143.86 93.12 3624.75 3213.96 -2603.76 1884.29 1.86 0.00 2.16 08-NOV-98 MWD 5364.98 59.44 142.85 94.37 3672.79 3295.19 -2668.93 1932.77 0.93 0.08 -1.07 08-NOV-98 MWD 5459.17 59.56 142.72 94.19 3720.59 3376.33 -2733.56 1981.86 0.17 0.13 -0.14 08-NOV-98 MWD 5554.64 59.95 143.19 95.47 3768.68 3458.80 -2799.39 2031.54 0.59 0.41 0.49 08-NOV-98 MWD 5649.32 59.62 143.11 94.68 3816.33 3540.61 -2864.86 2080.61 0.36 -0.35 -0.08 08-NOV-98 MWD 5743.82 58.21 144.60 94.50 3865.12 3621.54 -2930.20 2128.35 2.01 -1.49 1.58 08-NOV-98 MWD 5836.93 57.89 143.75 93.11 3914.39 3700.54 -2994.26 2174.59 0.85 -0.34 -0.91 08-NOV-98 MWD 5931.56 57.96 143.37 94.63 3964.65 3780.72 -3058.77 2222.22 0.35 0.07 -0.40 08-NOV-98 MWD 6023.40 58.00 143.80 91.84 4013.34 3858.59 -3121.43 2268.44 0.40 0.04 0.47 08-NOV-98 MWD 6118.27 58.11 144.41 94.87 4063.54 3939.09 -3186.65 2315.64 0.56 0.12 0.64 08-NOV-98 MWD 6209.87 57.97 144.30 91.60 4112.02 4016.80 -3249.80 2360.93 0.18 -0.15 -0.12 08-NOV-98 MWD 6304.42 57.36 145.06 94.55 4162.60 4096.67 -3314.98 2407.12 0.94 -0.65 0.80 08-NOV-98 MWD 6399.34 57.45 145.19 94.92 4213.73 4176.62 -3380.59 2452.84 0.15 0.09 0.14 08-NOV-98 MWD 6493.26 57,33 146.31 93.92 4264.34 4255.68 -3445.98 2497.37 1.01 -0.13 1.19 08-NOV-98 MWD 6587.22 58,45 '144.57' 93.96 I 4314.29 4335.22 -3511.52 2542.52 1.97 1.19 -1.85 08-NOV-98 MWD 6680.86 58.66 145.02 93.64 4363.14 4415.10 -3576.79 2588.57 0.47 0.22 0.48 08-NOV-98 MWD 6774.91 58.46 146.83 94.05 4412.20 4495.27 -3643.25 2633.53 1.66 -0.21 1.92 r: SURVEY CALCULATION AND FIELD WORKSHEET ! ~ Job No. 0451-02024 Sidetrack No. Page 4 of 5 I~ Company ARCO ALASKA, INC. Rig Contractor & No. DOYON- #141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2L/325 Survey Section Name Definitive Survey BHI Rep. L. HENSLEY/K. CHRISTENSEN INTL=~ WELL DATA Target TVD (FO Target Coord. N/S Slot Coord. N/S -218,46 Grid Correction 0.000 Depths Measured From: RKB ~ MSL0 SS~ Target Description Target Coord. E/W Slot Coord, E/W -864.82 Magn. Declination 26,810 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build~Walk\DL per: 100ft~ 30m~ 10m[-J Vert. Sec. Azim. 143.68 Magn. to Map Corr. 26.810 Map North to: OTHER SURVEY DATA -- Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FO (DD) (DD) (FO (FT) (FO (FO (Per 100 FT Drop (-) Left (-) 08-N OV-98 MWD 6869.64 58.86 145.36 94.73 4461.47 4576.10 -3710.40 2678.66 1.39 0.42 -1.55 08-NOV-98 MWD 6962.59 59.79 147.03 92.95 4508.90 4655.97 -3776.83 2723.13 1.84 1.00 1.80 -- 08-N OV-98 MWD 7058.81 61.01 143.00 96.22 4556.44 4739.58 -3845.34 2771.10 3.86 1.27 -4.19 ' 08-NOV-98 MWD 7152.99 62.59 141.85 94,18 4600,94 4822.56 -3911.11 2821.72 1.99 1.68 -1.22 08-NOV-98 MWD 7248.71 61,04 142.17 95.72 4646.15 4906.89 -3977.61 2873.65 1.65 -1.62 0,33 08-NOV-98 MWD 7341.57 60,22 142.38 92.86 4691.69 4987,79 -4041,61 2923.16 0.90 -0.88 0.23 09-NOV-98 MWD 7435.42 59.15 141.48 93.85 4739.06 5068,76 -4105.39 2973.12 1.41 -1.14 -0.96 -- 09-NOV-98 MWD 7528.56 59.85 139.92 93,14 4786,34 5148.90 -4167.49 3023.95 1.63 0.75 -1.67 09-NOV-98 MWD 7625.99 58.19 141,46 97,43 4836.49 5232.31 -4232.11 3076.87 2.18 -1.70 1.58 09-NOV-98 MWD 7720.07 58.18 141.39 94.08 4886,09 5312.20 -4294,61 3126,72 0.06 -0.01 -0.07 09-NOV-98 MWD 7814.28 58.17 142.13 94,21 4935.77 5392,20 -4357.48 3176.26 0.67 -0,01 0.79 09-NOV-98 MWD 7909.98 58.33 142.06 95,70 4986.12 5473.55 -4421,69 3226.26 0.18 0.17 -0.07 09-NOV-98 MWD 8001.52 58.55 141.53 91.54 5034.04 5551.50 -4482.98 3274.50 0.55 0.24 -0.58 ., 09-NOV-98 MWD 8094.70 56.64 140.15 93.18 5083.97 5630.07 -4543.98 3324.17 2.40 -2.05 -1.48 09-NOV-98 MWD 8189.42 55.86 141.61 94,72 5136.60 5708.73 -4605.08 3373.86 1.52 -0.82 1.54 09-NOV-98 MWD 8283.92 55.17 143.62 94.50 5190.10 5786.60 -4666.96 3421.15 1.90 -0.73 2.13 09-NOV-98 MWD 8378,25 55.56 145.05 94,33 5243.72 5864.21 -4730.02 3466.40 1.31 0,41 1.52 09-NOV-98 MWD 8474.16 55.63 144.09 95.9i 5297.91 5943.33 -4794.50 3512.27 0,83 0.07 -1.00 09-NOV-98 MWD 8566.78 56.31 144.74 92.62 5349.74 6020.08 -4856.92 ! ! 3556.94 0,94 0.73 0.70 09-NOV-98 MWD 8660.81 57.57 144.87 94.03 5401.04 6098.87 -4921.32 3602.36 1.35 1.34 0.14 09-NOV-98 MWD 8753.87 56.70 143.08 93.06 5451.54 6177.03 -4984.54 3648.32 1.87 -0.93 -1.92 09-NOV-98 MWD 8846.74 55.95 145.07 92.87 5503.04 6254.31 -5047.11 3693.67 1,96 -0.81 2.14 -- 09-NOV-98 MWD 8941.73 56.46 144.97 94.99 5555.87 6333.22 -5111.79 3738.92 0.54 0.54 -0.11 09-NOV-98 MWD 9035.42 57.28 145.12 93,69 5607,08 6411.66 -5176.10 3783.88 0.89 0.88 0.16 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-02024 Sidetrack No. Page 3 of 5 , Company ARCO ALASKA, INC. ' Rig Contractor & No. DOYON - #141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2L/325 Survey Section Name Definitive Survey BHI Rep. L. HENSLEY/K. CHRISTENSEN ~lllrr~i~ WELL DATA Target TVD (F-r) Target Coord. N/S Slot Coord. N/S -218.46 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~] SS~ Target Description Target Coord. E/W Slot Coord. E/W -864.82 Magn. Declination 26.810 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m~ 10m~ Vert. Sec. Azim. 143.68 Magn. to Map Corr. 26.810 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(-I-) / W(-) DL Build (+) Right (+) Comment Type (F'r) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 07-N OV,98 MWD 4611.86 56.59 142.25 94.32 3278.55 2653.69 -2152.47 1552.27 1.05 -0.31 -1.20 ~ 07-NOV-98 MWD 4706.68 56.62 144.14 94.82 3330.74 2732.85 -2215.85 1599.69 1.66 0.03 1.99 07-NOV-98 MWD 4801.04 58.00 143.23 94.36 3381.70 2812.26 -2279.84 1646.73 1.67 1.46 -0.96 07-NOV-98 MWD 4892.63 58.08 144.99 91.59 3430.19 2889.96 -2342.79 1692.28 1.63 0.09 1.92 07-NOV-98 MWD 4989.29 58.75 144.73 96.66 3480.81 2972.28 -2410;12 1739.67 0.73 0.69 -0.27 07-NO¥-98 MWD 5082.89 59.27 143.60 93.60 3529.01 3052.52 -2475.17 1786.65 1.17 0.56 -1.21 08-NOV-98 MWD 5177.49 59.36 141.85 94.60 3577.29 3133.86 -2539.90 1835.92 1.59 0.10 -1.85 08-NOV-98 MWD 5270.61 59.36 143.86 93.12 3624.75 3213.96 -2603.76 1884.29 1.86 0.00 2.16 .,_ 08-NOV-98 MWD 5364.98 59.44 142.85 94.37 3672.79 3295.19 -2668.93 1932.77 0.93 0.08 -1.07 08-NOV-98 MWD 5459.17 59.56 142.72 94.19 3720.59 3376.33 -2733.56 1981.86 0.17 0.13 -0.14 08-NO¥-98 MWD 5554.64 59.95 143.19 95.47 3768.68 3458.80 -2799.39 2031.54 0.59 0.41 0.49 -- 08-NOV-98 MWD 5649.32 59.62 143.11 94.68 3816.33 3540.61 -2864.86 2080.61 0.36 -0.35 -0.08 ._ 08-NOV-98 MWD 5743.82 58.21 144.60 94.50 3865.12 3621.54 -2930.20 2128.35 2.01 -1.49 1.58 08-NOV-98 MWD 5836.93 57.89 143.75 93.11 3914.39 3700.54 -2994.26 2174.59 0.85 -0.34 -0.91 ._ 08-NOV-98 MWD 5931.56 57.96 143.37 94.63 3964.65 3780.72 -3058.77 2222.22 0.35 0.07 -0.40 08-NOV-98 MWD 6023.40 58.00 143.80 91.84 4013.34 3858.59 -3121.43 2268.44 0.40 0.04 0.47 08- NOV-98 MWD 6118.27 58.11 144.41 94.87 4063.54 3939.09 -3186.65 2315.64 0.56 0.12 0.64 ,, 08-NOV-98 MWD 6209.87 57.97 144.30 91.60 4112.02 4016.80 -3249.80 2360.93 0.18 -0.15 -0.12 -- 08-N OV-98 MWD 6304.42 57.36 145.06 94.55 4162.60 4096.67 -3314.98 2407.12 0.94 -0.65 0.80 08-NOV-98 MWD 6399.34 57.45 145.19 94.92 4213.73 4176.62 -3380.59 2452.84 0.15 0.09 0.14 08-N OV-98 MWD 6493.26 57.33 146.31 93.92 4264.34 4255.68 -3445.98 2497.37 1.01 -0.13 1.19 08-NOV-98 MWD 6587.22 58.45 144.57 93.96 4314.29 4335.22 -3511.52 2542.52 1.97 1.19 -1.85 08-N OV-98 MWD 6680.86 58.66 145.02 93.64 4363.14 4415.10 -3576.79 2588.57 0.47 0.22 0.48 . 08-NOV-98 MWD 6774.91 58.46 146.83 94.05 4412.20 4495.27 -3643.25 2633.53 1.66 -0.21 1.92 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-02024 Sidetrack No. Page 5 of 5 --- ---!· '-[! [4 '- I =(--t Company ARCO ALASKA, INC, Rig Contractor & No, DOYON - #141 Field TARN DEVELOPMENT FIELD E~B~B"~IA Well Name & No. TARN DRILLSITE 2L/325 Survey Section Name Definitive Survey BHI Rep. L. HENSLEY/K. CHRISTENSEN WELL DATA Target TVD (FO Target Coord. N/S Slot Coord. N/S -218.46 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[~ ssr~ Target Description Target Coord. E/W Slot Coord. E/W -864.82 Magn. Declination 26.810 Calculation Method MINIMUM CURVATURE Target Direction (OD) Build\Walk\DL per: lOOft[~ 30m~ 10mo Vert. Sec. Azim. 143,68 Magn. to Map Corr. 26.810 Map North to: OTHER i SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FO (DD) (DD) (FO (FO (FO (FO (Per 400 FT) Drop (-) Left (-) 09-N OV-98 MWD 9123.16 58.03 144.11 87.74 5654.02 6485.77 -5236.53 3826.80 1.29 0.85 -1.1 5 . 10-NOV-98 MWD 9200.00 58.03 144.11 76.84 5694.71 6550.96 -5289.34 3865.01 0.00 0.00 0.00 Projected Data- NO SURVEY -" -- .... ul 0 Ft I I._1-- I IM I~ SE I:IL~I r' G S WEI,I, LOG TRANSMITFAL To: RE: State of Alaska Alaska Oil and Gas Conservation Cormn. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs May 11, 1999 2L-325, AK-MM-90008 The technical data listed below is being submitted herewith. Please address any problems or cone, ems to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2L-325: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20275-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20275-00 2" x 5" MD Neutron & Density Logs: 50-103-20275-00 2" x 5" TVD Neutron & Density Logs: 50-103-20275-00 l Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sept: Gas ~ns. C~mmis$i0a 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company WELL LOG TRANSMITFAL To: RE: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 May 6, 1999 MWD Formation Evaluation Logs 2L-325, AK-MM-90008 I LDWG formatted Disc with verification listing. APl#: 50-103-20275-00 PLEASE ACKNOWLEDGE RECElPT BY SIGNING AND RETURNING THE ATTACHED COPY OF TltE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 - !VEC (.~ ~ ~-,.~,,r.. ,..¢.¢~ · 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company · .:- STATE OF ALASKA .... ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ 2. Name of Operator Suspend __ Alter casing __ Repair well _ Change approved program __ Operation Shutdown __ Re-enter suspended well __ Plugging__ Time extension _ Stimulate__ Pull tubing__ Variance__ Perforate__ Other X Annular lniection 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 219' FNL, 865' FEL, Sec. 22, T10N, R7E, UM At top of productive interval 239' FSL, 2622' FEL, Sec. 23, T10N, R7E, UM At effective depth At total depth 232' FNL, 2287' FEL, Sec.26, T10N, R7E, UM 6. Datum ele(/ation (DF or KB) 28' RKB feet 7. Unit or Property name Kuparuk River Field/Tarn Oil Pool 8. Well number 2L-325 9. Permit number 98-209 10. APl number 50-103-20275 11. Field/Pool Kuparuk River Field/Tarn Oil Pool 12. Present well condition summary Total Depth: measured 9200' feet (approx) true vertical 5695' feet Effective depth: measured 9078' feet (approx) true vertical 5630' feet Casing Length Size Structural Conductor 80' 16" Surface 2771' 7.625" Intermediate Production 8316' 5.5" x Liner 832' 3.5" Plugs (measured) Junk (measured) None Cemented 9 Cu High Early 371 sx ASIIILW & 235 sx Class G 240 sx Class G Measured depth True vertical depth 108' 108' 2799' 23OO' 8344' 5224' 9176' 5682' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 3.5", L-80,9.3# @ 8360' Packers and SSSV (type and measured depth) CSR @ 8344' N/A ORISINAL 13. Attachments Description summary of proposal Contact Paul Mazzolini at 265-4603 with any questions. Detailed operation program 14. Estimated date for commencing operation November 1998 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Tarn Drilling Team Leader Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Suspended__ IAppr°vall Plug integrity _ BOP Test _ Mechanical Integrity Test_ Subsequent form require 10- Approved by the order of the Commission Form 10-403 Rev 06/15/88 Location clearance u ' ginal Signed By 0avid W. Johnston - C~9~ Commissioner . _.o~O'4eO ,,~' SUBMIT IN TRIPLICATE CASING TEST and FORMATION INTEGRITY TEST Well Name: 2L-325 Supervisor: G.R. Whitlock Date: 11/7198 Casing Size and Description: Casing Setting Depth: Mud Weight: 9,1 ppg Hole Depth: 2,330' TVD 830 psi + 9.1 ppg EMW LOT = (0.052 x 2,300') = 16.0 ppg Fluid Pumped = 0.8 bbl 7 5/8", 29.7 ppf, L-80, BMTC 2,799' TMD 2,300' TVD EMW = Leak-off Press. + MW 0.052 x TVD Pump output: 0.1000 bps TIME LINE :2,300 psi ~ ' - -' - lONE MINUTE 2,200 psi ,, ' 2,100 psi : : It I, ~, I ' ~ I: ,:;:; ~, ~ I -- 2,000 psi 1,900 psi 1,800 psi -- 1,700 psi I ...... 1,600 psi ~f , -- 1,500 psi ILl 1,400 psi ~ 1,300psi f O} 1,200 psi j .... w" 1,000 psi --e=' LEAK-OFF TEST I1, 900 psi 800 psi [~ --,~--CASING TEST ....... LOT SHUT IN TIME -- 700 psi J I~ --"*-' CASING TEST SHUT IN TIME 600 psi f ~!; ; TIME LINE 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi· .... 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64 66 68 70 72 74 76 78 80 82 stk stk stk stk stk stk stk stk stk stk S(k stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk Stk stk stk stk stk stk stk stk stk stk stk stl< stk stk STROKES LEAK-OFF DATA MINUTES FOR FIT STROKES PRESSURE ......................... !_.s..tk._s. .......... .4..o..p..s.! .... j 2 stks 100 psi ........................ __4__s._t.k., ......... .4_.o_o._p..s.L_.j ........................ .S...s.!.k._s_ ......... _s_.to.__p_.s.L__J .- ...................... _.S..s._t.k..s. ......... .7..4_o...p..s_L..~ 7 stks 820 psi : ' , SHUT IN TIME SHUT IN PRESSURE .... 'd'.iS'Ffii~ .... r ....................... .... .]:_o__.m.j.n. .... : ....................... _4..3.0..p..s_L _ j 2.0min ~ 420 psi F"'~'.~'~fi'~; .... ! .................. i .... z~'~'i~;i"'i r'"'~'.tF~fi'~ .... r .................. :, .... ~'~"~a'"~ L..._s:.o._r?:.n. .... ,, .................. .,, .... .4..o.o._p..s.[__.j 6.0min j j 390 psi 'Z?i'F. iEi6iZEiiZZZZZiEi~.i~i~KEii CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE j 2 stks 60 psi i 10 stks 1,$40 ~si , SHUT IN TIMEI ...................... 1.0 m~n j ., 1,930 Esi 15.0 minj 1,870 psi 25.0min i 1,860 psi 30.0m~n ~ ~ 1,860 psi NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 2L-325 Supervisor: G.R. Whitlock Date: 11/7/98 Casing Size and Description: Casing Setting Depth: Mud Weight: 9.1 ppg Hole Depth: 3,218' TVD 650 psi + 9.1 ppg EMW LOT = (0.052 x 2,300') = 14.5 ppg Fluid Pumped = 0.8 bbl 7 518", 29.7 ppf, L-80, BMTC 2,799' TMD 2,300' TVD EMW = Leak-off Press. + MW 0.052 x TVD Pump output = 0.1000 bps 700 psi. TIME LINE 2,300 psi [ J~ lONE MINUTE 2,200 psi i .............. I ...............' 2,100psi Ill '': : ;;'';,',;;~:: !:;,~'~=~ ~ ~' '= :,:~ ........................... 2,000 psi ....... .~.. 1,900 psi I "' = ~*'~ -- ' 1,800 psi , 1,700 psi , 1,600 psi 1,500 psi, 1,400 psi / 1,300 psi / 1,200 psi 1,100 psi 1.ooo psi ~ -e--LEAK-OFF TEST 9oo psi j --a"CASING TEST 9oo ps~ j LOT SHUT IN TIME / .... *-CASING TEST SHUT IN TIME ~oo psi ~ ~ ~ - TIME LINE 40o psi ~ ~ - = ~ ~= -- 300 psi .... ff -- ~ 200 psi 100 psi~ ~ 0 psi, ~. .. 0 stk6 stk~ 3 stk 19 s[k 26 stk 32 ~tk 38 stk 45 stk 51 s[k 58 ~tk 64 s[k 70 stk 77 stk 83 stk 90 stk STROKES LEAK-OFF DATA MINUTES FOR FIT STROKES PRESSURE i I stks i 30 psi ................... [ .... -~-~i[~- .... i ..... ~-~--~a .... r .................. r .... ':~-~i[~- .... :, .... Yy~'~a-'-~ I- .................. I- .................. .I .................. L .................. ', .... _4___s__t~:. .... j .... .2_?_o__p__s_L._~. , [ 5stks i 380 psi .................. i .... '~-i~i[~' .... i .... ~.~'~'~i'---] ................... [ .... '~'~i[~' .... ~ .... ~'~'~['"~ ................... I' .................. -I .................. ~ [ 8 stks .,' 630 psi .................. : .... '~'i~iii~' .... i .... i~'~'~["': [' .................. [ .... .r~-;[[~----~ .... ~-~-~a---i L .................. L..__~.o_..s.L~_.s..._i .... ~?.?_P.~L..j : 25stks i 460 psi r .................. f .... ~'~'~i[~'""~ .... ~.~'~'i~[---i I- .................. ~ .................. ~ .................. -I L .................. L__..:}}..s.t..k..s....i .... .4..4.o._.p_.s.i._..j i 40stks i 390 psi I l ................... f .................. ~ .................. -I :::::::::::::::::::::::::::::::::::::::::::::::::::::::::: CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE 0 stks 0 psi ......................... ~'-~i'~ ......... ~b"~'~ ...... ......................... ~;'~i-~; ........ ~i~b-'l~'~i .... 8 stks 1,250 psi .................. i .... ¥~--~i'~'---T--T;~',4iri~a'"~ ................... i .... :~-~'-~-[~'--'T--~;6-~ii'i~i'''~ ! .................. .~ .................. .4.. .................. i .................. i ! ! SHUT IN TIME ................... ' ' ' : 1.Omen I : 1,9301~si ................... f .................. i .................. i ................ .... ..................................... SHUT IN TIMEi SHUT IN PRESSURE i ' 3.~'r~in 'i .................. T-';I-~§"~J'~-i--' .... -o:~-~'~;.; ? .... .................. '~ ~O"~T"'~ [ ~:o"~r~'-"] .... .... .................. i"¥;i~iri;a'"' ............ .. ...... ~ .................. ~ .................. .~ ............. ... ........................................ ..... !.,.o___m.j.n. .... .,, .................. ~ .... .3..s.o...p..s.[...j .... j..o...9_.m.,.~_,j ..................... .1.,.s.s_.o..R.sj... 2.0min [ j 340psi ! .... '~-~i~ .... i .................. ! .... .... '~li:i'~i~i .... ,r .................. ! .... ~i~']~i~['"! ............ -. ...... f .................. t .................. '{ ..5_._0..m.j.n... [ .................. j.. 330_.psi '" 6.0'min "j j "~,'~ ~['"j .... ..~:.o...m.j.,. .... :, .................. .= .... ].~.o...p..s.[...j 9.0min j i 320~si NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ARCO Alaska, Inc. Cementing Details Well Name: 2L-325 Report Date: 11106/98 Report Number:. 4 Rig Name: DOYON 14¶ AFC No.: AK9485 Field: Casing Size Hole Diameter. Angle thru KRU: Shoe Depth: LC Depth: I % washout: 7.625 9.875 59.35 2799 2712 I Centralizers State fype u~ed, intervals covered and spacing Comments: Bow spring centralizers on its t ,2,77 & 78 on stop collars 1lit. Centralizers 1lit on casing collars on its 17, 20, 23, 26, 29, 32, 36, 39, 42, 45, 48, 51, 54, 57,60 Mud Weight: PV(prior cond): PV(affer cond): I YP(prior cond): YP(affer cond): Comments: 10.2 28 22 I 24 15 Gels before: Gels after. Total Volume Circulated: 15127 8112 1105 Wash 0 Type: ~ Volume: Weight: Comments: ARCO Wash !20 8.4 Spacer 0 Type: Volume: Weight: Comments: ARCO 40 10.5 Lead Cement 0 Type: I Mix wtr tamp: No. of Sacks: I Weight: Yield: Comments: ASIII I 70 371 [ 10.7 4.43 Additives: 50% D124, 9% D44, .4°/o D46, 30¥, D53, 1.5% S1,1.5% D79 Comments: I G I I 170 235 15.8 1.17 Additives: I 0/, S1, .2¥° 1348, .3% D65 Displacement 0 'Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 6.9 6.1 80 Reciprocation length: Reciprocation speed: Str. Wt. Down: 10 10 fpm 65 Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 124.5 125.9 Calculated top of cement: i CP: Bumped plug: I Floats held: Surface I Date: 1116198 yes I yes Time:09:19 Remarks:Had full returns throughout job. Circulated 150 bbl cement to surface. Cement Company: ]Rig Contractor: Approved By: DS I DOYON G.R. Whitlock Daily Drilling Report ARCO Alaska, Inc. AFC No. Date Rpt No Rig Accept - hrs Days Since Accept/Est: 3.33 / AK9485 11106/98 4 11103/98 08:00:00 Rig Relase - hrs: PM Well: 2L-325 Depth (MD/TVD) 2815/2321 Prev Depth MD: 2815 Progress: 0 Contractor: DOYON Daily Cost $ 247312 Cum Cost $ 523083 Est Cost To Date $ Rig Name: DOYON 141 Last Csg: 7-5~8" (~ 2799" Next Csg: 5-1/2" x 3-1/2" (~ 9172' Shoe Test: 16.6 Operation At 0600: Drilling 2860' Camp/rig on highline 24 hfs Ul~coming Operations: Drill ahead MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LSND 2R1 N TST 11104/98 11/07/98 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.1 ppg 6.75 10/28/98 11/02/98 VISCOSITY PU W-I' MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 46sqc HTC N SPACE 10/31/98 PV/YP SO w-r TYPE TYPE TYPE FUEL & WATER 14 / 15 STR554 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 1500 5 / 6 / 1901317 APl WI_ MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 900 8.8 11/06/98 BBLS HTHP WI_ TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 107 mi/30 min 2815 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 4.0% 0 2L-329 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP °F 0 110bbl 01 I I 0 / / 2L-325 MBT PUMP NO WOB 2 WOB 2 RATE (bpm) WIND SPEED 0 10.0 1121 I 3.2 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION ° 8.5 81611 625 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR OF 0.00 2.2% 0 I 0 J I Fresh Water 200 PIT VOL GPM 2 JETS JETS Diesel ARCO PERSONNEL 1 500 ololl IIIII IIIII 30 o DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $7o45 III o PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $51588 III III III 230 COMPANY MUD vv'r GRADE GRADE TOT FOR WELL (bbl) SERVICE 10 BAROID III III III 230 PERSONNEL TOTAL 43 TIME J END HOURS J OPS CODE j HOLE SECT J PHASE OPS J OPERATIONS FROM 0000 - 0000 12:00 AM 02:00 AM 2,00 CASG SURF Casing and Hold pre-job safety meeting. Run 7-5/8" casing to 1650' Cementing 02:00 AM 02:30 AM 0.50 CIRC SURF Casing and Cbc casing volume Cementing 02:30 AM 04:30 AM 2.00 CASG SURF Casing and Run 7-5/8" casing to 2799' Cementing 04:30 AM 07:30 AM 3,00 ClRC SURF Casing and Circ hole clean. Cementing 07:30 AM 09:30 AM 2.00 CEMENT SURF Casing and Cement wi 371 sx. Lead ~ 10.7 ppg and 235 sx Tail (~ 15.8 Cementing ppg. Displace wi 24.5 bbl h2o and 100 bbl mud. Bump plug and check floats. CIP (~ 09:19 09:30 AM 02:30 PM 5.00 ND_ND SURF Casing and L/D landing it. Flush stack N/D diverter system. Cementing 02:30 PM 05:00 PM 2.50 ND_ND SURF Casing and N/U speed head, tubing head and DOPE Cementing 05:00 PM 08:00 PM 3.00 DOPE SURF Casing and Test all DOPE components to 250~3500 psi. Install wear Cementing ring 08:00 PM 11:00 PM 3.00 BHA PROD Making Hole M/U directional MWD. Test MWD. 11:00 PM 12:00 AM 1.00 TRIP_IN PROD Making Hole RIH to 2670' tag cmt 24.00 Supervisor: G.R WHITLOCK Daily Drilling Report: 2L-325 11/06/98 Page I ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company Casing Detail 7.625" Surface Casino WELL: TARN 2L-325 DATE: 11/5/98 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RKB to LR = 28.00' TOPS Above RKB 7 5/8" Landing Joint 28.20 FMC GEN V- Prudhoe 7 5/8" Csg Hgr 2.02 28.20 .its. 42-63 7 5/8", 29.7#, L-80 BTC-mod(22 its) 929.13 30.22 jt. 78 7 5/8", 29.7#, L-80 BTC-mod (Thread Locked Collar) 41.91 959.35 TAM 7 5/8" Port Collar (BAKERLOK) 2.45 1001.26 jt. 77 7 5/8", 29.7#, L-80 BTC-mod (Thread Locked Collar) 43.03 1003.71 jts. 3-41 7 5/8", 29.7#, L-80 BTC-mod (39 jts) 1665.67 1046.74 Gemeco Float Collar 1.31 2712.41 its 1-2 7 5/8", 29.7#, L-80 BTC-mod 84.14 2713.72 Gemeco Float Shoe 1.48 2797.86 Casing shoe @ 2799.34 T.D. @ 2815' leaving 15.66' of rathole 31 Gemeco Bow Spring CENTRALIZERS Run centralizers in center of Jts. 1,2, 77, 78, over stop collars and over casing collars on Jts. 3-14 and over collars of its. 17, 20, 23, 26, 29, 32, 36, 39, 42, 45, 48, 51,54, 57, 60. Joints 64-76 (13 joints) will remain in the pipe shed. · Remarks: String Weights with Blocks: 80K Up,65K Dn,12k Blocks. Ran 65 joints of casing. Drifted casing with 6.750" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated. Doyon 141 Drilling Supervisor:G. R. Whitlock "i98'209-0 KUPARUK'"Riv"~'T'~ "" ~L2~2~ ....................... 5~2'""i'~'32~{~7520'~'- ~HI~iP~"~KA INC Roll #1: Start: Stop Roll #2: Start Stop MD 09200 TVD 05695 Completion Date: 11/12/98 Completed Status: 1-OIL Current: Name Interval Sent Received T/C/D D 9142 2 ~/ SPERRY MPT/GR/EWR4/CNP/SLD OH 5/6/99 5/6/99 L DGR/CNP/SLD-MD '~/ FINAL 2815-9200 OH 5/11/99 5/11/99 L DGR/CNP/SLD-TVD c/FINAL 2321-5694 OH 5/11/99 5/11/99 L DGR/EWR4-MD t/FINAL 2815-9200 OH 5/11/99 5/11/99 L DGR/EWR4-TVD .J FINAL 2321-5694 OH 5/11/99 5/11/99 R SRVYCALC / BHI.~ ~'q2~E> OH 1/21/99 1/22/99 Tuesday, January 09, 2001 Page 1 of 1 STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ Suspend __ Alter casing __ Repair well _ Change approved program __ Operation Shutdown __ Re-enter suspended well __ Plugging__ Time extension _ Stimulate__ Pull tubing__ Variance__ Perforate__ Other X 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 218' FNL, 865' FEL, Sec. 22, T10N, R7E, UM At top of productive interval 179' FSL, 2555' FEL, Sec. 23, T10N, R7E, UM At effective depth At total depth 175' FNL, 2292' FEL, Sec.26, T10N, R7E, UM 6. Datum elevation (DF or KB) 28' RKB feet 7. Unit or Property name Kuparuk River Field/Tarn Oil Pool 8. Well number 2L-325 9. Permit number 98-209 10. APl number 50-103-20275 11. Field/Pool Kuparuk River Field/Tarn Oil Pool 12. Present well condition summary Total Depth: measured 9172' feet (approx) true vertical 5692' feet Effective depth: measured 9172' (approx) true vertical 5692' Casing Length Size Structural Conductor 90' 16" Surface 2755' 7.625" Intermediate Production 8295' 5.5" x Liner 849' 3.5" Perforation depth: measured Plugs (measured) feet Junk (measured) feet None Cemented Measured depth 9 Cu High Early 118' 290 sx ASIIILW & 2783' 240 sx Class G & 60 sx AS I True vertical depth 118' 2300' 230 sx Class G 8323' 5205' 9172' 5692' true vertical Tubing (size, grade, and measured depth) 3.5", L-80 Packers and SSSV (type and measured depth) N/A N/A 13. Attachments Description summary of proposal Contact Paul Mazzolini at 265-4603 with any questions. Detailed operation program BOP sketch __ 14. Estimated date for commencing operation November 1998 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas__ Service Suspended __ ORl6!i !A! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~.~ ~~ Title Tarn Drilling Team Leader FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10- Approved by the order of the Commission (~riqinal Signed By ;-'-v'.:', W. Johnston Form 10-403 Rev 06/15/88 Commissioner [Approval No.':: Date SUBMIT I1~ TRIPliCATE ARCO Alaska, Inc. · - Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 5, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2L-325 (Permit No. 98-209) Sundry Application Dear Mr. Commissioner: Enclosed is a sundry to change the bottomhole location for KRU 2L-325. In order to provide our Operations personnel additional rathole on completed Tarn wells, AAI will be drilling an additional 100' (normally 200' below the C35 marker- now 300' below the C35) on all Tarn wells. Future Permits to Drill will reflect these changes in the proposed BHL. This additional rathole should prevent the requirement of a coiled tubing clean out below the float collar which has been necessary on several wells. Sincerely, ORIGINAL P. Mazzolini Tarn Drilling Team Leader Tarn Development PM/skad TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION November 3. 1998 Paul Mazzolini, Drilling Team Leader ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 ae~ Kuparuk River Unit 2L-325 ARCO Alaska. Inc. Permit No: 98-209 Sur Loc: 218'FNL. 865'FEL. Sec. 22. T10N, R7E. UM Btmhole Loc. l l0'FNL, 2341'FEL, Sec. 26. T10N, R7E, UM Dear Mr. Mazzolini: Enclosed is the approved application for permit to drill the above referenced well. Your request to transport waste from this well to the 2N pad for disPosal will not be approved unless sufficient evidence is presented to confirm thc inadequacy of thc 2L-329A ,,','ell for annular disposal. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 arc met. Annular disposal of drilling waste '`'`'ill be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records. FIT data. and anv CQLs must be submitted to thc Commission on form 10-403 prior to the start of disposal operations. Please note that anv disposal of fluids generated from this drilling operations which are pumped down the surface/production casing annulus of a well approved for annular disposal on either drill site must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35.000 barrels through the annular space of a single well or to usc that well for disposal purposes for a period longer than one 3'car. The permit to drill docs not exempt you from obtaining additional permits required by lax'`, from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission ~f BOPE installed prior to drilling new hole. Notice may be given ld inspector on the North Slope pager at 6'59-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures Department or' Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALA'~¥~,A OIL AND GAS CONSERVATION COMM:dSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Reddll I lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 117' feet Kuparuk River Field 3. Address 6. Property Designation Tarn Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380053, ALK 4601 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 218' FNL, 865' FEL, Sec.22, T10N, R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 179' FSL, 2555' FEL, Sec. 23, T10N, R7E, UM 2L-325 #U-630610 At total depth 9. Approximate spud date Amount 110' FNL, 2341' FEL, Sec. 26, T10N, R7E, UM 11/3/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'rVD) property line 2L-329 9072' MD 110' @ TD feet 59.9' @ 400' feet 2560 5635' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 800' feet Maximum hole angle 58.4° Maximum surface 1357 psig At total depth (TVD) 1610 psig 18. Casing program Settin9 Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 16" 62.5# H-40 Weld 90' 28' 28' 118' 118' _+200 CF 9.875" 7.625" 29.7# L-80 BTC MOB 2755' 28' 28' 2783' 2300' 1) 50 Sx Arcticset III L & 240 Sx Class G 2) 240 sx ASIII L & 60 sx ASI 6.75" 5.5" 15.5# L-80 LTC-M 8295' 28' 28' 8323' 5205' 230 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 749' 8323' 5205' 9072' 5635' (included above) 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing ConductorStructural Length s,z E I V E D Measured depth True Vertical depth Productionlntermediate .. ?'f, ~ U .; I W ~'~ OCT Liner Perforation depth: measured N~ 0ii & Gas Cons. true vertical Anchorage 20. Attachments Filing fee X Property plat [~. BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot F~ Refraction analysis F,~ Seabed report ~ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '"~_._~_J ~//~2./2/2~_.._' _., Title Drilling Team Leader Date ! ~ ~ Commission Use Only Per~t~umb¢~' APl number O~ 50-lb,'&-2, r,-1 )~"- ~ IAppr°va'date ///"~¢ '-"~'-~ Iseec°ver'etterf°r -, other requirements Conditions of approval Samples required [~ Yes [~ No Mud log required [~ Yes [~, No Hydrogen sulfide measures F" Yes [~ No Directional survey required ~ Yes ~ No Required working pressure forBOPE ~' 2M ~ 5M F. 10M ~1 15M Other: Original Signea By by order of Approved by David W. Johnston Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate ~ - ARCO Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2L 325 1. Move in and rig up Doyon 141. 2. Install diverter system. 3. Drill 9.875" hole to 7-5/8" surface casing point according to directional plan. , Run and cement 7-5/8" 29.7#, L-80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. NOTE: TAM Port Collar will be placed in the 7-5/8" casing _+:t000' TVD/ below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGCC. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. See attached TAM Port Collar Utilization Decision Tree. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. . Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 7. Drill 6.75" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). , Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. · , EIVED 11. ND BOPE and install production tree. OCT 67 Ai~i,a Oil & Gas Cons. I~t~qJSsion Anchorage ..r _. ARCO Alaska, Inc. Secure well. Rig down and move out. ]3. Hydrocarbon intervals will be tested after the rig move. ARCO Alaska, Inc. '-~-' DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2L-325 Drillinq Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.0-10.2 ppg 15-35 25-50 70-120' 10-25 15-40 5-7 9.5-10 _+10% Drill out to TD 8.5 - 10.0 ppg 12-24 15-30 45-60 2-6 4-8 4-6 through Arete & Tarn 9.0-10 <11% Drillinq Fluid System' Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Degasser Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur at a surface pressure of 1,357 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2L pad are expected to be -2,350 psi (0.50 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. ARCO Alaska, Inc. Well Proximitv Risks: The nearest well to 2L-325 is 2L-329. The wells are 59.9' from each other at a depth of 400'. Drillinq Area Risks- The primary risk in the 2L-325 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8 - 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. 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 casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal 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 2L-325 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 2L-325 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. 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 surface casing shoe will be set a minimum of 100' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,100') + 1,500 psi Max Pressure = 2,810 psi .... ARCO Alaska, Inc. ~ .... This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5½" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi 3Y2" 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). Cement above Port Collar (1000' 'T'VD), I Perform Top Job J as per requirements of AOGCC Nipple Up and Test BOP's Continue with Completion TAM TARN Port Collar Utilization Decision Tree No Cement to Surface i Begin Primary One Stage Cement JobI / / If Top Job is ineffective or unacceptable to AOGCC Top of Cement below Port Collar (1000' TVD)/ Open Port Collar using drillpipe Circulate Cement to Surface and close Port Collar I Cement to Surface Nipple Up and Test BOP's Continue with Completion Indicators of Cement Top 1. Observation of Tracers in Spacer ahead of lead cement 2. Calculated Displacement 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface Nipple Up and Test BOP's Continue with Completion 500 500 10o0 1500 2000 2500 3000 3500 4ooo 4500 c~,~ W ~:~ ..... For: BRASSFIELD O~te proHed : 1-0ct-98 P!ot Referenca ia 325 Yers;o~ ~13. C~rd~nates ore ;n feet reference slot ~325. True Vertical Dep[he ~e RK8 (~an 141). ARCO Alaska, Inc. £ast (feet) -> 500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 ~ ~ ~ r ~ ~ ~ ~ ~ ~ ~ ~ r ~ ~ r ~ ~ ~ ~ 500 SURFACE LOCAT ON: ,._(~ Begin__ Turn to Target 0 I SEC. 22, T10N, R7E I ~',. Base west Sak Sands =oo ~k7 5/8" Pt Casing 143;68 AZIMUTH X, cso 1ooo 6060 (TO TARGET) _ ***Plane of Proposal*** ~ 1500 2000 0 2500 % I ~7§' FSL, 2555' ['Et. 300o '~ c4o%, I SEC. 23, Il ON, R7E I RKB ELEVATION- 1 45' ~~ TARGET M · x~ TVD=5383 3500 ~ TMD=8633 ~ DEP=6060 ~ SOUTH 4883 EAST 3589 4000 RaP TVI]=800 TMD=800 DEP=0 BEG,N TURN 24.81 54.72 DLS: 5.00 deg per 100 ft T2 -Bcse Bermude"-->~C.55 \%.'~ 5000 4-4.67 TO - Casing Pt 54.6.5 BASE WEST SAK SANDS TVD=1964 TMD=2145 DEP=547 EOC TVO=lg80 TMD=2176 OEP=573 5500 TO LOCATION: 110' FNL, 234-1' FEL SEC. 26, TiON, R7E C50 TV0=3765 TMD=5582 OEP=3474 C40 TVO=4095 TMD=6212 OEP=4011 5O0O 5500 60OO TARGET ANGLE 55 DEG BEG,a ANGLE DROP TVD:5111 TM0:8152 OEP ..... ENOANGLEDRO~ 2 T 3 ~ ~ ~Z%~%51L~=%~2o~ ~¢ ~=%%2 o'~. ~.~7 T3 -TOP BERMUDA ~0=5320 TMD=8525 OEP=E970~ DLS- 2.00 deg per 100 ft TARGET - ~ID BERMUDA TVD=E383 T~D=8633 DEP=6060~ ' T2 - BASE BERMUDA ~D=54~5 TMD=87~l DEP=6149 ~ C35 ~D=5520 TMD=8872 DEP=6256 ~ ] I I [ I I I I I I I II I I II I I I II I I I I I I I I 500 0 500 1000 1500 2000 2~00 3000 ,3500 4000 4500 5000 5500 6000 6500 7000 VerTicalSecTion (feeT)-> AzimuTh 143.68 with reference 0.00 N, 0.00 E from slot #325 MAXIMUM ANGLE 58.41 DEG 7 5/8" CASING PT TVD=2300 TMD=2786 DEP=1093 C80 'FVD=2477 TMD=3124- DEP=1380 Iz~'°~'" ~"~w'°" For: BRASSFIELD Plot Reference is 325 Ver~ 120 80 8O 120 160 200 2¢0 280 32O 360 400 440 480 52O 56O 6OO JSfructure : Tarn 0rill -ire 2L Well : lField : Tarn 0evelopmenf F;eld LocaHon :Norfh Slope, Alaska East (feet) -> 120 80 40 0 40 80 120 160 200 240 280 320 360 400 440 480 520 ''''''''''' ' '' ' ' ' ooo /"~ 800 / 800 ........ ;~'O~B': ....... ; /70% .... -~-~ .... 8o ; 1700 ' A 6~- ~- ..... 9_ ......... +~OO 1_1 O0 1200 1300 ...... ~¥OU' ........ ~ ,*uu ' } 1500~ ~_700 ....... ~._. ' ...... 10an -'-~~_1400 1400 40 · ou~ --. '"- 11 ~ '-= ,-, .,. 700C~ .... ,~. 900 --... U'O... ~-.:. ~ ~. ~...~ ---~.j..uuu ...... ~. 1000 ........ ' ..... ~.11 O0 ...... ~t 70OraL"' 900"'"""~K~O0 ......... 1206 ...... ..1100 ....... .1.2.0~ ......... 1200 '"l~ ,~;~j900 ~ 700 . 900 ".. 100~'-.. '¢.~0 ..... ~ 1300 .......... ' ...... ~' ........ 0 (~ 700~ 10(" '. _~ · ~ -.. --~ , ~uu -.. '-.. 3.,. 1000 '.~ 1100'-. ". ~no --=.1 400 -... '--.~ 1300 ....... 1 '-:-:aY ........ ~00 ~ 3200-', 1' }0% '-. ".,. l'?'qLO" .... .. 1500 ......... ' .... 3300 ~,, "~ 11 O0 ".. 1200 '-... '-.:... 1.000 ....... . 16(~-1._~uu ......... ' 200 ,, ".. '.~ i z~Lu '--. '-.. '--.. . 3400 ~' "~ 1200 "...1300 '-... "-...~ tlO0 ..... '-!70(~ ....... , 1400 '""~1 40 ' 1500 ',. ". '".. 1'390 ....... .. 18~)'" 3500 ' ",, 1~00 ""- 1400 '"-. '"'- '-. ""-. ', ~ ".. "-. "-~ 1200 "-.. "-. 1.~^ L 1400 ". '-. q "-~ 14E<) '"'-... 19Od'"'- 3uu / 80 ', ".. "-~ 150Q '"-..2000 / ~soo ',,, "" '"-- '"'-- '"--.,~. 3700 ' "., ~soo ".,j6oo '"'-.. '"'-.. ~4oo " "- "- "' ' 160 '~ 1 600 ""' 160n '"". 1700 '"'-. '"'-. ~ .3800 ', ~.. "' ".. '-.. '-.~ .... ", ".. "-. "-.~ 17C~0.. 200 / "',1700 '...J 700 "-,..1800 '""'.. 1 ;'~'0'. t ' ', ' ',, '-. ~8oo'.., i ".., "x 1 800 4000 '" "'",\,,,., ",~ 1800 ~ '"'~ 1900 i 4100 " "".~ 2000 ,. I ',,., 1900 i ' [ 4200 '.. 2100 ' i 4300 ',, 2000 ",..., ~ '.. 520 i "% 2200 : 560 ! 4~00 , ~l % 600 i i i i i i t''~z i i i i i i i i i i i i i i i i i i i i i i t i 20 80 40 0 40 80 120 160 200 240 280 320 ..360 400 440 480 520 East (feet) -> 0 '-~. 1900 280 -. "- 320 '",..200 % 360 ¢00 4¢0 480 I¢"°~ ~ ~'°" For: BRASSFIELD note plaited : 2-0ct-98 Plot Reference i~ 325 Ver~o~ 400 600 800 1000 12OO 1400 1600 1800 2000 ti,-. c- 22oo 0 Of') 2400 I V 2600 2800 5000 3200 3400 3600 3800 4000 Structure: Tarn Odll Site 2L Well : Field : Tarn Davelopmen! Field Location : North Slope, Alaska East (feet) -> 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 34.00 I I I I I I I I I I I I I I I f I I I I I I I ' 4nn ',, ,, '"-, 2200"-,"-, '"' .,,.28'(5'0 .... '"' ' ....' ..... ' ".. ".. '". '"-'."-. "-. ' .... .. ~'21D3 ........ ' ......::::: ......... 2200 i L~ 600 ",, '",, '",, '"Q"'.. '"'-. '"'--. ' ..... ., 2000 ..... -. 2600 2 ~ ~]"0" .... -'~ ............ ",. 2200',,24'°° ,,? oo'-...'.,.2:~00'-.., 300d .... '- ' ...... ' ...... ' .... " ", "- 240¢'-"-. "- "-.... '--. '". ¢ -.~k 800 '".. '".. '"... '"-Q"-.. ""-... 2400"-... ""--.. ' ........ ',.,,, '--..... '-..... '--..::.-....... '-....:,oo ...... ....;.....~=..o.o ...... . ..... / '"~ 2400 "% 2600 '"-. '"-.~"-... "'--.. ' .... ... 26'0'0... ' ...... -. 2800 / [ 1000 ,,.,. -...... ?o 2'~'g"'-?~°~'"'~°° -. .... ...- ....... ..~oo · -,,~oo '"'..,~,,o;"-. ".-..:'--... '---...~oo~'°°'--- .... . "---...,.,' "%L'~°° ",,., "-... '"-... "---..'."---... '"--.... ':/ .... ';;~,.~oo ", '"-, "'- 2800 '.......... ....380o.? ---... '--,~L ",, 2soo "-, %, 2so~"--..'"'...2~°° '->,.(.' ..... ,,,.'~ "' '" 00" "- "- ,' "- ~:~hh 1600 ,,,,,,, ,.,,.,... -.....:?::. """,. 3000 '"'"''"'"' '"' '"'"'""'"" """"'4- ' ~ 800 .. ".. '... .." "-... "-... "-.,. 200[-' ',, "- ",. 3000 ," "-, '", ';"~% I ,,, '-~ 3200 ,., ," 3000'%. "-.. 2800"-kgD '.. '... '-... I;~ "-.. '--.. I- 2000 '",.)200 '""'.. '"'",. '"'"'.. '%i ""'",.."'""-?""-.., ~oo '--.% L 2200,,,,~ 34-00 '""" '"" '", '", "', % 3600 '-, · ",. 3600 2600 '\,,,,, '".. '"-.. 3400 ""' '" '" i 2800 -, '~ 3800",.. '~ 3800 '""-...,,, ""',, '"'"'",,,, '-,..,,, "~00~0 ! 3000 "',~ 4000 L "",,,,,,. %'"'% 3200 ',. 4200 · ,, 3400 % 4400 3600 ""'"~ 4600 [ 3800 I I I I I I I I t i I i I I i I I i i i I I I I I i I i i i i 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 East (feet) -> IARCO Alaska, : ne. F I · Location : Norfh Slope, Alaska WELL PROFILE DATA ..... Pont ..... ~ In¢ O~r ~ No,'th Ea~ V. Sec~ Oe<j/t O~ T~ an 0.~ 0.~ 0.~0 0.~ 0.~ 0.~ 0.~ 0,~ K~ ~.~ O.~ 1~.60~.~ 0.~ 0.~ 0.~ 0.~ g~;n Turn TO Tenet I~.~ 1~.~ t~ ~294.31 -~.~a 27.~ ~1 3.~ End ~f ~d 8152.98~.41 143.55 5111.~ -~5.18 ~2.85 ~6&,l& 0.~ ~d ef ~n 8323.2855.00143.35 5205.28 -~7g.343437,86 58~.47 Tore~ 2L-325 V5 28-5e 8655.125500 1~.355~5.~-~2,gl ~g.4( ~.27 0.~ ~d ;f H~d ~71.g7 55.~0143.35 5520,~ -~5g.8~3~6,2g6255.g2 0,~ T.D. ~ [~ ~ ~d~071.g755.00143.33 565~.71 -5171.24 ~4.13 6~1g.75 0.~ 54O TRUE NORTH 550 0 10 ~,,, 530 520 '"'",, /~500 510 500 20 ~ For: BRASSFIELD Date plotted : 2-Oct-g8 Plot Reference is' 325 Version ~.~. S ! 3300? .......... ~ ,:3100 ~L-~- ..... 5500 ~ 2300 i 50 ~, 1700 ~oo 60 290 5OO 280 80 270 ~oo 500 + go( 90 11oo 26O 100 250 110 240 120 250 150 220 1 40 210 150 200 1 60 190 180 170 Normal Plane Travelling Cylinder - Feet All depths shown ore Measured depths on Reference Well ARCO Alaska, Inc. Tarn Drill Site 2L 325 slot #325 Tar~ Development Field North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 325 Version #3 Our ref : prop3157 License : Date printed : 2-0ct-98 Date created : 28-Sep-98 Last revised : 28-Sep-98 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 12 49.742,w150 18 33.414 Slot location is n70 12 47.593,w150 18 58.520 Slot Grid coordinates are N 5927627.594, E 460785.761 Slot local coordinates are 218.46 S 864.82 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath 311 Version #3 308 Version #2 307 Version #3 305 Version #3 317 Version #4 321 Version #2 327 Version #2 ,,311,Tarn Drill Site 2L ,,308,Tarn Drill Site 2L ,,307,Tarn Drill Site 2L ,,305,Tarn Drill Site 2L ,,317,Tarn Drill Site 2L ,,321,Tarn Drill Site 2L ,,327,Tarn Drill Site 2L 323 Version #2,,323,Tarn Drill Site 2L 329 (Arete) Version #10,,Arete,Tarn Drill Site 303 Version #3,,303,Tarn Drill Site 2L 310 Version #1',,310,Tarn Drill Site 2L 309 Version #2,,309,Tarn Drill Site 2L 301 Version #1,,301,Tarn Drill Site 2L 315 Version #3,,315,Tarn Drill Site 2L 313 Version #4,,313,Tarn Drill Site 2L 318 Version #3,,318,Tarn Drill Site 2L 319 Version #1,,319,Tarn Drill Site 2L Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 23-Aug-98 210 23-Aug-98 255 21-Aug-98 270 5-Aug-98 299 23-Aug-98 117 28-Sep-98 60 28-Sep-98 30 28-Sep-98 30 28-Sep-98 59 1-0ct-98 329 1-Oct-98 225 1-Oct-98 239 1-0ct-98 360 1-0ct-98 149 2-0ct-98 180 2-0ct-98 105. 1-Oct-98 90. 0 500.0 0 400.0 I 500.0 9 400.0 5 1100.0 I 600.0 i 800.0 0 600.0 9 400.0 9 400.0 0 500.0 9 500.0 0 300.0 9 600.0 1 200.0 I 300.0 I 500.0 500 0 400 0 500 0 400 0 6040 0 600 0 $00 0 1725 0 400 0 400 0 500 0 500.0 300.0 600.O 200.0 300.0 500.0 ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS 3" 5,000 psi WP OCT i~l MANUAL GATE / KILL LINE ~j~ 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator / / DSA 13-5/8" 5,000 psi WP -'~L x 11" 3,000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams L_ ] 3" 5,000 psi WP Shaffer GATE VALVE ~raulic actuator jdl ~~ MA' "3" 5,000N~jS/~L%AOTCETVALVE 13-5/8" 5,000 psi WP DRILLING SPOOL L] w/two 3" 5M psi WP outlets I ARCO Alaska, Inc. '~ Diverter Schematic Doyon 141 Flowline 21 ¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" OD DIVERTER LINE 16" 62 ppf PEB CONDUCTOR PIPE set at @0' (GL) ARCO Alaska, Inc. , r Post Office Box 100360 Anchorage, Alaska 99510-0360 October 7, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2L-325 Surface Location: 218' FNL 865' FEL Sec 22 T10N R7E, LIM Target Location: 179' FSL, 2555' FEL Sec. 23, T10N, R7E, UM Bottom Hole Location: 110' FNL, 2341' FEL Sec. 26, T10N, R7E, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2L-325, located approximately six miles southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will completed with Doyon 141 also. Attached is the information required by 20 AAC 25.005(c). The_re will be no reserve pit for this well. Due to the fact that 2L-325 will be ~ the second weird on the Tarn 2L pad, a surface/production casing annulus may not be available for waste drilling mud disposal. ARCO requests permission to haul the waste drilling mud from 2L-325 to one of the approved casing annuli on the Tarn 2N pad. Please refer to a separate letter dated 10/7/98, requesting a waiver to 20 AAC 25.080. If an approved annulus is available on Drillsite 2L when 2L-325 is drilled, then waste drilling mud will be disposed of as allowed. If permission is not granted to haul the waste drilling muds to 2N pad, or an approved annulus is not available on 2L pad, then the drilling mud wastes will be hauled to a KRU Class II disposal well. All cuttings generated will be either stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption from the H2S requirements. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany David W. Johnston Application for Permit to Drill Page 2 KRU 2L-325 However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. The following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group Attachments cc: KRU 2L-325 Well File - ARCO Alaska, Inc. - GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2L 325 1. Move in and rig up Doyon 141. 2. Install diverter system. 3. Drill 9.875" hole to 7-5/8" surface casing point according to directional plan. , Run and cement 7-5/8" 29.7#, L-80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. NOTE: TAM Port Collar will be placed in the 7-5/8" casing _+:t000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGCC. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. See attached TAM Port Collar Utilization Decision Tree. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. . Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). . , Drill 6.75" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(0). Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. ND BOPE and install production tree. ~' ARCO Alaska, Inc. Secure well. Rig down and move out. ]3. Hydrocarbon intervals will be tested after the rig move. ARCO Alaska, Inc.- .... DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2L-325 Drillinc~ Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.0-10.2 ppg 15-35 25-50 70-120' 10-25 15-40 5-7 9.5-10 +10% Drill out to TD 8.5 - 10.0 ppg 12-24 15-30 45-6O 2-6 4-8 4-6 through Arete & Tarn 9.0-10 <11% Drillinq Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Degasser Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1,357 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2L pad are expected to be -2,350 psi (0.50 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. ? ~ ;¢~ ~ !'~ f ~ ARCO Alaska, Inc.·~ Well Proximitv Risks: The nearest well to 2L-325 is 2L-329. The wells are 59.9' from each other at a depth of 400'. Drillinq Area Risks- The primary risk in the 2L-325 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8- 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. 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 casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal 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 2L-325 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 2L-325 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. 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 surface casing shoe will be set a minimum of 100' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,100') + 1,500 psi Max Pressure = 2,810 psi ARCO Alaska, Inc. ~ This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of ..OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5Y2" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi 3Y2" 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). TARN TAM Port Collar Utilization Decision Tree No Cement// to Surface ,, Cement above Port Collar (1000' TVD) / Perform Top Job as per ............................................ requirements of If Top Job is ineffective or AOGCC unacceptable to AOGCC Nipple Up and Test BOP's Begin Primary Onei Stage Cement Job · Cement to Surface Cement / below Port / Collar / (1000' TVD)/ Open Port Collar using drillpipe Circulate Cement to Surface and close Port Collar Nipple Up and Test BOP's Continue with Completion Indicators of Cement Top 1. Observation of Tracers in Spacer ahead of lead cement 2. Calculated Displacement 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface Continue with Completion Nipple Up and Test BOP's Continue with Completion [ c~,.~ w ,~,o-~.~.~. For: BRASSFIELD] Oote ~lot~¢<l : ~-o~-g8 P~t Re~r~nca ,~ ~25 V~r~ t5. [ C~rd~nate~ are ,n feet reference slot ~25. ~ True Ve~icol Oepth~ :~e RgB (~ycn 141}. ARCO Alaska, Inc. , ~~ 0~,~--- -;:,: 32W- --- F'[eld : Tarn Development Field Lacation : North Slope, Alcska, 500 0 500 1000 1500 2000 East (feet) -> 2500 3000 3500 4000 I I I I I I ! I SURFACE LCCATION: 218' FNL, 865' FEL SEC. 22, T10N, R7E Begin Turn to Target Base West Sok Sands EOC t43.68 AZIMUTH 6060' (TO TARGET) ***Plane of Proposal*** '7 5/8" Casing Pt C80 4500 5OO 500 1000 1500 2OOO 50O 500 1000 1500 2COO 25O0 3COO 5500 4000 4500 5OOO 5500 6000 iO0 RKB ELEVATION: 145' KOP TVD=800 TMD=800 DEP=0 .3.00 DLS: 3.00 dee per 100 ft 9' ~UgUASE"~ PERMAFROST TVD=1195 TMD=1198 OEP=40 TOP WEST SAK SANOS TV0=1235 TM0=1239 OEP=4-9 BEGIN TURN TO TARGET TVD=1294 TMD=1300 OEP=64 24.81 54.72 DLS: 5.00 dee per ~00 ft 4-4.67 54.63 BASE WEST SAK SANDS TVD=1964 TMD=2145 DEP=547 EOC ,'rVD=1980 TMD=2176 OEP=573 7 5/8" CASING FT TVD=2300 TMD=2786 OEP=ia95 C80 'PFD=2,~77 TMD=3124. DEP=1380 MAXIMUM ANGLE 58.41 9EG C5( C4~ TARGET LOCATION: 179' FSL, 2555' FEL SEC. 23, TION, R7E TARGET TVD=5383 TMD=8653 OEP=6060 SOUTH 488.3 EAST 5589 Begin Angle End Anole T3 Top TARGET - Mid Bermuda T2 - Bose C35 TD - Ccsing Pt TO LOCATION: 1~0' FNL, 2341' FEL SEC. 26, TiON, RTE i2500 t 3000 3500 4000 4500 50aa ,L 755C0 L C50 TVD=3765 TMD=5582 DEP=347~ C40 TVO=4C95 TM0=6212 DEP=4-O11 TARGET ANGLE 55 DEG ENO T3 -TOP BERMUDA TARGET - MID BERMUDA TVD=5383 TMD=I T2 - BASE BERMUDA TVD=5445 TMD=87~1 OEP=6149 C35 TVD=5520 TMD=8872 DEP=6256 TD - CASING PT TVD=5635 TMD=g072 DEP=6420 i i I i ] i i i i ~ ii , I i ~ , i ~ ~ i : : i 0 500 1 COO 1500 2000 2500 3COO 3500 4000 4500 5000 5500 6000 Verficol Secfion (feet) -> Azimuth 14.3.68 with reference 0.00 N, 0.00 E from slot #325 57.47 OLS: 2.00 deE per 100 ft 6500 7000 i~'°~" w ~-' For: BRASSFIELDI P'-~ Ret.re.ce ,~ 525 Var~ ~3. C~r~ln~tes ore ;n feet relerence slot ~T~ua V~/ca; O~oms ~re r~fer~nc. IARCO Alaska, Inc., I Slructure : Tarn Orill Site 2L Well : 325 Tarn Development Field Location : NoAh Slope, Alaska! East (feet) -> 20 80 40 0 40 80 120 160 200 240 280 320 360 400 4¢0 '*80 520 0 ....... ;1'~: ....... · ' ~' 80 .... ,, 1~oo '7o% ao ,, / .... ; 1 700 _ ~ 1100 ~200 1 .... .... ~ ~ 700~' 1 ~"~ 900 ...... ~ 11~-. '-=~%z;z-~-. ~ ~ ~ ~-.~ "'-Cuuu ..... ~ 1000 ....... ' .....~ 1 ~ O0 .... 0 ~ ........ ~0 0 1 ~oo ", ",, ~oo '"-.. ~2~-.. '-.. ,~ '"'"': :~h'- ~3oo .......... '"~ ', "~ ~ 20o., '-.. "-.. ~b~ '"--:~ ' ...... ' ..... 40 I ~ 3400 ',, ", 1200 ",~ 1300 ",. "-.. . '"-.~ 170~'--... ~ 4~ '"'--_~ i 40 ' ~ ', ~ ~oo ", .... -.... ;.zeb~ oo ...... "--:. ~ ~L ~ ' ~ " '- "'- '- "-~ 1800 "-- "3500 ' ", 1~00 ". 1400 '-. "- " '"' I 80 f ", ", ~ "'-, "-. "-~1200 '"" '"' 1~ ~ '~ 1400 ", ',. "~ 1~ "-.. ~cn~".. ~uu i 80 ~ ,, ,, '.., . '-.. '-... ~-:.~ ~ -..... '~ ~600 ',,, "~, 1400 '...1~00 ""-. ""-. i5Q0 '""-. ~ ', ', '", "-~ ~ 5DO '"-~ 2000 / 120 500 '"',1500 '"'-..1600 '"'"" "'"'"- 1400 "'%[ 120 ~3700 '"":"., "".. "'.. ""-. 16~. 160 ~ ~ 180 '.~1 600 '"'~ 1600 %..., 700 ""-. '"'-~, 500 F L 5800 2co ",,, "',,., '"%. '"-..~7~o..... [ 20o ,< oo , ' '- '--.. , oo ... ~ ',1800 "- '%~ 280~1 ~.,, 4000 '"'""".~ 1800 '""'"'... "x '-.I~00... -. ~ 28o 320 ~ '[ '"'"'"',.. '"" "'" ~ 200~d ~ '. -% 1900 320 , ~, "% ~ %.. ~eo~ _ i .. 3so ~ '~, ". "2000 I ' '~ 19C0 ~.. ] 4co q, '.,, ",........ "..... '~ ~oo i 4200 '.. 4~0 ' "% 440 ~ x.... % 2i00 ~8C ' '. L 480 ~ 4500 ' 2000 '"' " '". 2200 560 ~ """, 560 ;~ 4400 '...... 600 " ~ 600 f i ; i i i J i [ J i i i i i i i i i i i i i i i i , i ; , 120 80 ~0 0 40 80 ~ 20 160 200 2~0 280 320 360 ~00 ~¢0 ~80 520 [asf (feel) -> 0..~ ~,,.~.. For: BRASSFIELD[ Co~e ¢oU. ed : 2-~-98 P~t Reference i. 325 Ver~ IARCO Alaska, Inc. Structure : Tarn OHII Site 2L Well : z25 Field : Tam Development Field Location : North Slope, Alaska East (feet) 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 4-00 I I I I I I I I ~ I t I I ~ J i ' i I I I I ~ I I I I I :. g,~ J I i 400 2000,, '.. ",,, 2200',.:-... '",....~'~'~. .......' ........ ' ..... :::::::: ........ ",, ........ 600 ".. ".. "-. "-."-.. ' -. .... ., 2~21~3 ..... ' .......' ........ 2200 i ~- 600 ".. '".. "'.. '"'-:'".. '"'-. ""-. ' ..... ,2000 ........ 2600 2~)'0' .... :: ............ ! L ',% 220~,,,..2400 '%.2400 '"'.::",~ 220~"...~ 30~ .... '" ..... ' ....... ' ........... ~i ........ " "- ". 240¢'-'"' -.. ' ..... ..... ' ..... ,~'008.... ~,_ 800 800 '",. "-.. "-... '".:::'-... "'--... 2460 ...... ' ........ ' ........ ,~ 5200~ '",, '"'. "'. ""-'"'- '"'-., 3200 '"'- '"--~ 2200 "--.. / " '"' "" '"""'" '"- ...... ' ........ ' ...... / ~ 1 ooo 1000 "~ 2400 '%, 2600 ".. "..."-.. '--.. "-.,,. 2600... '"'--. 2800 / J / · ,,,, -..., ' ;'~,-~:"-..:'-.00'"43°° "' ..... ' ...... .24o0":,' ..... 1400 '-.... ". 2800 "'" '%' 28~'" "'"" 2600 '"-....;.'" ......... ,~oot ,,,,, ....,.~ooo ...... '-....'-/:' "--....,,ooo 1800 '"~ 3000 '"'-. '"'. ."' '""-. '""-. '""-. ~,nnl- ~ 800 ..,... ...... ...,., '"--... J '",, '"'-. '"-., ~ '"'... '"'-... I- 2000 2000 0 '"~ 3200 '"-. "'-. '". '~J (" ,r- 2200 0 O0 2400 I V 2600 2800 3000 3200 · '-,. 3400 "... "" "-. ".~ 3200 '.%3400 ",....,,,..,., ".,.,,,,..,,. · % 3600 3400 3600 3800 3800 "~ 4000 -% 4000 3600"-. F '""-. "'"'. ? 2600 "'... '"-~ 3400 j · i F '-% 380~"... I 2800 3000 f 3400 3600 F 3800 ,, '. 4200 '~ ~400 · "~ 4600 I " 4000 i i i i i i i i i i i [ I i i i i i i , i i i i i J i i i i i 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 ~000 3200 3400 Easf (feel) -> 2200 ~ ',-4- 2400 ~ I I ARCO Alaska, Inc.i 1 Strucfure : Tarn 0HII $[fe 2[ Well : 325 F' eld : Tarn Oevelopmenf Field Location : North Slope, Alcskaj WELL PROFILE DATA ..... Pc,,~t ..... ~ ~c o,', Ivo ~ort, [=m ¥. sect ~1~ T~ on o.~ o.~ o.~o o.~ o.~ o.~ o.~ o.~[ ~ ~.~ o co i ~oo~.~ o.~ o.~ o.~ ~.~ ~;n Turn To f~et I~.~ tS.COI~ 1294.31 E~ ef ~,Jd~um 2173.~ 38.411~55 1~.34 -481.59512.12572.90 5.~ :nd al ~ ~23.28 55 ~ 1 ~.33 5203.28 -~7g.343437,86 ~.47 2,~ Targ~ 2L-525 V3 28-5e 8633.1255~ t~.355~3.~-~2.gI 5~g.4&~.27 ~.~ ~ ef ~d 887t.g755 ~ 143.35 5320.~ -~3g.843~6.2g525~.g2 0.~ T.O. ~ E~ ~ H~9071.g7~5~ 143.33 ~634.71 -~171.24 ~4.15 6~lg.~ o.~ 510 ~, ~30 320 """,7 · 340 350 300 TRUE NORTH 0 10 /\ $o p{ ,'poo i50 /; 20 29O 28O 270 I \ ~-0~ 5oo T ~ 5O0 I 260 ~'~ .... ~'"" For: BRASSFIELD ! 0ate olotfe,~ : 2-0ct-98 P~ot Reference ~s 525 Vem~on Coor~i~a True V~cal 0~hs~are~relerence~ / 55op2_ ................ ¥0 ;;oo 2300 50 1700 2100 60 , ~1500 ; 7O ! ! 80 700 -~ ',~ ::._~_~_p_,____!_~_ .Or2-! 100 '~-. 1100 ' !00 25O 110 240 250 220 210 2OO i90 Normal Plane Travelling Cylinder - Feet 120 t30 2 0 !40 150 160 !80 170 Ail depths shown ore Meosured dep(hs on Reference We!~ ARCO Alaska, Inc. Tarn Drill Site 2L 325 slot #325 Tarn Development Field North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 325 Version #3 Our ref : prop3157 License : Date printed : 2-0ct-98 Date created : 28-Sep-98 Last revised : 28-Sep-98 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 12 49.742,w150 18 33.414 Slot location is nT0 12 47.593,w150 18 58.520 Slot Grid coordinates are N 5927627.594, E 460785.761 Slot local coordinates are 218.46 S 864.82 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath 311 Version #3,,311,Tarn Drill 308 Version #2,,308,Tarn Drill 307 Version #3,,307,Tarn Drill 305 Version #3,,305,Tarn Drill 317 Version #4,,317,Tarn Drill 321 Version #2,,321,Tarn Drill 327 Version #2,,327,Tarn Drill Site 2L Site 2L Site 2L Site 2L Site 2L Site 2L Site 2L 323 Version #2,,323,Tarn Drill Site 2L 329 (Arete) Version #10,,Arete,Tarn Drill Site 303 Version #3, 303,Tarn Drill Site 2L 310 Version #1', 310,Tarn Drill 309 Version #2, 309,Tarn Drill 301 Version #1, 301,Tarn Drill 315 Version #3, 315,Tarn Drill 313 Version #4, 313,Tarn Drill 318 Version #3, 318,Tarn Drill 319 Version #1,,319,Tarn Drill Site 2L Site 2L Site 2L Site 2L Site 2L Site 2L Site 2L Closest approach with 3-D Minimum Distance method Last revised Distance 23-Aug-98 23-Aug-98 21-Aug-98 5-Aug-98 23-Aug-98 28-Sep-98 28-Sep-98 28-Sep-98 28-Sep-98 1-Oct-98 1-Oct-98 1-Oct-98 1-Oct-98 1-0ct-98 2-Oct-98 2-Oct-98 1-0ct-98 210.0 255.0 270.1 299 9 117 5 60 1 30 1 30 0 59 9 329 9 225 0 239 9 360.0 149.9 180.1 105.1 90.1 500.0 400.0 500.0 400.0 1100.0 600.0 800.0 600.0 400.0 400.0 500.0 500 0 300 0 600 0 200 0 300 0 500 0 Diverging from M.D. 500.0 400.0 500.0 400.0 6040.0 600.0 800.0 1725.0 400.0 400.0 500.0 500.0 300.0 600.0 200.0 300.0 500.0 ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSi BOP COMPONENTS 3" 5,000 psi WP OCT i-- MANUAL GATE V KILL LINE L 3" 5,000 psi WP Shaffer GATE VALVE 1 w/hydraulic actuator / J / BSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi wP Shaffer GATE VALVE _ __ ~/hydraulic actuator ~ CHOKE LINE 13-5/8" 5,000 psi WP DRILLING SPOOL I ~.~.~ w/two 3" 5M I:)si WP outlets SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams ARCO Alaska, Inc. Diverter Schematic Doyon 141 211/~,, 2,000 psi WP DRILLING SPOOL w/16" Outlet Flowline 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" OD DIVERTER LINE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 October 7, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2L-325 Surface Location: 218' FNI. 865' FEL Sec 22 T10N R?E, UM Target Location: 179' FSL, 2555' FEL Sec. 23, T10N, R?E, UM Bottom Hole Location: 110' FNL, 2341' FEI_ Sec. 26, T10N, RTE, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2L-325, located approximately six miles southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will completed with Doyon 141 also. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Due to the fact that 2L-325 will' be only the second well drilled on the Tarn 2L pad, a surface/production casing annulus may not be available for waste drilling mud disposal. ARCO requests permission to haul the waste drilling mud from 2L-325 to one of the approved casing annuli on the Tarn 2N pad. Please refer to a separate letter dated 10/7/98, requesting a waiver to 20 AAC 25.080. If an approved annulus is available on Drillsite 2L when 2L-325 is drilled, then waste drilling mud will be disposed of as allowed. If permission is not granted to haul the waste drilling muds to 2N pad, or an approved annulus is not available on 2L pad, then the drilling mud wastes will be hauled to a KRU Class II disposal well. All cuttings generated will be either stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption from the H2S requirements. ARCO Alaska, Inc. is a Subsidiary. of AtlanticRichfieldCompany David W. John's%on Application for Permit to Drill Page 2 KRU 2Lo325 However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. The following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071 ) 265-6967 If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group Attachments cc: KRU 2L-325 Well File · WELL PERMIT CHECKLIST COMPANY ~ ~C.. ~ WELL NAME Y.,f~LL ,3, J,.- 3 ~. ~' PROGRAM: exp [] dev J~ redrll [] serv [] wellbore seg II ann. disposal para req ~.X~. FIELD S POOL INIT CLASS ~ [==_ ~ [ - c~ ~. L.- GEOL AREA ~ cL O UNIT# ON/OFF SHORE ADMINISTRATION 1. . 3. 4. 5. 6. 7. 8. 9. 10. 11. 13. Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well Iocaled in a defined pool .................. Well located proper dislance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficienl acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected pady ................... Operator has appropriate bond in force ............. Permil can be issued without conservation order ........ Permil can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... ENGINEERING DATE , :GEOLOGY 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMr will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................. 26. BOPE press rating appropriate; test to "~ O~:~"~-~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown .......... . . 29. Is presence of H2S gas probable ................. ~N (~N N (~N N N Y N 30. Permit can be issued w/o hydrogen sulfide measu~ Y N 31. Data presented on potential overpres~~ ....... Y N 32. Seismic analysis ofshall~~nes ..... ' ........ Y N 33. Seabedcond~ey(ifoff-shore) ........... Y N 34~ogress reports ....... Y N exploratory omy$ ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... ~) N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... ~ N ~u~,~. 5,S¢,~.5~,- T-~-~~.A..`.z-~?"-~..D.~.~:t"~.~.`.~-~N-~--~-z~-J-~.~!.~ ...... to surface; 'Tt~,~ t5 --,r~e ~_..~ v,.~-.' ~J..- 5'2-'~ 3~ou~.o 15c_ Is...T ~(u.z.. · (C) wiiJ'~bt impair.._mechanical integrity of the well used for disposal; (~ N (D) will nol damage producing formation or impair recovery from a~ N pool; and will not circumve, nt 20 AAC 25.252 or 20 AAC 25.412... t~_ N GEO~i~_zG_Y: ENGINEERING: UIC/Annular COMMISSION: DWJ~ RNC~ CO Comments/Instructions: M chekhsl ~;v 0512919~.~ 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. Sperry-Sun Drilling Services LIS Scan Utility Wed May 05 10:30:38 1999 Reel Header Service name ............. LISTPE Date ..................... 99/05/05 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 99/05/05 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 KUDARUK RIVER UNIT, TARN POOL ~s~rs/~ LOSS 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 (PT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MWD RUN 2 AK-MM-90008 G. GRIFFIN G. WITHLOCK 2L-325 501032027500 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 05-M3kY-99 22 10N 07E 218 865 146.20 144.70 117.10 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 108.0 9.875 7.625 2799.0 6.750 9200.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED NEUTRON POROSITY (CNP) AND STABILIZED LITHO-DENSITY (SLD). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM DEDE SCHWARTZ OF ARCO ALASKA, INC. ON 09 DECEMBER, 1998. SPERRY-SUN MWD DATA IS PRIMARY DEPTH CONTROL (PDC) FOR WELL 2L-325. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9200'MD, 5694 ' TVD. SROP = SMOOTHED R_ATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBDC = SMOOTHED BULK DENSITY - COMPENSATED. SCOR = SMOOTHED STANDOFF CORRECTION. SNPE = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED IN PROCESSING NUCLEAR/NEUTRON LOG DATA: FIXED HOLE SIZE = MI/D WEIGHT = MUD SALINITY = FORMATION WATER SALINITY = FLUID DENSITY = MATRIX DENSITY = ~ITHOLOGY = $ File Header Service name ............. STSLIB.001 6.75" 9.1 - 9.8 PPG. 400 - 600 PPM. CL- 19149 PPM. CL- 1.0 G/CC 2.65 G/CC SANDSTONE Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NIIMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMM~Y PBU TOOL CODE START DEPTH STOP DEPTH GR 2775.0 9107.5 PEF 2799.0 9094.0 DRHO 2799.0 9094.0 RHOB 2799.0 9094.0 FET 2799.0 9114.5 RPD 2799.0 9114.5 RPM 2799.0 9114.5 RPS 2799.0 9114.5 RPX 2799.0 9114.5 FCNT 2810.0 9079.0 NCNT 2810.0 9079.0 NPHI 2810.0 9079.0 ROP 2815.0 9200.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 2 2815.0 9200.0 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 A]0sent valu~ ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 EQUIVALENT UNSHIFTED DEPTH MERGED M3~IN PASS. $ Name DEPT ROP FET GR RPD RPX RPS RPM NPHI FCNT NCNT RHOB DRHO PEF Service Order MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Units Size Nsam FT 4 1 FT/H 4 1 HOUR 4 1 API 4 1 OH]~M 4 1 Om~M 4 1 OHMM 4 1 OHM_M 4 1 P.U. 4 1 CNTS 4 1 CNTS 4 1 G/CC 4 1 G/CC 4 1 BA/~N 4 1 Rep 68 68 68 68 68 68 68 68 68 68 68 68 68 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name DEPT ROP FET GR RPD RPX RPS RPM NPHI FCNT NCNT RHOB DRHO PEF Min 2775 0 35 0 31 40 47 1 34 1 28 1 24 1 18 11 22 150 53 13679.9 1.27 -0.77 1.42 Max 9200 919.53 89.65 235.47 2000 2000 2000 2000 63.18 1079.22 32180.6 2.72 0.52 12.76 Mean Nsam 5987.5 12851 240.357 12771 1.19078 12632 124.427 12666 5.26579 12632 4.86544 12632 4.80059 12632 5.14847 12632 35.2643 12539 263.627 12539 18291.8 12539 2.28178 12591 0.127196 12591 3.13199 12591 First Reading 2775 2815 2799 2775 2799 2799 2799 2799 2810 2810 2810 2799 2799 2799 Last Reading 9200 9200 9114.5 9107.5 9114.5 9114.5 9114.5 9114.5 9079 9079 9079 9094 9094 9094 First Reading For Entire File .......... 2775 Last Reading For Entire File ........... 9200 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/05 Maximum Physical Record..65535 File Type ................ 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 ....... 99/05/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 P~AW 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 2775.0 9107.5 PEF 2799.0 9094.0 DRHO 2799.0 9094.0 RHOB 2799.0 9094 0 FET 2799.0 9114 5 RPD 2799.0 9114 5 RPM 2799.0 9114 5 RPS 2799 0 9114 5 RPX 2799 0 9114 5 FCNT 2810 0 9079 0 NCNT 2810 0 9079 0 NPHI 2810 0 9079 0 ROP 2815 0 9200 0 $ LOG HEADER DATA DATE LOGGED: 10-NOV-98 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 3.2.12.3 DOWNHOLE SOFTWARE VERSION: CIM 5.46,SP4 5.16,SLD 10.87 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9200.0 TOP LOG INTERVAL (FT) : 2815.0 BOTTOM LOG INTERVAL (FT) : 9200.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 55.2 MAXIMUM ANGLE: 62.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY Pl146NL4 EWR4 ELECTROMAG. RESIS. 4 Pl146NL4 CNP COMPENSATED NEUTRON Pl146NL4 SLD STABILIZED LITHO DEN Pl146NL4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' ~ CASING DEPTH (FT) : BOREHOLE CONDITIONS 6.750 6.8 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 CIRC~TING TERMPERATLrRE: 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 LSND 9.80 48.0 9.0 600 4.8 2.800 1.817 4.700 2.600 .0 Name Service Order Units Size Nsam Rep Code Offset channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 NPHI MWD 2 P.U. 4 1 68 32 9 FCNT MWD 2 CNTS 4 1 68 36 10 NCNT MWD 2 CNTS 4 1 68 40 11 RHOB MWD 2 G/CC 4 1 68 44 12 DRHO MWD 2 G/CC 4 1 68 48 13 PEF MWD 2 BARN 4 1 68 52 14 45.9 First Name M~n Max Mean Nsam Reading DEPT 2775 9200 5987.5 12851 2775 ROP 0.35 919.53 240.357 12771 2815 Last Reading 9200 9200 GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF 40 47 1 28 1 24 1 18 1 34 0 31 11 22 111 25 13679.9 1.27 -1.11 1.42 235.47 124.427 12666 2000 4.86544 12632 2000 4.80059 12632 2000 5.14847 12632 2000 5.26579 12632 89.65 1.19078 12632 63.18 35.2643 12539 1079.22 262.906 12539 32180.6 18291.8 12539 2.72 2.28178 12591 0.52 0.127135 12591 12.76 3.13199 12591 2775 9107.5 2799 9114.5 2799 9114.5 2799 9114.5 2799 9114.5 2799 9114.5 2810 9079 2810 9079 2810 9079 2799 9094 2799 9094 2799 9094 First Reading For Entire File .......... 2775 Last Reading For Entire File ........... 9200 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/05/05 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/05/05 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File