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185-260
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. / ~- _~ ~ _~ Well History File Identifier Organization (done) ~.. Two-Sided RESCAN n Color items: GrayScale items: Poor Quality Originals: DIGITAL DATA [] Diskettes, No, [] Other, No/Type TOTAL PAGES: ?/ ORGANIZED BY: ~REN NOTES: VINCENT SNERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds Other Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is/ Scanned ,done) IIIIIIIIIIIIIIIIIII PAGES:q/ (at the time of scanning) SCANNED BY: BEVERLY E~REN VINC~ARIA LOWELL RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI General Notes or Comments about this file: ~/O/~-~"--/O ~'--- PAGES: --'3'~'------~ Quality Checked (done) III Illllalllll al Rev1 NOTScanned.v40d STATE OF ALASKA RE., AL/ OIL AND GAS CONSERVATION COMMON IVED REPORT OF SUNDRY WELL OPERATIONS JUL 2 5 2013 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate P' Other `",t' Alter Casing Pull Tubing E Stimulate-Frac r Waiver r Time Extension Change Approved Program ""Operat. Shutdown "` Stimulate-Other r Re-enter Suspended Well 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 185-260 ' 3.Address: 6.API Number: Stratigraphic "" Service "" P. O. Box 100360,Anchorage,Alaska 99510 50-103-20051-00' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25587 2H-10 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool ' 11.Present Well Condition Summary: Total Depth measured 7979 - feet Plugs(measured) none true vertical 6351 feet Junk(measured) none Effective Depth measured 7878 feet Packer(measured) 7495 true vertical 6277 feet (true vertical) 5986 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 118 118 SURFACE 2824 9.625 2860 2781 PRODUCTION 7927 7 7960 6337 Perforation depth: Measured depth: 7622-7637, 7648-7681,7713-7734 True Vertical Depth: 6081-6093,6101-6126,6150-6165 SCANNED NOV 0 5 201 Tubing(size,grade,MD,and ND) 3.5, L-80, 7615 MD,6076 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER'F-1'PERMANENT PRODUCTION PACKER @ 7495 MD and 5986 ND SSSV-TRMAXX-CMT-5-SR SSSV @ 1819 MD and 1817 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 247 1061 234 -- 209 Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development P. Service 1- Stratigraphic E 16.Well Status after work: Oil I . Gas r WDSPL F Daily Report of Well Operations XXX GSTOR f WINJ r WAG r GINJ r SUSP r 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: none Contact John Peirce @ 265-6471 Email John.W.Peircer'a.conocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature ,/ ._ Phone:265-6471 Date 7/0.4/1 3 !// ,f-- RBDMS AUG - 2 0145//-- Form 10-404 Revised 10/2012 /4,,y%, Submit Original Only 4 2H-10 Well Work Summary DATE SUMMARY 6/14/2013 PULLED SOV @ 7379' RKB, SET DV @ SAME, MIT TBG 3000 PSI PASS, MIT IA 2500 PSI PASS, ATTEMPTED TO PULL CATCHER ON XX PLUG @ 7518' RKB, BAILED MUD &CHUNKS OF ALUMINUM, NO MARKS ON BOTTOM OF BAILER. IN PROGRESS. 6/15/2013 BAILED MUD & METAL TRASH FROM CATCHER ON 2.81 XX PLUG @ 7518' RKB, PULLED 3 1/2 CATCHER @ SAME, PULLED 2.812 XX PLUG @ 7518' RKB, DRIFTED TBG FOR 2 1/2 PERF GUNS& 2.75"WHIPSTOCK TAGGED @ 7816' SLM - 122' RAT HOLE. IN PROGRESS. 6/16/2013 MEASURED BHP @ 7651' SLM (3058 psi) . READY FOR ELINE. 6/27/2013 SUCCESSFULLY RAN 15' PERFORATING GUN. KUP 2H-10 ConocoPhillips Well Attributes Max Angle&MD TD µ Ai ll k 1 IOC Wellbore API/UWI Field Name Well Status Inc!C) MD(665) Act Btm(MB)) cnnocaPhiulps 501032005100 KUPARUK RIVER UNIT PROD 49.82 3,425.00 7,979.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date "' SSSV:TRDP 75 12/30/2012 Last WO: 6/4/2013 39.51 11/25/1985 Well Confi9:'-2H-10i 79 dual .39:16 AM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 7,816.0 6/15/2013 Rev Reason:PERFORATION,TAG,GLV C/O haggea 7/2/2013 HANGER,32 -. --- Casing Strings Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd CONDUCTOR 16 15.062 36.0 118.0 118.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top OMB) Set Depth(f...Set Depth(ND)...String WE..String...String Top Thrd SURFACE 9 5/8 8.921 35.4 2,859.5 2,780.9 36.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd PRODUCTION 7 6.276 33.6 7,960.5 6,336.7 26.00 J-55 BTC Tubing Strings 1 4 , ' . . I. Tubing Description String 0... String ID...Top(ftK8) Set Depth(f...Set Depth(ND)...String WI...String... String Top Thrd ( TUBING WO Upper 3 1/2 2.992 I 31.5 I 7,503.3 5,992.2 9.30 L-80 EUE-M I CONDUCTOR, Completion Details 36118 _ Top Depth (ND) Top Inc' Nomi... Top(MB) (MB) (") Nem Description Comment ID(in) SAFETY VLV, 'o, I 31.5 31.5 -0.35 HANGER FMC GEN III HANGER 2.992 1,819 1 ill 1,818.8 1,816.5 9.71 SAFETY VLV TRMAXX-CMT-5-SR SAFETY VALVE"X"PROFILE 2.812 7,438.3 5,943.7 42.64 NIPPLE HES'X'NIPPLE 2.812 7,490.7 5,982.7 41.48 LOCATOR BAKER LOCATOR 2.950 GAS LIFT' Tubing Description strip 0... String ID T GBH-22 BONDED BAKER SEAL ASSY 2.950 7,491.5 5,983.3 41.49 SEAL ASSY 2614 ^� o ftKB Set Depth(f...Set Depth ND String Wt...String String Top Thrd -- � 9 String 9 Pl 1 P P ( 1��� 9 9��� 9 P ! TUBING WO Lower 6.02 5.050 7,494.7 7,614.5 6,075.6 14.00 H-40 8RD STC Completion Details 'Top Depth (ND) Top tool Nomi... Top(ftKB) (RKB) C) Rem Description Comment ID(in) J 7,494.7 5,985.7 41.50 PACKER BAKER'F-1'PERMANENT PRODUCTION PACKER 4.000 SURFACE,A7,498.0 5,988.2 41.50 SBE BAKER 80-40 SBE,10 long,3-1/2 EUE pin on bottom 4.000 7,518.0 6,003.2 41.61 NIPPLE HES X NIPPLE 2.812 GAS LIFT, 7,530.8 6,012.7 41.55 WEARSOCK 1 BAKER WEARSOCK 5.050 4,321 7,572.6 6,044.0 41.36 WEARSOCK 2 BAKER WEARSOCK w/BEVELED SHOE 5.050 IIIII Perforations&Slots Top(N Shot D) Btm(TVD) Dens GAS LIFT, Top(ftKB)Btm(ftKB) (MB) (RKB) Zone Date Ish... Type Comment 5,4e1 7,622.0 7,637.0 6,081.2 6,092.5 A-3,2H-10 6/27/2013 6.0 APERF 60 degree phase,15' PERFORATING GUN 7,648.0 7,681.0 6,100.8 6,125.6 A-4,2H-10 12/17/1985 4.0 IPERF 180 deg.Phasing ail 7,713.0 7,734.0 6,149.7 6,165.4 A-3,2H-10 12/17/1985 4.0 IPERF 90 deg.Phasing;4"Schlum. GAS LIFT,0 siom4 HyperJet 6,37 Notes:General&Safety W End Date Annotation 1/19/2006 NOTE:WAIVERED WELL:IA x OA ANNULAR COMMUNICATION GAS LIFT, 10/27/2010 NOTE:View Schematic w/Alaska Schematic9.0 7,014 r 7/12/2012 NOTE:***TUBING SET DEPT WCOMPONENT DEPTHS ARE WLM"' MI III GAS LIFT, - u 7,380 III NIPPLE,7,438 <' MI Illa LOCATOR, 7,491 PACKER,7,495 _ - SEAL ASSY, 7,491 , , SBE,7,498 -r t i g illt NIPPLE,7,518 ii if ir WEARSOCK 1, 7,531 WEARSOCK 2, Mandrel Details 7.573 Top Depth Top Port (ND) Intl OD Valve Latch Size TRO Run N...Top(ftKB) (MB) Cl Make Model (In) Sem Type Type (in) (psi) Run Date Com... 1 2,613.8 2,567.5 26.94 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/3/2013 7.622-7,637 2 4,321.0 3,805.2 45.61 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/3/2013 3 5,480.9 4,600.8 46.99 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/3/2013 7,648-7,681 4 6,370.3 5,205.1 48.92 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/3/2013 5 7,014.0 5,638.7 44.33 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/3/2013 1-7734 -` 6 7,379.8 5,900.6 42.09 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 6/14/2013 7,7137,734 ... PRODUCTION, 34-7,960N A TO 7,979 STATE OF ALASKA • � y � , r AL OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS � ,, -•a 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r Perforate r Other H..r t, ~,,, .." Alter Casing r Pull Tubing P . Stimulate - Frac r Waiver r Time Extension r Change Approved R - ogram rOperat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. • Development r . Exploratory r 185 -260 ' - 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50 103 20051 - 00 r 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25587 2H - ' 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / Kuparuk River Oil Pool • 11. Present Well Condition Summary: Total Depth measured 7979 ' feet Plugs (measured) none true vertical 6351 feet Junk (measured) none Effective Depth measured 7878 feet Packer (measured) 7495 true vertical 6277 feet (true vertical) 5986 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 118 118 SURFACE 2824 9.625 2860 2781 PRODUCTION 7927 7 7960 6337 Perforation depth: Measured depth: 7648 -7681, 7713 -7734 True Vertical Depth: 6101 -6126, 6150 -6165 SCANNED JUN 18 2013 Tubing (size, grade, MD, and TVD) 3.5, L - 80, 7615 MD, 6076 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER 'F -1' PERMANENT PRODUCTION PACKER @ 7495 MD and 5986 TVD SSSV - TRMAXX -CMT -5 SSSV @ 1819 MD and 1817 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 247 1061 234 -- 209 Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development 17 • Service r Stratigraphic r 16. Well Status after work: Oil F. Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Drew Huck Cad 265 -6828 Email Andrew .Hucka,conocophillips.com Printed Name Drew Huck Title Sr. Drilling Engineer Signature a 9 ,A Phone: 265 -6828 Date C / i Z / 1 3 i/ 00 RBDMS JUN 12 2013 — /J/I3 Form 10 -404 Revised 10/2012 Submit Original Only . KUP 2H -10 ConocoPhillips ' t wM(C , Well Attributes Max Angle & MD TD Alaska Inc, Wellbore API /UWI Field Name Wellbore Status Inc! ( °) MD (ftKB) Act Btm (ftKB) con... fidbps' - 501032005100 KUPARUK RIVER UNIT PROD 49.82 3,425.00 7,979.0 CommeM H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date ••• _SSSV: 75 12/30/2012 Last WO: 6/4/2013 39.51 11/25/1985 Well Gonfin: --1,6/02013'. Sc ic -Adual 10 18'25 AM ' Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: SLM 7,768.0 5/17/2013 Rev Reason: WORKOVER haggea 6/10/2013 HANGER, 32 - - - -- Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 36.0 118.0 118.0 62.50 H - 40 WELDED Casing Description String 0... - String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.921 35.4 2,859.5 2,780.9 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd PRODUCTION 7 6.276 33.6 7,960.5 6,336.7 26.00 J -55 BTC Tu S trin s Tub Des String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING WO Upper 3 1/2 2.992 31.5 7,503.3 5,992.2 9.30 L - 80 EUE - M CONDUCTOR, Completion Details 36 -118 Top Depth (TVD) Top Inc! Nonni... Top (ftKB) (ftKB) (1 Item Description Comment ID (in) SAFETY VLV, 31.5 31.5 -0.35 HANGER FMC GEN III HANGER 2.992 1,919 ° ll 1,818.8 1,816.5 9.71 SAFETY VLV TRMAXX- CMT -5-SR SAFETY VALVE "X" PROFILE 2.812 7,438.3 5,943.7 42.64 NIPPLE HES 'X' NIPPLE 2.812 7,490.7 5,982.7 41.48 LOCATOR BAKER LOCATOR 2.950 7,491.5 5,983.3 41.49 SEAL ASSY GBH -22 BONDED BAKER SEAL ASSY 2.950 GAS LIFT, Tubin Description String 0... String ID ... Top ftKB Set Depth f Set Depth (TVD) String Wt... String String Top Thrd 2,614 " 9 Pt 9 9 P ( 1 pt ( -•• Pt (Tg ) -- 9 g .- 9 P a TUBING WO Lower 6.02 5.050 7,494.7 7,614.5 6,075.6 14.00 H -40 8RD STC Completion Details Top Depth f (TVD) Top Inc' Nonni... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 7,494.7 5,985.7 41.50 PACKER BAKER 'F -1' PERMANENT PRODUCTION PACKER 4.000 SURFACE, J l 7,498.0 5,988.2 41.50 SBE - BAKER 80-40 SBE, 10' long, 3-1/2 EUE pin on bottom 4.000 3s - z.860 7,518.0 6,003.2 41.61 NIPPLE HES X NIPPLE wDOC PLUG w /JUNK CATCHER 2.812 7,530.8 6,012.7 41.55 WEARSOCK 1 BAKER WEARSOCK 5.050 GAS LIFT, 4,321 7,572.6 6,044.0 41.36 r WEARSOCK 2 BAKER WEARSOCK w/BEVELED SHOE 5.050 IIIII Perforations & Slots Shot all Top (TVD) Btm (TVD) Dens T op (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (811.^ Type Comment GAS LIFT, ___ 7,648.0 7,681.0 6,100.8 6,125.6 A 2H 12/17/1985 4.0 IPERF 180 deg. Phasing 5.481 IIII 7,713.0 7,734.0 6,149.7 6,165.4 A -3, 2H -10 12/17/1985 4.0 IPERF 90 deg. Phasing; 4" Schlum. HyperJet Notes: General & Safety End Date Annotation GAS LIFT, 111= 1/19/2006 NOTE: WAIVERED WELL: IA x OA ANNULAR COMMUNICATION 6,370 IIII 10/27/2010 NOTE: View Schematic w/ Alaska Schematic9.0 III 7/12/2012 NOTE: "" TUBING SET DEPTH /COMPONENT DEPTHS ARE WLM'a' IIIII GAS LIFT, 7,014 IIM al GAS LIFT, Mb 7,350 MI MI NIPPLE, 7438 l i x , MA LOCATOR, 7,491 PACKER, 7,495- -T : SEAL ASSY, a•:_' 7,491 , , SBE,7,498 / 1 ( NIPPLE, 7,518 I._ -l; WEAR50753 1.. Mandrel Details V Top Depth Top port 5... (TVD) Inc! OD Valve Latch Size TRO Run W0ARSO 7673 N... Top (ftKB) (ftKB) r) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 7,573 1 2,613.8 2,567.5 26.94 Camco KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 6/3/2013 2 4,321.0 3,805.2 45.61 Camco KBMG 1 GAS LIFT GLV BK -5 0.000 0.0 6/3/2013 IPERF, 3 5,480.9 4,600.8 46.99 Camco KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 6/3/2013 7.648.7.681 4 6,370.3 5,205.1 48.92 Camco KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 6/3/2013 5 7,014.0 5,638.7 44.33 Camco KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 6/3/2013 P 7•]13 - 7 E .734 6 7,379.8 5,900.6 42.09 Camco KBMG 1 GAS LIFT SOV BEK 0.313 0.0 6/3/2013 PRODUCTION. 34 -7,960 N TO, 7,979 2H -10 Well Work Summary • DATE SUMMARY • 3/11/2013 (PRE RWO) FUNCTION TESTED LDS, T- POT(PASSED), T -PPPOT (PASSED), IC -POT (PASSED), IC -PPPOT (PASSED), MIT -OA (PASSED), TIFL (PASSED). 5/17/2013 TAGGED @ 7768' SLM, 7798' RKB; EST 64' RATHOLE. MEASURED BHP @ 7660' RKB: 2413 PSI. BRUSHED & FLUSHED TBG TO D NIPPLE © 7523' RKB; GAUGED TO 2.3 ". IN PROGRESS. 5/18/2013 PULLED GLVs @ 7052', 6197', 4185', 2259' RKB. SWAB VALVE REPEATEDLY SERVICED. IN PROGRESS. 5/19/2013 PROVIDED CRANE ASSIST, DSM CHANGED OUT SWAB VALVE. SET DVs @ 2259', 4185', 6197', 7052' RKB. PULLED OV @ 7430' RKB. SET CAT SV @ 7523' RKB. IN PROGRESS. 5/20/2013 LOADED TBG/ IA WITH 195 BBL SW, 98 BBL DSL. U -TUBE FOR FREEZE PROTECT. ATTEMPTED CMIT T x IA 2500 PSI, FAILED. ATTEMPTED EXERCISE SSSV, NO FLOW TUBE MOVEMENT. BLED OA WHILE PUMPING AND TESTING. IN PROGRESS. 5/21/2013 ATTEMPTED MIT T x IA 2500 PSI, FAILED. SET DV @ 7430' RKB. MIT -IA 2500 PSI, PASSED. `PULLED DV g3/4130' RKB, CAT SV @ 7523' RKB. READY FOR BPV. • • f Time Log & Summary Conoco;hillips Wel/view Web Reporting Report Well Name: 2H - 10 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 5/30/2013 3:00:00 AM Rig Release: 6/4/2013 6:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/29/2013 24 hr Summary Move Rig and modules from 1F-16A to 2H -10. 00:00 08:00 8.00 0 0 MIRU MOVE MOB P PJSM, HRW and HRC on rig move. Prep Rig for move unplug electrical lines, disconnect steam, water, air and fuel lines. (Wait on trucks.) 08:00 09:30 1.50 0 0 MIRU MOVE MOB P PJSM w/ Truck drivers. break power pack apart. line up trucks and prepare to depart from 1F to 2H pad as per Peak Truck Pusher. 09:30 12:00 2.50 0 0 MIRU MOVE MOB P Mobilize power pack to 2H pad. 12:00 12:15 0.25 0 0 MIRU MOVE MOB P PJSM- Cont Mob Power pack to 2H -10 12:15 13:30 1.25 0 0 MIRU MOVE MOB P Move Pipe Shed and sub off well, prep sub for move. 13:30 17:00 3.50 0 0 MIRU MOVE MOB P Move sub and pipeshed to 2H -10. 17:00 18:45 1.75 0 0 MIRU MOVE MOB P Spot sub over well. 18:45 23:00 4.25 0 0 MIRU MOVE MOB P Lay Matts & Herculite, spot power pack, pipe sheds, rockwasher. 23:00 00:00 1.00 0 0 MIRU MOVE RURD P PJSM- Work on rig acceptance list. 05/30/2013 Rig Move, Spot over well, rig up. R/U for circulate out Freeze protect w/ 8.6 ppg seawater, well flowing. Kill well w/ 9.2 ppg brine. OWFF and R/D. N/D tree and N/U BOPE. Test BOPE t/ 2 PS I Noble of AOGCC waived witness of test.l tm l oOAO '03:00 3.00 0 0 MIRU MOVE RURD P PJSM- Work on rig acceptance checklist. Calibrate and test gas detectors. 03:00 06:00 3.00 0 0 MIRU WHDBO RURD P Build scaffolding, Spot tiger tank, choke house and M/U hardline. SIMOPS Load 4" XT -39 Drill pipe in pipeshed. (Rig accepted at 0300) 06:00 07:45 1.75 0 0 MIRU WHDBO RURD P P/U and M/U lubricator and pull BPV as per FMC rep. (IA= 150psi, tubing= 450psi) 07:45 08:00 0.25 0 0 MIRU WHDBO SFTY P PJSM on killing well. 08:00 08:15 0.25 0 0 MIRU WHDBO RURD P Blow air through lines, flood lines and test to 3500 psi. (good) Page 1 of 7 • • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:15 10:00 1.75 0 0 MIRU WHDBO KLWL P Pump 32 bbls of 8.6 brine down IA @ 2bpm, 450 psi taking returns to the tiger tank, shut down and UU to pump down tubing, pump 133 bbls 8.6 brine © 2 bpm, 250 psi. Shut down bleed tubing and IA pressures to zero, shut in well and observed tubing pressure = 120 psi, IA =150 psi. total pumped = 165 bbls, returns = 158 bbls. decision made to weight up brine to 9.2 ppg. 10:00 12:00 2.00 0 0 MIRU WELCTLCOND P Weight up brine to 9.2 ppg. 12:00 13:00 1.00 0 0 MIRU WELCTL COND P PJSM- Continue weighting up brine to 9.2 ppg. 13:00 15:30 2.50 0 0 MIRU WELCTL KLWL P PJSM- Pump 9.2 ppg kill weight brine S/S @ 2 bpm, 350 psi ICP, 300 psi FCP, pumped 307 bbls, 289 bbls returned, loss 18 bbls, pumped down tubing and returns through IA. 15:30 16:00 0.50 0 0 MIRU WELCTL OWFF P Shut in, Monitor Pressure, tubing zero psi, IA zero psi, open well and monitor (slight vac both IA & tubing). 16:00 17:15 1.25 0 0 MIRU WHDBO RURD P PJSM - B/D Lines, R/D Lines, R/D scaffold, R/U to keep IA full via charge pump. (Hole fill 2 bbls / hr) 17:15 17:30 0.25 0 0 MIRU WHDBO SEQP P PJSM- Set FMC "IS" BPV. 17:30 19:15 1.75 0 0 MIRU WHDBO NUND P PJSM, Nipple up tree and adapter flange. 19:15 21:15 2.00 0 0 MIRU WHDBO NUND P PJSM, Nipple up BOPE. 21:15 22:00 0.75 0 0 MIRU WHDBO BOPE P Rig up to test BOPE. 22:00 00:00 2.00 0 0 MIRU WHDBO BOPE P PJSM on testing BOPE. Test BOPE t/ 250/3500 PSI for 5 minutes each. Test #1: Top pipe rams, CV 1,12,13,14 and manual kill. Test #2: Upper IBOP, HCR kill, CV 9 and 11. Test #3: Lower IBOP, CV 5,8 and 10. AOGCC rep. Bob Noble waived witness of the test. 05/31/2013 Cont test BOPE to 250/3500 PSI. Bob Noble of AOGCC waived witness. R/U and pull hanger to floor. CBU and OWFF. POOH LID 2 -7/8" completion. R/D tubing tools and test lower pipe rams to 250/3500 PSI. M/U BHA #1 and RIH to fish packer. Page 2of7 • • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 05:00 5.00 0 0 MIRU WHDBO BOPE P PJSM - Test BOPE to 250/3500 for 5 min. Dart valve, C.V. #4, #6, #7. Floor valve, C.V. #2 HCR choke, 4" kill line Demco valve. Manual choke valve, test annular preventer with 2.875 ", 3.5" and 4" test joints. Test top rams 2.875" x 5" with 2.875 ", 3.5" and 4" test joints. Blind Rams, C.V. #3. Accumulator test: System pressure 2920 psi, pressure after closed = 1600 psi, 200 psi attained = 31 sec, full pressure attained = 206 psi, 5 bottle avg = 1950 psi. "Test waived by state of Alaska Representative Bob Noble" at 18:04 5/30/2013. 05:00 06:15 1.25 0 0 MIRU WHDBO RURD P R/D equipment, blow down choke, choke line, kill line and top drive. Drain stack. 06:15 07:00 0.75 0 0 COMPZ RPCOM PULD P PJSM on pulling BPV, check for pressure and pull BPV as per FMC rep. 07:00 08:00 1.00 0 0 COMPZ RPCOM RURD P R/U to pull hanger. 08:00 08:15 0.25 0 0 COMPZ RPCOM PULD P PJSM- pulling hanger. 08:15 08:30 0.25 0 7,474 COMPZ RPCOM PULD P P/U 110k, slack off to 75k, P/U to 110k, observe weight pop off to 70k. pull hanger to rig floor. (Tubing hanger to mark on joint at rig floor is 24.1') 08:30 10:00 1.50 7,474 7,474 COMPZ RPCOM CIRC P CBU @ 3 bpm, 500 psi, 38% flow. SIMOPS P/U casing tools and control line to rig floor. 10:00 10:15 0.25 7,474 7,474 COMPZ RPCOM OWFF P Monitor well. (slight flow) decision made to circulate through choke. 10:15 10:30 0.25 7,474 7,474 COMPZ RPCOM CIRC P Circ 30 bbls through gas buster @ 2 bpm, 210 psi. 10:30 10:45 0.25 7,474 7,474 COMPZ RPCOM OWFF P Monitor well, static to slight losses. 10:45 11:15 0.50 7,474 7,474 COMPZ RPCOM PULL P Take control line of hanger, blow down choke and T.D. UD Landing joint and hanger. 11:15 12:00 0.75 7,474 7,002 COMPZ RPCOM PULL P LID 15 joints 2.875" tubing w/ control line. 12:00 13:15 1.25 7,002 5,804 COMPZ RPCOM PULL P UD 2.875" tubing w/ control line. (total =54 joints, 28 clamps) 13:15 18:30 5.25 5,804 0 COMPZ RPCOM PULD P Cont LID 2.875" tubing. LID 237 joints, 7 GLMs, SSSV and seal assy. Measure OD on seal assy to ensure correct grapple size for spear, 3 5/8" OD seals. 18:30 19:30 1.00 0 0 COMPZ RPCOM RURD P Clean and clear rig floor, LID tools, R/D tongs. 19:30 20:00 0.50 0 0 COMPZ WHDBO RURD P R/U to test lower rams w/ 3.5 ", 4" test joints. 20:00 21:15 1.25 0 0 COMPZ WHDBO BOPE P Test lower pipe rams w/ 4" and 3 -1/2" test joint to 250/3500 PSI for 5 minutes each on chart. Page 3 of 7 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 21:15 21:45 0.50 0 0 COMPZ WHDBO RURD P R/D testing equipment. 21:45 22:15 0.50 0 0 COMPZ WHDBO PULD P Set wear bushing, 6 -3/8" ID. 22:15 23:00 0.75 0 0 COMPZ RPCOM PULD P P/U Baker tools from beaver slide. 23:00 00:00 1.00 0 255 COMPZ RPCOM PULD P PJSM, M/U fishing BHA #1, spear as per Baker rep. 06/01/2013 RIH, engage fish and jar packer free. CBU, OWFF and POOH. UD fish (Packer and tailpipe assembly).P /U clean out BHA and RIH to 7343'. 00:00 00:45 0.75 255 315 COMPZ RPCOM PULD P PJSM P/U and M/U BHA as per Baker rep. 00:45 06:15 5.50 315 7,454 COMPZ RPCOM PULD P Single in hole w/ spear and grapple from 315'MD to 7454' MD. Actual displacement 34.65 bbls, calc fill= 45.58 bbls. 06:15 06:30 0.25 7,454 7,454 COMPZ RPCOM FISH P Est parameters, P/U wt = 142k, S/O wt = 102k, rot wt = 120k, rpm = 15, TQ = 4k, 2 BPM = 510 psi. Obtain SPR's @ 6:30 hours w/ 9.2 ppg fluid. 06:30 07:00 0.50 7,454 7,454 COMPZ RPCOM FISH P RIH from 7454' MD to 7469' MD. top of packer @ 7463' MD set down 7k, pull 40k over bleed jars open. P/U to 60k, 75k, 100k no shear. Jar @ 200k five times, 225k seven times. Observed wt dropoff to 148k, 6k over string wt. 07:00 07:15 0.25 7,454 7,424 COMPZ RPCOM OWFF P P/U 30 ft. Let element relax. monitor well. (static) 07:15 07:30 0.25 7,424 7,391 COMPZ RPCOM FISH P RIH to 7468' MD, 5' past packer depth to ensure packer released. POOH two full joints to ensure packer passes collar. (slight overpull past collar) 07:30 09:15 1.75 7,391 7,391 COMPZ RPCOM CIRC P CBU @ 2 bpm, 600 psi, 11% flow. (well flow observed, decision to circulate through choke) 09:15 09:45 0.50 7,391 7,391 COMPZ RPCOM CIRC P Circulate 50 bbls through choke @ 2 bpm, 550 psi. 09:45 11:00 1.25 7,391 7,391 COMPZ RPCOM OWFF P Monitor well (well flow then to static) (Breathing) 11:00 12:00 1.00 7,391 7,015 COMPZ RPCOM TRIP P POOH from 7391' MD to 7015' MD. Act fill = 2.8 bbls, Calc fill = 2.7 bbls. 12:00 12:30 0.50 7,015 7,015 COMPZ RPCOM SFTY P Hold Safety Stand Down, discussed the recent incidents (Dropped object and Spill) Discussed all key factors involved in the incidents and proactive measures to prevent further incidents. 12:30 16:00 3.50 7,015 345 COMPZ RPCOM TRIP P PJSM, Continue to POOH from 7015' MD to 345' MD. Act fill= 52.61 bbls, Calc fill= 46.02 bbls. 16:00 16:15 0.25 345 345 COMPZ RPCOM OWFF P Monitor well at collars. (static) 16:15 18:00 1.75 345 0 COMPZ RPCOM PULD P PJSM, UD BHA #1 and fish. Packer, 2 -7/8" joint, DB nipple, 2 -7/8" joint and shoe. Total length= 83.03'. 18:00 18:30 0.50 0 0 COMPZ WELLPF PULD P Clean and clear rig floor. Page 4 of 7 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 19:00 0.50 0 0 COMPZ WELLPF PULD P PJSM, P/U Baker tools from beaver slide. 19:00 19:45 0.75 0 268 COMPZ WELLPF PULD P M/U BHA #2, string mills and junk mill. 19:45 00:00 4.25 268 7,343 COMPZ WELLPF TRIP P RIH f/ 268' MD to 7343' MD. P /U= 145K, 5/0= 100K. Act fill= 41.99bbs, Calc fill= 45.72 bbls. 06/02/2013 RIH w/ cleanout assembly to 7859'. Circulate hole clean and spot 30 bbls of inhibited 9.2 ppg brine. POOH and L/D clean out BHA. R/U HES E -line and run F -1 packer w/ E -Line. Set packer w/ top @ 7495'. POOH and R/D E -Line. M/U 3 -1/2" completion and RIH to 4889'. 00:00 00:15 0.25 7,343 7,348 COMPZ WELLPF TRIP P PJSM, RIH from 7343' MD to 7348' MD, Obtain SBR's and parameters. 00:15 00:45 0.50 7,348 7,859 COMPZ WELLPF WASH P Wash and Ream from 7348' MD to 7859' MD @ 5 bpm, 550 psi, 39% flow, 80 rpm, TQ =5k, ROT wt =120k, P/U wt =147k, S/O wt =105k. tagging up @ 7859' MD set 7k down, P/U shut down ROT and set down 7k. 00:45 02:15 1.50 7,859 7,859 COMPZ WELLPF CIRC P CBU x2 @ 6 bpm, 800 psi, 43% flow, 80 rpm, TQ =5k. (lots of sand, Circ hole clean.) 02:15 02:45 0.50 7,859 7,859 COMPZ WELLPF OWFF P Monitor well (slight flow, down to static) 02:45 03:45 1.00 7,859 7,859 COMPZ WELLPF DISP P Pump 30 bbls inhibited brine, chase with 75 bbls brine © 2 bpm, 125 psi, 16% flow. 03:45 04:30 0.75 7,859 7,814 COMPZ WELLPF TRIP P POOH from 7859' MD to 7814' MD. Attempt to rack back one stand of drill pipe and blow down, observe well out of balance. Mix 10 bbls of 9.8 brine and pump down drill pipe. Blow down T.D. 04:30 05:00 0.50 7,814 7,814 COMPZ WELLPF OWFF P Monitor well (slight flow down to static) 05:00 08:30 3.50 7,814 268 COMPZ WELLPF TRIP P PJSM, POOH from 7814' MD to 268' MD. Actual fill = 48.79 bbls, calulated fill 4805 bbls 08:30 08:45 0.25 268 268 COMPZ WELLPF OWFF P Monitor well. (Slight losses) 08:45 09:30 0.75 268 0 COMPZ WELLPF PULD P PJSM, L/D 6 joints drill collars and L/D cleanout assembly. 09:30 10:15 0.75 0 0 COMPZ WELLPF RURD P Clean and clear rig floor. 10:15 10:30 0.25 0 0 COMPZ RPCOM RURD P P/U and R/U csg equipment. SIMOPS spot halliburton E -line trucks. 10:30 12:00 1.50 0 0 COMPZ RPCOM PULD P PJSM, M/U packer and 2 joints wearsock pipe. 12:00 13:30 1.50 0 0 COMPZ RPCOM RURD P PJSM, Rig up HES E -line as per Halliburton rep. 13:30 16:30 3.00 0 7,495 COMPZ RPCOM ELOG P Run F -1 packer and wearsock joints on HES E -Line. Set packer w/ packer top @ 7494.72, wearsock joints f/ 7530.76' to 7614.50'. 16:30 17:00 0.50 7,495 0 COMPZ RPCOM ELOG P POOH w/ HES E -Line. 17:00 18:00 1.00 0 0 COMPZ RPCOM RURD P PJSM, R/D HES E -Line and L/D tools. Page 5of7 • • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 19:00 1.00 0 0 COMPZ RPCOM RURD P PJSM, R/U to run 3 -1/2" completion. 19:00 00:00 5.00 0 4,889 COMPZ RPCOM RCST P PJSM, Run 3 -1/2" 9.3 ppf L -80 tubing as per program to 4889' MD. P /U= 69K, S /O= 65K. Actual displacement= 15.98 bbls, Calculated displacement= 16 bbls. 06/03/2013 Cont RIH w/ 3 -1/2" completion. Locate top of packer @ 7494'. Space out, displace well with inhibited brine and land 3 -1/2" completion string 3.27' off located position. Pressure test tubing and IA. Set BPV and N/D BOPE, N/U tree. Test tree to 250/5000 PSI. Freeze protect well and L/D drill pipe. 00:00 00:15 0.25 4,889 5,565 COMPZ RPCOM RCST P PJSM, Cont to run 3 -1/2" completion as per detail and M/U SSSV 00:15 01:00 0.75 5,565 5,565 COMPZ RPCOM RURD P Mobilize control line equipment to rig floor and test control line to 5000 PSI, good. 01:00 01:15 0.25 5,565 5,565 COMPZ RPCOM SFTY P Hold PJSM on running tubing with control line. 01:15 04:00 2.75 5,565 7,503 COMPZ RPCOM RCST P Cont running 3 -1/2" completion. Run 236 joints total, 60 SS bands used on control line. Actual displacement= 9.35 bbls, Calculated displacement= 9.30 bbls. 04:00 04:45 0.75 7,503 7,503 COMPZ RPCOM RCST P Tag top of packer @ 7494'. P/U 10' pup and R/U circ equipment. With charge pump on sting into seals, observed a pump pressure increase. Pressure up tubing to 500 PSI to confirm that seals are into SBE. 04:45 05:45 1.00 7,503 7,503 COMPZ RPCOM HOSO P Space out. L/D 1 full joint of tubing. M/U FMC tubing hanger and control line. Test control tine to 6000 PSI. M/U landing joint with circ equipment. 05:45 06:45 1.00 7,503 7,503 COMPZ RPCOM OTHR T Wait on Inhibited brine, brine delayed due to water over the Kuparuk river bridge. 06:45 07:00 0.25 7,503 7,503 COMPZ RPCOM SFTY P Hold PJSM on displacing well with inhibited 9.2 ppg brine. 07:00 08:45 1.75 7,503 7,503 COMPZ RPCOM DISP P Displace well w/ inhibited brine. Pump 30 bbls of clean 9.2 ppg brine from pits followed by 265 bbls on 9.2 ppg inhibited brine, pump @ 3 BPM= 210 PSI, 38% flow. 08:45 09:00 0.25 7,503 7,503 COMPZ RPCOM HOSO P M/U control line to hanger and drain stack. 09:00 09:15 0.25 7,503 7,503 COMPZ RPCOM THGR P Land tubing hanger. Landed hanger with seals 3.27' off located position, top of seals @ 7491.45'. RIDS. 09:15 11:00 1.75 7,503 7,503 COMPZ RPCOM PRTS P Test tubing to 3000 PSI f /,10 min. Bleed tubing pressure down to 1500 PSI and shut in, pressure up IA to 2500 PSI for 30 min, good. Bled off IA and observed that tubing pressure was bleeding off also. Bled off all pressure and pumped down IA and observed returns in tubing, SOV had sheared ey Page 6 of 7 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:00 1.00 7,503 0 COMPZ RPCOM OWFF P Monitor well through IA and tubing, static. 12:00 12:15 0.25 0 0 COMPZ WHDBO RURD P PJSM, rig down landing joint. 12:15 12:45 0.50 0 0 COMPZ WHDBO SEQP P Set BPV and test to 1000 PSI for 5 min, good. 12:45 13:30 0.75 0 0 COMPZ WHDBO NUND P Blow down lines and suck fluid out of BOP stack. 13:30 14:30 1.00 0 0 COMPZ WHDBO NUND P Nipple down BOPE. 14:30 15:45 1.25 0 0 COMPZ WHDBO NUND P Install adapter flange and N/U tree as per FMC. 15:45 16:15 0.50 0 0 COMPZ WHDBO PRTS P Test adapter flange void to 5000 PSI for 10 min. 16:15 17:15 1.00 0 0 COMPZ WHDBO SEQP P Open SSSV, pull BPV and install tree test plug. 17:15 18:00 0.75 0 0 COMPZ WHDBO PRTS P Test tree to 250/5000 PSI for 5 min, good. 18:00 19:00 1.00 0 0 COMPZ WHDBO SEQP P Pull tree test plug and R/U LRS to freeze protect well. 19:00 20:00 1.00 0 0 COMPZ WHDBO FRZP P PJSM, freeze protect well. LRS pumped 75 bbls of diesel @ 1.5 BPM, taking returns to rock washer. 20:00 22:00 2.00 0 0 COMPZ WHDBO PULD P PJSM, LID 4" drill pipe from derrick, SIMOPS U -tube freeze protect. 22:00 23:00 1.00 0 0 COMPZ WHDBO SISW P Install BPV, dress tree and secure well. IA pressure= 0 PSI, Tubing pressure= 0 PSI. 23:00 00:00 1.00 0 0 DEMOB MOVE PULD P Cont to LID 4" drill pipe from derrick. 06/04/2013 Cont. to UD 4" DP. R/D and prep to move rig. Release rig @ 6:00 hours. 00:00 00:45 0.75 0 0 DEMOB MOVE RURD P PJSM, Spot Vac truck in cellar and clean out tote and cellar area with Vac truck. 00:45 04:00 3.25 0 0 DEMOB MOVE PULD P Cont. to LID 4" drill pipe out of derrick. 04:00 06:00 2.00 0 0 DEMOB MOVE RURD P Pull mouse hole, clean rig floor and floor drains. Perp to move. Release rig @ 6:00 hours. Page 7 of 7 • • o'6 5 -2-60 2t -{or, WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 14, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 C�1�NED Ju 013 ry 1 9 2 RE: Gas Lift Survey / Bottom Hole Pressure Survey: 2H -10 Run Date: 8/23/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2H -10 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20051 -00 Gas Lift Survey / Bottom Hole Pressure Survey Log 1 Color Log 50- 103 - 20051 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: t t i Signed: `° j b , ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 14, 2008 ~; ~t~, Mr. Tom Maunder Alaska Oil & Gas Commission ~~ 333 West 7t" Avenue, Suite 100 Anchorage, AK 99501 IdIA`l ~ ~ 2Dfl$ ~~ ~~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled•with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with. the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped April 3 2008 and the corrosion inhibitor/sealant was pumped on April 20th and 30th of 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, /~~ _ . a Perry Kle ConocoPhillips Well Integrity Projects Supervisor ,, ConocoPhillips Alaska lnc. Surface Casitilg by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 5/14/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 26-01 184-115 25' S" 3.25 23" 4/3/2008 1.7 .4/20/2008 2B-02 184-122 30' S" 0.5 20" 4/3/2008 4.3 4/20/2008 26-03A .203-009 4' 0.5 33" 4/3/2008 10.2. 4/20/2008 26-04 184-120 30' ~ 4 28" 4/3/2008. 6.4 4/20/2008 2B-06 184022 26' S 19" 4/3/2008 8.5 4/20/2008 2B-09 184-027 74' ~ 10.5 32" 4/3/2008 11.1 4/20/2008 26-10 184-029 74' ~ 10.5 33" 4/3/2008 17 4/2012008 2B-11 184-035 50' 7.5 29" 4/3!2008 6 4/20/2008 2B-12 184-038 6' 1 29" 4/3/2008 6 4/20/2008 2H-01 184-077 SF n/a SF n/a 2.5 4/30/2008 2H-02 184-073 SF n/a SF n/a 2 4/30/2008 2H-03 184-070 SF n!a SF n/a 4 4/30/2008 2H-04 184-055 SF n/a SF n/a 2 4/30/2008 2H-08 185-171 2' 6" n!a 2' 6" n/a 25 4/30/2008 2H-10 185-260 SF n/a SF n/a 2 4/30/2008 2H-11 185-261 SF n/a SF n/a 2.5 4/30/2008 2H-12 185-262 SF n/a SF n/a 2.5 4/30/2008 2H-13 184-096 2" n/a 2" n/a 2 4/30/2008 2H-14 184-095 SF n/a SF n/a 2 4/30/2008 ) ) ~~~~! : f fÆ~fÆ~~~] AlfASKA OIL AND GAS CONSERVATION COltDllSSION FRANK H. MURKOWSKI, GOVERNOR November 26, 2004 333 W. 7f" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 . ~"¡ . ""'° L~'ID \~,?'. Mr. Mike Wheatall Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Wheatall: The Alaska Oil and Gas Conservation Commission ("Commission") received a well safety valve . system (SVS) test report from ConocoPhillips at Kuparuk River Unit 2H pad ("KRU 2H") dated November 10,2004. Attached is a copy of the SVS Test Report. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. An SVS component failure rate of 11.1 percent was identified during the above-noted inspection. Commission policy, "as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13, 2003, supported retention of the 100/0 failure threshold. Effective November 10, 2004 and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2H must be tested every 90 days. When testing is scheduled, you must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to witness the SVS test. Sincerely, cf~ g~eac. James B. Regg -ll Petroleum Inspection Supervisor Attachment SCAN!\fED ,It1N 11 2005 ) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: ConocoPhillips Operator Rep: Noble - AES AOGCC Rep: Waived Submitted By: Brad Gathman FieldfUnit/Pad: KRU 2H Separator psi: LPS Date: 11/10/2004 96 HPS 'rfffiiltrl9¡li~~ . .. Well Permit Separ Number Number PSI 2H -01 1840770 2H-02 1840730 2H-03 1840700 2H-04 1840550 2H-05 1851680 96 2H-06 1851690 96 2H-07 1851700 96 2H-08 1851710 96 2H-09 1852590 96 2H-I0 1852600 96 2H-ll 1852610' 96 2H-12 1852620 96 2H-13 1840960 2H-14 1840950 2H-15 1840860 2H-16 1840870 2H-17 2000190 J~r~'[~~1:itQ'i::,~.J , Set LIP PSI Trip R:~Sj~~~r~$s/fl£ 'l!¡~t¡g~I~iig~Ìf't¡¡~~ ~,Jg~flt/!¡jj!R~~~: Test Test Test Date Tested and or Code Code Code Passed Retest or SI Oil, WAG, GINJ, GAS, CYCLE, SI WAG WAG WAG WAG OIL OIL OIL OIL OIL 11/11/2004 OIL OIL 11/11/2004 OIL WAG OIL WAG WAG WAG 70 50 P P 70 65 P P 70 70 P P 70 50 P P 70 55 P P 70 50 P 4 70 55 P P 70 60 P 4 70 50 P P 96 Wells: 9 Components: 18 Þàilures: 2 Failure Rate: 11.11 o/B 90 Day Remarks: 2H-I0 & 12 serviced and passed re-test Pad to be re-tested in 90 days RJF 09/19/02 Page 1 of 1 SVS KRU 2H 11-1 0-04.xls MEMORANDUM TO: Julie Huesser, Commissioner State of Alaska Alaska Oil and Gas Conservation cOmmisSion /~.~'~"~ DATE: December 2,~ 2000 THRU' FROM: Tom Maunder, P. I. Supervisor Chuck Scheve; Petroleum Inspector SUBJECT: Safety.valve TeSts Kuparuk River Unit 2H Pad Saturday, December 2,-2000: I traveled to the Kuparuk River Field and witnessed the semi annual safety valve system testing on 2H Pad. : . As the attached AOGCC Safety Valve System Test Report-indicates .I witnessed the testing of 9 wellS and 18 components with four failures Observed The Iow pressure~ pilots on wells 2H-5,2H-6 and 2H-12 tripped Well below the required set pOint and the surface safety valve on well 2H-12 failed to Pressure test. The three failed pilots were adjusted and retested at the time of this test. The failed valve will be repaired. and retested by the operator. The 22.2% failure rate will require a retest of this Pads .Safety valve System in ~90 days rather than the n°rmal/~,c~day cycle. ' Earnie Barndt conducted the testing today he demonstrated gOod test Procedure and was a pleasure to work with Summary: River Field. KRU 2H Pad, 9 wells, · ; I witnessed the semi annUal SVS testing at 2H Pad in the Kuparuk 18 compOnents, 4 failures 22% failure rate Attachment: SVS KRU 2H Pad 12-2-00 CS confidential (Unclassified if doc. RemOved) X Unclassified SVS KRU'2H Pad 12-2-00 Cs'doc Alaska Oil and Gas ConservatiOn CommiSsion Safety Valve SYstem Test Report Operator: Phillips Submitted By: Chuck Scheve Date: 12/2/00 Operator Rep: Emie Bamdt Field/Unit/Pad: Kupamk / KRU / 2H Pad AOGCC Rep: Chuck Scheve . Separator psi: LPS 96 HPS Well Permit Separ Set L/P Test - Test Test Date Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code passed GAS or 2H-01 1840770 · 2H-02 1840730 - 2H-03 1840700 2H-04 1840550 2H-05 1851680 96 70 20 3 P 12/2/00 . oIL 2H-06 1851690! 96 70 10 3 P 12/2/00 OIL 2H-07 1851700~ 96 70 60 'P P ' OIL 2H-08 1851710 96 70 60: P P OIL . 2H-09 1852590 96 70 50 P P '. ' OIL 2H-10 1852600 96 70 50 P P - OIL 2H-11 1852610 96 70 50 P P OIL 2H-12 1852620 96 70 10 3 4 : remarks . . 2H- 13 1840960 2H-14 1840950 961 70 60 'P P OIL 2H- 15 1840860 2H-' 16 1840870 . 2H- 17 2000190 · . Wells: 9 Components: 18 FailUres: 4 Failure Rate: 22.0% ~90 my .. Remarks: three failed pilots repaired and retested, failed SSV to be repaired and retested bY op Pad on 90 day teSt cycle .. ' . 12/4/00 Page 1 of t · SVS KRU 2H Pad 12-2-00 CS.xls '~_.- STATE OF ALASKA ~--: ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate X Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 130' RKF 3. Address: Exploratory ~. 7. Unit or Property: P,O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 170' FNL, 594' FI:L, Sec 35, T11N, RSE, UM 2H-10 At top of productive interval: 9. Permit number/approval number: 1363' FSL, 1206' FEL, Sec 35, T11 N, R8E, UM 85-260 At effective depth: 10. APl number: 1150' FSL, 1248' FEL, Sec 35, T11 N, R8E, UM 50-103-20051-00 At fatal depth: 11. Field/Pool: 1098' FSL, 1248' FEL, Sec 35, T11 N, R8E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 7979 feet Plugs (measured) None true vertical 6353 feet Effective Deptt measured 7878 feet Junk (measured) None true vertical 6277 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 250 Sx CS II 118' 118' Surface 2825' 9-5/8" 750 Sx CS III & 2860' 2783' 330 Sx Class G Production 7926' 7" 350 Sx Class G & 7960' 6340' 175 Sx CS I Liner Perforation Depth measured 7648'-7681 ', 7713'-7734 true vertical 6104'-6129', 6158'-6169' 'ilVAL Tubing (size, grade, and measured depth) 2-7/8", 6.5 lb/", J-55 @ 7557' Packers and SSSV (type and measured depth) Packer: Brown HB @ 7486' · SSSV: Baker FVL @ 1782' 13. Stimulation or cement squeeze summary .......... Fracture stimulate "A" sands on 5/7/98. Intervals treated (measured) 7648'-7681', 7713'-7734 Treatment description including volumes used and final pressure Pumped 224,362 lbs of 16/20 and 12/18 ceramic proppan~ into formation, fp was 8084psi. 14. Representitive Daily Average Production or Injection Data Oii-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 615 415 8 945 256 Subsequent to operation 855 435 79 1189 212 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~ Oil _X Gas _ Suspended _ Service _ 17. I herel~y certify that the foregoing is true and correct to the best of my knowledge. Signed/I./~~~_ Title: Production Engineering Supervisor Date ~/~/~'~ Form 10-404 R~/~)'115/88 SUBMIT IN DUPUCATE ' ARC.O Alaska, Inc. ~ ~ KUPARUK RIVER UNIT ~ .JELL SERVICE REPORT '~ F' K1(2H-10(W4-6)) WELL JOB SCOPE JOB NUMBER 2H-10 FRAC, FRAC SUPPORT 0502981631.3 DATE DALLY WORK UNIT NUMBER 05/07/98 A SAND REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 (~) Yes O ,oI ® Yes O No DS-GALLEGOS JORDAN FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTI MATE KD2182 23ODS28HL $137,773 $147,017 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann ~ Final Outer Ann 160 PSI 1120 PSI 350 PSI 500 PSII 700 PSII 700 PSI DALLY SUMMARY PUMPED A SAND REFRAC. FLUSHED 2 BBL SHORT OF PERFS, LEFT WELL FREEZE PROTECTED WITH DIESEL. TIME LOG ENTRY 06:00 MIRU DS FRAC - GALLAGOS. TGSM. PT SFC LINES TO 9273 PSI. SB TO CHANGE OUT PUMP. PT SFC EQUIP TO 9273 PSI OK. 11:11 START BREAKDOWN AND SCOUR. ISIP 1892 PSI. PUMP PULSES. 12:36 PUMP DATA FRAC. ISIP 1954 PSI. SD TO MONITOR. 14:30 BEGIN PUMPING FRAC PAD AND SAND STAGES. 15:03 TREATING PRESSURE INCREASING AT 5181 PSI. CUT ACTIVATOR FROM 5 GPT TP 4.5.. -~ 15:21 TREATING PRESSURE INCREASING AT 5644 PSI. CUT ACTIVATOR FROM 4.5 TO 4.0. ~' 15:33 TREATING PRESSURE AT 5699 PSI STEADY, MAINTAIN 15 BPM AND CONTINUE TO 10 PPA STAGE. 15:59 EXTEND 10 PPA STAGE. DECIDED NOT TO CONTINUE RAMP TO 12PPA. ~'~ 16:02 PRESSURE INCREASING. CUT INJECTION RATE TO 14 BPM AND.GO TO FLUSH.~ ~ 16:19 SD WITH FLUSH 2 BBL SHORT OF PERFS. 224,362 LB PROPPANT IN PERFS WITH 58OLBS LEFT IN PIPE. 18:00 RDMO SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $3,757.00 APC $7,000.00 $7,000.00 DOWELL $125,973.00 $125,973.00 HALLIBURTON $0.00 $1,487.00 LI'I-i'LE RED $4,800.00 $8,800.00 , TOTAL FIELD ESTIMATE $137,773.00 $147,017.00 1. Type of Request: ----" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown __ Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing. Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. 12. O. Box 100360, Anchorage, AK 9951O 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 170' FNL, 594' FEL, Sec. 35, T11N, R8E, UM At top of productive interval 1363' FSL, 1206' FEL, Sec. 35, T11N, R8E, UM At effective depth 1150' FSL, 1240' FEL, Sec. 35, T11N, R8E, UM At total depth 1098' FSL, 1248' FEL, Sec. 35, T11N, R8E, UM Present well condition summary Total Depth: measured true vertical 7979' 6353' feet Plugs (measured) feet 6. Datum elevation (DF or KB) RKB 1 7. Unit or Property name Kuparuk River Unit 8. Well number 2H-10 Producer 9. Permit number/approval number ,8-408 lO. APl number 50-103-20051 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 7878' true vertical 6277' feet Junk (measured) feet Casing Length Structural Conductor 118' Surface 2860' Intermediate Production 7 9 6 0' Liner Perforation depth: measure Size Cemented I 6" 250 Sx CS II 9 5/8" 750 Sx CS III & 330 SX Class G 7" 350 Sx Class G & 175 Sx Sx CS I 7648'-7681 ', 7713'-7734' Measured depth 118' 2860' 7960' MD True vertical depth 118' 2783' 6340' true vertical 6104'-6129', 6153'-6169' TVD Tubing (size, grade, and measured depth) 2 7/8", 6.5 Ib/ft, J-55 IPC, 7557' MD Packers and SSSV (type and measured depth) SSSV: Baker FVL 1782' Packer: Brown HB 7486' 13. Stimulation or cement squeeze summary Intervals treated (measured) 7648'-7681', 7713'-7734' Treatment description including volumes used and final pressure Fracture Stimulate the A Sand with 79,637 lbs of 16/20 Carbo-lite. Final Pressure - 5200 PSI 14. Prior to well operation Produce Representative Daily Average Production or Injection Dat~, OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 314 249 0 --- Tubing Pressure 175 PSIG Subsequent to operation Produce 630 682 0 160 PSIG 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil ~ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 ~ev 06/15/88 ~'~'~'~ Date '~ ~ ~ 7 SUBMIT IN DUPLICATE Subsidiary of Atlantic Richfield Compan,' CON]'RACTOR REMARKS ?.JPARUK OPEP.~.T!O.N$ E.NG!.NEER!NG /t.I ]?qS'" 15~/ 5 13'30 o I! I'-1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp' I Chill Fact°r I Visibility IWindVel'Report °F °F miles knots I Signed ARCO Alaska, Inc. Date: July 29, 1988 Transmittal #: 7239 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. Please acknoWledge receipt and return '~ 3H-20 -*~"~ 3 H- 19 3H-20 3H-19 ~2H-10 -Kuparuk Well Pressure Report Kuparuk Well Pressure Report Bottom-Hole Pressure Survey Bottom-Hole Pressure Survey Kuparuk Fluid Level Report 7 - 1 2 - 8 8 Amerada 7-1 2-88 PBU 7 - 0 9 - 8 8 PBU 7 - 0 9 - 8 8 PBU 7 - 2 1 - 8 8 Casing Receipt Acknowledged: DISTRIBUTION: D&M '- State of Alaska -Chevron SAPC Mobil Unocal STATE OF ALAS'I~A ALAS~._.. OIL AND GAS CONSERVATION COMI~_~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend '" Operation Shutdown ii Re.enter suspended well L~ Alter casing [] Time extension Change approved program S! Plugging ~ Stimulate J Pull tubing'' Amend order ~ Perforate [_' Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface ].70' FNL, 594' FEL, Sec. 35, T].].N, R8E, UM 5. Datum elevation (DF or KB) RKB 130' feet 6. Unit or Property name Kuparuk River Unit 7. Well number 2H-10 At top of productive interval ].363' FSL, ].206' At effective depth ].150' FSL, ].240' At total depth ].098' FSL~ ].248' FEL~ Sec. 35~ 11. Present well condition summary Total depth: measured true vertical FEL, Sec. 35, FEL, Sec. 35, T11N, R8E, UM T11N, R8E, UM T11N, R8E, UM 7979' feet Plugs(measured) 6353' feet 8. Permit ~p_rr~b~% 9. APl number 50-- 103-20051 10. Pool Kuparuk River Oil Pool Effective depth: measured true vertical 7878' feet Junk (measured) 6277' feet Casing Structural ConduCtor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented Measured depth ~ue Vertical depth 118' 16" 250 Sx CS II 118' 118' 2860' 9-5/8" 750 Sx CS III & 2860' 2783' 330 Sx CS II 7960' 7" 350 Sx Class "G" & 7960' 6340' 175 Sx Sx CS I 7648'-7681', 7713'-7734' MD true vertical 6104'-6129' 6153'-6169' TVD Tubing (size. grade and measured depth) 2 7/8", 6.5 lb/ft, J-55 IPC, 7557' MD Packers and SSSV (type and measured depth) SSSV: Ba~er FV/ 17R?' Pac~e~_- R~own HR 12.Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch ~ Hydraulically fracture stimulate the A Sands with 8OM# of 16/20 Carbo-Lite sand. 13. Estimated date for commencing operation May, 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to t/¥ best of my knowledge - - d ' Commissi(~n Use OCn'n'n/ly - Date Conditions of approval Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Notify commission so representative may witness [] Plug integrity [] BOP Test ~ Location clearance 'Approved Copy Returned' Commissioner Form 10-403 Rev 12-1-85 by order of the commission Date Submit in triplicate Messrs. Ma~y 12, 1988 Page 4 Well 2H-10 Refracture Fracture Procedure (5/11/88) Material Requirements Diesel/lO% Musol Diesel Gel led Diesel 8 Hr Breaker for 6 Hr Breaker for Lo-Temp Breaker for Silica Flour for (40 lbs/lO00 gals) Proppant 20/40 mesh Carbo-Lite 79,637 lbs 50 bbls 45 bbls 947 bbl s 600 bbls gelled diesel 302 bbls gelled diesel 45 bbls gelled diesel 500 bbls gelled diesel Procedure Pre-frac Operations: a. Tag fill to insure perforations are clear. b. Insert dummy valves in all mandrels. c. Fill backside with diesel. d. Pressure test tubing. e. Obtain stabilized welltest off gas lift. 2. SI wel 1. e Pump diesel/Musol spear per attached schedule at least '6 'hours before pumping fracture treatment. e Record ISIP after pumping spear. Pressure up annulus to 3500 psi. Note: Annulus pressure will rise as the treatment is pumped. The annulus pressure should not be allowed to rise above 3500 psi during the job. The maximum allowable wellhead at this casing pressure will be 6500 psi. 6. RU treating equipment, including treesaver. e Pump fracture treatment per attached schedule. Expected maximum WHTP is 5400 psi. Monitor and record the wellhead tubing pressure during and after treatment. A record of WHP readings should be obtained for 30 minutes after shutdown. 8. Release pressure on annulus. M,ay 12, 1988 Page 5 e The flowback should begin as soon as practical. The initial rate should be 50-100 BFPD. 10. Bring well back 100 psi per 24 hours the first four days. Record tank straps, choke settings, and WHPs during the entire flowback period. 11. Take BS&W samples after every choke change. Visually inspect samples for presence of frac sand. If frac sand is observed, increase WHP 100 psi and contact Operations Engineering. Well can be turned into CPF when BS&W is below 2%. 12. After flowback is complete, turn well into test separator for A Sand production test. KUPARUK WELL 2H-10 'A° SAND FRACTURE PUMP SCHEDULE 5111188 STAGE FLUID DESCRIPTION CLEAN VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT WT BBLS BPM PPG DESCRIPTION LBS DIRTY VOLUME HIT PERFS STG/CUM BBLS I DIESEL/10% MUSOL 2 DIESEL FLUSH 3 GD PRE-PAD 100.0 50.0 5 0 - - 45.0 5 0 - - SHUT DOWN OVERNIGHT 20 0 - - SHUT DOWN FOR ISIP 20 0 - - 0 20 2 20/40 M CARBO-LITE 3860 20 4 20/40 M CARBO-LITE 9998 20 6 20/40 M CARBO-LITE 15944 20 8 20/40 M CARBO-LITE 23599 2 0 I 0 20/40 M CARBO-LITE 26237 20 0 - - 0 4 GD PAD 500,0 5 GD w/2 PPG 45.9 6 GD w/4 PPG 59.5 7 GD w/6 PPG 63,3 8 GD w/8 PPG 70,2 9 GD w/10 PPG 62,5 1'0 GD FLUSH 45.0 +SV 0 50/ 5O 47 0 45/ 95 97 0 1 00/ I 00 47 5.OO/ 500 47 5O/ 55O 547 70/ 620 597 80/ 7OO 667 95/ 795 747 90/ 885 842 45,0/ 930,0 932 NOTES: TOTAL DIESEL = TOTAL GELLED DIESEL = TOTAL M USOL = 90,0 BBLS +SV 946,4 BBLS 5.0 BBLS 16/20 M CARBO-LITE = 79637 LBS Stage I is Diesel with 10% Musol Stage 3 is Gelled Diesel with 8 hr breaker Stage 4 is Gelled Diesel with 40 lbs/1000 gal silica flour and enough breaker for a 8 hour break, Stages 5 through 9 are Gelled Diesel with 6 breaker and without silica flour, Stage 10 should include a volume adjustment for surface equipment between the wellhead and densitometer and Iow temperature breaker(6 hr. break), This job is intentionally underflushed by 2 bbls. The blender tub should be bypassed at flush, All fluids should be maintained at 70 to 90 F on the surface, Sundry Notice - Well 2H-10 A Sand Fracture Treatment No BOP's will be used during the treatment. The treatment will be pumped through a manifold on the surface. No workover fluids will be used during this process. A Sand pressure (6200'SS) = 3156 Psi 7/17/87 WHP/FL ARCO Alaska, '--..~; Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 09-15-86 TRANSMITTAL ~ 5761 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: Schl: CET or CBL Logs: One * of each lA-7 12-03-85 Run ~3 7585-8532 lA-14 .12-05-85 Run #1 4550-4850 1H-4 12-26-85 Run #2 6893-7466 1H-8 12-08-86 Run #3 7875-8368 1H-8 12-09-86 Run #4 7850-8450 lQ-9 01-28-85 Run #1 4898-6534 lQ-13 06-02-85 Run #1 5300-7621 2C-16 02-19-85 Run #1 7200-8294 2E-9 01-14-85- Run #1 6780-8052 2E-15 01-12-85 Run #1 3350-6874 2E-16 01-12-85 Run #1 4840-7578 2H-10 12-05-85 Run #1 6500-7863 3A-7 11-04-85 Run #1 5726-7164 3A-11 12-15-85 Run #1 5796-7206 3A-12 12-16-85 Run #1 6426-7768 3A-13 12-29-85 Run #2 5644-7482 3A-14 12-29-85 Run #2 5462-7744 3C-13 10-30-85 Run #1 7075-9474 3F-5 11-13-85 Run #1 6947-8647 3F-6 11-13-85 Run #1 4600-7570 3F-9 12-19-85 Run #1 6188-7490 3J-5 12-22-85 Run #1 7000-8636 Receipt Acknowledged: Vault*films ~aska 0il & Gas Cons. Date:AnchOrage NSK Files*bl ARCO Al&lkl. I~'1C. ~i · Sul:)$idiery of AII·~IIcRicn'~eldcOmpln¥ · STATE OF ALASKA -- ,¢~ ALASKA 0~'~ AND GAS CONSERVATION CO-iV~ISSION E_. WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well ~,~ · ! OIL E~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-260 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50- 103-20051 4. Location of well at surface 9. Unit or Lease Name 170' FNL, 594' FEL, 5ec.35, T11N, RSE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1363' FSL, 1206' FEL, Sec.35, TllN, R8E, UM 2H-10 At Total Depth 11. Field and Pool 1098' FSL, 1248' FEL, Sec.35, TllN, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 130' RKBJ ADL 25587 ALK 2673 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore J 16. No. of Completions 11/1 7/85 11/23/85 11/25/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7979'MD,6353'TVD 7878 'MD ,6277 'TVD YESOX NO[]I 1782 feetMD 1500' (approx) 22. Type Electric or Other Logs Run D IL/GR/SP/SFL, FDC/CNL, GR/CCL/CET/Gauge ring, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 118' 24" Conductor report not yet received. 9-5/8" 36.0# J-55 Surf 2860' 12-1/4" 750 sx CS Ill & 330 sx CS II Top job performed w/13~, sx CS II 7" 26.0# J-55 Surf 7960' 8-1/2" 350 sx Class G & 175 sx CS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7648' - 7681' w/4 spf, 90° phasing 2-7/8" 7557' 7486' 7713' - 7734' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Addendum, dated 2/27/86. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips· Noneprr IVED APR0 A.~,~.. ~,i ~ ~"~ 6on~. ~ An~orage Form 10-407 * NOTE: Tubing was run and the well perforated 12/18/85. GRU13/WC16 CONTINUED ON REVERSE SIDE Submit in duplicat~ Rev. 7-1-80 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7570' 6044' N/A Base Kuparuk C 7579' 6051' Top Kupauruk A 7610' 6074' Base Kuparuk A 7810' 6225' -. 31. LIST OF ATTACHMENTS Addendum (dated 2/27/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge' ~ v~ Associate Engineer INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all ty.pes 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~i/~tta'c~ed '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". ~¢m 1N-~N7 ADDENDUM WELL: 12/02/85 12/06/85 1/12/86 2H-10 Arctic Pak well w/175 sx CS I. Log w/GR/CCL/CET/Gage Ring f/7863'-6500'. Rn GCT gyro f/7878'-surf. Frac Kuparuk "A" sand perfs 7648'-7681 & 7713'-7734' in 3 stages per 1/9/86 procedure using gelled diesel, Musol & 20/40 sand. Press'd ann to 1500 psi w/diesel. Tst lns to 7000 psi; OK. Pmp'd 20 bbls 5% Inflo 40 Musol, followed by 46 bbls cln diesel on 1/11/86. Stage 1: 15 bbls gelled diesel pad @ 5/5.9 BPM @ 3590/3370 psi. Stage 2: 16.5 bbls gelled diesel w/6 ppg 20/40 mesh sand @ 5/5.6 BPM @ 3250/3000 psi. Stage 3: 45 bbls gelled diesel flush @ 17.7/19.1BPM w/final press of 4210 psi. Pmp'd 2850# 20/40, 6 ppg sand in formation leaving 395# 20/40, 6 ppg sand in 7" csg. Load to recover 73 bbls of diesel. Job complete @ 1320 hrs, 1/12/86. Drilling ~uperintendent ARCO Oil and Gas ComPany Well HistOry- Initial RepOrt- Daily- Instructions; Prepare and submit the "Initial Ral~rl" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District I County. parish or borough I State Alaska I North Slope Borough I Alaska Field JLease or Unit ADL 25587 Kuparuk River' Auth. or W.O. no. ITitle - · AFE AK0057 I Co~:~lett o~ Roll'N 4 AP1 50-103-~005 JWell no. 2H-10 Operator I ARCO W.I. A~¢O Inc.. ' '-'" -'-':' ' 'i~ :'~" -:" . [,or .tatue if 56.24% . . JHoor~' · W"~-.- aW.O. Alaska., . I~''' i2/~5-/S~- .. l-?~::~-20S0: ' '. . It ~--"~ '"-' "-' ~.'~".-. : ;-~'~%~:~-~ =-/~;:~F~7~------~~ -' - ~-~--~"- ~-:~ ~- - ': ~'" ~ '. AccepC rig ~ 2030. hr.-, 12/15/8E,~-., ~-IOwe~::'~a~- ~[::cs,~ -BO~[~-. ' g~. - Attempt ~o.. ~ perf ~n-- th~ w/0~-'success, - POE,-f.- Preps.-t0 ..... ' 12/17/85 7". ~ 7960' ._ . 7878' PB~, RIH to perf " 9.7 ppg NaC1/NaBr RIH w/4" du~y ~n, tag obstruction ~ 93'-. Attempt to ~. tl thru w/o success, POOH. ~ Schl. Heat up brine, wsh brine ice plug ~ 3/4 BPM w/6-1/8" bit assy, PU 2-7/8" tbg f/108'-360', broke th~ ice plug. ConC TIH w/6-1/8't bit & PU 2-7/8" tbg, tag PBTD ~ 7870' (~)-, rev circ hole vol, POOH. RU Schl, RIH- w/parr gum. Spudded or W.O. begun Co~lete_.,. Date end depth., .. aa of 8:00 a.m~ · '' 12/15/85.~- · ' thru- [2/[6/85 12/18/85 7" @ 7960' 7878' PBTD, Set BPV- 6.9'ppg diesel im-tbg & anm RIH, perf "A" sand w/4" gun, 4 SPF, 90°~ phasing f/7648'-7681' & 7713'-7734', RD Schl. RIH w/239 its, 2-7/8", 8RD tbg & set. w/SSSV @ 1782', HB Pkr @ 7486', TT @ 7557', "D" Nipple @ 7523'. Tst tbg, shear off PBR, re-lnd tbg. Tst ann & pkr, tst SSSV. ND BOPE. NU & tst tree. Displ well to diesel. Tst orifice vlv. Prep to set BPV. The above is correct Signature For form prepara, tlo-n-and dlstributl~l. see Procedures Manuel, Section 10, Drilling, Pages 88 and 87. ITitle Drilling Superintendent 'ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time, On workovers when an official test is not required upon completion, report completion and represenlative test data in blocks provided_ The "Final Report" form may be used for reporting lhe entire operation if space is available. District lCounty or Parish I Alaska Field ~Lease or Unit I Kuparuk River Auth. or W.O. no. ~Title I AFE AK0057 A.R.Co. W.I. Operator ARCO Alaska, Inc. Spudded or W.O. begun Date Complete Date and depth Complete record for each day reported as of 8:00 a.m. North Slope Borough ADL 25587 12/19/85 IAccounting State cost center code Alaska JWell no. 2H-10 Completion AP1 50-103-20051 ~Total number of wells (active or inactive) on this Icost center prior to plugging and I 56.24% labandonment of this well I IHour I Prior status if a W.O. 12/15/85 ! 2030 hrs. I 7" @ 7960' 7878' PBTD, RR '' 6.9 ppg diesel in tbg & ann Set BPV. PR @ 0900.hfs, 12/18/85. Old TD Released rig 0900 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data New TD Date 12/18/85 I PB Depth 7878 PBTD Kind of rig Rotary IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Well no, Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % CDR Gravity Allowable Effective date corrected The above is correct Signature For form preparation and di~'tribution, see Procedures Manual, Section 10, Drilling, Psges 86 and 87. Date ITitle Drilling Superintendent ARCO OII and Gas Company . Well History- Initial Report- Daily Inal~g,~tleM: Prepare and submit the "Initial RelisH" on the first Wednesday after a well is spudded or workover operations are started. Daily won prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field -- Kuparuk River Auth. or W.O. no. AFE AK0057 Nabors 26E ICounty, parish or borough . North Slope Borough tea~e or Unit ADL 25587 Title Drill IState Alaska IWell no. 2H-10 AP1 50-103-29951 Operator ARCO Alaska, Inc. Spudded 11 / 17/85 Date and depth aa of 8:00 a,m, 11/18/85 11/19/85 11/2o/85 11/21/85 11/22/85 Complete record for each day reported 2200 hrs. IARCO W.I. Prior status if a W.O. 56 24% 16" @ 118' 1416', (1298'), Drlg Wt. 8.9, PV 15, YP 25, PH 9, WL 13, Sol 5 Accept rig @ 1600 hrs, 11/17/85. NU diverter sys. 2200 hrs, 11/17/85. Drl 12~' hole to 1416'. Spud well @ 16" @ 118' 2875', (1459'), Circ Wt. 9.2+, PV 16, YP 18, PH 10, WL 9.6, Sol 7 Navi-Drl to 2416', POH f/angle bldg assy. RIH, drl to 2875' make wiper trip, C&C hole to rn csg. 502' .1° S13.8W, 502 TVD, 0.4 VS, .4S, .1W 1371': .6°, , . , , S 1.2W, 1371 TVD, 4.7 VS, 4.4S 2 1W 2108', 15.9°, S14.2W, 2098.4 TVD, 108 VS, 107.3S, 14.0W 2845', 31.9°, S 8.2W, 2770.2 TVD, 403.2 VS, 402,9S, 39.9W 2885', (10'), Prep f/LOT Wt. 8.7, PV 5, YP 0, PH 9, WL --, Sol 4 POH. RU & rn 72 jts, 9-5/8", 36# BTC csg w/FS @ 2860'. Cmt w/750 sx CS III, followed by 330 sx CS II. Displ using rig pmps, bump plug. Good rtns, no cmt to surf. CIP @ 1600 hrs, 11/19/85. ND diverter sys. Perform 134 sx CS II top job. NU & tst BOPE. RIH w/DO assy, tst csg to 2000 psi, DO cmt & flt equip + 10' new hole to 2885'. 9-5/8" @ 2860' 5000', (2115'), Navi-Drl Wt. 9.1, PV 12, YP 8, PH 10, WL 8.0, Sol 6 Conduct formation tst to 12.5 ppg EMW. POOH, PU Navi-Drl, drl 8½" hole to 5000'. 3006', 34.7°, S 8.2W, 2904.8 TVD, 491.6 VS, 490.2S, 53.5W 3344', 49.6°, S10.2W, 3155.5 TVD, 716.7 VS, 712.6S, 89.9W 3977', 47.9°, Sll.2W, 3572.6 TVD, 1192.8 VS, 1180.7S, 176.2W 4481', 45.1°, Sll.2W, 3921.9 TVD, 1556.0 VS, 1537.7S, 243.6W 4701', 47.4°, S 9.2W, 4074.0 TVD, 1714.9 VS, 1694.0S, 271.8W 9-5/8" @ 2860' 7225', (2225'), Navi-Drl Wt. 9.5, PV 15, YP 8, PH 10, WL 6.5, Sol 8 Navi-Drl & surv 8½" hole to 7225'. 5015', 47.1°, S 9.2W,.4287.2 TVD, 1945.4 VS, 1921.7S, 308.7W 5644', 46.2°, Sll.2W, 4717.2 TVD, 2404.4 V$, 2373.5S, 389.9W 6466', 48.6°, S 9.2W, 5274.6 TVD, 3008.2 VS, 2969.7S, 486.4W The above is correct Signature /~ For form preparation arks dlst~butl~n, see Procedures Msnual,'Section 10, Drilling, Pages 88 and 87. Drilling Superintendent ARCO Oil and Gas Com' any Daily Well History-Final Report Instructione: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District Field Alaska ICounty or Parish Lease or Unit Title North Slope Borough cost center code Alaska Kuparuk River ADL 25587 IWell no. 2H-10 Auth. or W.O. no. AFE AK0057 Drill Nabors 26-E Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded IA.R.Co. Date Date and depth as of 8:00 a.m. 11/23/85 thru 11/25/85 Complete record for each day reported API 50-103-29951 W.I. [Total number of wells (active or inactive) on this Icost center prior to plugging and I 56.24% labandonment of this well I IHour I Prior status if a W.O. 11/17/85 ! 2200 hrs. I 7" @ 7960' 7878' PBTD, 7979' TD, RR 9.6 ppg NaC1/NaBr Navi-Drl, rotary drl & surv 8½" hole to 7979', 10 std short trip, CBU, POH. RU Schl, log w/DIL/GR/SP/SFL f/7968'(WLM)-2860', FDC/CNL f/7968'(WLM)-7350' & 3600'-2860', RD Schl. RIH, rm to btm, CBU, POH, LD DP. RU & rn 185 jts, 7", 26#, J-55 BTC csg w/FS @ 7960', FC @ 7878' & mkr jt @ 7576'. Cmt w/100 sx C1 "G" w/6% gel, 3% KC1, 1% ~-31, .25% R-5 & .2% D-6, followed w/250 sx C1 "G" w/l% D-19, .5% D-31 & .3% A-2 + 1 gal/100 sx D-6L. Displ hole w/9.6 ppg NaC1/NaBr, bump plug. CIP @ 1830 hrs, il/24/85. Did not recip pipe. ND BOPE, NU tbg spool & 2-7/8" lower tree, tst to 3000 psi. RR @ 0430 hrs, 11/25/85. Moving to DS 2H-9 7403', 42.8°, S6.2W, 5925.8 TVD, 3680.3VS, 3636.5S, 578.2W Alaska Oil & Gas Cons. 6ommissior~ Anchorage Old TD New TI:) Released rig Date 0430 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data I PB Depth 7979 ' TD 11/25/85 I [Kind of IType completion (single, dual, arc.) Single Official reservoir name(s) Kuparuk Sands 7878' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature I Date . JTitle For form preparation and ~,stribution, see Procedures Manual, Sectidn 10, Drilling. Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. Post Office ~0'~'~ 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 11, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2H-10 Dear Mr. Chatterton' Enclosed is a copy of the 2H-10 Well History (completion details) to include with the Well Completion Report, dated 01/27/86. If you have any questions, please call me at 263-4944. Si ncerely, J. Gruber Associate Engineer JG/tw GRU13/LI06 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. L Post Office B~"~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 27, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 2H-10 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for 2H-10. I have not received the Well History (completion details). When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Si ncerely, . Gruber Associate Engineer JG/tw GRU13/L29 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~.~.. AND GAS CONSERVATION CO~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL j~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-260 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 103-20051 4. Location of well at surface LC)CATIONS 9. Unit or Lease Name 170' FNL, 594' FEL, Sec.35, T11N, R8E, UN VERIFieD Kuparuk River Unit At Top Producing Interval Surt:._.J~___ 10. Well Number 1363' FSL, 1206' FEL, Sec.35, TllN, R8E, UM B.H. L/ 2H-10 ___ At Total Depth 11. Field and Pool 1098' FSL, 1248' FEL, Sec.35, TllN, RSE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 130' RKBI ADL 25587 ALK 2673 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore J 16. No. of Completions 11/1 7/85 11/23/85 11/25/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. DePth where SSSV set I 21. Thickness of Permafrost 7979 'MD ,6353 'TVD 7878 'MD ,6277 'TVD YES ~X NO [] 1782 feet MDI 1500' (approx) 22. Type Electric or Other Logs Run D IL/CR/SP/SFL, FDC/CNL, CR/CCL/CET/Gauge ring, CCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 118' 24" Conductor report not ¥~;t received. 9-5/8" 36.0# J-55 Surf 2860' 12-1/4" 750 sx CS Ill & 330 sx CS II Top job performed w/131 sx CS I! 7" 26.0# J-55 Surf 7960' 8-1/2" 350 sx Class G & 175 s; CS I 2~. 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) . 7648' - 7681' w/4 spf, 90° phasing 2-7/8" 7557' 7486' 7713' - 7734' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD JJ~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE J~ 28. CORE DATA B~ief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None R F C E i~'~/E D Alaska Oil & Gas Cor~s, 6o~-~ission Anchorage Form 10~,07 * NOTE: Tubing was run and the well perforated 12/18/85. TEMP3/WC59 Submit induplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7570' 6044' N/A Base Kuparuk C 7579' 6051' Top Kupauruk A 7610' 6074' Base Kuparuk A 7810' 6225' 31. LIST OF ATTACHMENTS Well History, AdCendum (dated 12/11/85), Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~//~/r~ ).~ LjL~.)L/ Title Associate'Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing 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". ADDENDUM WELL: 2H-10 12/02/85 Arctic ?ak well w/175 sx CS I. Drillin~ Superintendent 8UB. SURFA DIRECTIONAL SURVEY [G~ UIDANCE ~.~ONTINUOU8 [~]OOL ARCO ALASKA INCORPORATED ¢~ml~aaY - II I i Well Natne ~-10 (170' FNL, 594' FEL, S35, TIIN, R8E, UM) _ llll I I I I l KUPARUK, NORTH SLOPE, ALASKA Fleld/Lo~&tlo. · _ I I I 71090 Date 1S-D~.CEMBER-85 Bo~ :]CT 3IR~CT-3NIL SURVEY SUST~. '~, :R LISTZN,S FO~ &RC] AL~SK~ ZNC, 2~-!3 KUPARUK NORTm SLOPE,~L6SKA SdRV~¥ OATE: OS DEC 85 ENGZNEER: ~ROJECTE3 05VIATION AND O'qTO ~ T4RGET ~ZIMUTH AZIMUTH OF SOUTq 10 DES 51 MIN WEST 2'i-10 KUPARUK. NJRTH TRU" ~ASURED V=RTICAL 9 -PTH DEPTd O.OO 0.00 lOO.O0 100.30 200.00 200.00 300.00 299.99 400.00 399.9') 500.00 4'~9.99 600.OJ 700.00 599.~9 800.00 799. ~9 ~30.03 3~9.99 lO00,OO 1100,00 i0~9,99 1ZOO,OD 1199,9~ 1300,00 1299,98 1~00,00 13~9,~3 1500.00 14~9.94 1500.00 1599.59 1700.00 1699.09 1800.00 1798.34 1900,00 1896,~5 2000.00 1994.1,5, 2100.00 2090.96 2200.00 21~5.$6 2300.00 2230.93 2400.00 2374.22 2500.00 2455.94 2600.00 2556,~3 2700.00 2~OO.OO 2731.34 2900.00 2816.70 3000.00 2899.%$ 3100.00 2980,57 3200, O0 30.56. $4 3300.00 3126. ~1 3400.00 3192.32 3500.00 3256. 3500.00 3322.39 3700.00 3388.51 3800.00 3453.~1 3900,00 351').95 ,23',!POT,A T I 3N INTERPOLAT=D VALUES 3J'3-SEA, COdRS~ V:~RT!CAL,:,DEVIATI-3N AZiM'jTq OEPT,H 'D"~G ~IN SEG -130.00 ' 0 0 Iq 0 -30,00 0 4 70,00 0 7 S 51 12 159,99 0 I0 S 26-~.99 0 3 N 30 369.99 0 14 S 22 39 459,99 0 569.99 0 13 S 55 53 `569.99 0 1.5 S 67 7 59 . 99 0 5 S 79 4 D4T:: lg-J~C-~5 ., ~V~N 100 F~ET O; 136~.15 13 16 'S 4 i~ 19,50.~6 15 43 S 1i 16 2055.55 13 14 S 11 43 2150,93 20 10 S 5 3~ 224~.2'2 22 i7 S 0 49 2'335.~ 24 29 5 1 35 2425.23 26 29 .S 3 12 ZSli.~O 25 34 5 4 53 2601.$4 30 44 ~ 7 5 2686.70 32 55 $ 7 58 2769.85 34 3,5 S 3 15 2850.67 39 5 S :~ 25 2926.54 43 2 S I0 !0 2990.81 47 3'3 S lO 6 3062.32 49 4,2 S 1J 52 3126.)9 ~9 39 S 10 49 3192.39 4~ ~2 ,5 10 3~ 3258.~i 48 53 S 10 25 3323.91 49 3 S 1J 34 333:3.95 48 ! S 1J 57 VSqTICAL 33GLEG SECTION SEVERITY ~ET OEG/iO0 0.00 0,03 O. 41 0, ~3 0.45 0.0~ 0.69 0,0~ 0.53 0.35 0.50 0.80 1,14 0.53 1.09 0.64 1.41 0,31 1.47 0.68 1,90 0.36 2.17 0,07 2.55 0.26 3.25 0.30 4.3'9 0.79 7,15 2,75 13.93 2.35 2~.73 1.75- 39.11 2.59 56.~5 2.99 MEASURE RECTAN NORTH/ FEE O. O. O. O. O. 3. 1. O. 1. 1. . 1. 2. 2. '4. 6. 13. 24. 35. 56. P~ '1 DAT~ Oi= SURVEY: 0.50=_C 85 KELLY :]US-tlNG ELEV&TZ3N: 130'.00 F1 W 77.90 3.3'7 77. W 102.91 3.12 102. W 132.20 2.66 130. W 16,5.22 3.36 163. d 200.52 2.23 199. W 240.07 2.04 239. W 232.58 2.23 282. ~ 328.45 2.20 328. Id 377.68 2.68 377. W 430,47 1,65 429, 485.96 1.83 484. 544.77 4.74 542. 509.73 ~.45 606. 580.93 ~.15 677. 756.47 0.46 751, 332.75 0.48 825. 909.40 0.41 900, 953,59 0.36 974, 1059.07 0,~'~ 1048, 1134.15 1.11 1122. W w W W D DEPTH SUL~R COORDINATES SOU T,~ EAST/WEST T FEET O0 N 0.00 E 33 S 0.42 W 35 S O, 57 W 55 S 0.7.5 W 68 $ 0.~0 W 69 S 0.65 W O1 S 0.79 W 99 S 0.63 W 28 S 0.80 W 29 S 1.07 W 63 S 1,04 W 93 S 1.50 W 27 S 1.67 W 97 S 1.84 W 04 S 2.28 W 75 S 2.82 W 57 S 3.25 W 45 S ~.04 W 74 S 5.69 W 26 S ,a..,~7 W 1.94 S 32 38 W 2.44 S 37 56 W 2.82 S 36 17 W 3.49 S 31 50 W '4.54 S 29 25 W 7.31 S 22 41 W 13.95 S 13 28 w 24.78 S 9 23 W 39.15 S 8 21 ,W 56.89 S 8 33 W 46 S 9.70 24 S 13.26 84 S 19.65 46 S 24.88 43 S 26.32 24 S 27.09 19 S 28.87 28 S 32.10 40 S 37,31 80 S 44.40 W 78.06 S T 8 W W 103.10 S 7 23 W W 132.31 S 8 32 W W 165.34 S 8 39 W W 201.16 S 7 31 W 240.77 S 6 27 W.- W 283.66 S 5 50 W W 329.84 S 5 35 W W 379.24 S 5 38 W 432.09 S 5 53 W 80 S 52.19 97 S 61.15 96 S 72.36 08 S 84.75 33 S 98.'62 25 S 113,03 58 S 127.07 50 S 140.80 71 S 154.60 50 S 168.53 487.60 S 6 8 W 545.40 S 6 25 W 611.26 S 6 47 W 582.36 S 7 8 W 757,78 S 7 28 W 833,94 S ? 47 W 909.50 5 ~ ,1 W 984.62 S ~ 13 W 1060.05 S 8 23 W 1135.08 S 8 32 W ~Rr, CG ALaSkA, iIC. 2~-10 KJPAR'J~ NgRTd SL,L1PE, AL,~SK A TRUe DEPTH DEPTfl 4333.00 3587,05 4100.00 3555.02 4200,00 3724,27 ~300.03 3793.}$ 4400.03 3354.]4 ~590.30 B:~B4.57 4500,00 400~,73 4700.00 ~072.~9 4800.00 4140.57 4900,00 4208.72 5000.00 4276.97 5100.00 4345.36 5200.00 4413,13 5300.00 4481.04 5%00.00 ~549.Z0 5500.00 ~617.55 5600.00 46~6.10 5700.00 ¢7.55. q'7 5800.00 4.824.. 35 5900,00 4891,98 6000,00 4959,88 6100,00 5027,77 6200,00 5095.38 6300,00 5162,45 6400.00 5228.92 6500.00 5295.17 6500.00 ~351.~6 5700,00 5426.21 6800.00 5495.25 6900.00 5563.11 7000.00 5532,59 7100.00 5702,94 7200.00 5773,70 7300.03 5845.45 7%00.00 5918.14 7500.00 7'600.00 7700,00 5142,14 7800.00 5217.47 7900.00 6293.19 C 3 ',1 i::, U T A T I 3 N D~T'=: 18-DEC-~5 INTERPOLATED V~LJES FDR =V~N 10O ;EE 5JB-SEA C3:JqS=._ VERTICAL ,DEViATI31 D'~DTH.',"DEG MIN 3457.05 47 48 3525.02 46 25 3594.17 45 58 ~553.96 45 3~ 3734.04 45' 18 5504.67 44 55 3~74.73 4~ 51 3942.39 47 23 4010,37 46 56 ~078.72 4,5 ~6 41~5.97 47 O ~215.05 47 ~Z{B.IO 47 7 4351.0~ 47 ~41.~'.20 46 56 ~556.10 46 2!5 ~625.47 ~6 459~.00 ~7 ~751.98 4'7 4829.8:~ 47 11 ~8~7.77 47 13 ~965.35 47 37 5032.45 4:9 7 50~.92 48 28 516.5.17 4~ 33 5231.4~ ~B 25 52}5.:21 47 57 5365.25 47 ~3 5433.11 46 30 V-RTICAL 3.3G AZZMdTn SSCTION S~V 0;3 MIN FEET S 11 7 N 1E08.29 S lO 35 W 12B1.63 S !.D 25 W 1353.7~ q IS ~ J 1~~ 4~ S !3 25 W !495.$2 S 10 !4 ~ 1557.61 $ ') 37 W 1638.95 5 9 20 ~ 1712.56 $ ~ 37 W 1785.87 5 ~ 58 W 1858,86 S ~ 59 ~ 1931,'94 S 13 ~ 4 2005,17 $ 10 13 ~ 2078.45 S 10 29 W 2151.82 S 10 52 W 2225.00 S 11 25 ~ 22'97,99 S 11 29 W 2370,79 S 11 22 W 24'42.81 5 9 53 W 2515,'57 S ~ 15 ;,1 '253B.92 S .~. 11 W 2562.26 S B 14 W 2735.61 S ,~ 31 W 2809,21 S 3 39 W 2383.33 S 5 45 W 2957.99 S 3 4~ ~ 3032,85 S 3 ~g W 3107,67 S 9 5 W 31;32.0;5 S $ 40 W 3256.25 S ,~ 3~ W 3329.63 S 9 ~ W 3401.51 S ~ 53 2 34'72.65 S 5 43 ~ 3543.16 S 5 27 W 3612.75 S 3 19 W 3581,37 S 5 33 ~ 3743,79 S 9 0 W 3~i5.04 S .~ 50 W 33~0.76 S 9 17 W 3945,49 $ 9 17 'J ~011,79 5502,59 45 gO 5572.34 ~5 ) 5543,70 44 34 5715,45 43 44 5738.14 42 57 5851.94 41 53 5936.80/ 41 14 ~012.14 41 7 ~0~7.07~ 40 47 S163.19 40 ~7 T DF L~G ERITY /100 0.49 1.03 0,48 0.24 0.53 0.05 3.05 0,44 0.45 0.36 0,49 0,14 0.22 0,47 0,62 0.23 1.35 1.24 1,64 0,25 0.20 0.45 0.55 3.43 0.50 0.54 0.30 0,28 0.83 1,93 '0.58 0.58 0.75 0.69 1.03 1.33 0.66 0.55 0.'00 0.00 PAGE 2 DATE OF SdRVEY: 05 DEC 85 KELLY BUSHING ELEfATigN: 13~.00 F ENGINE=R: URAM M~ASUR':D DEPTH :'~ RE'TAN NORTM/ SULAR SOUTH T 1195.24 S 1267.24 S' 1338.20 S 1408.73 S 1478.85 S 1548.50 S 161~.73 S 1591.30 S 1763.72 S 1835.65 S 1907. 1979. 2051 · 2124. 2193. 2257. 2338. 2409. 2481, 2553. 2626, 2698. 2771. 2845. 2918. 2992. 3066. 3140. 3213. 3286. 63 S 75 S 88 S 07 S 98 S 59 S 95 S 52 S O1 S 54 S 20 S 86 S 75 S 10 S 95 S 98 S 98 S 54 S 83' S 48 S 3357.51 S 3427.81 S 3~97.52 S. 3566.38 S 3634.32 S 3701,07 S 3766,58 S 3831,54 S 3896.51 S 3960.98 5 COORDINAT~=S t'"I..~.R ~:Z. ,,,. fAS'T/WEST ~ ~~,i:i:: 1 ,"32 · 31 W 120 g':'"W~ ~::' 196.79 W 1Z82~:,'.&'3':"." $ 209.87 W 1354,~5 S 222.86 W 1426.25' S 235.76 W 1497.56 S 248.55 W 1568.32 S 261.13 W 1539.66 S 273.10 W 1713.29 S 285,17 W 1786,63 S 297,63 W 1859.62 S 310.30 W 1932.'70 S 323.07 W 2005.94 S 335.98 W 2079.21 S 349.15 W 2152.57 S 362,68 W 2225.73 S 376,84 W 2298,69 S 391.27 N 2371.45 S 405.67 W 2%43.43 S 419.21 W 2516.18 5 430,48 W 2589,57 5 DEPARTURE AZIMUTH DEG MIN 8 41 W 8 49 W 8 54 W 8 59 N 9 3 " 9104 9 12 ~ 9 14 W '~ 16 W 9 17 W 9 20 W 9 22 W 9 26 W 9 29 W 9 33 N 9 35 W 9 34 N 441,01 W 2652,97 S 9 31 W 451,51 W 2736.37 S 9 29 W 462,24 W 2810,03 S 9 28 ~ 473.27 W 2384,20 S 9 26 ~. 484,62 W 2958.90 S 9 25 ~ 496.05 W 3033.81 S 9 24 ~. 507.43 W 3108,67 S 9 23 W 518,97 W 31~3.13 S 9 22 ~' 530.56 W 3257.33 S 9 22 ~ 541.34 W 3330.76 S 9 21 W 552.56 W 3402.68 S 563.73 W 3473.85 S 574.61 W 3544.41 S 585.04 W 3614.05 S 595.08 W 3382.72 S 60~.97 W 3750.19 S 615,17 W 3816.~8 S 625.39 W 38~2.24 S 635.57 W 3948.00 S 646,12 W 4013.33 S 9 20 W 9 19 N 9 18 W 9 17 W 9 17 N g 16 W 9 15 W 9 15 W 24-10 NGRTH SLGPE,.ALASK6 TRUE EASUR:O VZRTZCAL 3EPTH DEPTq 7979.00 5353.3'0 C]M~UTATZGN 9ATt-: lS-O'C-B5 INTERPOLATED VALjES :!]R nV 'N 100 :EET OF SJ'S-S;A CSURSE VERTICAL DGGLEG V~RTI'AL' DEVIATIG]~ AZZ~-~,UTt SECTION SEVERITY DEPTH ,:~{)EG MIN 9ES ,~,i:,~ F~ET DE'S/lO0 ~223.00 40 ~7 5 9 17 W ~055.38 0.00 PAG: " 3 . DATE OF SORVEY: 05 OEC 85 KELLY 5USHING ELEVATI2N: 130.~0 ENGINEER: UREM FT ME ADORED RECTANGULAR NORTH/SOUTH FEET 4011.91 S DEPTH COaRDINATES HD~..lZ.'~/":. ' PARTURE -10 C S"10 U T &Ti 3~,~ DDT--: 1B-DEC-,B3 ZNTERPOL~TED VAL,JES =DR -V;N 1000 F~=T 3F TRU: SJ6-SE~ SUR=3 V:RTZCAL 'VERTICAL EPTH DEPTi 9EPTH CDjRSE DE'VI&TION AZ '-Mj T-~ DEG M'IN OEG O. 03 O. D 0 -1'~ 0.00 00.0,3 9-)9. :)9 359.99 O0.OO 1994.15 i8,54.16 00.00 2:199. ~.(:, Z75S.36 O0.OO 3537.05 3~57.35 03.00 ~Z7~.'~7 OO.O0 ~95~.33 00.00 563Z.~) 550Z.59 79.00 5353.00 5223.00 V~RTICAL DOGLEG S=CTi~N SEVERITY FEET DEG/iOD MEASO DATE KELLY PA'SE '4 ~ DF SURVEY: 05 D=C B5 3USHING ELEVATIDN: 130. O0 'FT ENGINEER:' URAM RED OEPT R=CTANSULAR COORD NORTH/SOUTH EAST/ FEET FEET 0.00 O.OO 0 1.~0 0.35 1 77.90 3.37 77 4~5.95 1.83 48~ i£0B.29 0.49 11'95 193!.9~ 0.49 1907 Z562.2~ 0.20 2526 3401.51 0.58 3357 ~.353.38 0.00 4011 .OO N O;OO E .53 S 1'.04 W .45 S ~.70 W .80 S 52.1) W .24 5 182.81 ~ .63 S 310.30 W ,20 S 441,01 W .51 S 352.56 W .91 S 654.45 W 0.00 1.94. 78.06 ~87.60 1Z09.14 1932.70 2562.97 3~02.68 4064.94 RTURE UTH MIN "N" "~": 0 0 6 S'.32 38 W S .,7 8 W S 6 8 W $ 8 41 W S 9 14 W S 9 ~1 W S 9 ZO N S 9 15 W ~-10 KJP6R,JK NERTH TRU:~ MEASUR;D VERTiCaL D~PTH DsPT4 0.00 0.00 33.00 30.00 130.00 130.30 230.01 230.00 330.01 330.00 430.01 430.30 530.01 530.30 830.01 $30.00 730.01 730.J0 830.01 930.01 930.JJ i030.01 1030.00 1130.01 1130.00 1230.01 1230.00 1330.02 1330.00 1630.03 1430.00 1530.11 1530.00 1630.44 1830.00 1731.2~ 1730.00 i832.39 1530.00 1934.25 1930.00 2038.90 2030.00 2140.57 2130.00 2245.~7 2230.~J 2352.41 2330.~0 2460.52 2w30.00 2570.7a 2530.03 2583.05 2530.03 2727.85 2730.00 2915.87 2830.00 3036.80 2930.00 3164.05 3030.30 3304.76 3130.00 3458.27 3230.00 3511.53 3330.~0 376,3.50 3430.J0 3915.00 3530.00 4053.57 3630.00 420~.2~ 4351.51 31330.03 C ,3 q P;J'T ~ T i'3 'i ~r=: 18-DEC-,{5 !NTERPOL~TE3 VSLUES F3R EV=N lOO FEET DF VSRTIS~L:.DEVIATI3N DEPTH D'EG. ~iN -130.0'0 0 0 -100.00 I 27 0.00 0 7 109.00 0 ,3 200.00 0 10 300.00 0 8 403.00 0 14 530.00 0 5 600.03 3 13 700,00 0 13 V=~TICAL DOGLEG AZI:MUT~ S:CTIDN S=VERITY D:G M!N FEET N 0 0 E 0.00 3.00 S 42 ~1 w 0.07 3.05 S ;~5 $5 W g.43 0.75 S 45 i7 W 0.51 O.ll S ~1 25 w 0.77 O.IO N 65 ~,4 ~ 0.79 0.10 S 7 40 W 3.93 0.37 q ~ 15 = 1.12 1.04 S 8 3 ~ !.18 0.8~ S B7 53 W 1.47 0.79 ~00.00 0 9 900.00 0 19 t000.00 0 13 1100.00 3 22 1.200.00 0 37 1300.3'3 1 11 1~00.00 3 '~i 1509.30 5 ~2 160,3.00 ~ '? 1700.00 9 I,BO0.O0 12 0 1900.00 i4 !i 2000.00 I~ 49 21.30.90 19 1,5 P200 30 ~! 7 2300.00 23 43 Z4OO.O0 25 52 2600.00 30 al 2700.00 33 11 2300.00 35 ZqO0.OO 41 2OO0.OO 47 3103.00 4'~ 42 3233.00 330'].00 49 i 5507.00 46 3600.00 a5 {,6 3700.00 1.51 0.34 1.95 0.54 2.24 0.80 2.73 0.30 3.55 0.51 4.92 1.13 ~.78 2.78 15.73 2.66 2~.00 1.63 ~a.41 2.29 53.75 2.68 86.65 2.BO 114.31 2.79 145.92 2.75 183.49 3.04 224.1'9 1.98 269.81 2.25 320.~6 2.30 376.59 2.70 439.13 1,58 507.04 3.14 555.52 5.25 634.47 4.01 ~00.92 O. 12 917.05 0.26 1031.49 0.36 i145.25 0.51 1255.16 2.31 1359.70 0.37 14~2.30 0,56 PAGE DATE OF SURVEY: 05 DEC 85 KSLLY BUSHING ELEVATIDN: 130,00 FT ENGINEER: URAM SUS-SEA OEPTH R;CTANGULAR NDRTm/SOOTH 0.00 N 0.36 S 0.35 S 3.40 S 0.52 S 0.65, S 0.82 S 0.98 S 1,09 S 1,32 S 1.34 S 1.76 S 1.97 S 2.46 S 3.24 S 4.55 S 8.37 S 16.38 S 2B,57 S 43.. 97 S 63.17 S 86,20 S 113.38 S 145.30 S 181.85 S 223.15 S 269,31 S 320.26 S 375.32 S 438.38 S 505.58 S 583.22 S 680.56 S 794.98 S 909.09 .S 1321.50 S 1133.42 S 1241.23 S 1344.02 S 144~,. 93 S CODRDINATES EAST/WEST FEET ' 0.00 E 0.06 W 0.46 W 0.82 W 0.82 W 0.55 W 0.54 W 0.83 W 0.58 W 0.93 N 1.03 W 1.13 W 1.65 W 1.67 W 1.96 W 2.44 W 2.98 w 3.43 W 4.48 W 6.5,1 w 9.08 W 10.81 W 22.39 W 25.98 W 26.69 W 28.20 W 31.45 W 37.17 W 45.61 W 55.27 W 68.10 W 85.38 W 107.02 W 128.65 W 149.54 W 170.55 W 191.~6 W 210.94 W 229.51 N .'., 0; 0'.~;'.~'.'::#', 0 O 0'-~,.0:.8~, "'$'.,2 58 W o.74.:'.s s7 35 ~ 1.o,a s sz 56 ~" 1.o'T- s sz s~ w~ ~.0~ S BT S8 N 1.29 S 40 15 W 1.23 S 2~ 7 ~ ~,52 S BS ~ W 1.59 S 37 38 W 2.10 S 32 41 W 2.57 S 39 57 W 2.97 S 34 13 W 3.78 S 31 9 W 5.16 $ Z~l 13 W 8.88 S 19 33 W 16.74 S 11 50 W 29. O1 S 8 53 W 44.45 S ,~ 25 ~ 63.82 S ,3 10 W 86. :S5 S 7 1 W 114.47 S 7 53 N 147.02 S 8 45 W . s 270.79 S 5 58 W 321.80 S 5 36 W 378.15 S 5 38 W 440.75 S ~ 56 ~ 508.69 S 6 14 W 5B7.19 S 5 39 N 6,,q 5.90 S 7 9 W ~02.16 S 7 40 W 91~. 14 S 8 3 W 1032.49 S 8 19 W 1146. 20 S 8 33 W 1255.97 S 8 47 W 1360.47 S 8 55 W 1~63.04 $ 9 1 ~ CO ~,LASKA, -10 RTH iNTerPOLATE3 C 3~q PUT &TI VAL:JES TRU~ SJS-S--A ' ' COURS:- SUR:3 V:RTICAL V~RTICAL DEi:~-Ii~.T. I3N AZ EPTH g, XeT -~ [)E~TH O E~'.(.'-M'"f N .93.40 3330.20 3~00.00 ,37.28 4030.00 '84.32 ~130.00 4030.00 ~31.19 4230.00 ~!00.00 )77.~9 4330.00 ~200.00 ~24.8~ 4~30.00 ~71.91 ~530.00 ~400.00 ;13.I~ ~530.30 ~500.00 i53.33 ~730.00 ~08.72 $~30.00 0700.00 i56.03 ~930.00 ~903.00 .03.29 5030.00 ~900.00 !51.~9 5130.00 ~01.63 5230.00 5100.00 552.60 5330.00 5200.00 ~02.67 5~30.00 5393.00 ~51.50 5530.30 5~00.00 ~5.29 5630.00 3300.00 L38.45 5730.00 5600.00 ~78.5~ 5530.00 5700.00 g16.19 5930.00 5~00.00 550.93 5030.00 5900.00 $83.~9 5130.00 5003.33 516,55 5230.00 5103.00 ~8.63 5330.00 ~2OO.O0 ~79.00 6353.00 S MIN · . .. 44.55 S 10 £~ '4728 S ~ 20 46 58 S ~ 34 46 58 S 10 47 3 S 13 ~7 10 S 10 15 45 58 S 10 43 46 ~7 S I1 25 46 0 S 11 33 47 5 $ R 45 42 4 ,{. 41 31 S 41 .5 42 ~7 S ~,3 ~7 S 42 47 S { 17 ~ 53 917 DAT:: 18-0EC-85 ~VEN 100 FZET OF V::qTICAL DOGLE.3 S-'CTiON S~VERITY FEET 1552.~4 1555.35 0.27 1774.79 0.59 1381.66 0.24 19~$.99 0.15 iO'~.5.55 0.33 2204.4'~ 0.72 £311.23 0.25 241.6.44 0.30 2~21,96 1.86 2530.04 0.39 273'3.02 0.48 2847.30 0.56 2359,21 0.50 3372.23 0.15 3184.07 0.28 .32'~4.22 1.27 3398.85 0.52 341)9..95 0.53 3597.96 1.20 3.592.38 0.8~ 37~2.50 3~70.19 0.37 ~ 957.30 O. O0 ¢94.3.55 0.00 ~0,53.38 O. O0 PASE 6 DATe O~ SURVEY: 05 O=C ~5 KELLY ~USHING ELEVATION: 133,00 ENGINEER: URAM FT SUB-SEA O;PTH RECTAN3ULAR NORTH/SOUT~ F~ET 1543.92 S 1545.77 S 1752,7,~ S 1858.11 S 1953,82 S 2069,~0 S 2175,84 S 2230.57 S 2383.58 S 2487,31 S 2594,27 S 2701.25 S 2a09,~5 S 2920.15 S 3031.93 S 3142.50 5 3251.42 S 3'354.90 S 3454.70 S 3551.73 S 3645.23 S 3734.52S 3321.08 S 3907.17 5 3992.33 ,S ~011.91 S COORO EAST/ FEET 247;7 25~'5 28 :3 301.5 320.2 339.Z 358.3 379.4 400.4 420.2 436.4 451.8 457. '~ 4 8~. a 502.0 519.2 536.1 552.1 567.9 582.~ 596.6 610.0 ~23.7 637.3 651,2 654.4 ., INAT~S I S T .'.~'~%jj~ U T H WE'ST ~DEET ,,~~..MIN' 3 W 1667.07 ".':"~'$~.: .9:, ~0 W 9 w ~882.43 S' 9 ~3 ~ 3 W 2397.~1 S 9 18 ~ 4 W 2205.23 S 9 21 W 7 W 2311.92 S 9 25 W 0 W 2~17.07 S 9 32 W 9 W 2522.57 S 9 35 W 0 W 2530.72 S 9 32 W 5 W 2738.79 S 9 29 W 0 W 2848.15 S :) 27 W 1 W 2960.12 S 9 25 W 2 W 3073.21 S 9 24 W 8 W 3135,11 S 9 22 W 7 W 3295,33 S 9 21 W 5 W 3'~00.03 S 9 20 W 5 W 3501.07 S 9 20 N 6 .W. 3599.24 S 9 19 W 6 W 3693.74 S 9 17 W 9 W 3764.03 S 9 16 W 5 W 3871.66 S 9 16 W, 2 W 3938,81 S '9 15 N 5 W 4045.10 S 9 15 N 5 W 4064.94 $ 9 15 W 24-10 N]RTH SLOP=S,~LiSKA BASE TOP PBT,3 TD ~NTERPOL&TZD V&Ld~'; ~IEASJ~- ~ 7570.30 7579.00 7513.33 7ulO.O0 7979.00 2~T=: 13-D:C-85 ~OSZN ~ORIZON$ ,= R C '4 K~ 50~4.2~ 6051.03 6074.35 6225.34 6275.53 5353.00 ORIGIN= TVD 170 ' SdB-SE6 5914.28 5921.03 594~.33 5095.04 5146.53 6223.00 PAGE ,? DAT~ 3F SURVEY: 05 9:C 85 KELLY SUSHING ELEVATION: 130~00 ENGINEER: URAM FT FNL, 5941 ' E N ., 3747.01 S 612.06 3752.89 $ 6~2.99 377~.08 S 6~6.20 3902.95 $ 636.63 3946,79 $ 643o~0 4011.91 $ 654.4~ ~C] ~L.~$KA, INC. .H-10 JPARUK tORTH SLSPE,AL&SKA CO.qm'JTO, TI]N DAT~: 18-D=C-B5 DATE OF SURVEY: 05 DEC 85 KELLY 5USMING ELEVATION: 130,00 FT ' ENGINEER: dRAM TOP &UPA~Ut 26TD TD =iNAL MEASURE~ OEPT~ 797'9.33 C ~ "':' OqlGI~= 170' FNL, ~EASJR" D DE~TH TVD 3~LOW K~ ;ROM K'S S'JS-SEA 7573.03 504~.2.B 5)14.2B 75'7'~. O0 ~051.03 5 ~21 · 03 7510. O0 6.37~. 33 5.)4~. 33 7~10.00 o225.0~ 6095.0~ ?~75.00 6276.53 5145.53 7979.00 5353.00 6223.00 WELL LOCATION TTJE VEqTZ~L 5353.00 ,~T T~:~ V~qT!3~L DEPTH $££3.30 mDR:IZ]NTAL DEPARTURE DISTANCE .~ZiMUTH ~EET DEG MIN 4054.~ S 9 15 594' F 'R= C 'NO S,U EL TA RT 374 375 377 393 394 401 RFACE ri / S 3 U T '1 '.E'A S"T'/W E S T . ~, 7.31 S 6.12.05 W 2.89 S 612.99 W 3,08 S 516,20 W 2.95 S 535.63 6.79 S 543.30 W 1.91 S 654.~5 W SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC. WELL 2H-lO FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO REFERENCE 000071090 WELL NAME: 2H- 10 ~-~ ._z SURFACE LOCATION: 170' FNL, 594' FEL, S35, TllN, R8E, UM ~0. VERTICAL PROJECTION sooo 6000 PROJECTION ON VERTICAL PLANE 190. ' 10. SCALEO IN VER%ICP4. 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'OPERATOR, WEI~L NAHE 'AND NUHB~.R Date Required Da~e ReCeived · · Samples ....... Hud Log ..... _ ,,, Core Ch fps Csr~ 'Description Inclination Survey t Drill Stem Test Reports ,,, / Log Run L.FJ.04 i '1 000' 900 , i !4467 "! :'"', i , , ~ . 800 ~00 600 500 400 300 ARCO Alaska, Inc. Post Office [5--~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC, ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 12-31-85 TRANSMITTAL ~ 5497 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints/ Open Hole/ Schl/ One * of each 2H-10~ 5" DIL/SFL-GR ~ 2" DIL/SFL-GR % 5" D. EN/NEU (poro) ~2" DEN/NEU (poro) \5" DEN/NEU (raw) ~2" DEN/NEU (raw) ~Cyberlook 2H-11 ~5" DIL/SFL-GR ~2" DIL/SFL-GR ~5" DEN/NEU-GR (poro) ~2" DEN/NEU-GR (poro) DEN/NEU-GR (raw) EN/NEU-GR (raw) yberlook 3A-11 '5" BIL/SFL-GR \2" DIL/SFL-GR 5" ~EN/NEU (poro) '2" ~EN/NEU (poro) ~5" ~EN/NEU (raw) ~2" DEN/NEU (raw) \Cyberlook 3A-i2~5'' DIL/SFL k2" DIL/SFL 5 DEN/NEU (poro) 2" DEN/NEU (poro) 5" DEN/NEU (raw) ~ 2" DEN/NEU (raw) ~--.Cyberlook 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run #1 11-16-85 Run #1 11-16-85 Run #1 11-16-85 Run #1 11-16-85 Run #1 11-16-85 Run #1 11-16-85 Run #1 11-16-85 Run #1 11-16-85 Run #1 11-16-85 Run #1 11-16-85 Run #1 11-16-85 Run #1 11-16-85 Run #1 11-16-85 Run #1 11-16-85 Rmn #1 1!-23-85 Run ~1 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run #1 11-2~-85 Run #1 2856-7960 2856-7960 2856-7934 2856-7934 2856-7934 2856-7934 7500-7900 2744-6752 2744-6752 2744-6727 2744-6727 2744-6727 2744-6727 6190-6705 3208-7330 3208-7330 6600-7303 6600-7303 6600-7303 6600-7303 6600-7250 3797-8006 3797-8006 7200-7981 7200-7981 7200-7981 7200-7981 7300-7700 Anch9r~e Receipt Acknowledged: State of Ak*bl/se Rathmell*bl Drilling*b 1 D&M*bl NSK Clerk*bl Vault*films Date: ARCO Alllkl. Inc. il · Subsidiary of AlllnticRichfielelCompany · ARCO Alaska, Inc. Post Office Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC, ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. return one signed copy of this transmittal. DATE12-19-85o TRANSMITTAL # 5473 Please acknowledge receipt and Open Hole LIS Tape plus listing/ schl/ One copy of each lQ-4/f G3-18-85 Run #1 4570.0-9471.0 ref#'70997-;~;~d~F~ ~2H-9/[ 12-02-85 Run #1 1800.0-8113.0 ref# 71048 ~2H-10~/ 11-23-85 Run #1 2856.0-7960.0 ref# 71002 "~2H-12 z, 11-07-85 Run #1 2743.0-6829.0 ref# 70947 ~2U-7// 03-19-85 Run #1 3594.5-8179.5 ref# ~2V-16/! 06-03-85 Run #1 2973.0-7168.0 ref# 70952-f~i~p ~3A-10]! 11-09-85 Run %1 3179.0-7014.0 ref# 70960 ~3A-11w~ 11-16-85 Run #1 3208.0-7330.0 ref# 70989 ~ 3A-12// 11-23-85 Run #1 3797.0-8006.0 ref# 71003 ~-3A-13;/ 12-01-85 Run %1 1800.0-7597.0 ref# 71047 ~3A-14'/ 12-09-85 Run %1 0144.5-7818.0 ref# 71073 ~- 3C-9 ~ 07-10-85 Run #1 3920.0-8332.5 ref#__70996--~ ~ 3F-8~! 11-09-85 Run %1&2 0115.0-7040.0 ref~ 70994 ~3F-9/~ 11-17-85 Run #1 3410.0-7770.0 ref# 70990 ~'~3F-10~ 11-27-85 Run #1 1800.0-6631.0 ref# 71037 '~J 3F-11 ~ 12-05-85 Run %1 0148.0-8618.5 ref# 71061 ~J3J-9~/ 11-24-85 Run #1&2 0~91.0-6789.0 ref# 71034 3J-10'~ 12-08-85 Run %1 0096.5-7348.5 ref# 71074 -- // -ILl - Receipt A~knowledged: 'STATE OF ALASKA* ARCO Alaska. Inc. ~s i Subsidiary of AllanlicRichl~eldComplny Date: ARCO Alaska, Inc. Post Office BO.~ 3360 Anchorage, Alas~~ 99510-0360 Telephone 907 276 1215 December 13, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the November monthly reports for the following wells: 2H-9 3A-11 3F-8 4-22 16-19 2H-10 3A-12 3F-9 4-29 L2-3 2H-11 3A-13 3F-10 16-7 L2-21 2H-12 3C-6 3J-9 16-15 L3-15 3A-10 3F-7 3J-10 16-18 WSP-12 WSP-20 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU12/L129 Enclosures RECEIVED I s 41~s~a OU & Gas Cons. Commission Anchorage . - ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany. .- STATE OF ALASKA ALASKA Ch-c: AND GAS CONSERVATION COrwc,,41SSION MQNTHI. Y REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc, 85-260 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 103-20051 4. Location of Well atsurface 170' FNL, 59~,' FEL, Sec.35, T11N, R8E, UN 5. Elevation in feet (indicate KB, DF, etc.) 130' RKB 9. Unit or Lease Name Kuparuk River Unit 6. Lease Designation and Serial No. ADL 25587 ALK 2673 10. Well No. 2H-10 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. November ,19 85 12. Depth at end of month, footage drilled, fishing jobs, dir~tional drilling problems, spud date, remarks Spudded well ~ 2200 hfs, 11/17/85. Dr]d 12-1/4" hole to 2875'. Ran, cmtd & tstd 9-5/8" csg, Drld 8-1/2" hole to 7979'TD (11/23/85). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 7878'. Secured well & RE ~ 0430 hfs, 11/25/85. 13. Casing or liner rgn and quantities of cement, results of pressure tests · 16", 62.5#/ft, H-40 weld conductor set @ 118', Conductor report not yet received. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 2860'. Cmtd w/750 sx CS III & 330 sx CS II. Top job performed w/134 sx CS II. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 7960'. Cmtd w/350 sx Class C. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/CR/SP/SFL f/7968' - 2860' FDC/CNL f/7968' - 7350' & 3600' - 2860' 16. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE-Report ~/n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. ..... ~ ~n,~ TEMP2/HR75 Submit in duplicate STATE OF ALASKA ALASKA O~..~AN D GAS CONSERVATION COI~ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well ~1~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-260 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 103-20051 4. Location of Well atsurface 170' FNL, 594' FEL, 3ec.35, T11N, R8E, UH 5. Elevation in feet (indicate KB, DF, etc.) 130' RKB Lease Designation and Serial No. ADL 25587 ALK 2673 For the Month of November ,19 85 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2H-10 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 2200 hrs, 11/17/85. Drld 12-1/~" hole to 2875'. Ran, cmtd & tstd 9-5/8" csg. Dr]d 8-1/2" hole to 7979'TD (11/23/85). Ran logs. Ran, cmtd, & tstd 7" csg, PBTD = 7878'. Secured well & RR ~ 0430 hfs, 11/25/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests · 16", 62.5#/ft, H-40 weld conductor set ~ 118'. Conductor report not yet received. 9-5/8", 36.0#/ft, J-55, BTC esg w/shoe ~ 2860'. Cmtd w/750 sx CS Ill & 330 sx CS II. Top job performed w/134 sx CS II. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 7960'. Cmtd w/350 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/GR/SP/SFL f/7968' - 2860' FDC/CNL f/7968' - 7350' & 3600' - 2860' 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report his form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP2/HR75 Submit in duplicate 'MEMORANOUM TO: THRU: FROM: State of Alaska ALASKA OIL AND GAS CONSERVATION .COMMISSION C. V/~tt~erton Chai~fn~-~ Lonnie C. Smith Co~i s s loner Bobby D. Foster Petroleum Inspector DATE: November 22, 1985 FILE NO: D. BDF. 120 TELEPHONE NO: SUBJECT: BOPE Test ARCO - K.R.U. - 2H-10 Permit ¢85-260 Kuparuk River Field Tuesday,..November 19, 1985: The BOPE test began at 12:00 AM and was concluded-at 1:00 AM, As Ehe attached BOPE test report shows, there were no failures. In summary, I witnessed the BOPE test on ARCO's 2H-10. Attachment 02-001AfRev. 10/79) O&G #4 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator Drillin~ Contractor ~ /~>~ ~ Rig #~~--'Rep-resentattve Location, General ~-/~ Well Sign~/~' ACCUMULATOR SYSTEM General Housekeepin. g~_~Rig _~/~/ Full Charge Pressure ~6~P psig Reserve Pit ~/~' Pressure After Closure /_~ID psig Visual Audio ~.~ Mud Systems Trip Tank Pit Gauge Flow Monitor Gas Detectors Test Pressure BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Pump incr. clos. pres. 200 psig - Full Charge Pressure Attained: .~ min~ sec. Controls: Master ! Remote~/~..~ Blinds switch coverlet. Kelly and Floor Safety Valves Upper Kelly / Test Pressure Test Results: Failures ~) Repair or Replacement of failed equipment to be made within Lower Kelly / Test Pressure all Type / Test Pressure Inside BOP / Test Pressure Choke Manifold ~-?~5Test Pressure Adjustable Chokes ~ Hydrauically operated choke / Test T~e / hrs. days and Inspector/ Commission office notified. Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor o. ARCO Alaska, Inc. Post Office I~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 1, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Ancho.rage, AK 99501 · SUBJECT: Conductor As-Built Location Plats - 2H Pad Wells 9-12 Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU12/L65 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany "'"" '" - ~ "- - - ': .:_-. d: :.~. ;;';: DRIL SITE 2.H CONDUCTORS--/:i~:~.~-: :::.,2.~:- :: ' ':_:::~: :"--' --:-'-::-: X:':~-: "497,864.90_ ' LoNG.~lSO°Ol'Oa.i63";- : -:::: -:'.:::/:--..- .. - .. : - · '.:.::.,'5.": :..:.~ .... - :-'-- . - :::--:': 170'FN 4'FEL- _-- Eh:. '"'" "~': -'" ' -" ": "' :' ~ ' ' ' J - ._. _- -: L - ' - . _ ~.~. -.~..:. ;_..:.. ~: ~.. · _ ~ - , .: ~ .- .~ - "::):::::~':~:')-()/"::" :'.~.):'.:'~?': ~ .: ~'-'~- -.-' ./--::::': Y:-:::5,9~8,6'g:.I4. . LAT. 70°16'15:"~2i:F :':<':: ..... "~' '- - ...... ".-"' . ..:. _:..: -T-:L- -'--:::.--'.:'::- '-'~:::~:~-497,80;',9z - ::::::::::::::::::::::::::::: ..... . :.-... ======================== .L':.: ...:::...::::/...: .:. ~ .. -::. :..:.._ .:_ .:-.-.~..../-._-: :.- -:.:o~:~,:.,~ :~,,::: -. . . -~'-.7-:;:.. . '.- .~_ _....,.-::..__ / , . ~. ~:..',..,... . . .-~ y~..' .:...-~..._ . , ' i 948,'693 O5 LAT.- 70°i6"'i5.79i0;'' 170~FNL,- FK~-:'-' EL = 94.8';OG-=--90.5%-. '<:':"' '- :'" '::' ':'"YE -: ~ ~' "' ' '" - .... .... '-- 7 ::- 80. ~ . Oil:-'. -;:,--."~7': .'_-: WELL '12-- ..:_: . -- _. <- : .... ~-"' .... :'" ' :;. ~ o.:_ .:... ":.~.:::::: ':- :.--::::-~ -::':J- :-':':':EL ::-::.' .- '_ :'._ ' ' ":.-': :?7' ~ .::'.'-:.'":-:--1--- :-7:/-' ' .... :.' - - ..... . ::-,-: " '-~ .. '.~-. - ....... %:' ,-:' ~ :.:'. '-:',:-:'.-:-,:': :: _- :::::::::::::::::::::: ::bT ::.--:: :::' ::' -:- :~::__:.--:....-::: _-7-~-: ._._ .v :-~_';.-:-7 .... ' .':' -':~' ' : · '":'":'~ :'"--:: '-- '::-: :","-at::: ~:'-~ .... ~:'~'--.._': '"::T-:Y_ :-: "--'---. :? :.:-' -':'::'Y-: :-.'..::';~' .,: .... ': .. :: .;~. ' :: ::: .':~:4~- 7~:~:::%F:~:-<~:~:&; -- " - " ' ' . ........... . .:.: ':.. :, ...' : - :.:._:::.:.- . L O C ITEO IN- S~GTION' B5 - - . - ~ . -' · - . .: ...... .-. :. : - . - ...':..-:-- -.- -: ...... .-~-.:_-._ ... :.. . ..- _. . .. - . ' : . . _ . _. . ..:'.'..':,' ..' ~ .. "-: :'. .... . . . ;.. ,-. : : .' . -" . _'_- -_ :- :-. : - - . .-~ _"- . -_ -: -. . . '_.'.:...- .... ::~: - "-'" - . ",.. . ,..-': "":. ":'"- . -' --_; ' ~'.: ::: ~OV'0'4 ~-_:~::~-:..¢-':-::;;:;- --.' ...... . . .' . . : % ::- . _ .~'::-'.~::__..' _. -.' . ..:...-'.-' -/ " : ' C - ' .... ..... ' " . · ": .... A~oraGe ' .' '-:'" ' '-- "' ' ' -- '-"- ~: ~" : ~'~ "" - I' /-" . - ~ u~s~s::':o ~,,C:Jc: :*~9,SURVE~G ~N THE 'sTATE OF. -.."--.j:~':'~:.- L.v.i.'.~ EL:: ,,'" .'"' J k~o :- "'"'.- - / ':/ ~:~s~,' ~._.:~,:...~,s .~:,::.":~:s.~":s ~':su~V:~' ~E':::.:-._ =~---:--T: ......... ~ I ~~ _:-..-;:_ : ARCO Alaska, inc.-.: '.: .:--~:. :-j.' .-~D. S2'H -'--'' I.,, ~:~ ' ,.::,-_.'~o/ec' ~-..-'North'SlOPe Drillin-~ .' :.- ': LOCATIONS' ---- . , ' .. __ , ~ ~ ................~ -'- ~ ~ 8SSOB D:,e 0c'ober,8, l,85 Scole: ~00'.-:~:~-' '~"~ Z ~ v.,_E ~1 ~ ) ~ ....... ~ Dro~ghtsmon:'MC ~g. no.:NSK85-28 ~'.-'- ;._ .: -. j :.) ... '-::'::::f' 12 · :- , ; ... : ... - . ,.. II · - ., ·. -..~o · - J 0~5 ---' .. ~. ' - I ':::' 9 · - - :.-:- ... ... _-..-:-_' , _.. - ~... : -.. :_ · ,..:...:.:.~ .-. .... _ ': .: ..'.i" ':'; ...... :':' '" t -' '-. .-: - '.i' : : ' ::.'.:_.r';..-,:_ · ~[ · ,... ._ . . ~.'-'::-. .~ ~' 80. . :-' 70 O . -. - ~. .<, ': : .. - :~:: -: 60. '- O . . . ~..-- : - .'. 50.- . '04"':-.. ..., : -~.... .., . ,..., . _ . . ' ' ":...." :"'--' .::'.'- . '--:. October 30, 1985 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2H-10 ARCO Alaska, Inc. Permit No. 85-260 Sur. Loc. 170'FNL, 594'FEL, Sec, 35, TI!N, R8E, UM. _ ~ R8E UM Btmhole Loc. lll~'FSL, 1359'FEL, Sec. 35, ~llN, , . Dear Mr. Kewin: Enclosed is. the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ve~wtr~lM vo,~s,~ · V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl, Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office BoX'-~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 23, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2H-10 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2H-10, along with a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plot o A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on November 18, 1985. If you have any questions, please call me at 263-4970. Regional Drilling Engineer JBK/lt PD/L96 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRlchfieldCompany STATE OF ALASKA ALASKA OTf_' AND GAS CONSERVATION CO'lwrCllSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~[X DEVELOPMENT GAS [] SERVICE [] -4/ STRATI~APHICYJ~]¢ SINGLE ZONE IX~9 MULT PLEZONE 2. NameofoperatOra, nc. ARCO A1 ska I 3. Address P, 0, Box 100360~ Anchorage~ Alaska 99510 4. Location of well at surface 170' FNL, 594' FEL, Se¢.35, TllN, RSE, UN At top of proposed producing interval 1388' FSL, 1307' FEL, Sec. 35, T11N, RSE, UN At total depth 1116' FSL, 1359' FEL, $ec.35, TllN, RSE, UH 5. Elevation in feet (indicate KB, DF etc.) RKB 130v PAD 95' 6. Lease designation and serial no. ADL 25587 ALK 2673 Federal Insurance ComPany 9. Unit or lease name Kuparuk River Unit 10. Well number 2H-10 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 12. Bond information (see 20 AAC 25.025) Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 170~ @ Surface feet 2H-11Well 60' ~ Surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 7936' MD, 6358' TVD feet 2560 November 18, 1985 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 1416feet. 20. Anticipated pressures MAXIMUM HOLE ANGLE 44° (see 20AAC25.035 (c) (2) Proposed Casing, Liner and Cementing Program ~1/+2 psig@ _ROOF Surface 3R17 psig@ 60k. 0 ft. TD (TVD) SIZE Hole 24" 12-1/4" 8-1/2" Casing Weight 16" 62.5# 9-5/8" 36.0# 7" 26.0# 22. Describe proposed program: CASING AND LINER Grade Coupling Length H-40 WeldI80, J-55 BTC J,~J ~ 7' HF-ERW J-55 BTC 17~/6/' HF-ERW SETTING DEPTH MD TOP TVD 36' I 36' I 36' 36' I I 35' ~ 35' MD BOTTOM TVD 116' 116' 2893' 12750' I 7936' 16358' I I QUANTITY OF CEMENT (include stage data) ±200 cf 670 SX CS I!1 + 330 sx Class G 300 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7936' MD (6358' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3500 psig upon installation and weekly thereafter. Expected maximum surface pressure is 3142 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 2H-10 will be 60' away from 2H-11 at surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. {continued on attached sheet) 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED TITLE Regional Drilling Engineer DATE The spac~/~w f~or~'q~,~io'h~se CONDITIONS OF APPROVAL Samples required Mud log required []YES [~NO I--lYES Permit number Approval date z073.0/857 APPROVEDBY Y~~~~ Form 10401 (LWK) PD/PD104 ," Directional Survey required ] APl number ~LY-E S i--I N O [ 50_ t~ 0..~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMM ISSI ON ER by order of the Commission DATE October 30~ 19R5 Submit in triplicate PERMIT TO DRILL 2H-10 Upon completion of the disposal process~ the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. 5elected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location~ this well will be fracture stimulated. ...... ?-- ARCO !ALASKA. INC'~--~ -- - .::_x:_L:. ;' PAD::2H. WELL' NO, 10. R ...... -f ....... KUPARUK' FIELD.~-NORTH SUOPE; i ALAS_KA:: :_;._/~ : ................................. ~ .... ........ ~ ....... 1 ....... . ....... ~ · ..... ~ ............................. ~ ...... ..... , .......... g- - TOP UGNU- SNDS 'TVD=t540 -TMD=I 540 DEP?4 ....... :" ~00 BU[LD' 3 DEG PER t00:FT ..... ~ : L::T"L:_~:_~.": :__:.:t}:_-:~39. :EOC'_(9 5/8~_CSG:PT) :_::::t:'/:L: : :T.': ..... .- -7: - .... '~--'-/':~---:::::':w 7-:::~: .... ~C:::::'-:':~-'-~ .... ~ ......... ~00~ _~ -: ...... ~ ...... ........ ~ .......... T/ -ZONE- C--~ TVD-6040 ~-Z492 ~P=3~5~~, : .... :~-:_.::L.' :_: .'..: '...:T/ ZONE- A'T_:TV.D=607~_ ...... ~ nu~ ~eu u~o~_~i ...... .._ ....... i ....... ............ .:_lTD (LOG PT~ ...... -TVD=635B-;THD=Fg36 ~-DEP=4067-4- ........................................ ~ ................................ ~ ~ ~ :~_'_:~_::.:.:::_.: :::::--:_ :: L.D:'.:-: --:..~' :':::::/::~ 000::'::: :- - -t2000-:_-7 :'. /L:: ~000-:?: ...... 4000 I ......... , . ~ ~ .......................... KUPARUK FIELD'-NORTH-: . : - ...... }~SLOPE~ ALASKA .................. . .......... ! ................¥ ....... : .... ..... · ....... : ........................ ..TD LOCAT.ION, ._i .......... ! .... ........................ . ....... 11 ! 6 ? FSL,- 1359' - FEL- ......... : ........................ $EC~--35,- -1'!-! N~-- RItE ............ i .......... i ~ ::::: .:::::'::::: '-'-': .... ::.-: :-. :-.:-'-: :'--:: ::::-:-.::-.-:::38:5:9-: ::-(T:O --:.:T-ARGET) -__w_-..:-::: .... :_. ' ! _. '-'.:' '_'?...::-___--:-:::: -_w~-._-:--: ::-_:._::'-:i : i - ~_ - ~,:~-~-~~.:~:.~i~:--~:~:~:~::.:.:/ . ,~. ~RG'ET- LOCATION, ---1320' ~ .........~ _-..-$OUTHT3ZeO:----_- ~$T .... 7-26 T AROE'TZ-~ITER _~' ~__~_ ...... ..... TYD,-614~ ~- ....... - ........... :-: TMD=763g + DE!~-3859 i .... KUPARUK IRI VER UNIT 20" DIVF_J TER SCHEMATIC DE S CR I PT I ON I. t6' C~CT 2. TA~I<O STARTER WEAD. 3. TANKO SAVER SUB. 4. TANKO LOWER QUICK-CO~XECT ASSY. 5. TANKO UPPER QU]CK-C~CT ASSY. 6. 20' 2000 PSI DRILLIN~ SPOOL W/I O' OUTLETS. 7o I0' HCR BALL VALVES W/lO" DIVERTER LINES, VALVES OPEN AUTOMATICALLY UPON CLOSURE OF A~IJL. AR PREVENTER. 8. 20' 2000 PSI AI',t~LAR PREVENTER. 2 MA:[ NTENANCE & OPERAT_I ON I. UP-ON INITIAL INSTALLATION. CLOSE PREVENTER AND -VERIFY THAT VALVES -- HAVE OPENED PROPERLY. 2. CLOSE ANI',IULAR PREVENTER AI'~ BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3; CLOSE A~LAR PREVENTER IN THE EVENT 'THAT AN ih,FLUX C)F ~I~:LL~ · '-FLUIDS OR GAS IS DETECTED. IF . NECESSARY, I',IA~ALLY OVERRIDE Aht~ CEOSE - APPROPR I ATE VALVE TO ACHIEVE DONNWlh~) DIVERSION, DO' NOT SHUT IN ~LL ANY C I RCUI~TANCES. ~ I {II~IXl R4 7 DIAGRAM #1 1~-5/8"~ PSI R~RRA BC~ STACK A¢~vt]LATOR CAPACITY TEST I. Q-ECX ~ FILL ACOJ4.t. ATGR RF_SERVOIR TO PRO=E~ LEVEL WITH HYERA~IC FLUID. 2, ASSLRE THAT A~TCR PRESStJ~ IS ~ ~I WI~ 4. ~~ ~ ~ ~, ~ A~~ L~ LIMIT IS 45 ~~ ~I~ T~ ~ 1~ ~I ~l~ 1 [- 3 2 , 13-5/8" BOP STACK T[ST !. FILL BCP STACX AMS) CH~ I~FCI_D WITH ARCTIC DIESEL. 2. C~CX THAT ALL LOCX D~ SC~ IN V~LLJ-F_AD ARE FLIJ_Y ~~. ~T WI~ ~I~ ~ ~ LI~ V~VES ~ TO 4, ~~ ~ TO ~ ~ ~ TO ~ ~I ~ ~ F~ I0 MIN. ~ ~~ TO 0 ~I. 5. ~ ~ P~ ~ ~~ KI~ ~ ~E -L[~ V~VES. ~ T~ P[~ ~ ~ ~ V~VES ~ ~ ~ ~ LI~. 6. T~T TO 2~ PSI ~ ~ PSI ~ IN S~ 4. 7. ~I~ TESTI~ A~ V~S, LI~, ~ ~S W[~ A ~ ~I L~ ~ ~ PSI HI~. ~T AS IN S~ 4. ~ ~ ~~ ~ST ~ A ~L ~I~ P~ITI~ ~ ~. ~Y 8. ~ T~ PI~ R~ ~ B~ PI~ ~ TO ~ ~[ ~ ~ ~I. ~ ~~ PIPE ~'. '~IF~ ~ LI~S T ~UID. ~ ~ V~VES IN PI~ ~~ V~VE, F~, SI~, ~ ~ TO ~I~I~ ~~~. ~Y ~~ ~I~Y ~~ ~ ~Y. REV. 2 CHECK LIST FOR NEW WELL PE~ITS .. ITEM APPROVE DATE ~ .. (2) J.o (2 thru 8) (3) Admin(8~ /o-~'t~× 9. (g thru 12) 10. #TH /~/~/¢'~ 11. (10 and 15) ' 12. (13 thru 21) -(22 th'~u 26) (6) Add .~. ~.~./O "27~C~ 1. Is 13. .14. 15. 16. 17. 18. 19, 20. 21. Company the permit fee attached ................................ 2. Is well to be located in a defined pool ................ 3. Is well located proper distance from property line ~ ~ 4. Is well located proper distance from other wells .... ''. ~' · 5. Is sufficient undedicated acreage available in this pool .. 6. Is well to be deviated and is wellbore plat included ...... 7. Is operator the only affected party .............. Lease & well No'. /~' YES NO REMARKS 22. 23. 24. 25. 26. 27. · · · · e e e · J e ~, · e ~ · e · e Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ , Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizOns .................. Will surface casing protect fresh water zones .............' tension';nd burstl. Will all casing give adequate safety in collapse, Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed .................... ' ........ Is a diverter system required ...... · ................... Are necessary diagrams of diverter a~d 'BO~'equipmen; Does BOPE have sufficient pressure rating - Test to ~O9 psig ../~ Does the choke mauifold comply w/API RP-53 (Feb.78) ..... ' ............ Is the pres of H2S gas probable ence ................................. Additional requirements .............................................. ~ Additional Remarks: ,, Geology: Engineering: HWK ~ LCS -- BEW WVA~ MTM .~7~. HJH~ JAL. rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , , ~ .>,~oor~ ).~ ,'1 ~ ~o Ill& o ~ ~u 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. ~ .SCHI~UMBE~GER..~.~ TAPE LVP 010.~!07 VEt~I~'ICATION LIS~'ING PAGE ******************************************************************************** , * NO'rE , * WAVEFOR~S AMD FaS~ CHANNEL DATA A~E NOT INCLUDED IN T~lS LISTING * * bVP OIO.HO? VERiFiCATION LISTi~!G PAGE 2 ** REEL ~EAD~R ** SERV!CW NA~:: :EDIT DATE :85/11/27 ORIGIN : REEL NAME :149190 COMTIN~tATInN ~ :01 PREVIOII$ REEL : CUMMENT$ :LIBRARY TAPE ** TAPE HEADER SEPVICF NA~E :EDTT DATE :85/11/~7 ORIGIN TAPE NA~E : CONT'~N!JATI~N ~ :01 PREVIOUS T~PE COMMFNTS :LIBR&~Y 'rAPE ** FILE HEADER V£R$ION ~ : DATE : ~A×I~U~ LENGTH : 1024 FILE TYPE PREVIOUS FTLK ** CO~EWT$ ** ************************************************************************************ * ~C[~LlJ~BERGER , A[,,ASgA CO~PUT,I:MG CENTEP' COMPANY : ARCO ALASKA INC, WELL = 2N~],O ' ~IEbD = KUPARUK COUNTY = NORTH e p ob[~ E B[)R~tlGH STATE = A~,ASK.A I~VP 010.1~O~ VERIFICATION LISTI},,}G PAGE 3 ,lO~ .~D~,lg, ER AT ACC..: 7 RUN #ONE, DATE bOGGED: 23-NOlt-t~5 LOP: C, WII',KIE CASING TYPE FLU?D DENSTT¥ PH Fb[.IID LOSS MATRIX SANDSTONE : 9.625" @ 36.00' - git SIZE : B.5" TO 7980.0' : LSND POI, Y.ER 10.7 [,B/G ~q 39.0 S RMF 10,0 R~C 7.0 C3 RM AT BHT ***** THIS DAT~ NAS NOT BERN DEPTH SHIFTED - OVER[jAYS FIEhD PRINTS ******************************************************************************* 3,31 a 76.0 DF "-" .... "--' ..... ~ ...... 3,47 ~ 76.0 DF .... 3,1~ ~ 76.0 DF 1,86 ~ !40, DF Alaska Oil & * SCHLU~BEgGER Lr~GS INCL[tDED ~,~ITH THIS t~AG~ETIC TAPE: * DiJAb INOI!CTI~N SPHERICALLY FOCUSED LOG (DIL) * FQRtqATION DENSITY COMPENSATED LOG (FDN) * C(]~PENSATED ~E~ITRi]~ LOG (FDN) , LVP OIO,HO? VEPIFICATION b!STIMG PAGE 4 DATA FORMAT RECORD E{~TRY BLOCWS TYPE SIZE REPR CODE 2 1 66 0 4 i 66 8 4 73 60 9 4 65 ,lin 16 1 66 0 1 86 0 DATU~ SPFCIFICATI[]N BbOCK$ MNE~ SERVICE SERVICE UNIT API API API ~PI FILE SIZE SPb R£PR ID DEPT S F [, U D I L lbD 'DIL IL~ DIL SP DIL ~R GR FDN CALl RHOB FDN DRHD FDN NR~T: FDN MpHI FD~' MCML FDM FCNL FDM PROCESS ~oG :r~P~ c~ss .OD ~o. CoD~ ~r oo ooo oo o o 4 ~ ~8 oooooooooooooo aMPul O0 220 O1 0 0 4 1 68 00000000000000 o.u~ oo t20 46 0 0 4 ~ ~8 00000000000000 or~ oo ~20 ~4 0 0 4 1 ~8 00000000000000 ~v oo ~o o~ o o 4 ~ ~8 oooooooooooooo ~A~ O0 ~0 O~ 0 0 4 ~ ~ 00000000000000 pz oo ~o o~ o o 4 ~ 60 oooooooooooooo ~ oo ~o oi o o ~ 1 68 ooooonoooooooo G/e3 O0 350 02 0 0 4, I 68 00000000000000 0/~3 O0 356 01 0 0 4 1 68 00000000000000 O0 420 01 0 0 4 1 68 00000000000000 PU oO 8~0 O0 0 0 4 1 68 0o000000000000 CPS no 330 31 0 0 4 1 6800000000000000 CPS O0 ]30 300 0 4 1 6800000000000000 ** DATA ** DEPT SP NCML 0OO0 SFLU 8005:195 GR ~6~,9092 DRHO 28 .5000 FCNL DE. PT SP RH~B NCNL 0286 2249 II.,M 2,8635 .!06: r~8 ~R t06. 0898 CALl 8,5020 0 .13~3; NRAT 3'..3623 DPHI 40.1855 654.3125 DEPT SP NCNL 000 .0000 SFbU 3. ~932 IbD 3, ~249 ILM 2, e752 . 39,4:883 GR 106,0898 GR i 06. 0898 CAL.I 23815,q0,. 2 DRH[.I 0,132 NR.AT 3..3362 MPHi 43,219 .5000 WCNL 654.3~5 7~00 ~000 SFLU 51,: 508 GR 2,4~6 DRHO 1984:,68'/5 FCNI., 3,]0~0 IbO 2,8596 ISM 2,8733 10~..5231 GR ~03.I523 CALI 8,6816 0,0854 NRAT 3,,4143 NPHI 41,3574 527..3125 LVP 010.H02 VE~.[FICATII~N L.T. STING ]::'AGE 5 DEPT 7800 0000 RHOB 2.492q NCNL 2611o 5000 DEPT 7ZO0!O000 SP .16 5264 ~HOB 9.. ~260 NCNL 2595. 5000 D£PT 7600. 0000 SP -999.2500 RHOb 2 4690 NCNL 2863:5000 SP .99,2500 RHOB 2.3674 NCML ! 962. 6875 DEPT 7400 O00O SP -999!2500 R~O~ 2 3674 ~C~i~ 198~.687~ DEPT 7300. 0000 SP -g9g, ~ 500 DEPT 7100 0000 SP -099:2500 RHOB -.999,2500 NCNL -999.250U DEPT 7000,00o0 SP ,999.2500 ~HOB :999,250() NCNL 999,2500 .EP~I~ 6900 0000 SP -o90:250u RHOB -999.2500 NCNL -O9q. 9~500 DEPT ~Ron.o()o0 SP '999 2500 RHn~ -999:2500 NCNL -999.~500 4 ~7n6 9625898 0.0308 717,8125 6,7117 9~,~148 0,0059 778,8~25 6 ~976 88}58g~ -0 0020 1006 8125 1 9424 120 0186 486 8906 ~ t2~3 ~34i3125 0 01o7 438 8906 ~ 99~4 ~4q:Ob~5 657. 25 5 llO1 999, 500 -999.2500 13~ '7581 .~125 -99~,~500 -99..2500 3.771'1 134.3125 -999,2500 -999.2500 ,1804 ~2 ,5273 -999.~500 -999. 500 4,~85! -qgg,,, O0 -999.2500 OR ~RAT GR MRAT GR IIbD GR NRaT I. LD NRAT NR~T I5D NR~T GR NRAT 4.0320 96,5898 3.~780 5.5945 98.214~ 3.0217 5 0671 88:5~98 2o6448 1.76~7 ~.28 3125 ~o8889 ~34,3125 3.928U 2 ~545 3.2131 241.8125 -999.2500 3.5803 ~.37,:8.125 -q99,2500 3~3948 134,'31~5 -099.2500 4,7742 120,5273 -999.2500 3.7639 .I26.0273 099.2500 I bM CALI MPHI CALl NPHI IbM CALI NPHi Ib~ CALI MPHI CALl I CALl NPHI I CALl CALf NPHI CALf NPHI CALI IL~ NPMI 4 2390 8!6973 37 0117 5,6765 8,697~ 34,1309 5.1960 8'9004 28.0762 1 8526 9i0879 47 705~ 2,9475 9,3066 49.8047 ~,4260 8,9707 37,2070 ].5100 -q99. 50 9~ 07 -099,:~ O0 3,~592 -q9g,~ 0 -999:2500 ~.6799 -999. 0 "- --- I '- II m -- =_m_ : .-; LVP 010,HO~ VEPlFICATiDN LISTING PAGE; b .ogpu' 6?oo oooo sF[,u sp :99oi 2500 GR RHOB o99 ~.500 DRMO NCNL -99q.~500 ~CNL D~:PT !6ooinooo srhu SP 999 2500 GH RHOb 990 2500 O~HO MCNL -999. 2500 WCNL DEPT b500.O000 S?LU SP -999.~500 GR RHOB -999.2500 DRHO NCNL -999.~500 ~CML DEPT 6300.n000 SFLU Sp -099,2500 GR RHOB -999.2500 DRHO MCNL -999.P500 FCNL DEPT 6~00.0000 SFI, U SP -999.2500 GR RHOB -999.2500 DRHO NCNb -999.~500 FCNb DEPT 6100 0000 SFLU -999:2500 ~R ~OB -q99:.2500 DRHO ~CN[, -990.~500 , CNL DEPT 6000,0000 SFLU SP -999,,2500 GR RHOB -q9q.2500 DRHO MCNL -999,~500 FCNL DEPT 900, 000 SFLU Sp 099.2500 GR RHOB -999.2500 DRHO MCNL -099,~500 FCNL D EP',r 5800. o000 SF~.,U SP -999,~500 ~R RH[1B -099.2500 DRHO MC'NL -999,.2500 FCNL OEPT 5700.0000 Sp 999,2500 OR R~IOB 2999.2500 4 0476 !bD 134:5b~5 GR T -999,~500 ~RA -990.2500 2 2874 ILD 11317773 GR -999 2500 ~R~T -999 2500 4,0125 134,1875 GR -999'2500 ~RAT -999.2500 4 0164 II]D 11711523 GR -g9q 2500 NRAT -999 2500 2 9709 · 100,7773 -999,2500 NR~T -99~.P500 3 3147 I.LD ,115~2148 GR 999.2500 NRAT -999, ~500 9'6,2773 CR -9991:.2:500 NRAT -090,2500 4, .I 140 ILD t. 27, ~98 ~R -990. O0 NRAT -qgg, ~.500 97,5898 GR -999,~5500 NRAT '099, O0 4,'0632 1.22,4648 GR '999,2500 NR~T '999*~500 3,9124 140,68'75 GR -990,,~500 MRAT 3.8303 134.5625 -999.2500 ~.3538 113.7'773 -999.2500 4.0632 1.34,1875 -999.2500 4.0789 -999,2500 =099.2500 3 2444 .'999i2500 999 ~500 3.m, 905 -999.2500 -999.2500 -999 0'0 -999 '2500 3,91~3 "999,25 0 '999.2500 2.~7~93 -99e~ , 2500 -99~ .2500 3 933U -9 o: soo -q 9.2500 .999 ,250° .2500 CALI NPHI IbM CALI NPHI IbM CALl NPHI CALI NPHI IbM CALl IbM CA I,, I MPHI NPHI IbM CALI NPHI I bM C A L .I NPHI CALl NpHI 3.8909 10.1504 -999,2500 2.4202 9 4395 -999~2500 4.1335 9,9395 -999,2500 -999.2500 -999.2500 3 3342 -q99~2500 -999.2500 3,5959 '999,]500 -999. 500 3,3206 :999,2500 999,2500 ,,99~'9475 ,2500 9.2500 2.~659 .999, 500 -999,2500 3.9592 -999 2500 - 9 :2 oo -999, 500 -999.~500 LVP OlO.N02 VERIFICATION LISTING PAGE 7 NCNb -099,2500 FCMb -990, DEPI 5600.0000 SP -999,2500 GR .139. RHOB -999.2500 DRNU 999. NCNb -090.2500 FCNL -999, DEPI: 5500 0000 SFI. U 3, SP -o99:2500 GR 189, RHOB -999°2500 DRHO -999. NCNb -999°2500 FCNL -099. DEPT 5400 0000 SFI.]U 2. SP -999:2500 GR 138, RHOB -q99.2500 DRHO -99q. NCNb -999. 2500 FCNb -~99. DEPI~ 5300 0000 SFLU 2. SP -099,2500 G~ 1.25 RHOB -099,~500 DRHO NCNb -q9q.~500 DEPT 5~00 oO00 SFLU ~, Sp -999:~500 QR 154, RBOB -~9Q,2500 DRHD -999. NCNb -999..500~ FCNL -~99. 2500 5772 5625 P500 ~500 9299 9375 2500 2500 2229 0625 2500 2500 4514 7773 2500 2500 5237 1875 500 500 DEPT .5100.0000 SFLU 3,3596 SP 999., ~500 .C,R 1 23,0898 NCNL -999.2500 FCaIL :90. 500 DEPT 4aO0,O000 SFLU 8P -999.2500 ~R 107, NC~L -~99.2500 FCNL -999. DEPT 4.700,0000 8FLU 2, SP 999,2500 ~R 112, ~HOB :.999,2500 DRHO -999, NCNb -999.25~0 FCNL -099. DEPT 4600 nuOo SF[,U 2, SP -999:2500 (IR 117. 4573 0 2500 7795 6523 ~500 5o0 193b 08 2500 9280 .1523 2500 2500 8850 3398 I bD GR NR~T GR NRAT NR ~T GR NR~T TLO GR NR~T GR NRAT T bD GR NRAT R~D NRAT gR NRAT NRA T 1 5782 -990:2500 -99~.2500 2.5413 :a99,2500 999.2500 2.2620 -999.2500 -999,2500 2.6467 -999,2500 -999.2500 3,0100 .-999,2500 q9g.2500 -99c, .59oo 3 0979 -999 2500 '999 2500 2,2659 '090. O0 2.6213 -999,2500 -999,2500 2,9 377 -~99.2500 CALI NPHI CALl CALi ~PHI NPHI IbM CALI NPHI CALl NPHI I L M CAl., 1 NPHI IbM CALl NPHI ILM C A [, ! NPHi C A L I NPItl C AL 1 1 5772 -99922500 -999.~500 3.1057 -999,2500 -999,2500 2,2913 -999,2500 -999.2500 2,5979 :999,2500 999.2500 2,9475 :999,2500 990.~500 3,~456 -g9g, 500 -999.2500 3 6448 :999' 999 ' ~500 .2500 3,0393 -999,2500 -999.2500 2.2620 '9999,:2500 9.2500 :999, O0 999, ~500 2,935'8 -999.2500 LVP 010.~{02 VERIFICATION LISTING PAGE 8 RHOB -999.~500 DRNO NCNL -999.2500 FCNg DEPT 4500.0000 SFLU SP -999.2500 GR RHOB -999.~500 DRHU gC~f, -Q99,~500 FCNL DEPT 4400 0000 SFLU SP -999i~500 ~R RHOB -999 2500 DRHO NCNL -999.2500 FCNL DEPT !300!0000 SFbU SP 9992500 GR R HO [~, 9992500 DRHO NCNL -999. ~500 FCNL DEPT 4~00,0000 SFLU Sp -.099,2500 ~a RHOB -999.~500 DRt40 NCNL -099,~500 FCNL DEPT !n00.0000 SP 999.2500 GR RHnB 999.~500 DRHO NCNL -999.2500 FCNL DEPI ]8000000 SFLU Sp~ ' GR 999,2500 RH[E -999,~500 DRHO NC. NL -999.~500 FCNL DEPT 3700,0000 SFLU Sp -~99.2500 OR RHOB -999 ~500 DRHO NCNL -999:2500 FCNb DEPT 3600.0000 8FLU SP -999,2500 ~R RHOB 2,2014 DRNO NCNb 214°,5000 FC~L DEPT 3500.0000 SFLU -999 2500 -999:2500 3.1917 II.,D 102.9023 aR '999.2500 ~RAT -999.~50U 29514 ILO -999,2500 NR~T -999°2500 3.3616 ILL 90.5273 GR -999.~500 NR~T -999.2500 . ~077148 GR -o99' -.099,2500 2,4592 ILD 9959.9648 CR -9 .2500 N~a'r -099.2500 3.3518 ILL -g9q.2500.. NRAT . 999.2500 3 ~95.2 1041 023 '999,~500 NRAT -990. 500 3,0237 ILL 99,3398 ~R -999,2500 NRAT -999,2500 .2,8850 I b I) :103~0898 999,2500 NR~T 2999,950(i) 4. 504..6 IbD . , 0024 NR ~'1 595..3125 ~.4656 ILD -099.2500 3.2795 -999.2500 -999.2500 3.0217 -999.2500 -999.2500 4,2781 :999.2500 999.2500 3 3401 -99 : 5oo -999.2500 3.3401 -c~99.2500 ,,999.2500 3 -999!~624500 -999 2500 3,~70~) -999, 50 -999o~500 3.4475 9~.2500 99~,3030 - .2500 -999.2500 5.0359 9q.~173 3 , .3'6 4,7625 NPHI ILM CALI NPHI CAbI NPHi IbM CALl NPHI IbM CALl NPHI CALI NPHI CALl NPHI ILM CALI NPHI IbM CALI CAEI N PHI IbM -999,2500 3.3030 '999,2500 -999.~500 2 9963 :9 ,: soo 999.2500 4 .6882 q99.2'500 3 2463 -999i2500 -999 ~500 3.1643 -999,~500 -999. 500 3,5276 99.2500 3.3772 -999,2500 -'999,2500 3,2874 -999,2500 -999.2500 3,189'7 -999.2500 -999.~500 4,8289 9,4160 40,7715 4.5710 DVP OIO,HO?. VERIFICATION LISTING PAGE 9 SP -999 2500 GR 93, RHOB 2~189'; DRHO O, ~CNL 2085,5000 FCNb 527, DEPT 3400.0000 SFI, L{ 3. SP -999.2500 GR 88' RMOB 2,2170 DRMO -0. MCNL 2313,5000 FCNL 495, DEPT 3.7i00.0000 SFLU SP -99q 2500 ~R RHO~ 2:2385 D~HO 0 NCNb 1928,6875 FCNL 51 DEPT 3100,0000 SFLU 3 SP -999,2500 GR 1.12: RHOB 2.2'795 DRHO 0 . NCNb 1796.6B75 FCNb 470, DEPT 3000 0000 SFLU 3, SP '99~' " ,2500 GR 84. RHOB .,2209 DRHO -0, NCNb 2019.6875 FCNh 466, D£PT ~qO0 0000 ,.q.F[,U 3 SP <)99:2500 GR 1.1 ,* NCNb 1861. 875 FCML 46 . DEPT 2840,0000 SFI...U 3, S'P -g99,2.500 GR 51, RMOB 2.03q] DRHO NCNb 1492.6875 WC~G FILE N~ME :EDIT .001 SERVICE NAME : VERSION # : DATE : FILE TYPF : NEXT FILE NAME : EOF ** TAPE THAII, EP ** SERVICF SAME :EDIT 1523 GR 0093 ~R~T 8125 5842 8398 GR 0044 NRAT 1406 6897 lhD 1523 ~R 0190 WRAT 6406 6140 lbo 0054 NRAT 6406 8342 ILL 6523 GR 0420 MRAT 1.406 697b 9023 GR 0044 NR~T 6406 951,4 6523 0063 MRAT 1.406 8108 ILL 9805 GR 4258 NRAT 6406 93.1523 3.5979 4.9695 88.8398 3,7952 4.1531 127.1523 3.5081 6.4382 113.5898 3,7600 4 4265 112:6523 3.7952 4.5359 3.9 2 5,0320 7.1..6523 3.7385 10,2676 51,9805 .1.023 CALl NPHI IbM CAbI IbM CALI NPHI C A L I IbM CALl NPHI IbM CALl NpHI CA[, I NPMI IhS C A,[, :i NPHi g 4629 4,2546 9.6035 46,9238 3.9866 10 5410 5,9070 10.7129 44,6 89 4.0906 I1.1426 45,0684 4,1.257 10,9004 47.4609 4,610~ 11.095 44'0430 20090,6875 '!660 53,2227 LVP 010,~02 VEP, IFiCATION LISTIMG PAGE 10 DATE :85/.1.1/?,7 ORIGIN :FS1, A TAPE NA~E : CONTI~]ATION # NEXT TAPF, ~!A~E : CO~ME~T$ :LIBRARY TAnE $~ REEL TRAILER SERVICE NAME :EDIT DATE :~5/11/?,7 ORIGIN : RE~L NA~F :149190 CONIINUATION ~ :0! 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