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Home My WebLink About185-102 Imag~roject Well History File Cover ~age XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. / _~'~_~-- ~_ ~- Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) D Color items: [] Diskettes, No, [] Ma ps: [] Grayscale items: [] Other. No/Type [] Other items scannable by large scanner [3 Poor Quality Originals: ,~ [] Other: .... OVERSIZED (Non-Scannable) · ~]~ Logs of various kinds NOTES: [] Other BREN V,NCENT S.ERYL MAR,A LOWEL,. °ATE: //. 1,02-,s, Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl_ DATE: /S/ Scanning Preparation ~2_ x 30 = ~ 0 BY: B~ BREN VINCENT SHERYL MARIA LOWELL Production Scanning Stage BY: Stage 2 DATE: ///a ~/S/ ~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDiVIDUAL PAGE BASIS DUE TO QUALrPf. GRAYSCALE OR COLOR IMAGES) PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES NO ~ BREN VINCENT SHERYL MARIA LOWELL IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BEVERLY BREN VINCENT (~ MARIA LOWELL D AT E/,/~,~)/O ~1~ ~.~.~ RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARia LOWELL DATE: /SI General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3 NOTScanned.wpd STATE OF ALASKA ALGA OIL AND GAS CONSERVATION COrveSION ' REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell rj Plug Perforations rv7 Perforate Other r Alter Casing r Pull Tubing p- Stimulate-Frac fl Waiver r Time Extension 'r Change Approved Program r Operat.Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: _ ConocoPhillips Alaska, Inc. Development p` Exploratory r - 185-102 3.Address: 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service , 50-029-21357-00^09 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25634 ' 3C-11 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): - none Kuparuk River Field/Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8862 feet Plugs(measured) 8147', 8511' true vertical 6731 feet Junk(measured) none Effective Depth measured 8771 feet Packer(measured) 8128,8487 true vertical 6671 feet (true vertical) 6246,6484 Casing Length Size MD TVD Burst Collapse CONDUCTOR 44 16 80 80 SURFACE 4435 9.625 4470 3800' RECEIVED PRODUCTION 8812 7 8856 6728 JAN 032013 AOGCC Perforation depth: Measured depth: 8386'-8400',8440'-8448',8457'-8465',8582'-8590',8595'-8640' True Vertical Depth: 6418'-6427',6453'-6458',6464'-6469',6548'-6553',6556'-6586' Tubing(size,grade,MD,and ND) 3.5, L-80,8487 MD,6484 TVD SCANNED AUG 0 1 2013 Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL RETR. PACKER @ 8128 MD and 6246 TVD PACKER-BAKER DB PERMANENT PACKER @ 8487 MD and 6484 ND SSSV-CAMCO TRMAXX-CMT-SR5 SSSV @ 1795 MD and 1774 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 shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development 17 Service r Stratigraphic r 16.Well Status after work: - Oil P Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: - 312-387 Contact Jonathan Coberly (a 265-1013 Email Printed Name J / Title Jonathan.Coberly @conocophillips.com Signature .,. / Phone:265-1013 Date I /gf,//Zl. Form 10-404 Revised 10/2012 RBDMS JAN 0 3 2013 Submit 3 Submit Original Only X41.6: a KUP • 3C-11 ConocoPhillips 0-4 Well Attributes Max Angle&MD TD Alaska Ir1C Wellbore AP W WI Field Name Well Status Inc!(°) MD(ftKB) Act Btm(ftKB) 500292135700 KUPARUK RIVER UNIT PROD 51.40 5,600.00 8,862.0 ""' Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date -' SSSV:TRDP 100 12/13/2011 Last WO: 11/30/2012 34.69 6/25/1985 Well Contiq'. 3C-11,113/2013 9'.39'.29 AM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 8,589.0 8/5/2012 Rev Reason:ADD PERFORATIONS osborl 1/3/2013 HANGER,33 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 80.0 80.0 65.50 H-40 WELDED r Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd SURFACE 95/8 8.921 34.6 4,469.5 3,798.6 36.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WE..String... String Top Thrd PRODUCTION 7 6.276 43.6 8,855.8 6,726.8 26.00 J-55 BTC Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)... String Wt...String... String Top Thrd CONDUCTOR. Upper Completion I Str 31/2 2.922 32.6 8,120.1 I 6,240.4 9.30 L-80 EUE-8rd 36-80 Completion Details Top Depth (ND) Top not Nomi... Top(ftKB) MKS) (1 Item Description Comment ID(in) 32.6 32.6 -0.11 HANGER TUBING HANGER 3.500 SAFETY VLV, C ( 1,794.6 1,773.8 22.14 SAFETY VLV CAMCO TRMA)0(-CMT-SR-5 SAFETY VALVE w/2.813"X-PROFILE 2.922 1,795 all 8,097.4 6,225.6 49.04 LOCATOR BAKER SEAL LOCATOR 2.960 8,097.7 6,225.8 49.03 SEAL ASSY BAKER 80-40 PBR SEAL ASSEMBLY 2.990 Tubing Description String 0... String ID ITop(ftKB) Set Depth(f Set Depth(ND)...String Wt...String String Top Thrd GAS LIFT, Lower Completion 3 1/2 2.922 I 8,104.7 8 487 0 6,483.6 9 30 L-80 EUE-8rd 2,737 Completion Details s c,1'/\ ; ... a NO, Top Depth (ND) Top Intl Noml... I Top(ftKB) (ftKB) P) hem Description Comment ID(in) 8,104.7 6,230.4 48.90 PBR BAKER 80-40 PBR 2.980 SURFACE, 8,127.8 6,245.6 47.82 PACKER BAKER FHL RETRIEVABLE PACKER 2.940 35-4,470' � 8,147.5 6,258.7 48.19 NIPPLE 'HES X NIPPLE w/RHC PLUG INSTALLED 2.812 ® 8,478.91 6,478.2 48.63 OVERSHOT BAKER POORBOY TUBING STUB OVERSHOT w/PACKING 2.980 GAS LIFT. - .. Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd 4,876 Original Tubing I 5.656 I 3.250 I 8,479.1 I 8,522.9 I 6,507.3 Completion Details Top Depth (ND) Top lncl Nomi... GAS LIFT, 4, - Top(ftKB) (ftKB) (1 Item Description Comment ID(In) 6.178 8,487.4 6,483.9 48.95 PACKER BAKER DB PERMANENT PACKER 3250 8,510.9 6,499.4 48.80 NIPPLE CAMCO D NIPPLE NO GO 2.250 8,522.4 6,506.9 48.87 SOS CAMCO SHEAR OUT SUB 2.375 GAS LIFT, Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 7,278 Top Depthl (ND) Top Inc! - Top(ftKB) (ftKB) (1 Description Comment Run Date ID(in) ® 8,147.5 6,258.8 48.19 PLUG RHC PLUG 11/27/2012 0.000 GAS LIFT _-.t:; ,._.. 8,507.0 6,496.8 48.82 CATCHER CATCHER(OAL=54") 10/16/2012 0.000 8.012 ME 8,510.9 6,499.3 48.80 PLUG 2.25"CA-2 PLUG 10/16/2012 0.000 a. Perforations&Slots Shot LOCATOR. Top(ND) Btm(TVD) Dens all 8'097 Top(ftKB)Bier MKS) (ftKB) (ftKB) Zone Date Ws... Type Comment SEAL ASSY. 8,386.0 8,400.0 6,416.9 6,426.2 C-1,UNIT B, 7/19/1985 12.0 IPERF 120 deg ph;5 1/2'Scallop Gun HJ II 0.360---- 30-11 PBR,8,105 ) al 8,440.0 8,448.0 6,452.8 6,458.0 UNIT B,3C-11 11/27/2012 6.0 APERF 33/8"HSC gun,Millenium II HMX PACKER,8.128 charges,60 degree phase 8,457.0 8,465.0 6,463.9 6,469.0 UNIT B,3C-11 11/27/2012 6.0 APERF 33/8"HSC gun,Millenium II HMX charges,60 degree phase NIPPLE,8,747 8,582.0 8,590.0 6,546.3 6,551.6 A-4,3C-11 7/19/1985 4.0 IPERF 90 deg ph;4"Carrier HJ II PLUG,8,148 ll/ i 8,595.0 8,640.0 6554.9 6,584.5 A-3,3C-11 7/19/1985 4.0 IPERF 90 deg ph;4"Carrier HJ II Notes:General&Safeti IPERF, IlL - End Date Annotation 8,388-8,400 __= 7/16/2010 NOTE:View Schematic w/Alaska Schematic9.0(2 pages) 11/27/2012 NOTE:7"CSG PERFORATIONS BELOW C-SAND FOR FUTURE CMT SQZ w/CTD RIG APEOF,8,440-8,448 APERF, 8,457-3485 OVERSHOT, . 8,479 11 TUBING,8,479 tl. 1, PACKER.8,487 _ ..,.. 3ar CATCHER, al i 8,5071 IP NIPPLE,8,511 '-"- Mandrel Details PLUG,8,511 Top Depth Top Port I (TVD) Inc! OD Valve Latch Size TRO Run SOS,8.522 I Stn Top(ftKB) (ftKB) P1 Make Model (in) Sery Type Typo (in) (psi) Run Date Cont... �= 1 2,737.1 2,544.9 47.24 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/28/2012 2 4,676.3 3,942.2 46.66 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/28/2012 IPERF, ■ 3 6,177.9 4,942.2 46.10 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/28/2012 8,582-8,590 4 7,278.3 5,686.9 47.83 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/28/2012 I I 5 8,012.3 6,169.8 49.78 CAMCO MMG 1 1/2 GAS LIFT SOV RKP 0.000 0.0 11/28/2012 IPERF, 0,595-0,040 PRODUCTION, 44-856-\---4 TD,8,18g 3C-11 Pre-Rig Well Work Summary DATE SUMMARY 1,0/14/12,(PRE-RWO)T POT- PASSED, PPPOT- PASSED; IC POT- FAILED; TE VOID WOULD NOT STAY BLED TO OPSI. AFTER 15MIN. IC PPPOT- PASSED; MITOA-PASSED; TIFL- PASSED; FUNCTION TESTED LDS-ALL FUNCTIONAL 10/15/12 BRUSHED AND FLUSHED TRDP @ 1797' RKB. NO FLOWTUBE MOVEMENT. IN PROGRESS. 10/16/12 BRUSHED& FLUSHED TO 8511' RKB. SET 2.25" CA-2 PLUG @ 8511' RKB. SET 2.28" NO-GO CATCHER ON CA-2 PLUG. PULLED GLV's FROM 7182', 5874', &3574' RKB; REPLACED W/ DV's. IN PROGRESS. 10/17/12 PULLED OV FROM 8158' RKB. LOADED TUBING & IA W/320 BBLS DIESEL. SET DV @ 8158' RKB. MITT TO 2500 PSI ( PASS ) . MITIA TO 2500 PSI ( PASS) . GOOD DRAWDOWN TEST TO 0 PSI ON TUBING. PULLED DV FROM 8449' RKB. IN PROGRESS. 10/18/12 MEASURED BHP @ 8449' RKB ( 3201 psi ) . READY FOR E-LINE. 10/18/12 ATTEMPTED TO HOIST BAKER MECHANICAL TUBING CUTTER. JOB SUSPENDED DUE TO BAKER MISSING A TOOL CROSSOVER. WILL RESTART TOMORROW. 10/19/12 ATTEMPTED TUBING CUTS USING BAKER MCT. COULD NOT PASS PRODUCTION MANDREL AT 8449'AFTER CORRELATION PASS. ATTEMPTED TO CLEAR OBSTRUCTION USING LRS PUMP TRUCK, UNABLE TO MAINTAIN HIGH PUMP RATE. JOB SUSPENDED WHILE SLICKLINE TROUBLESHOOTS OBSTRUCTION. 10/20/12 BAILED THROUGH BRIDGES FROM 8421' SLM TO 8466' SLM ( CATCHER 8507' RKB ) DRIFTED TBG WITH 20'x 2.125"TO 8566' SLM. BRUSHED TBG FROM 8400'-8466" SLM. READY FOR E/L 10/22/12 CUT TUBING USING MECHANICAL CUTTER AT 8481', 8337'AND 8173'. CUTTING BLADE BROKE AFTER 2ND CUT, PIECES OF 1/16"THICK STEEL CUTTING BLADE LEFT IN HOLE. I • ConocoPhilli s Time Log & Summary p Wellview Web Reporting Report Well Name: 3C-11 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 11/20/2012 7:00:00 PM Rig Release: Time Logs - Date. From To Dur S. Depth E.Depth Phase Code Subcode T Comment 11/20/2012 24 hr Summary Release rig from 3Q-06 @ 21:00 hours. Rig down and prep to move rig. 21:00 22:30 1.50 MIRU MOVE RURD P Rig move. Blow down water and rig down glycol. 22:30 00:00 1.50 MIRU MOVE RURD P Shut steam in and blow down lines 11/21/2012 Move rig from 3Q-06 to 3C-11. Spot rig over well and rig up.Accepted rig @ 19:00 hours.Take on 9.9 ppg brine in pits and rig up to kill well. 00:00 01:00 1.00 0 0 MIRU MOVE RURD P PJSM, Blow down steam and disconnect interconnect lines. Unplug electrical lines. 01:00 03:00 2.00 0 0 MIRU MOVE MOB P Load rock washer on to trucks and move to 3C pad. 03:00 03:15 0.25 0 0 MIRU MOVE SFTY P Hold PJSM with truck drivers and crew on moving rig. 03:15 04:00 0.75 0 0 MIRU MOVE MOB P Jack up power pack units and mobilize to 3C pad. 04:00 06:00 2.00 0 0 MIRU MOVE MOB P Move power pack unit to 3C pad. 06:00 07:45 1.75 0 0 MIRU MOVE MOB P Prep pipe shed to move and pull sub base of 3Q-06. 07:45 09:00 1.25 0 0 MIRU MOVE MOB P Move sub base and pipe sheds to 3C pad. 09:00 10:30 1.50 0 0 MIRU MOVE MOB P Position rig and crab down pad. 10:30 11:30 1.00 0 0 MIRU MOVE MOB P Spot rig of well 3C-11. 11:30 12:00 0.50 0 0 MIRU MOVE MOB P Lay rig mats for power pack. 12:00 14:00 2.00 0 0 MIRU MOVE MOB P PJSM,spot pits, pumps,motors and boiler complex. 14:00 15:00 1.00 0 0 MIRU MOVE MOB P Spot rock washer and pipe shed. Work on rig acceptance. 15:00 17:15 2.25 0 0 MIRU MOVE RURD P Rig up inner connects,stairs, burms and electrical. 17:15 18:30 1.25 0 0 MIRU MOVE RURD P Turn on waste heat and steam. Install steam traps. 18:30 19:00 0.50 0 0 MIRU MOVE RURD P Finish pumps. Rig accepted @ 19:00 hours 19:00 20:30 1.50 0 0 MIRU WELCTL RURD P Install double valve in annulus. Rig up to kill well. 20:30 21:45 1.25 0 0 MIRU WELCTL RURD P Take on 9.9 ppg brine in to pits. 21:45 22:30 0.75 0 0 MIRU WELCTL OTHR P Clean and clear rig floor. 22:30 00:00 1.50 0 0 MIRU WELCTL RURD P Rig up tiger tank and scaffolding in cellar.Cont.taking on fluid in pits. Page 1 of 9 Time Logs • • Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 11/22/2012 24 hr Summary Unable to circulate. R/U E-Line and shoot holes in tubing @ 8185'MD. Pumps 310 bbls of 9.8+fluid.OWFF, still flowing.Shut well in and monitor pressure.Tubing=260 PSI and IA=300 PSI.Circulate well though choke while viscosifying fluid to hold barite. 00:00 00:30 0.50 0 0 MIRU WHDBO RURD P PJSM, Rig up scaffolding in cellar. 00:30 01:15 0.75 0 0 MIRU WHDBO RURD P Pick up and rig up lubricator. 01:15 01:30 0.25 0 0 MIRU WHDBO PRTS P Test lubricator with diesel t/1500 PSI for 5 min. 01:30 01:45 0.25 0 0 MIRU WHDBO OTHR P Pull BPV as per Cameron rep, observed 300 PSI on tubing when pulled. 01:45 02:15 0.50 0 0 MIRU WHDBO RURD P Rig down lubricator and send down beaver slide. 02:15 02:30 0.25 0 0 MIRU WELCTL RURD P Double check all hoses and valve alignment to tiger tank. 02:30 02:45 0.25 0 0 MIRU WELCTL SFTY P Hold PJSM on killing the well. 02:45 03:00 0.25 0 0 MIRU WELCTL PRTS P Blow air through lines and pressure test to 3000 PSI. 03:00 04:00 1.00 0 0 MIRU WELCTL KLWL T Attempt to circulate down tubing and up the IA. No success, pressured up to 2000 PSI. 04:00 04:30 0.50 0 0 MIRU WELCTL KLWL T Check hoses and valve alignment once again,observed all valves are lined up properly. 04:30 04:45 0.25 0 0 MIRU WELCTL PRTS T Pressure test lines to 5000 PSI. 04:45 05:00 0.25 0 0 MIRU WELCTL KLWL T Attempt to circulate,once again down the tubing and up the IA.The tubing pressred up to 3000 PSI.,no communication between tbg and IA. Bled off pressure to tiger tank. Changed out the gauge on tubing to see if it was reading tbg pressure right.After changing the pressure gauge tubing pressure read 1100 PSI and climbed to 1400 PSI. Establishing the tubing had a bad gauge on it. 05:00 06:00 1.00 0 0 MIRU WELCTL OTHR T Decision made to blow down lines and discuss options. 06:00 08:00 2.00 0 0 MIRU WELCTL OTHR T Decision made to shoot holes in tubing with HES E-line tubing punch. 08:00 10:00 2.00 0 0 MIRU WELCTL RURD T Spot HES E-line truck,gather tools and equipment. 10:00 10:15 0.25 0 0 MIRU WELCTL SFTY T Hold PJSM on rig up HES E-line. 10:15 12:00 1.75 0 0 MIRU WELCTL RURD T Rig up HES E-line as per Halliburton rep. 12:00 12:15 0.25 0 0 MIRU WELCTL PRTS T PJSM,test Halliburton grease head to 250/3000 PSI. Page 2 of 9 • Time Logs • • Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 12:15 13:15 1.00 0 0 MIRU WELCTL ELOG T RIH with tubing punch on E-Line. Tubing pressure=1300 PSI, IA=50 PSI.Shoot holes in 2-7/8"tubing @ 8185'MD,pressure dropped on tubing and increased on IA confirming shots fired. Pressure equalized @ 1200 PSI on tbg/IA. Fired 2 feet of perfs w/4 shoots per ft,8 holes total. 13:15 14:30 1.25 0 0 MIRU WELCTL ELOG T POOH w/E-Line. 14:30 15:30 1.00 0 0 MIRU WELCTL RURD T Close master valve and bleed off 1200 PSI of pressure. Rig down HES E-line. 15:30 15:45 0.25 0 0 MIRU WELCTL SFTY P Hold PJSM on killing well. 15:45 18:30 2.75 0 0 MIRU WELCTL KLWL P Rig up to pump down tubing w/ returns to tiger tank. Kill well pumping 9.8+ppg fluid @ 3 BPM=1400 PSI, FCP=1100 PSI. Pumped a total of 310 bbls of 9.8+ ppg fluid. 18:30 18:45 0.25 0 0 MIRU WELCTL KLWL T Attempt to bull head 15 bbls, pressured up to 3000 PSI,shut down pumps. Pressure slowly bled off but was unable to establish injection rate. 18:45 19:30 0.75 0 0 MIRU WELCTL OWFF T Monitor well,slight flow. Flowed.85 bbl in 30 min. 19:30 20:45 1.25 0 0 MIRU WELCTL CIRC T Decision made to circulate.Circulate surface to surface. Fluid weight 9.8+ in/out. 20:45 21:30 0.75 0 0 MIRU WELCTL OWFF T Monitor well,still flowing slightly. Flowed.85 bbl in 30 min. 21:30 00:00 2.50 0 0 MIRU WELCTL SIPB T Shut well in and record pressures. Pressure stabilized with IA=300 PSI Tubing=260 PSI. 11/23/2012 R/U&Visc brine t/50 FV,weight pit system t/11.1 ppg,Circ.kill wt fluid around well,OWFF static,Set& test BPV U 1500 psi, Nipple down tree, Nipple up adaptor flange& BOP's, R/U&test BOPs. M/U landing joint. 00:00 00:30 0.50 0 0 MIRU WELCTL RURD T R/U t/pump down tubing U take returns through super choke. 00:30 00:45 0.25 0 0 MIRU WELCTL SFTY T Pre Job Safety Meeting on circ. through super choke. 00:45 01:15 0.50 0 0 MIRU WELCTL PRTS T Blow air through choke lines,test lines U 1500 psi,good test. 01:15 04:00 2.75 0 0 MIRU WELCTL CIRC T Super choke closed, pressure up U 500 psi,open well and bring pumps U 84 gpm 750 psi, hold 410 psi w/ choke until fluid coming back reached 50 vis, FCP-750 psi,CSG- 400 psi, Shut in well,blow down lines. 04:00 05:45 1.75 0 0 MIRU WELCTL COND T WT. up pit system f/9.9 ppg U 11.1ppg,change shaker screens. Page 3 of 9 • • Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 05:45 09:45 4.00 0 0 MIRU WELCTL KLWL T Line up&Circ. 11.1 ppg kill wt.mud down tubing taking returns through super choke, FCP-500 psi,shut down pumps blow down lines. 09:45 10:15 0.50 0 0 MIRU WELCTL OWFF P Observe well for flow,well static. 10:15 11:00 0.75 0 0 MIRU WHDBO OTHR P Set BPV test t/1500 psi 11:00 11:15 0.25 0 0 MIRU WHDBO SFTY P Pre Job Safety Meeting on N/D tree 11:15 12:30 1.25 0 0 MIRU WHDBO RURD P R/D scaffolding, N/D tree. 12:30 13:30 1.00 0 0 MIRU WHDBO EQRP P CIO Gland nuts on wellhead 13:30 16:30 3.00 0 0 MIRU WHDBO NUND P Nipple up adaptor flange,stack& riser. 16:30 17:00 0.50 0 0 MIRU WHDBO RURD P R/U t/test BOP's 17:00 22:00 5.00 0 0 MIRU WHDBO BOPE P Test BOPE U 250/4500 PSI w/2-7/8" test joint. Test#1: Upper pipe rams, CV 1,12,13,14&manual kill. Test #2: Upper IBOP, HCR kill,CV 9& 11. Test#3: Lower IBOP,CV 5,8& 10. Test#4: Dart valve, CV 4,6&7. Test#5: Floor valve&CV 2. Test #6:HCR choke&4"kill line Demco. Test#7:Manual choke&HCR kill. Test#8:Annular. Test#9: Blind rams&CV 3. System pressure= 3000 PSI,pressure after closing= 1800 PSI,200 PSI attained=41sec &full pressure attained=199 sec. Nitrogen bottles average=2050 PSI. Witness waved by AGOCC inspector Chuck Scheve. 22:00 22:30 0.50 0 0 MIRU WHDBO RURD P Rig down test equipment, blow down choke and kill lines. 22:30 23:00 0.50 0 0 MIRU WHDBO SEQP P Drain stack and pull test dart/BPV. 23:00 00:00 1.00 COMPZ RPCOM OTHR P Install landing joint and BOLDs. 11/24/2012 Pull Hanger U floor, Break Circ.stage pumps U 168 gpm FCP 1100 psi, Pull 2.875 completion,Clear rig floor R/U&Test BOP's w/3.5"&4"testjt,set wear ring, P/U Fishing BHA&RIH 00:00 00:15 0.25 8,173 8,142 COMPZ RPCOM PUTB P Pull Hanger U rig floor, broke free @ 102K, PUW-74K 00:15 02:15 2.00 8,142 8,142 COMPZ RPCOM CIRC P Break Circ. @ 97 gpm 1500 psi, stage pumps U 168 gpm FCP 1100 psi. 02:15 02:45 0.50 8,142 8,142 COMPZ RPCOM OWFF P Observe well for flow,well static, LJD landing jt. 02:45 12:15 9.50 8,142 0 COMPZ RPCOM PULL P POOH L/D 2.875 tubing, recover 1 SSSV, 11 GLM, 1 cut jt.261 jts. tubing,total length recovered 8111.91' 12:15 14:00 1.75 0 0 COMPZ WELLPF OTHR P Clean&clear rig floor, R/D tubing equipment. 14:00 14:15 0.25 0 0 COMPZ WHDBO SFTY P Pre Job Safety Meeting on testing BOP's Page 4 of 9 Time Log$ Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 14:15 17:30 3.25 0 0 COMPZ WHDBO BOPE P R/U&test BOP's w/3.5"&4"test jt. U 250 low 4500 high,test ann.t/250 low 3500 high on both test jts. R/D blow down lines. 17:30 17:45 0.25 0 0 COMPZ WHDBO RURD P Rig down test equipment. 17:45 18:00 0.25 0 0 COMPZ WELLPF OTHR P Set wear ring 18:00 18:15 0.25 0 0 COMPZ WELLPF SFTY P Pre Job Safety Meeting on P/U BHA 18:15 19:45 1.50 0 320 COMPZ WELLPF PULD P P/U Overshot BHA#1 19:45 00:00 4.25 320 3,590 COMPZ WELLPF PULD P RIH picking up 4"drill pipe w/over shot f/310'MD U 3590'MD.Actual displacement=19.3 bbls, Calculated displacement=21.6 bbls. 11/25/2012 RIH picking up pipe,circ&conditioning mud every 2000'U 8150'tag top of fish rot.@ 10 rpm wash over fish U 8156',work over pull to 43K Jar 3 times,fish free,CBU,OWFF static, POOH, L/D fish 45.37'recovered, C/O BHA comp. RIH U packer.Jar packer free and CBU 00:00 00:30 0.50 3,590 4,097 COMPZ WELLPF TRIP P Continuie singling in the hole f/3590' U 4097' 00:30 01:00 0.50 4,097 4,097 COMPZ WELLPF CIRC P Circ.&condition mud 252 gpm 1100 psi. 01:00 02:30 1.50 4,097 6,017 COMPZ WELLPF TRIP P RIH f/4097'U 6017' 02:30 03:15 0.75 6,017 6,017 COMPZ WELLPF CIRC P Circ.&condition mud 210 gpm 800 psi. 03:15 05:30 2.25 6,017 8,050 COMPZ WELLPF TRIP P RIH f/6017't/8050' 05:30 06:30 1.00 8,050 8,050 COMPZ WELLPF CIRC P Circ.&condition mud 210 gpm 1000 psi 06:30 07:30 1.00 8,050 8,156 COMPZ WELLPF TRIP P RIH U 8123'M/U TD,Wash U 8150' top of fish, ROT @ 10 rpms wash over fish t/8156',straight pull 18K over stage U 40 K Overpull fire jars 3 times fish pulled free. 07:30 08:00 0.50 8,156 8,156 COMPZ WELLPF CIRC P Circ. Bottoms up @ 210 gpm 1000 psi. 08:00 08:15 0.25 8,156 8,156 COMPZ WELLPF OWFF P Observe well for flow,static. 08:15 12:15 4.00 8,156 330 COMPZ WELLPF TRIP P POOH f/8156'U 330' 12:15 14:15 2.00 330 0 COMPZ WELLPF PULD P Stand back&L/D BHA&fish, recover 45.37'of fish. 14:15 14:45 0.50 0 325 COMPZ WELLPF PULD P C/O BHA components, redress graple, RIH U 325' 14:45 21:00 6.25 325 8,155 COMPZ WELLPF TRIP P RIH w/BHA#2 f/325'U 8155'. P/U= 153K, S/0=97K.Actual displacement=49.6 bbls,Calculated displacement=49.9 bbls. 21:00 22:00 1.00 8,155 8,179 COMPZ WELLPF FISH P Pick up 2 joints and set down on fish @ 8179'MD.Set down 15K, pick up 40K overpull and jar 5 times. No success,jar w/50 K overpull 3 times,jarred free on 3rd attempt. Pick up 10'and CBU,observed gas @ BU. 22:00 00:00 2.00 8,179 8,169 COMPZ WELLPF CIRC P Circulate out gas,pump @ 4 BPM=525 psi. Page 5 of 9 Time Logs • • Date From To Dur - S.Depth E.Death Phase Code Subcode T Comment 11/26/2012 24 hr Summary Observe well for flow,static. POOH w/fish t/319'UD BHA&fish, recover packer,glms,blast jt&cut jt. Clear floor nipple down riser, Nipple up shooting flange R/U HES E-line, RIH w/7"perf.guns t/8448'unable to work get down, POOH w/guns, R/D E-line, Nipple down shooting flange nipple up riser. 00:00 00:15 0.25 8,169 8,169 COMPZ WELLPF OWFF P Observe well for flow,well static. 00:15 04:30 4.25 8,169 319 COMPZ WELLPF TRIP P POOH f/8169't/319' 04:30 06:30 2.00 319 0 COMPZ WELLPF PULD P UD&stand back BHA t/cut jt. 06:30 11:15 4.75 0 0 COMPZ WELLPF PULD P R/U&UD Fish, recover packer, glms,blast jts.&cut jt. R/D casing equipment,clean&clear floor, Service break 11:15 12:00 0.75 0 0 COMPZ WELLPF RURD P N/D riser&adaptor flange. 12:00 12:45 0.75 0 0 COMPZ WELLPF OTHR P Set wear bushing 12:45 15:00 2.25 0 0 COMPZ WELLPF NUND P Nipple up shooting flange. 15:00 15:15 0.25 0 0 COMPZ WELLPF SFTY P Pre Job Safety Meeting on R/U E-line 15:15 17:15 2.00 0 0 COMPZ WELLPF RURD P R/U E-line 17:15 21:00 3.75 0 0 COMPZ WELLPF PERF T RIH w/Perf.guns t/8448'set down unable to work through, POOH w/ guns, UD Perf.guns. 21:00 21:30 0.50 0 0 COMPZ WELLPF RURD T R/D E-line 21:30 21:45 0.25 0 0 COMPZ WELLPF SFTY T Pre Job Safety Meeting on nippling down shooting flange&nippling up riser. 21:45 00:00 2.25 0 0 COMPZ WELLPF NUND T Nipple down shooting flange and nipple up riser boot. 11/27/2012 M/U wash pipe RIH U 8300',slip&cut drill line, RIH tag fill @ 8382'Wash t/8468'top of packer,POOH, R/U Eline RIH w/pelf.guns, Perf. 7"casing f/8457'-8565', POOH, RIH w/second perf.guns U 8440'&perf.7" casing f/8440'-8448' 00:00 00:30 0.50 0 0 COMPZ WELLPF PULD T P/U Washpipe BHA U floor 00:30 00:45 0.25 0 0 COMPZ WELLPF TRIP T Single in hole 6 jts.&rack stands back in derrick. 00:45 02:15 1.50 0 370 COMPZ WELLPF PULD T M/U Washpipe BHA U 370' 02:15 04:30 2.25 370 3,000 COMPZ WELLPF TRIP T RIH w/washpipe U 3000' 04:30 05:00 0.50 3,000 3,000 COMPZ WELLPF CIRC T Break circ.CBU, 168 gpm 400 psi, pump 20 bbl slug 05:00 07:30 2.50 3,000 8,300 COMPZ WELLPF TRIP T Cont. RIH f/3000'U 8300' 07:30 09:15 1.75 8,300 8,300 COMPZ WELLPF SLPC T Slip&cut drill line 60'service rig 09:15 09:45 0.50 8,300 8,382 COMPZ WELLPF TRIP T RIH f/8300'U 8382'Tag top of fill. 09:45 10:30 0.75 8,382 8,468 COMPZ WELLPF WASH T Wash down f/8382'U 8468'210 gpm 1100 psi RPM 50,5-10 tq. 10:30 11:30 1.00 8,468 8,468 COMPZ WELLPF CIRC T Circ&condition mud, pump 28 bbl Hi-Vis sweep around, 11:30 12:00 0.50 8,468 8,468 COMPZ WELLPF OWFF T Obtain slow pump rates,Observe well for flow well static. 12:00 12:30 0.50 8,468 8,468 COMPZ WELLPF SVRG T Service Rig 12:30 15:15 2.75 8,468 370 COMPZ WELLPF TRIP T Pooh f/8468'U 370' Page 6 of 9 • • Time Logs Date From To Our S.Depth E.Depth Phase Code Subcode T Comment 15:15 16:30 1.25 370 0 COMPZ WELLPF PULD T UD Washpipe BHA 16:30 17:00 0.50 0 0 COMPZ WELLPF OTHR T Clean&Clear Rig floor. 17:00 19:00 2.00 0 0 COMPZ WELLPF NUND T Nipple down riser&Nipple up shooting flange. 19:00 20:00 1.00 0 0 COMPZ WELLPF RURD T R/U Eline 20:00 22:00 2.00 0 0 COMPZ WELLPF PERF P RIH w/perforating guns t/8471' corelate w/logs position guns& 8457',perforate 7"casing f/8457'U 8465', POOH w/eline Guns fired. 22:00 22:45 0.75 0 0 COMPZ WELLPF PERF P C/O perforating guns f/second run. 22:45 00:00 1.25 0 0 COMPZ WELLPF PERF P RIH w/second perforating gun U 8440 corelate,perforate 7"casing f/ 8440'U 8448', POOH w/e-line. 11/28/2012 POOH and R/D e-line, N/D shooting flange and N/U riser, R/U and run overshot Lower completion,Circ corrosion inhibitor, Engage stub with overshot and test(Good)shear out PBR, POOH,set storm packer and test same, N/D BOP and C/O pack-off,test same. 00:00 01:00 1.00 0 0 COMPZ WELLPF PERF P Pooh w/perforating guns. 01:00 02:00 1.00 0 0 COMPZ WELLPF RURD P R/D Eline Clear floor. 02:00 03:15 1.25 0 0 COMPZ WELLPF NUND P Nipple down shooting flange nipple up riser. 03:15 04:30 1.25 0 0 COMPZ WELLPF RURD P R/U tubing equipment&handling tools. 04:30 06:00 1.50 0 390 COMPZ WELLPF RCST P RIH w/Poorboy Overshot Completion U 390' 06:00 13:00 7.00 390 8,411 COMPZ WELLPF TRIP P RIH w/Poorboy Overshot on DP U 8411' 13:00 13:15 0.25 8,411 8,462 COMPZ WELLPF OTHR P M/U top drive RIH U 8462'Tag up on top of stub. 13:15 14:45 1.50 8,462 8,462 COMPZ WELLPF CIRC P Pump 84 gpm 500 psi,Circ.pipe volume, R/U&circ.45 bbls corrosion inhibitor,spot in IA around Packer. 14:45 15:45 1.00 8,462 8,462 COMPZ WELLPF PACK P S/O and engage overshot on to tubing stub,set 15K, Pressure test tubing U 2500 psi f/15 min,bleed off psi,shut ann.test IA U 3500 psi f/15 min, bleed off and psi up on tubing U shear PBR,shear out w/15K over pull. 15:45 16:00 0.25 8,462 8,462 COMPZ WELLPF OWFF P Observe well for flow static. 16:00 18:15 2.25 8,462 1,600 COMPZ WELLPF TRIP P Pooh w/Seals t/1600' 18:15 19:30 1.25 1,600 1,600 COMPZ WELLPF PULD P M/U storm packer and set @ 100' test U 3500 psi. 19:30 19:45 0.25 1,600 1,600 COMPZ WELLPF SFTY P Pre-Job safety Meeting on Nippling down BOP's 19:45 21:30 1.75 1,600 1,600 COMPZ WELLPF NUND P Blow down lines, Pull wear ring, Nipple down stack and rack back. 21:30 22:45 1.25 1,600 1,600 COMPZ WELLPF NUND P N/D Tubing spool,Casing did not grow,Change out pack-off. 22:45 00:00 1.25 1,600 1,600 COMPZ WELLPF NUND P N/U new tbg spool Page 7 of 9 • Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 11/29/2012 24 hr Summary Test packoff t/3500 psi, Nipple up BOP's&test U 250/4500 psi, retrieve storm packer&L/D, POOH&LID seal assy, R/U&run upper completion U 8104', Located and space out, Install control line to hanger,Circ 580 bbls sea water and spot inhibited sea water around seals, land tbg, RILDS,Test tbg to 3500 for 15 min, Bleed to 2500. 00:00 01:00 1.00 1,600 1,600 COMPZ WELLPF PRTS P Test 7"Casing packoff&void U 3500 psi f/10 min. 01:00 02:30 1.50 1,600 1,600 COMPZ WELLPF NUND P Nipple up Bop's 02:30 03:45 1.25 1,600 1,600 COMPZ WELLPF BOPE P R/U&test breaks on Bop's U 250/4500 psi R/D test equip. 03:45 04:15 0.50 1,600 1,600 COMPZ WELLPFOTHR P Set Wear Ring 04:15 05:30 1.25 1,600 1,600 COMPZ WELLPF PACK P RIH Retreive Storm Packer Pooh, LID Packer. 05:30 06:00 0.50 1,600 0 COMPZ WELLPF TRIP P POOH&UD Seal Assy. 06:00 07:30 1.50 0 0 COMPZ WELLPF OTHR P Pull Wear ring, R/U U run upper completion. 07:30 14:30 7.00 0 6,312 COMPZ WELLPF RCST P Run 3.5 upper completion to 6312" MD. 14:30 16:00 1.50 6,312 6,312 COMPZ WELLPF OTHR P PJSM and R/U control line spooler unit. 16:00 20:30 4.50 6,312 8,104 COMPZ WELLPF RCST P RIH F/6312'T/8104'MD, P/U=91K, S/O=70K, Fully locate and LID 3 joints and P/U 8.10'pup for space out, P/U joint 256 and hanger and R/U landing joint. (Camco ran total of 60 strainless bands on control line) 20:30 21:00 0.50 8,104 8,104 COMPZ WELLPFOTHR P Install control ine to hanger and pressure up to open SCSSV with 5000 psi. 21:00 22:45 1.75 8,104 8,104 COMPZ WELLPFCIRC P PJSM, Displace well with 400 bbls 8.5 ppg sea water chase with 35 bbls inhibited sea water followed with 78 bbls sea water to spot inhibitor around seals. (Pump @ 6 BPM= 1400 psi) 22:45 23:00 0.25 8,104 8,104 COMPZ WELLPF OTHR P Drain stack and land hanger. 23:00 23:15 0.25 8,104 8,104 COMPZ WELLPF OTHR P Run in lock downs on hanger. 23:15 00:00 0.75 8,104 8,104 COMPZ WELLPF OTHR P Pressure test tbg to 3500 psi F/15 min, bleed down to 2500 psi. 11/30/2012 Finish testing tbg and SOV, R/D SLB clear floor,set 2-way check, N/D stack and N/U tree,test same, Pull 2-way check and open SCSSV, Freeze protect well and U-tube,set BPV, LID 4"dp via mouse hole, Prep rig for move. 00:00 01:00 1.00 8,104 8,104 COMPZ WELLPF OTHR P PJSM, Pressure up on IA to 3500 psi &record on chart, Dump TBG and shear out valve,close SCSSV and test to 1000 psi for 5 min,Good, Bleed off. 01:00 02:00 1.00 8,104 8,104 COMPZ WELLPF OTHR P PJSM, Rig down SLB and control line, R/D casing tools and clear rig floor. 02:00 02:30 0.50 8,104 8,104 COMPZ WELLPF OTHR P Suck out stack and set 2-way check valve. 02:30 05:30 3.00 8,104 8,104 COMPZ WELLPF NUND P PJSM, Nipple down BOP's. Page 8 of 9 • Time Logs Date° From To Dur S.Depth E.Depth Phase Code Subcode T Comment 05:30 09:30 4.00 8,104 8,104 COMPZ WELLPF NUND P N/U adapter flange and tree,test same to 250/5000 psi 09:30 09:45 0.25 8,104 8,104 COMPZ WELLPFOTHR P Pull 2-way check valve and open SCSSV. 09:45 10:00 0.25 8,104 8,104 COMPZ WELLPF OTHR P R/D test equipment and R/U circ line in cellar for freeze protection. 10:00 10:30 0.50 8,104 8,104 COMPZ WELLPFOTHR P Spot LRS and hold PJSM. 10:30 11:30 1.00 8,104 8,104 COMPZ WELLPF OTHR P Pressure test lines to 2500 psi, pump 75 bbls of diesel down IA, ICP @ 2 bpm=600 psi, FCP=225 psi. 11:30 12:30 1.00 8,104 8,104 COMPZ WELLPF OTHR P U-Tube well. 12:30 13:45 1.25 8,104 8,104 COMPZ WELLPF OTHR P Blow down and rig down lines,set BPV and secure well 13:45 16:00 2.25 8,104 0 COMPZ WELLPF PULD P PJSM, and L/D drill pipe via mouse hole. 16:00 16:15 0.25 0 0 COMPZ WELLPF OTHR P Crew change out. 16:15 20:15 4.00 0 0 COMPZ WELLPF PULD P Cont. LAD dp 20:15 23:00 2.75 0 0 COMPZ WELLPF OTHR P Prep for Rig Move, Blow do water lines,secure pipe shed. 23:00 00:00 1.00 0 0 COMPZ WELLPF OTHR P Jack pipe sheds and Boiler complex, Release rig. Page 9 of 9 ' • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION W ELL 1a.WeIlStatus: oil El C OR R REPORT I AND LOG 20AAC 25.10 20AAC 25.110 l /� Development Q Exploratory ❑ GINJ El WINJ El WAG El WDSPL El Other II] No. of Completions: ? Service ❑ Stratigraphic Test El 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: January 23, 2013 - 185 - 102 / 312 - 481 • 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 June 17, 1985 / 50 029 - 21357 - 00. 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1177' FNL, 876' FEL, Sec. 14, T12N, R9E, UM June 23, 1985 / 3C - 11 Top of Productive Horizon: 8. KB (ft above MSL): 82' RKB 15. Field /Pool(s): 1408' FNL, 1432' FEL, Sec. 13, T12N, R9E, UM GL (ft above MSL): 47' AMSL Kuparuk River Field • Total Depth: 9. Plug Back Depth (MD + TVD): 1445' FNL, 1028' FEL, Sec. 13, T12N, R9E, UM 8771' MD / 6671' TVD Kupuruk River Oil Pool . 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 528698 y 5995255 Zone 4 8859' MD / 6729' TVD ADL 25634 • TPI: x - 533423 y - 5995044 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 533827 y 5995009 Zone 4 1795' MD / 1774' TVD . 2567 18. Directional Survey: Yes ❑ No Q 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1715' MD / 1700' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re - drill /Lateral Top Window MD/TVD none not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 36' 116' 36' 116' 24" 215 sx CS II 9.625" 36# J -55 35' 4470' 35' 3799' 12.25" 1360 sx AS III, 320 sx Class G 7" 26# J -55 44' 8859' 44' 6729' 8.5" 325 sx Class G 24. Open to production or injection? Yes ❑ No ISI If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5" 8487' 8128' MD / 6246' TVD and 8487' MD / 6484' TVD p■�y perfs squeezed off 1 ®E D Was hydraulic fracturing used dung completion? SQUEEZE, ETC. Yes ❑ No El FEB 2 6 2012 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED �y�°o li cement squeeze 8355-8470' 3 bbls AO C ' 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) suspended Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No El Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE SCANNED J'UL 0 8 2013 RBDMS FEB 2 6 2013 e Form 10-407 Revised 10/2012 CONTINUED ON REVERSE 7.5• /3 SSubmit original only ?/43 74.6/G •4‘ 74 G, 29. GEOLOGIC Iv1ARKERS (List all formations and ilk encountered): 30. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1715' 1700' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: not applicable 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. / Lc Contact: Kai Starck @ 263 -4093 Email: Kai.Starck(cilconocophillips.com Printed Name Lamar Ga tt Title: CTD Supervisor �ttG11�. n Z Signature �QFa � � `� (;`�,t, Date /z 5 / /3 Phone 263 -4021 / 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 10/2012 ' , KUP • 3C -11 COIIOCOPhitlips ii - Well Attributes Max Angle & MD TD Alaska. Inc. Wellbore API /MI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) CoroCORatkps 500292135700 KUPARUK RIVER UNIT PROD 51.40 5,600.00 8,862.0 " Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: TRDP 100 12/13/2011 Last WO: 11/30/2012 34.69 6 /25/1985 Well Confer - 3C -11, 122/2013 8:41:48 AM - Schemata, Weal Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 8,480.0 12/16/2012 Rev Reason: ADD PERFS /CMT PERFS osborl 1/8/2013 HANGER. 33 -'- 11•11t �" Casing Strings ' „ Casing Description String 0... String ID ... Top (ftKB) Set Depth (L,. Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 36.0 80.0 80.0 65.50 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd SURFACE 95/8 8.921 34.6 4,469.5 3,798.6 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String WL.. String ... String Top Thrd PRODUCTION 7 6.276 43.6 8,855.8 6,726.8 26.00 J -55 BTC ii Tubing Strings CONDUCTOR, Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String.., String Top Thrd 36 Upper Completion 31/2 I 2.922 J 32.6 8,120.1 6,240.4 9.30 L -80 EUE -8rd 111 1 Completion Details AL Top Depth (TVD) Top Inc! Nomi... MI Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) SAFETY VLV, I 32.6 32.6 - 0.11 HANGER TUBING HANGER 3.500 7,795 l NIP 1,794.6 1,773.8 22.14 SAFETY VLV CAMCO TRMAXX- CMT -SR -S SAFETY VALVE w/ 2.813" X- PROFILE 2.922 I. 8,097.4 6,225.6 49.04 LOCATOR BAKER SEAL LOCATOR 2.960 ::. 8,097.7 6,225.8 49.03 SEAL ASSY BAKER 80-40 PBR SEAL ASSEMBLY 2.990 GAS LIFT, 2,737 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd It Lower Completion 31/2 2.922 8,104.7 8,487.0 6.483.6 9.30 L -80 EUE -8rd 1 Completion Details 1 1 Top Depth t (TVD) Top Inc' Noml... Top (ftKB) (580) ( °) Item Description Comment ID (in) SURFACE, _ 4 L 8,104.7 6,230.4 48.90 PBR BAKER 80 PBR 2.980 35 - 4.470 - 7 8,127.8 6,245.6 47.82 PACKER BAKER FHL RETRIEVABLE PACKER 2.940 GAS LIFT, 8,147.5 6,258.7 48.19 NIPPLE HES X NIPPLE 2.812 4,676 8,478.9 6,478.2 48.63 OVERSHOT BAKER POORBOY TUBING STUB OVERSHOT w/ PACKING 2.980 Tubing Description 'String 0... 'String ID ...'Top (ftKB) 'Set Depth (f... 'Set Depth (TVD) ...'String Wt..'String ... 'String Top Thrd Original Tubing 5.656 3.250 8,479.1 8,522.9 6,507.3 GAS LIFT. r Completion Details 6.178 E' Top Depth (TVD) Top Inc' Noml... - Top (ftKB) (ftKB) ( °) Item Description Comment ID (!n) 8,487.4 6,483.9 48.95 PACKER BAKER DB PERMANENT PACKER (WV set Tubing string OD /ID from 3.250 GAS UFT Packer, since there are no full tubing joints) 7276 8,510.9 6,499.4 48.80 NIPPLE CAMCO D NIPPLE NO GO 2.250 8,522.4 6,506.9 48.87 SOS CAMCO SHEAR OUT SUB 2.375 GAS LIFT Other In Hole retrievable plugs, valves, pumps, fish, etc.) 8,012 (TVD) Top Inc! Top (ftKB) (ftKB) ( °) Description Comment Run Date ID ('n) 8,147.5 6,258.8 48.19 PLUG RHC PLUG 11/27/2012 0.000 LOCATOR, 8,507.0 6,496.8 48.82 CATCHER CATCHER (OAL =54 ") 10/16/2012 0.000 8,097 8,510.9 6,499.3 48.80 PLUG 2.25" CA - 2 PLUG 10/16/2012 0.000 SEAL ASSY, 8,098 P00 8,105 ( Perforations & Slots Shot PACKER, 8,128 Top (ND) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (81(B) Zone Date Oh- Type Comment 8,364.0 8,368.0 6,402.4 6,405.0 C-3, 3C -11 12/30/2012 6.0 CMT Behind CMT, Pre -CTD 2.5" HSC NIPPLE, 8,147 SQZ Millenium HMX, 60 deg phase PLUG, 8,148 8,386.0 8,400.0 6,416.9 6,426.2 C -1, UNIT B, 7/19/1985 12.0 IPERF 120 deg ph; 5 1/2' Scallop Gun HJ II :: 3C-11 i 15 8,440.0 8,448.0 6,452.8 6,458.0 UNIT B, 3C -11 11/27/2012 6.0 CMT Behind CMT, Pre -CTD- 33/8" HSC C SQZ gun, Millenium II HMX charges, 60 CMT SOZ, degree phase 8,384 ift I 8,457.0 8,465.0 6,463,9 6,469.0 UNIT B, 3C -11 11/27/2012 6.0 CMT Behind CMT, Pre -CTD - 3 3/8" HSC t. IPERF, 8,3868,400 z, SQZ gun, Millenium II HMX charges, 60 degree phase as 8,460.0 8,464.0 6,465.8 6,468.4 UNIT B, 3C -11 12/29/2012 6.0 CMT Behind CMT, Pre -CTD 2.5" HSC CMT SaZ, _ SQZ Millenium HMX, 60 deg phase 8,440.8,448 __._ 8,582.0 8,590.0 6,546.3 6,551.6 A-4, 3C -11 7/19/1985 4.0 IPERF 90 deg ph; 4" Carrier HJ II CMT SOZ, 8,457.8,465 N - 8,595.0 8,640.0 6,554.9 6,584.5 A 3C 7/19/1985 4.0 IPERF 90 deg ph; 4" Carrier HJ II CMT SOZ, . 8,460 -8.464 Notes: General & Safety End Date Annotation i i - 7/16/2010 NOTE: View Schematic w/ Alaska Schematic9.0 (2 pages) CMT 8 ,355 16 ° 1/8/2012 NOTE: 7" CSG PERFORATIONS BELOW C -SAND FOR FUTURE CMT SQZ w /CTD RIG OVERSHOT, 8,479 TUBING, 8,479 ISNImms 11r PACKER, 8,487 ` *t^` ME CATCHER. IP Mandrel Details 8,51 t1 Top Depth Top Port NIPPLE, 8,511 - PLUG, 8,517 5... (ND) Inc! OD Valve Latch Size TRO Run - N... Top(ftKB) (ftKB) (1 Make Model (in) Sery Type Type (!n) (psi) Run Date Com... 1 2,737.1 2,544.9 4724 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/28/2012 SOS, 8,522 2 4,676.3 3,942.2 46.66 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/28/2012 3 6,177.9 4,942.2 46.10 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/28/2012 IPERF, ® ■ 4 7,278.3 5,686.9'47.83 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/28/2012 8,582 - 8,590 5 8,012.3 6,169.8 49.78 CAMCO MMG 1 1/2 GAS LIFT OPEN 0.000 0.0 12/14/2012 IPERF, 8.5958,640 11 Ill PRODUCTION, 448,856 TD(3C -11), + an 8,862 3C -11 Pre -Rig Well Work DATE SUMMARY • • 12/11/2012 (PRE -CTD) RIG WORK, BPV IN PROFILE, MV, SSV, SV PASSED PT, SSV, SV PASSED DDT. 12/13/2012 ASSIST VALVE CREW PULL BPV. DRIFT TO RHC PLUG W/ PULLING TOOL AND CONFIRM NO BALL & ROD IN PLUG. IN PROGRESS. 12/14/2012 TAG RHC PLUG BODY WITH LIB; PULL SOV FROM @ 8012' RKB. PERFORM NO FLOW CLOSURE TEST ON TRSSSV . ( GOOD TEST ). LAY DOWN EQUIPMENT DUE TO COLD WEATHER. IN PROGRESS. MIT-IA 2500 PASS PULLED RHCM BODY 8147' 7 RKB; TAG FILL 12/16/2012 SET DV @ 8012' RKB; MI ( ) @ @ 8480' RKB ( EST 27' FILL ON CATCHER ). JOB COMPLETE 12/29/2012 PERFORATE INTERVAL 8460' -8464' USING 2.5" HSC LOADED 6 SPF, PHASED 60 DEG. LOG CORRELATED TO SLB CET LOG DATED 29 JUN 1985. TUBING DETAIL RECORD APPEARS TO BE 13' SHALLOW IN RELATION TO THE CET LOG. JOB IN PROGRESS. 12/30/2012 PERFORATE INTERVAL 8364' -8368' USING 2.5" HSC LOADED 6 SPF, PHASED 60 DEG, MILLENIUM HMX CHARGES. NO PRESSURE CHANGE AFTER PERFORATING. LOG CORRELATED TO SLB CET LOG DATED 29 JUN 1985. LOG BOTTOM HOLE PRESSURE SURVEY. 8450' - 3731 PSI, 154.4 F, 8299' - 3647.62 PSI, 152.9 F. WAITED ON BOTTOM FOR WELL TO STABILIZE AND APPEARS TO STILL BE EQUALIZING DURING LOG PASSES. READY FOR LRS. 12/31/2012 (PRE -CTD) MV DDT PASSED, SSV DDT PASSED, SV DDT PASSED. LRS INJECTIVITY TEST RESULTS: 2850 PSI AT 0.5 BPM, 3000 PSI AT 0.7 BPM. PUMPED TOTAL 43 BBLS DIESEL DOWN TUBING. 1/6/2013 STANDBY TILL 12:00 WAITING ON WEATHER. MOBILIZE CTU TO LOCATION AND STAGE EQUIPMENT. WAITING ON ASRC TO RIG UP HARDLINE TO SUPPORT THE OPERATION. 1/7/2013 PERFOMED SQUEEZE USING 15.8 PPG CEMENT. SQUEEZED APPROXIMATEL - _ - —1 1 PIPE. ACHIEVED SQUEEZE PRESSURE OF 1800 PSI. WASHED DOWN TO TOP OF CEMENT AT 8355'. TRAPPED 1300 PSI ON SURFACE. WELL FREEZE PROTECTED JOB IN PROGRESS. 1/8/2013 PERFORMED BOPE TEST. MILLED CEMENT FROM TAG AT 8360' CORRECTED DEPTH TO 8470' USING 2.68" - 2.98" BICENTER BIT. SAW GOOD MOTOR WORK THROUGHOUT JOB. MAINTAINED 1:1 RETURNS THROUGHOUT JOB. WELL FREEZE PROTECTED TO 2000' ND. JOB COMPLETE. 1/10/2013 TAG TOC @ 8478' RKB. DRIFT TBG BAKER DUMMY WHIPSTOCK TO TOC @ 8478' RKB; MITT AGAINST CEMENT PLUG TO 2000 PSI ( PASSED) READY FOR BPV AND CTD. • S Conoc ©Phillips Time Log & Summary Wel(view Web Reporting Report Well Name: 3C -11 Rig Name: NABORS CDR2 -AC Job Type: DRILLING SIDETRACK Rig Accept: 1/21/2013 10:30:00 PM Rig Release: 2/5/2013 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/21 /2013 24 hr Summary Arrive 3C pad 4:15am. Spot rig, Rig up and safe out rig for operations. Start BOPE testing. State Witness Waived By Chuck Sheve 00:00 07:00 7.00 MIRU MOVE MOB P Moving rig from 3Q -06 to 3C -11 07:00 11:00 4.00 MIRU MOVE MOB P Spot rig modules on 3C -11, spot shop, 11:00 17:00 6.00 MIRU MOVE MOB P RU Putz, berm up around cellar. RU interconnect, steam, landings, load pits. 17:00 22:30 5.50 MIRU WHDBO NUND P NU BOPE equipment, hammer up all flanges, found several loose flanges. 22:30 00:00 1.50 MIRU WHDBO BOPE P Start full BOPE test 250/4000 annular 2500 psi. Test witness waived by Chuck Shieve, AOGCC. Rig Accept 22:30 01/22/2013 Finished BOP test, C -9 and C -10 failed. Unfreeze TT line. PT PDL's and TT line. 00:00 08:30 8.50 0 0 MIRU WHDBO BOPE P Cont. testing BOP's. 08:30 09:00 0.50 0 0 MIRU WHDBO BOPE P BOP test complete. 2 failures. C9, C10, Choke manifold. Valves replaced. Passed retest 09:00 15:30 6.50 0 0 MIRU WHDBO CTOP P RD /LD BOP test joint, blow down test pump. Cut CTC off, MU to well, fill CT, reverse circ. for slackmanagement. Cut 6' CT to find E -line. Cut a total of 20' for clean pipe. MU CTC, pull test 35k. Tiger tank line froze up, Thaw out. MU drilling head, psi test 4K. 15:30 16:30 1.00 0 0 MIRU WHDBO BOPE P Pull BPV. 16:30 17:30 1.00 0 0 MIRU WHDBO CTOP P MU nozzle, stab onto well and pump slack forward, Cont. to thaw tiger tank line. 17:30 18:00 0.50 0 0 MIRU WHDBO CTOP P Crew change, PJSM 18:00 20:30 2.50 0 0 MIRU WHDBO CTOP T Call Dispatch to swap TT out. Continue working on thawing tiger tank line. 20:30 21:00 0.50 0 0 MIRU WHDBO CTOP P Cancel TT swap through dispatch. TT line free of ice. Round up crew for PJSM on plan forward. 21:00 00:00 3.00 0 0 MIRU WHDBO CTOP P Unstab INJH, Test TT line and PDL's. 01/23/2013 Trip in hole and set TOWS at 8442ft. POOH, M /U, and RIH with first milling BHA. Mill 6ft of dual string exit. Page 1 of 15 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 0 0 PROD1 RPEQPI PULD P Rig back PDL's. Bleed 140 well head pressure off to tiger tank. install fuseable cab onto SSV. Stab INJH, Test BHI tools 01:30 05:00 3.50 72 8,000 PROD1 RPEQP1TRIP P RIH w WS setting BHA# 1 05:00 06:00 1.00 8,000 8,452 PROD1 RPEQP1DLOG P Tie in depth +1' correction, Perform CCL 8000' -8460' 06:00 06:30 0.50 8,452 8,452 PROD1 RPEQPI WPST P WS on depth, 8442' TOWS, 8452.29 MD. Close EDC, Set whipstock highside, 3700psi CTP, 4k wob. set down 2k wob. PU, WS set. 06:30 08:45 2.25 8,452 0 PROD1 RPEQP1 TRIP P POOH displacing SW out of hole with 9.6ppg Flo -Pro 08:45 09:00 0.25 0 0 PROD1 RPEQP1SFTY P At surface, PJSM, flow check 09:00 09:30 0.50 0 0 PROD1 RPEQP1 PULD P LD BHA 09:30 10:15 0.75 0 0 PROD1 WHPST PULD P PU milling BHA (.6 ako, 2.8 whipstock mill, w /string reamer) k 10:15 12:15 2.00 73 8,050 PROD1 WHPST TRIP P RIH ()C. \ 12:15 12:30 0.25 8,050 8,050 PROD1 WHPST DLOG P Tie in depth to K1. +2.5' correction 12:30 12:45 0.25 8,442 8,442 PROD1 WHPST TRIP P RIH, dry tap TOWS 8442.6'. PU 35K. Online with pumps 1.37 bpm, 3866 ctp off bottom, 19k ctw 12:45 14:45 2.00 8,442 8,444 PROD1 WHPST MILL P Start Time milling 8442.2' @ 1 fph. 1.37 bpm, 3925psi ctp, on bottom, 1.5k wob. 14:45 20:45 6.00 8,444 8,446 PROD1 WHPST MILL P Stall. Clean PU. RBIH cont milling, slow down ROP .6 - .8 fph, Weight transfer looking good, with good trend of milling off. 1.4 bpm, 3811 ctp, 3831 bhp, 2k wob 20:45 22:45 2.00 8,446 8,448 PROD1 WHPST MILL P OB milling 8446.28ft. milling 1 fph. 2.2k WOB. 8448.2ft TD first WS milling run with BOT. 22:45 23:30 0.75 8,448 8,440 PROD1 WHPST MILL P Performed 3 reaming passes at 1fph. Looks clean. 23:30 00:00 0.50 8,440 7,022 PROD1 WHPST TRIP P POOH 01/24/2013 Finish milling dual string window exit. POOH and Undeploy milling BHA# 3 00:00 02:00 2.00 7,022 0 PROD1 WHPST TRIP P Continue POOH with EDC open 02:00 02:15 0.25 0 0 PROD1 WHPST SFTY P PJSM- for L/D BHI tools. Check well for flow. No flow unstab INJH. 02:15 03:45 1.50 0 0 PROD1 WHPST PULD P L/D BHI tools, gauged mills both 2.79OD no -go. M/U weatherford motor to BHI tools, stab INJH onto stump and test tools. 03:45 06:00 2.25 0 8,050 PROD1 WHPST TRIP P RIH w /second milling BHA with fixed 2° bend motor and fat radius mill. 06:00 06:15 0.25 8,050 8,050 PROD1 WHPST DLOG P Tie in depth +3' correction 06:15 06:45 0.50 8,050 8,450 PROD1 WHPST DLOG P RIH dry tag 8450'. PU online with pumps. 1.4 bpm, 3819 ctp off bottom. Page 2 of 15 �PV of THE STATE Alaska Oil and Gas ��rr ° L Conservation Commissi on O w 4 GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 4 Main: 907.279.1433 SCANNED JAN 16 2013, Fax: 907.276.7542 Kai Starck 0 CTD Engineer �.� ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3C -11 Sundry Number: 312 -481 Dear Mr. Starck: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this "2° day of December, 2012. Encl. ' STATE OF ALASKA • A.. OIL AND GAS CONSERVATION COMNSION ,` I IEC 14 2.W... t �°; • 20 AAC 25.280 \v AOGC 1. Type of Request: Abandon r Rug for Redrill I. • Perforate New Pool r Repair well r Change Approved Program r Suspend r Rug Perforations P • Perforate r Pull Tubing r Time Extension E Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 • Exploratory E 185 -102 • 3. Address: Stratigraphic r Service' 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 50- 029 - 21357 -00' 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require spacing exception? Yes r No Pr 3C -11 - 9. Property Designation (Lease Number): 10. Field /Pool(s): . ADL 25634 . Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8862 • • 6731 8771' 6671' 8147', 8511' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 44 16 80' 80' SURFACE 4435 9.625 4470' 3800' PRODUCTION 8812 7 8856' 6728' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8386 -8400, 8582 -8590, 8595 -8640 6417 -6426, 6546 -6552, 6555 -6585 3.5 L -80 8487 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER FHL RETRIEVABLE PACKER MD =•8128 TVD= 6246 PACKER - BAKER DB PERMANENT PACKER MD =•8487 TVD= 6484 SSSV - CAMCO TRDP 1A -SSA SSSV MD =1795 TVD =1777 12. Attachments: Description Summary of Proposal p 13. Well Class after proposed work: Detailed Operations Program BOP Sketch j" Exploratory r Stratigraphic r Development • Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12/24/2012 011 r Gas r WDSPL r Suspended - 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR fl SPLUG r 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kai Starck @ 263 -4093 Email: Kai.Starck(5 conocoohiIIips.com Printed Name Ka. rck Title: CTD Engineer Signature C. N, Phone: 263 -4093 Date /2-15 - 2-0 ( 2_ Commission Use Only Sundry Number: 3 Z46 ( Conditions of approval: Notify Commission so that a representative may witness lJ Plug Integrity r BOP Test ]VMechanical Integrity Test r Location Clearance r RRr S DEC 2 1 2012 ,>; 3 500 pS.: /SDP Ts _ .rrz') No, Other: - t e i— A l4. GrA4 . ID f, p /4crne.t.4 -- 4 pf roucfs r e, z o 44c- S Z Spacing Exception Required? Yes ❑ No i Subsequent Form Required: / 0 — y o, APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Date: ` /Z� L N Appro -a application is valla for 11 montns trom the Gate or approval. v 0 o -4 3 (Revised 10/2012) Submit Form and Attachments in Duplicate �tJ cv • • KRU 3C -11 CTD Summary for Plugging Sundry (10 -403) Summary of Operations: Well KRU 3C -11 was originally completed in June 1985 as a single selective A and C sand producer that produces via gas lift. It has been on production since 1985 until the recent rig workover in preparation for the CTD sidetrack. The workover resulted in pulling the completion above the lower packer and replacing the tubing and the upper packer. During the workover additional perforations were shot at 8440' to 8465' in the Kuparuk B to ensure good cement behind the 7" casing at the planned window. The B and C -sand perforations will be squeezed off and the 3 %" X 7" annulus between the packers will be cemented before the CTD sidetracks. There is a tubing tail plug that isolates the original A -sand perforations which will have a cement plug above it. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A -sand perfs in this manner. There is insufficient room to meet these plugging requirements while still accommodating a sidetrack from 8455' MD. A mechanical whipstock will be placed in the 3'/2" tubing at the planned kickoff point. The 3C -11A sidetrack will exit the 3 %" tubing and the 7r casing at 8455' MD and target the A3 sand to the north of the existing well with a 2745' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,200' MD with an aluminum billet at 8770' MD. The 3C -11AL1 lateral will kick off from the aluminum billet at 8770' MD and will target the A3 sand south of the existing well. The hole will be completed with a 2%" slotted liner to the TD of 10,800' MD with a liner top deployment sleeve at 8445' MD. Fraror<e,P t„ Wi/ co,-•r•� /f(t/ /ti - C COX/- rnc/.:y ,.lam ex ati On OW aoda ,'eCa -4 CTD Drill and Complete 3C -11 Laterals: January 2013 Or f (e)4/0/4 rr y lP erl/e G t The wrlfri j-- Pre -CTD Work 0 qhc) n ?/ 1. MIRU slickline. Dummy all GLMs. Pull RHC plug. 2. MIRU e-line. Perforate 3 -1/2" tubing at 8473 -8477' and 8364'- 8368'. 3. Perform injectivity test into open C -sand perfs. 4. MIRU coiled tubing. Cement squeeze the open C -sand perforations and lay in cement in the 3 -1/2" X 7' annulus, leaving a cement plug in the 3 -1/2" tubing. p_7- PL � 2�� r sz, 5. Coiled tubing. Mill cement from — 8355' to 8481' with a bi- center bit. This`(vill leave a cement plug on top of the CA -2 plug set in the 2.25" nipple at 8511', plugging off the A -sand perforations. 312; `(8t 6. MIRU slickline. Run whipstock dummy inside 3'/2' liner. 7. Prep site for Nabors CDR2 -AC, including setting BPV Rii� Work 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7- 1/16" BOPE, test. A 2. 3C -11A Sidetrack (A3 sand, North) a. Set whipstock at 8455' MD with high -side orientation b. Mill 2.80" window through 3'/2' Tubing and 7" casing at 8455' MD c. Drill 2.70" x 3" bi- center lateral to TD of 11,200' MD d. Run 2%" slotted liner with an aluminum billet from TD up to 8770', using the SSSV as a barrier to Y formation pressure if available 3. 3C -11AL1 Lateral (A3 sand, south) a. Kick off of the aluminum billet at 8770' MD Page 1 12/13/2012 • • b. Drill 2.70" x 3" bi- center lateral to TD of 10,800' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 8445' MD inside the 3W tubing, using the SSSV as a barrier to formation pressure if available. 4. Freeze protect. Set BPV, ND BOPE. 5. RDMO Nabors CRD2 -AC. Post -Rig Work 1. Pull BPV 2. Obtain static BHP, Install gas lift valves 3. Put well on production Page 2 12/13/2012 KUP • 3C -11 • Conoct�Phi $� Well Attributes Max Angle & MD, TD • AtaSka Inc ��i Wellbore API /UWI Field Name Well Status Inc' (1 MD (ftKB) Act Btm (ftKB) COnocoftalNp, 500292135700 KUPARUK RIVER UNIT PROD 51.40 5,600.00 8,862.0 • Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "• SSSV: TRDP 100 12/13/2011 Last WO: 11/30/2012 34.69 6 /25/1985 Well Confin - 30-11, 1 2/11201 2 12 '.15'57 PM schematic - actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 8,589.0 8/5/2012 Rev Reason. WORKOVER ninam 12/1/2012 HANGER, 33 ".". 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 80.0 80.0 65.50 H - 40 WELDED Casing Description String 0... String ID ,.. Top (RKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd I EI 1 SURFACE 95/8 8.921 34.6 4,469.5 3,798.6 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 43.6 8,855.8 6,726.8 26.00 J -55 BTC Tubing Strings Tubing Description Strng 0... String ID ... Top (5KB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd Upper Completion I 3 1/2 I 2.922 I 32.6 I 8,120.1 6,240.4 I 9.30 I L-80 EUE -8rd coNDUC36 -05 Completion Details Top Depth (ND) Top Inc' Nomi... la Top (RKB) (RKB) (°) Rem Description Comment ID (in) 32.6 32.6 -0.11 HANGER TUBING HANGER 3.500 1,794.6 1,773.8 22.14 SAFETY VLV CAMCO TRMAXX- CMT -SR -5 SAFETY VALVE w/ 2.813" X- PROFILE 2.922 ♦ SAFETY 1, 7 5 { 0 8,097.4 6,225.6 49.04 LOCATOR BAKER SEAL LOCATOR 2.960 8,097.7 6,225.8 49.03 SEAL ASSY BAKER 80-40 PBR SEAL ASSEMBLY 2.990 Tubing Description String 0... String ID ... Top (RKB) Set Depth (L.. Set Depth (ND) ... ng Wt... String ... String Top Thrd Lower Completion 'String I 2922 I 8,104.7 I 8,487.0 I 6,483.6 'String I L - 80 I EUE - 8rd GAS LIFT, Completion Details E:, 2,737 Top Depth (ND) Top Incl Nomi... ((( Top (RKB) (RKB) (1 Kern Description Comment ID (in) (I jj 8,104.7 6,230.4 48.90 PBR BAKER 80-40 PBR 2.980 IJ U 8,127.8 6,245.6 47.82 PACKER BAKER FHL RETRIEVABLE PACKER 2.940 J l 8,147.5 6,258.7 48.19 NIPPLE HES X NIPPLE w/ RHC PLUG INSTALLED 2.812 SURFACE, 8,478.9 6,478.2 48.63 OVERSHOT BAKER POORBOY TUBING STUB OVERSHOT w/ PACKING 2.980 35 4,470 t Tubing Description String 0... ing ID ...Top (RKB) Set Depth (I... Set Depth (TVD) ... String Wt... String ... String Top Thrd ( Original Tubing I 5.656 I Str 3.250 I 8,479.1 I 8,522.9 I 6,507.3 GAS LIFT, .. 4,878 Completion Details IF Top Depth (ND) Top Incl Nomi... i Top (51(8) (ftKB) (°) Item Description Comment ID ('n) 8,487.4 6,483.9 48.95 PACKER BAKER DB PERMANENT PACKER 3.250 GAS LIFT, ti 8,178 8,510.9 6,499.4 48.80 NIPPLE CAMCO D NIPPLE NO GO 2.250 8,522.4 6,506.9 48.87 SOS CAMCO SHEAR OUT SUB 2.375 t Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (ND) Top Inc! GAS LIFT. 8 Top (RKB) (ftKB) ( °) Description Comment Run Date ID (in) li 7,27 8,147 6,258.8 48.19 PLUG RHC PLUG 11/27/2012 0.000 at 8,507 6,496.8 48.82 CATCHER CATCHER (OAL =54') 10/16/2012 0.000 8,511 6,499.3 48.80 PLUG 2.25" CA -2 PLUG 10/16/2012 0.000 GAS LIFT, s r - 8,012 i � Perforations & Slots ,.. . Shot Top (ND) Btm (TVD) Dens Top (ftKB) Btm (RKB) (ftKB) (RKB) Zone Date Oh- Type Comment 8,386 8,400 6,416.9 6,426.2 C UNIT B, 7/19/1985 12.0 IPERF 120 deg ph; 5 1/2" Scallop Gun HJ II LOCATOR, i- 8,097 ( 3C -11 f 8,582 8,590 6,546.3 6,551.6 A-4, 3C-11 7/19/1985 4.0 IPERF 90 deg ph; 4" Carrier HJ II SEAL ASSY, 8,098 8,595 8,640 6,554.9 6,584.5 A - 3, 3C - 11 7/19/1985 4.0 IPERF 90 deg ph; 4" Carrier HJ II PBR, 8,105 )�' Notes: General & Safety PACKER, 8,128 64g06 End Date Annotation 7/16/2010 NOTE: View Schematic w/ Alaska Schematic9.0 (2 pages) III NIPPLE, 8,147 ill PLUG, 8,148 IPERF, 8,388 -8,400 IM OVERSHOT, 8.479 " TUBING. 8,479 m , PACKER, 8,487 CATCHER, 8,507 NIPPLE, 8,511 PLUG, 8,511 Mandrel Details Top Depth Top Port (ND) Inc! OD Valve Latch Size TRO Run SOS, 8,522 Stn Top (ftKB) (ftKB) P) Make Model (in) Sery Type Type (in) (psi) Run Date Corn... 1 2,737.1 2,544.9 47.24 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/28/2012 2 4,676.3 3,942.2 46.66 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/28/2012 IPERF, 3 6,177.9 4,942.2 46.10 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/28/2012 8582 - 8.590 4 7,278.3 5,686.9 47.83 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/28/2012 II 5 8,012.3 6,169.8 49.78 CAMCO MMG 1 1/2 GAS LIFT SOV RKP 0.000 0.0 11/28/2012 IPERF, 8595-8.040 PRODUCTION, 44-8,858 TD, 8,882 3C -11 RWO for CTD (Blue - new) 3 -1/2" Schlumberger TRMAXX- CMT -5 -SR @ 1794' TVD 3 -1/2" 9.3# L -80 EUE 8rd Tubing to surface 3 -1/2" Camco gas lift mandrels 16" 65# H -40 shoe @ 80' RKB 9 -5/8" 36# J -55 shoe @ • 4469' RKB Baker 3 -1/2" PBR (3" ID) ' Baker FHL packer © 8128' RKB (4.0" ID) C -sand perfs 8386' - 3 -1/2" Camco DS landing nipple @ 8148' (2.812" min ID) 8400' MD - . perfs during ws. �/� RWO: —�— _ ' Poor -Boy overshot over cut 2 -7/8" @ 8481' RKB (5' above Baker locator) 8440' - 8448' MD 1 • 8457' - 8465' MD Existing 2 -7/8" Baker DB packer @ 8487' RKB 2-7/8" Camco D landing nipple @ 8511' RKB (2.25" min ID, No -Go) • w ith eq ualizing plug and sand I ' 111, .''I 2 7/8" tubing tail @ 8522' RKB MIL A -sand perfs 8582' - 8590' RKB 8595' - 8640' RKB 7" 26# J -55 shoe @ 8855' RKB 3C -11 Proposed CTD Schematic (Post -RWO) 3 -1/2" Schlumberger TRMAXX- CMT -5 -SR @ 1794' TVD 3 -1/2" 9.3# L -80 EUE 8rd Tubing to surface 3 -1/2" Camco gas lift mandrels @ 2737, 4676, 6178, 7278, 8012 16" 65# H -40 shoe — @80'RKB Baker 3 -1/2" PBR 9 -5/8" 36# J -55 shoe @ — Baker FHL packer @ 8128 RKB (4.0" ID) 4469' RKB 3 -1/2" Camco DS landing nipple @ TBD (2.812" min ID) • Poor -Boy overshot over cut 2 -7/8" @ 8481' RKB (5' above Baker locator) Existing 2 -7/8" Baker DB packer @ 8487' RKB C -sand perfs 8386' - 8400' MD .i .� 2 -7/8" Camco D landing nipple @ 8511' RKB (2.25" min ID, No -Go) "t with equalizing plug and sand • • 2 -7/8" tubing tail @ 8522' RKB Squeeze perfs during RWO: 1 8440' - 8448' MD 8457' - 8465' MD -� �■ 3 -1/2" monobore whipstock @ 8455' MD 3C- 11L1 -01 wp01 (south) • :was TD @10,800'MD 2 -3/8" slotted liner A -sand perfs 8582' - 8590' RKB _ . \\ _ 77 8595' - 8640' RKB = Po aluminum billet 3C-11L1 wp02 (north) @8770' MD TD @11,200'MD 7" 26# J -55 shoe @ 8855' RKB • ofr %i I s THE STATE Alaska Oil and Gas fALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue pF E• L � . _ j4 , , tl ' � E` Anchorage, Alaska 99501 -3572 ALAS , - Main: 907.279.1433 Fax: 907.276.7542 J. Coberly ©. Wells Engineer Jam' 1 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3C -11 Sundry Number: 312 -387 Dear Mr. Coberly: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 7 Cathy . Foerster Chair DATED this 1/ day of October, 2012. Encl. + • • R ECEIV ED OCT 2012 Conoco Phillips G Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 October 4, 2012 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the - Kuparuk Producer 3C -11 (PTD 185 -102). 3C -11 was originally completed in June 1985 as a single selective A and C sand producer that is producing via gas lift. It has been produced from 1985 through present time. It currently produces approximately 19a stbd of oil with a water cut of 14% from the A- Sand. This well has not had a workover throughout the life Of the well. The last MIT -OA passed on 5/18/2009 and a MIT -T passed on 6/24/2010. This well has been identified as a coiled tubing sidetrack candidate to access areas of the Kuparuk A -3 sands that are believed to be isolated due to faulting. The well currently has a 2 %" completion and CTD requires a minimum of 3 1 /2" tubing, thus a workover is required to upsize the tubing. The objective of this workover is to pull the 2' /s" completion down to the bottom packer, perforate the Unit • B sands, and install a 3 ' /2" selective completion across the Unit B and Kuparuk C sands. The CTD laterals are planned to kick off in the Unit B sands of the selective. Prior to CTD, the selective will be cemented and the Unit B sands squeezed, in an effort to isolate ourselves from the highly pressured C -sand above during the CTD sidetrack. The most recent SBHP in the Kuparuk C -Sand as of 8/8/2009 measures 4,017 psi at the depth of 6,486' MD, equivalent to 12.3 ppg equivalent mud weight. The current SBHP in the Kuparuk A -Sand as of 8/5/2012 measures 1,828 psi at a depth of 6,565' MD, equivalent to 5.4 ppg equivalent mud weight. Another SBHP on the Kuparuk C -Sand will be obtained just prior to the workover to calculate the necessary KWF, regardless, drilling mud is planned to be used. If you have any questions or require any further information, please contact me at 265 -1013 or Jonathan .Coberly @conocophillips.com. Sincerely, Jonathan Coberly Wells Engineer CPAI Drilling and Wells + STATE OF ALASKA (7� (0 V • AL OIL AND GAS CONSERVATION COMMI•N `f 1f fig" APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon `°` Plug for Redrill 1 Perforate New Pool r Repair well Change Approved Program ' Suspend r Plug Perforations 1"fk� .�9•' Perforate ' , Pull Tubing ri Time Extension r t o Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p Exploratory r • 185 -102 • 3. Address: Stratigraphic r Service 6. API Numbgr: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 21357 -00 - DO 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 3C -11 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25634 ' Kuparuk River Field / Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8862 • 6731 • _ Casing Length Size MD TVD Burst Collapse CONDUCTOR 44 16 80' 80' SURFACE 4435 9.625 4470' 3800' C r V PRODUCTION 8812 7 8856' 6728' P J ' 17 12_ OC1 10 ZOIZ AOGCC Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8386- 8400', 8582'- 8590', 8595' -8640' 6416- 6427', 6546- 6553', 6556' - 6586' 2.875 J - 8522 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - CAMCO HRP -1 -SP PACKER MD= 8216 TVD= 6304 PACKER - BAKER DB PERMANENT PACKER MD= 8487 TVD= 6484 SSSV - CAMCO TRDP -1A -SSA MD =1797 TVD =1777 12. Attachments: Description Summary of Proposal p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch 1' Exploratory r Development p" ' Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/5/2012 Oil - F,- • Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ WAG r Abandoned r Commission Representative: GSTOR r SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jonathan Coberly @ 265 -1013 Email: Jonathan .Coberlvlaconocoohillips.com Printed Name J. Co Title: Wells Engineer Signature � Phone: 265 -1013 Date i 0 iq fc Z Commission Use Only 8-7 Sundry NumberJ' j Z 2 onditions of approval: Notify Commission so that a representative may witness r '° Plug Integrity r BOP Test Mechanical Integrity Test f Location Clearance E . Other: 5 b /J 1-r,5 1 to `f 5 - 0 0 p 5 RBDMS OCT 19 11 Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: / 0 — it G 1- ,' P p pPy� APPROVED BY Approved by: 10/2012) COMMISSIONER THE COMMISSION Date: �� 7 — C roved a ation Is Vaud tor 12 montns trom the date of approval. Form 10 -403 (Revise ��/ / f Form and Attachments in Duplicate 10100 i, oRIGINAtmit ,p,, • • 3C-11 Rig Workover, CTD Setup (PTD #: 185 -102) Current Status: Kuparuk well 3C -11 is a single selective A and C sand producer. The well is currently producing through the Kuparuk A -Sand. It has been identified as a candidate for a CTD lateral. Scope of Work: 2'/8" completion, install a new 3 ' /z" scab liner across the Kuparuk C sand inside the 7" casing, and re- complete with 3 '' /z" tubing in order to set the well up for CTD in the Winter of 2012 -2013. General Well info: MASP: 3,368 psi Reservoir pressure/TVD: Kuparuk C -Sand - 4,017 psi / 6,486' TVD (11.9 ppg EMW) measured 11/16/11. Kuparuk A -Sand - 1,828 psi / 6,565' TVD (5.4 ppg EMW) measured 8/5/12. Wellhead type /pressure rating: CIW Gen 4, 3 Vs" 5M top x 7 '/ 5M btm Doyon 141 BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: MIT-OA-passed on 5/18/09. MIT -IA - scheduled to be completed in pre -rig work. Well Type: Producer Estimated Start Date: November 5, 2012 Production Engineers: Evan Riley / Jeremy Mardambek Workover Engineer: Jonathan Coberly (265 -1013 / Jonathan .Coberly @conocophillips.com) Proposed Pre -Rig Work: Slickline 1. RU SL. RIH with lockout tool to 1,797' RKB. Lock out SSSV. POOH. 2. R111 w/ plug to D- nipple at 8,511' RKB. Set plug in D- nipple (2.25 "). POOH. 3. RIH and set catcher sub above plug at 8,510' RKB. 4. RIH w/ setting tool. Pull GLV's and set DV's in GLM's 2, 6, 9, and 11. POOH. 5. RU pump truck to tubing and pressure test tubing plug to 2,500 psi. Conduct a drawdown test to 0 psi. 6. RU pump truck to casing and MIT -IA to 2,500 psi. C SA N I 7. RIH w/ setting tool. Pressure up on the tubing to 1,12 (assuming 8.6 ppg fluid in tubing and 4,017 psi reservoir pressure). Pull GLV 14. POOH. 8. Let tubing pressure stabilize. RIH w/ dual Panex gauges and record updated C -sand reservoir pressure. 9. RD SL. E -Line 10. RU E -Line. RIH w/ Baker MCT /CCL and cut tubing at 8,481' RKB. 11. PU to 8,337' RKB and cut tubing. 12. PU to 8,173' RKB and cut tubing. POOH. 13. RD E -Line. Other 14. Pressure test the tubing and casing packoffs. Function test the lock down screws. 15. Set BPV prior to rig arrival. Proposed Procedure: N 1. MIRU. c !< 2. Pull BPV, circulate 12.3 ppg drilling mud around until 12.3 ppg mud returns at surface. Bullhead an additional 15 bbls to the formation. SI and monitor well for 30 min. Record SITP & SICP, verify well is dead. 3. Set BPV & CIW blanking plug. ND tree, NU & test BOPE. .gyp /tf t ¢ 45 dU )�S 4. Pull blanking plug &BPV. ri o ¢ c bee. 21- tiv5 Gdv i C& • • 5. MU landing joint, BOLDS, and POOH laying down tubing. 6. RIH on drill pipe w/ overshot. Latch on to tubing stub and POOH w/ OEJ seal barrel standing back DP and DC's. LD fish. 7. RIH on drill pipe w/ overshot. Latch onto slickstick and jar Camco HRP -1 -SP packer to release. POOH w/ fish standing back DP and DC's. LD fish. 8. RIH w/ washover pipe and overshot. Washover tubing and blast rings to 8,438' MD. Latch on to the tubing stub and POOH w/ fish. LD fish. a. If fish does not pull in under 10.0K lbs over neutral weight, RU E -Line and cut tubing below GLM and POOH w/ fish. 9. RU E -Line. RIH w/ casing perforation gun and perforate the following intervals of the 7" production casing w/ charges at 6 spf and 60 degree phasing. POOH. RD E -Line. a. 8,457' MD — 8,465' MD b. 8,440' MD — 8,448' MD *The tie in log for depth correlation is the SWS CET log conducted on 6/29/1985. 10. MU 3 'h" scab liner assembly w/ overshot and RIR to 8,481' MD. Spot 20 bbls of corrosion inhibited brine to fill tubing and IA below the PBR. Engage overshot onto the tubing stub and set the Baker FHL packer at 8,130' RKB. POOH laying down drillpipe. iV *If the overshot packoff failed to test during packer set, RU E -line and set plug in `X' nipple to set packer. 11. TOH w/ all but 1,600' of drillpipe. MU storm packer and RIH. Set storm packer at -100' MD. Pressure test packer. ND BOP and tubing head using Hydratight tensioners. Replace the tubing head and IC packoffs. NU BOP and test to 4,500 psi. Release the storm packer and POOH laying down the drill pipe and storm packer. 12. Offload the old tubing string. Load and strap a new 3 'h ", 9.3 #, L -80 8rd EUE tubing string into pipe shed. 13. MU and RIH w/ the new 3 'h" gas lift completion w/ SCSSSV. 14. Locate the PBR, space out 7' off bottom. Space out w/ tubing pup joints and MU tubing hanger. Feed control line through the hanger and secure w/ swage lock fittings. Pressure up the control line to open the SCSSSV. 15. If the overshot packoff test passed in step #10. Load the well w/ corrosion inhibited seawater. Land hanger and RILDS. 16. PT the tubing to 3,000 psi, bleed tb to 2,500 psi, PT the IA to 3 for 30 min and record on chart recorder. Bleed the IA to zero, then the tubing to zero. Ramp up the IA pressure quickly to shear the SOV. Function test the SCSSSV and pressure test to 1,000 psi from below. Bleed IA pressure to zero. 17. Pull landing joint, set BPV, NDBOP. 18. NU and test tree. Pull BPV. Install tree test plug. Pressure test tree and tubing hanger packoffs. 19. Pull tree test plug. Open SCSSSV. 20. Reverse circulate diesel to freeze protect. Set BPV. *If the overshot packoff test failed in step #10, load well with corrosion inhibited seawater. 21. RDMO. Proposed Post -Rig Work: 1. Pull BPV. 2. RU Slickline: a. Pull the SOV from the bottom GLM and replace w/ a DV. POOH. b. Pull plug in `X' nipple and P0011 (if plug was installed). c. Pull catcher sub. POOH. d. RIH w/ dump bailer. Dump bail 10' of sand above D- nipple plug at 8,511' RKB. POOH. RD SL. 3. Turn well over to CTD Operations. • • C011000PhillIPS Well: 3C -11 2012 RWO PROPOSED COMPLETION API: 500292135700 Conductor: PTD: 185 -102 16 ", 65.5 #, H -40 to 80' Wellhead: CIW Gen IV X -mas Tree: 3 -1/8 ", 5K psi Surface Casing: Lift Threads: 3 -1/2" 8rd EUE • sssv 9.625 ", 36.0 #, J -55 to 4470' Proposed 3 Completion J Production Casing: • Tubing, 3'/ ", 9.3 ppf, L -80, 7 ", 26.0 #, J-55 to 8856' 8rd EUE • SSSV, TRMAXX -5E w/ 2.812 " 'DS' Perforations: profile at 1800' TVD MD Zone • PBR J 8386' - 8400' Kuparuk C -Sand 8582' - 8590' Kuparuk A -Sand • Packer, Baker 31/4" x 7" FHL at 8595' - 8640' Kuparuk A -Sand 8,130' MD • Nipple, 2.812" 'X' profile A J , • Tubing • Overshot 1 k .,. ► 4— PBR Gas Lift Mandrels: r Type MD TVD MMG 2745 2550 f— Baker FHL Packer MMG 4688 3950 at 8,130' RKB MMG 6189 4950 X Nipple r� $3 y�, -Plc" MMG 7292 5696 x _ — �_ c s iD P F MMG 8052 6196 — — Casing Perforations at — " \ — f— 8,457-65', 8,440' -48' RKB / / f 4 Overshot at 8,481' RKB 1 1 Baker DB 4— Permanent Packer Directional: at 8,487' RKB Max Incline: 51.4° @ 5600' Max Dogleg: 11° @ 8080' IIP"Al 4— 'D' Nipple at 8,511' RKB Z V" fb� L sos 4— SOS at 8,522' RKB c,,,.,T 1 L b 7Z Fill at: 8,622' RKB Last Updated: 9- Oct -12 / 2 TD: 8,862' RKB Updated by: JRC f ' 1,-- KUP 3C -11 • ConocoPhi lips ' .°kig Well Attributes Max Angle & MD TD Alaska ,Inc. Wel!bore API /UWI Field Name Well Status Inc! (•) MD (ftKB) Act Btm (ftKB) a ■ Lona 500292135700 KUPARUK RIVER UNIT PROD 51.25 5,600.00 8,862.0 Comment H25 (ppm) Date Annotation End Date KB (ft) Rig Release Date we coons: •��CC--tt e2ormu 72733 AM SSSV• TRDP 100 12/13/2011 Last WO: 34.69 6/25/1985 Sehsmatk •Aehal Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 8,589.0 8/5/2012 Rev Reason: TAG ninam 8/21 /2012 HANGER.33 Casing Strings Casing Description String 0... String ID ... Top (SIKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd I CONDUCTOR 16 15.062 36.0 80.0 80.0 65.50 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 34.6 4,469.5 3,800.3 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 43.6 8,855.8 0728.0 26.00 J -55 BTC I Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING I 2 7/8 I 2.441 I 32.6 I 8,522.9 I 6,508.6 I 6.50 I J -55 EUE 8RD I Completion Details CONDUCTOR, Top Depth 36.80 (ND) Top Intl Nomi... SAFETY VLV. _ Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 1,797 32.6 32.6 0.18 HANGER CAMERON TUBING HANGER w/3.5" PUP 3.500 1 1,797.2 1,776.9 22.03 SAFETYVLV CAMCOTRDP -1A -SSA 2.310 GAS LIFT, 1,867 ilt- 8, 6,293.9 48.52 PBR CAMCO OEJ PBR 2.297 11 8,216.2 6,305.4 48.36 PACKER CAMCO HRP -1 -SP PACKER 2.2971 GAS LIFT, - 8,359.5 6,400.5 48.30 BLAST RINGS CARBIDE BLAST RINGS (2) 2.441 3,574 8,486.4 6,484.5 48.83 LOCATOR BAKER LOCATOR w /10' SEALS 2.441 8,487.4 6,485.2 48.83 PACKER BAKER DB PERMANENT PACKER 3.250 8,510.9 6,500.7 48.83 NIPPLE CAMCO D NIPPLE NO GO 2.250 8,522.4 6,508.2 48.83 SOS CAMCO SHEAR OUT SUB 2.375 SURFACE, A 354,470 p erforations & Slots GAS LIFT, - WI Shot 4,499 - W I Top (ND) Btm (TVD) Dens I Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh.- Type Comment GAS LIFT, 8,386 8,400 6,418.1 6,427.4 C - 1, UNIT B, 7/19/1985 12.0 IPERF 120 deg ph; 5 1/2' Scallop Gun HJ 11 illt 4,967 30 8,582 8,590 6,547.5 6,552.8 A-4, 3C -11 7/19/1985 4.0 IPERF 90 deg ph; 4" Carrier HJ II GAS514F0T4, 8,595 8,640 6,556.1 6,585.8 A -3, 3C -11 7/19/1985 4.0 IPERF 90 deg ph; 4" Carrier HJ II Notes: General & Safety GAS LIFT, End Date Annotation 5,874 7/16/2010 NOTE: View Schematic w/ Alaska Schematic9.0 (2 pages) GAS LIFT. 6,283 I GAS LIFT,_ 6,747 I. GAS LIFT, lir 7,183 a GAS LIFT, lir 7,685 t • GAS LIFT, 6.156 F # P8R, 8,199 PACKER, 8,216 WISIIIIIIMal ■ . PRODUCTION, 8,255 E PRODUCTION, 8,322 E t IPERF, • � q �{9 1 8,386 -8,400 A V` PRODUCTION, J• � �� -1 \I1 8,449 \\ e/ x J \ rAl t _A PACKER, 8,487 NIPPLE, 8,511 glj Mandrel Details SOS, 8,522 Top pt h T Port (N D) 1461 op OD • Valve Latch 5140 TRO Run Stn Top (ftKB) (ftKB) (°) Make Model (in) Sery Type Type (In) (p91) Run Date Com... 1 1,867.1 1,841.1 24.23 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/5/1995 IPERF, ® 2 3,574.1 3,141.3 42.01 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,407.0 4/22/2004 8,582.8,590 3 4,498.5 3,820.6 45.59 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/5/1995 I II 4 4,967.4 4,138.0 48.91 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/22/1985 IPERF, 5 5,404.2 4,420.8 50.33 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 6/22/2010 8,595-8,840 6 5,874.4 4,737.5 45.00 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,380.0 4/22/2004 7 6,283.4 5,016.9 46.45 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 4/22/2004 8 6,747.4 5,331.9 47.82 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/22/1985 9 7,182.7 5,624.4 47.83 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,357.0 4/22/2004 PRODUCTION, T44D8,856 IL 10 7,685.0 5,957.4 49.32 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 3/13/2001 , 8,862 z KUP • 3C -11 ConocoPhillips O.& Alaska. Inc. lips . e - KB-Grd (ft) Rig Release Date ••• 34.69 6/25/1985 Well Confi9: -3C -11 812012012 727 33 AM Schematic - Actual HANGER, 33 O CONDUCTR , 36 -8 SAFETY 797 J I 7 J GAS LIFT, 1,867 GAS LIFT, 3,574 SURFACE, L 35 -4,470 GAS LIFT, 4,499 GAS LIFT. } 4,967 ) GAS LIFT, 5,404 GAS LIFT. 5.874 GAS LIFT, 6.283 GAS LIFT, 6,747 GAS LIFT, 7.183 GAS LIFT. a 7,685 GAS LIFT, 8,158 P8R. 8.199 PACKER, 8,216 - PRODUCTION, 8.255 PRODUCTION, 8,322 IPERF, 8,386 -8.400 a � PRODUCTION, _. 8,449 PACKER, 8,487 NIPPLE, 8,511 - —. Mandrel Details SOS, 0.522 - - E2 Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (19(9) (RKB) (1 Make Model (in) Sery Type Type ON (psi) Run Date Coin... 11 8,157.6 6,266.7 48.65 MERLA TGPD 1 1/2 GAS LIFT OV RK 0.188 0.0 4/22/2004 IPERF, 12 8,254.7 6,331.0 48.38 CAMCO KBMG 1 PROD DMY BEK 0.000 0.0 6/24/2010 85828,590 13 8,321.8 6,375.2 48.15 CAMCO KBMG 1 PROD DMY BEK 0.000 0.0 6/24/2010 14 8,448.7 6,459.7 48.84 CAMCO KBMG 1 PROD DMY BEK 0.000 0.0 6/24/2010 IPERF, 8.585 -8,640 PRODUCTION. 44-8,856 TD, 8,862 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 3C-11 Run Date: 4/27/2010 May 19, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3C-11 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21357-00 Production Profile Log 50-029-21357-00 ~"' -` ~ " 1 Color Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNII~TG AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax:907-273-3535 ~: ~ rafael.barreto •~ ~~ ~ _= ,,,; .;~ 'ai ~=, ~ .~, ~ Date: ~Gj ~~~ /~ ~' Signed: .,~; ConocoPhllips a~~ ~~ APR05'2010 Galion ~Ail& P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~j G` ~" ~ 3 Dear Mr. Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLT). 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 March 2 and 21, 2010. The corrosion inhibitor/sealant was pumped March 27, 28 and 29, 2010. The attached spreadsheet presents the well name, t'op 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, MJ L veland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3131/10 30_ ~R ~r sr ~N ~i ~i inn ~n A ~Q ~en~e Well Name API # PTD # Initial top o cement Vol. of cement um ed Finai top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3A-02 50029214310000 1852050 Surface n/a 26" n/a 4.25 3!292010 3A-04 50029214330000 1852070 SF n/a 26" n/a 4.25 3/29/2010 3A-07 50029214440000 1852230 SF n/a 25" n/a 4.25 3/29/2010 3A-16 50029214920000 1852840 SF n/a 23" n/a 3.4 3/29!2010 3B-10 50029213660000 1851140 6'6" n/a 6'6" n/a 25.5 3/28/2010 3C-11 50029213570000 1851020 ,SF Na 25° Na 4.25 3/27!2010 3G-08 50103201280000. 1900650 SF 0.65 27" 3/2!10 5.52 3/28/2010 3G-09 50103201290000 1900670 SF 0.60 22" 3/2/10 4.67 3/28/2010 3G-22 50103201470000 1901420 SF n/a 22" n/a 4.25 3/28/2010 3H-01 50103200840000 1871100 SF n/a 21" Na 4.25 3/28/2010 3H-03 50103200850000 1871110 17" 0.40 8" 3/21/10 1.7 3/28/2010 3H-14B 50103200920200 2050210 SF n/a 23" Na 3.4 3/29!2010 31-02 50029215150000 1853080 SF Na 22" n/a 2.97 3/29/2010 31-10 50029219340000 1890370 39' 3.50 24" 3/21!10 3.4 3/29/2010 3J-04 50029214000000 1851650 SF n/a 23" n/a 3.4 3/28/2010 3J-14 50029214960000 1852880 SF n/a 25" n/a 4.67 3/28/2010 3J-15 50029214970000 1852890 SF Na 22" n/a 3.4 3/28/2010 3M-05 50029217060000 1870250 SF Na 21" n/a 3.4 3/29/2010 3M-07 50029217080000 1870270 SF n/a 22" n/a 4.25 3/29/2010 30-09 50029218250000 1880610 SF n/a 23" n/a 4.25 3/27/2010 30-16A 50029217960100 1880430 SF Na 22" Na 3.52 3/27/2010 3R-10A 50029222530100 1920310 SF n/a 21" Na 4.25 3/27/2010 3R-11 D 50029222480000 1920160 SF n/a 17" n/a 3.25 3/27/2010 3R-15 50029222580000 1920340 SF n/a 24" n/a 3.82 3/27/2010 3R-19 50029222690000 1920460 1" n/a 21" n/a 5.1 3/27/2010 3R-25 50029226220000 1951810 SF n/a 21" n/a 5.52 3/27/2010 ) ConocJP'hillips ) Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 November 15, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 NOV 1 2004 Subject: Report of Sundry Well Operations for 3C-11 (APD # 185-102) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 3C-11. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, !v1. /11~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad SCANNED NOV 1 8 LOOL!. OR!GINAL ) ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS NO\! Repair Well D Pull Tubing D Operat. ShutdownD 7004 r~th~r, ..;. . ; [d Time Ext~~~iPh;;¡':.~~ Abandon D Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: 1. Operations Pe rformed: Stimulate 0 Waiver D Plug Perforations 0 Perforate New Pool 0 Perforate D 4. Current Well Status: Development - 0 Stratigraphic 0 Exploratory 0 Service D Re-enter Suspended Well 0 5. Permit to Drill Number: 185-1 02 1 6. API Number: 50-029-21357 -00 P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 82' 8. Property Designation: ADL 25634 9. Well Name and Number: 3C-11 10. Field/Pool{s): Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION Perforation depth: measured 8862' feet true vertical 6732' feet measured 8628' feet true vertical 6577' feet Length Size MD 80' 16" 80' 4388' 9-5/8" 4470' 8774' 7" 8856' Plugs (measured) Junk (measured) TVD Burst Collapse 80' 3801' 6728' Measured depth: 8386'-8400',8582'-8590',8595'-8640' true vertical depth: 6418'-6427', 6547'-6553', 6556'-6586' SCANNED NOV 1 8 2004 Tubing (size, grade, and measured depth) 2-7/8", J-55, 8523' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'DB'; CAMCO 'HRP-1-SP' pkr= 8487'; 8216' SSSV=1797' 12. Stimulation or cement squeeze summary: 8386'-8400' RBDMS BFL NOV 1 7 2004 Intervals treated (measured) refer to summary 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 116 16 117 25 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: Oil 0 GasD WAGD GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Oil-Bbl 105 101 Casinq Pressure Tubinq Pressure 115 141 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations _X Contact Printed Name Signature WDSPLD Mike Mooney @ 263-4574 Mike Mooney 4k. j/f~ Title Phone Kuparuk Wells Team Leader /'. . Date Ii 1C>.~4 Prepared bv SharoZIl~UP-Drake 263-4612 ORIGINAL Submit Original Only Form 1 0-404 Revised 04/2004 ) 3C-11 Well Events Summary ) Date Summary 10/15/04 PERFORMED AN ASP HAL TINE REMOVAL BY MEANS OF A 50/50 DIESEUBAKER PEP-? SOLUTION. BULLHEADED FROM SURFACE BY SCHLUMBERGER AT A MAXIMUM TREATMENT PRESSURE OF < 2,000# IN ITS ENT1RETY. WELL BORE AND FLOW LINE FREEZE PROTECT WITH DIESEL. SCANNE[] NOV 1 8 2004 sssv (1797-1798. OD:2.875) PBR (8199-8200. OD:2.875) PKR (8216-8217. OD:6.151 ) Perf (8386-8400) PKR (8487-8488. OD:6.151) NIP (8511-8512. OD:2.875) TUBING (0-8523. OD:2.875. ID:2.441) Perf (8582-8590) Perf (8595-8640) ) ) ConocoPhillips Alaska,IQt1~ 3C-11 (' I !~ - ..t "I ~.J «II i 1 ~.:'; .1 j ~.\ .1 1 '-1, "I 1 ~.( I 1111' j' Illllii1: .. I "I., c, I ~ "I I --~;;, cmJ8 ~ .~t ... .l., n~ . KRU 3C-11 Angle Angle API: SSSV Type: TRDP Well Type: Orig 6/25/1985 Completion: Last W/O: Annular Fluid: Ref Log Date: TO: 8862 ftKB Max Hole Angle: 51 deg @ 5600 Reference Log: Last Tag: 8628 Last Tag Date: 10/8/2004 Casing String - ALL STRINGS Description CONDUCTOR SURFACE PRODUCTION Tubing String - TUBING Size I Top 2.875 0 Perforations Summary Interval TVD 8386 - 8400 6418 - 6427 8582 - 8590 6547 - 6553 8595 - 8640 6556 - 6586 Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr V Type V OD Latch Mfr 1 1867 1841 Camco 2 3574 3141 Camco 3 4499 3821 Camco 4 4967 4138 Camco 5 5404 4421 Camco 6 5874 4731 Camco 7 6283 5017 Camco 8 6747 5332 Camco 9 7183 5625 Camco 10 7685 5957 Camco 11 8158 6267 Merla Production MandrelsNalves St MD TVD Man Man Type V Mfr V Type V OD Latch Mfr 12 8255 6331 Camco KBMG MACCO DMY 13 8322 6376 Camco KBMG MACCO DMY 14 8449 6460 Camco KBMG MACCO DMY Other (plugs, equip., etc.) - JEWELRY Depth TVD Type 1797 1777 SSSV 8199 6294 PBR 8216 6305 PKR 8487 6485 PKR 8511 6501 NIP 8522 6508 SOS 8523 6509 TTL Size Top Bottom 16.000 0 80 9.625 0 4470 7.000 0 8856 Bottom TVD Wt 8523 6509 6.50 Rev Reason: TAG FILL, set DMYs Last Update: 10/9/2004 TVD 80 3801 6728 Wt Grade Thread 65.50 H-40 36.00 J-55 26.00 J-55 I Grade I J-55 Thread 8RD EUE Zone C-1,UNIT B A-4 A-3 Status Ft SPF Date Type Comment 14 12 7/19/1985 IPERF 120 deg ph; 51/2" Scallop Gun HJ II 8 4 7/19/1985 ¡PERF 90 deg ph; 4" Carrier HJ II 45 4 7/19/1985 IPERF 90 deg ph; 4" Carrier HJ II KBMG KBMG KBMG KBMG KBMG KBMG KBMG KBMG KBMG KBMG TGPD DMY GLV DMY DMY DMY GLV DMY DMY GLV DMY OV 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.5 1.0 1.0 1.0 Description Camco'TRDP-1A-SSA' Camco 'OEJ' Camco 'HRP-1-SP' Baker 'DB' Camco 'D' Nipple NO GO Camco SCANNED NO\ì 1 8 200L, BK BK BK BK BK BK BK BK BK BK RK Port TRO Date Vlv Run Cmnt 0.000 0 10/5/1995 0.188 1407 4/22/2004 0.000 0 1 0/5/1995 0.000 0 7/22/1985 0.000 0 7/22/1985 0.188 1380 4/22/2004 0.000 0 4/22/2004 0.000 0 7/22/1985 0.188 1357 4/22/2004 0.000 0 3/13/2001 0.188 0 4/22/2004 Port TRO Date Vlv Run Cmnt 0.000 0 10/7/2004 0.000 0 1 0/7/2004 0.000 0 10/7/2004 ID 2.312 2.297 2.297 3.250 2.250 2.441 2.441 BK BK BK PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 October 9, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 3C-11 (185-102) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the stimulation treatment on the KRU well 3C-11. If there are any questions, please contact me at 263-4574 or 659-7348. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad RECEIVED O0 ? 1 7 2001 Oil & _Gas Cons 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 elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 82 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 service__ Kuparuk Unit 4. Location of well at surface 8. Well number 1176' FNL, 874' FEL, Sec. 14, T12N, RgE, UM (asp's 528698, 5995255) 3C-11 At top of productive interval 9. Permit number / approval number 185-102 / At effective depth 10. APl number 50-029-21357 At total depth 11. Field / Pool 1447' FNL, 1026' FEL, Sec. 13, T12N, R9E, UM (asp's 533828, 5995006) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 8862 feet Plugs (measured) true vertical 6732 feet Effective depth: measured 8626 feet Junk (measured) true vertical 6577 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 80' 16" 215 sx cs II 80' 80' SURFACE 4388' 9-5/8' 136o sx AS III, 320 sx Class G 4470' 3801' PRODUCTION 8774' 7" 325 sx Class G 8856' 6728' Perforation depth: measured 8386'-8400', 8582'-8590', 8595'-8640' true vertical 6418'-6427', 6547'-6553', 6556'-6586' RECEIVED Tubing (size, grade, and measured depth) 2-7/8",6.5#, J-55 -I'bg @ 8523' MD.k ~')~'~ ~- .~. Packers & SSSV (type & measured depth) BAKER 'DB' @ 8487' MD; CAMCO 'HRP-I-Sl~ @ 8216' MD; ~J/a$_~ Oi/(~ ~85 ~-,01~S CAMCO 'TRDP-1A-SSA' @ 1797' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oit-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3 247 1 - 88 Subsequent to operation 288 706 5 125 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ X Gas __ Suspended __ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Moon@y263-4574 Signed ~ ~~ ~/~' /x-~ ~,~.~ Title Staff Engineer Date / ,/ M~chael Mooney Prepared by Sharon Al/sup-Drake 265-46 f2 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment 3C-11 Event History 08/01/01 WASHED THROUGH 3 HARD ICE PLUGS FROM 275'-1600' CTM. WASHED TO 8600' WITH 160 DEG DIESEL. BULLHEADED 25 BBLS 50/50 XYLENE INTO A SAND PERFS, 25 BBLS INTO C SAND PERFS. POOH WASHING WITH REMAINING 50 BBLS XYLENE, SWAP TO DIESEL. BRING WELL ONLINE TO FAClLI Page I of I 9/7/01 . ,-..-.~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate X Plugging Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1177' FNL, 876' FEL, Sec 14, T12N, R9E, UM At top of productive interval 1408' FNL, 1432' FEL, Sec 13, T12N, At effective depth 1439' FNL, 1094' FEL, Sec 13, T12N, At total depth 1445' FNL, 1028' FEL, Sec 13, T12N, R9E, UM R9E, UM R9E, UM ORtGiNA 12. Present well condition summary Total Depth: measured 8 8 5 9 true vertical 6 7 2 9 feet feet Perforate Other 6. Datum elevation (DF or KB) RKB 82 7. Unit or Property name Kuparuk River Unit 8. Well number _ 3C-11 9. Permit number/approval number 85-102 10. APl number 50-029-21357 11. Field/Pool Kuparuk River Oil Field/Pool feet Plugs (measured) None Effective depth: measured 877 1 true vertical 6671 feet feet Junk (measured) None Casing Length Size Structural Conductor 8 0' 1 6" Surface 4431 ' 9.625" Intermediate Production 88 1 2' 7" Liner Perforation depth: measured 8386'-8400', true vertical 6417'-6426', Tubing (size, grade, and measured depth) 2 7/8", 6.5#, J-55 @ 8523' Packers and SSSV (type and measured depth) Cemented 215 Sx CS II 1360 Sx AS III & 320 Sx Class G 325 Sx Class G Measured depth True vertical depth 8582'-8590', 6546'-6552', 8595'-864O' 6555'-6584' 116' 116' 4470' 3800' R E E D MAY 0 7 1996 PKR: Camco 'HRP-1SP' @ 8216' & Baker 'DB' @ 8478'; SSSV: Camco TRDP-1A-SSA @ 1788' 13. Stimulation or cement squeeze summary Stimulate "A" Sand interval on 10/14/95. Intervals treated (measured) 8582'-8590', 8595'-8640' Treatment description including volumes used and final pressure Pumped 88.8 Mlbs of 20/40 & 12/18 ceramic proppant into formation, fp was 5600 psi. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 177 39 3 1419 135 Subsequent to operation 4 8 2 391 7 953 138 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Title Wells Superintendant Date SUBMIT I!~ DUPLICATE ARCO Alaska, Inc. '~"~- '--~;UPARUK RIVER UNIT -...~ WELL SERVICE REPORT ,, K1(3C-11(W4-6)) VVFll JOB SCOPE JOB NUMBER 3C-11 FRAC, FRAC SUPPORT 1004951650.1 DATE DALLY WORK UNIT NUMBER 10/14/95 INITIAL "A" SAND FRAC 3 t~) Yes O No J (~) Yes O No DS-YOAKUM CHANEY ESTIMATE 998482 230DS36CL $111,745 $119,472 , Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer~Afin 150 PSI 700 PSI 1500 PSI 500 PSII 150 PSI 1,~00 PSI DALLY SUMMARY "A" SAND.FRAC COMPLETED 1202 BBLS PUMPED IN, SCREENED OUT TOP TO BTM, (8000# OF 20/40, 90919# OF 12/18) TOTAL PROP 98919#. APP: 88800# IN PERF'S AND 10119# IN THE PIPE. TIME 09:00 11 '30 12:15 12:45 15:00 LOG ENTRY MIRU DOWELL EQUIP, DHP, AND VAC TRK. HELD SAFETY MTG (14 ON LOCATION). PT THE BACKSIDE HARDLINE TO 4500PSI AND RAISED 7" PSI TO 1500 PSI. PT HI-PRESS PIPING TO 8100 PSI. TREESAVER WOULD NOT SET, PULLED AND CHANGED TO 3 1/2' CUPS. PT THE HI-PRESS PIPING AGAIN TO 7500 PSI. SET TREESAVER. TREESAVER WOULD NOT GO DOWN WITH LARGER CUPS, PULLED AND ADDED EXTRA EXTENSION AND INSTALLED 2 7/8" CUPS AGAIN. PT HI-PRESS PIPING TO 8100 PSI, SET TREESAVER. (REQUIRES 30" EXT ON TREESAVER) PUMPED BREAKDOWN STAGE fSTRAIGHT WATER) 142 BBLS ISIP 2200 PSI. SD FOR CLOSURE. PUMPED DATAFRAC STAGE (50# DELAY-XL GW/ 152 BBLS ISIP 2576 PSI. SD FOR CLOSURE. PUMPED FRAC (50# DELAY-XL GW) 908 BBLS, SCREENED OUT TOP TO BTM. MAX PSI REACHED 5600 PSI. (8000# OF 20/40. 90919# OF !2/18) TOTAL PROP 98919#. APP: 88800# IN PERF'S AND 10119# IN THE PIPE. 1 7- 1 5 DEPRESSURED 7" PSI TO 500 PSI. STARTED TO RD DOWELL EQUIP AND DHP. 1 9' 3 0 RD COMPLETE AND WELL SECURED. SERVICE COMPANY - SERVICE ApC~LABOR APC-PUMPING APC-TRUCKING DOWELL-STIMULATION HALLIBURTON TOTAL FIELD ESTIMATE DAILY COST ACCUM TOTAL ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 4, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3C-11 Dear Mr. Chatterton: Enclosed is a copy of the 3C-ll Well History (completion details) to include with the Well Completion Report, dated 09/18/85. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/lt GRU12/L19 Enclosure cc: 3C-11 Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany l'?Y~ARCQOil~andiGas~pany,~," Well History - Initial Report - Daily · ~ln'llvctlolts:-:Pmpere and submit the "Initial R~l~ort" on the fimt Wednesday after a well is spudded or workover operations are started. Dally Work prior to spudding should be summarized on the form giving inclusive dates only. District - Field Alaska County, parish or borough North Slope Borough IL, as~ or Unit ADL 25634 [?itin '' Completion Kuparuk River Auth. or W;O. no. AFE 604909 State Alaska tWell no. 3C-11 WWS 1 API 50-029-21357 Operator ' -~:i: _: ARCO Alaska, Inc. Complete 7/17/85 Date and depth as of 8:00 a-m. /18/85 7/19/85 Complete record for each day repo~ted 1530 hrs. ARCO W.I. Prior status if a W.O. 7" @ 8856' 8770' PBTD, Circ dn DP 10.3 ppg NaCl/NaBr Accept rig @ 1530 hfs, 7/17/85. ND tree, NU & tst BOPE. Perf w/4" guns, 4 SPF f/8464'-8466'. PU Bkr RAM & set pkr @ 8215'. Tst pkr; OK. Unseat pkr & att to circ w/o success. Rev circ one DP vol. Circ dn DP @ 37 SPM, 175-200 psi. 7" @ 8856' 8770' PBTD, Drlg cmt 10.3 ppg NaCl/NaBr Set pkr. Est IR @ 1BPM, 2750 psi. Pmp 100 sx C1 "G" w/.8% D-60, .2% D-46 & 3% KC1. Displ w/brine. ISIP = 2000 psi. Unseat pkr. Rev circ, POOH, LD pkr. Rn bit & scrprs. WOC. Tag top of cmt @ 8418'. Drl cmt. 56.24% The.~bove is correc~ Stiln atl~. '~,~ For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Title 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 r~ot 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. Accounting cost center code District ICounty or Parish State Alaska I North Slope Borough Alaska Field ILease or Un,t . ]We,,no. Kuparuk River ADL 25634 3C-ll Auth. or W.O. no. ~Title AFE 604909 I Completion WWS #1 API 50-029-21357 Operator IA.R.Co. W.I. ~Total number of wells (active or inactive) on this1 ARCO Alaska, Inc. 56.24% icost center prior to plugging and labandonment of this well Spudded or W.O. begun IDate IHour I Prior stalus if a W.O. Complete 7/17/85 1530 hrs. Date and depth Complete record for each day reported as of 8:00 a.m. Old TD Released rig 7" @ 8856' 8762' PBTD, RR Crude Oil w/diesel Cap Drl cmt to 8467'. Wsh & rm to PBTD @ 8762'. Tst csg to ll00 psi; OK. Displ well to cln brine. POH, LD DP. Perf 4", 4 SPF f/8595'-8640' & 8582'-8590'. Perf 5-1/2", 12 SPF f/8386'-8400'. Rn GR/JB to PBTD. Rn & set Bkr DB pkr @ 8478' WLM. Rn 2-7/8", 6.5#, J-55, 8RD EUE compl string. Stab into btm pkr. Lnd tbg. Drop ball. Set pkr. Shear SBR. Tst SSSV; OK. Shear out ball. ND BOPE. NU & tst tree. Displ well to diesel/crude. Tst orifice vlv; OK. RR @ 7/21/85. DB Perm Pkr @ 8457' - "D" Nipple @ 8480' - TT @ 8492' SSSV @ 1767' 7/20/85 thru 7/22/85 Classifications (oil, gas, etc.) O-Il Flowing Producing method INew TD PB Depth 8762' PBTD I Date. K nd of rig 7/21/85 Rotary IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C,P. Water % GOR Gravity Allowable Effective date corrected , . '~heaboveisco~ct t~,\ %~ Title /-~i,~ka i~i , ~:~: ~.',/,:~, ~':~ :~:, : , ~, O~.%. [~[~¢ Drilling Superintendent For for~ preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Alaska, In' Post Office 6ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 .*. DAT~: 10-22-85 TRANSMITTAL NO: 5410 RETURN .TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK · ATO-1115B " . -' ' _. -...-.-__ P.O. i~OX 100360 ' :' ANCHORAGE, AK 99510 · * CEMENT. BOND- L~G/ VARIABLY- DENSITY " "~3B-8 ':' 06-06-85 .RUN #1 5850-8369 ,1 5900-8258 ~q2X-15 '.. 11-07-.84 "~2X-13. .-11-17-84 ~ 2X-12 _ 12-08-84 'w2X-11 12-08-84 · -'~.X- 10 12-21-84 "~ 2X-9 12-20-84 "~ 2W-6 .' 11-25-85 "'2V-16 .... 06-06-85 '~2V-15 ~'. 06-07-85 ~'2V-13 i'".~.: 06-03-85 04-02-85 04-01-~5 03-31~-85 04-01-85 03-02-85 "~ 2D-16 _-~:. 12-19-84 ~'~2D- l" 11-03-84 . .. · '~lR-8 ' : 06-17-85 - ~lR-7 :- 06-08-~5 · '",Jl~-5. '" 06-08-85 ,'~iL- 15 -' 11-05-84 "~lQ-15 .i'< 05-27-85 '~1Q-3 ~_'i.i. 04-17-85 RUN RUN RUN RUN i~UN RUN RUN · RUN . ' RUN - - RUN · RUN ' RUN -_ . RUN RUN RUN hUN RUN RUN }{UN · RUN RUN RUN RUN . RUN ' %CPF-1A.!'-12-21-84 t{UN cEMENT EVALUATION TOOL ~,..~-_il 63~2- 03-12-85 RUN 5896-8410 3050-7215 3100-6370 3350-6973 5100-8338 5700-7290 4550-7108 4650-6428 6590-8553 4970-693~' 0070-~122 5600-8107,~ 5994-9161 6284-7850 5200-7469 3285-6454" 5693-6652 5987-~324 430Z-7028 6950-8628 4883-6600' 6490-7566 - 897~-10744 · ~"lh'5 ?-.:!;~?'!:'. 06-26-85 RUN ~ ~,lRh5 i~-!)~i~: 06-27-85'- -~: RUN _ .. ~ ~-2 U-2 :.{;!?ii:.:i:j' 03'25-85' hUN ' ~ 2U-.15;.:~L' 03-07-85 RUN '~3B-9 ::~-:.~.~ 06-30-85 '_] RUN '~3C-1i-;.% 06-29~85_.- RUN . . -. . PLEAS~ ACKNOWLEDG~ . . .. , .. . · . · %1- 8269-8712 " %1 6974-8644 ...... - .. .~.' : ' · ..- - . _92 '- 8254-8532 . ~1 -5790-9450' ·:.,. ..... ..- ' ' ' C" :;.i. ... #1- 6400-7002 ii" 6500-8726 ~1.. 5400-7457 . ' - .-- . : -.. - ..~, .. ;~ .,--. · ~:e ... . BPAE -' _-. :.-' DRILLINS*BL W. PAShSR STA'f~ 0~, ~~L :. CHEVRON:.:.' ;' '" L,IOBIL P~ILLIPS OIL UNION ._ D a M. -"' '" .... ; NSK CLEKK*DL ' " j. ~TH~JELL'- VAUL~/~O*FILM -.. . . . . . . .. :-.. '.:.;-....: . . . - : . . · .. - . ARCO Alaska, Inc. is a SubsiOiary of AllanlicRichlieldCompanY ~1 2200-3856 LOGS/ C}24ENT ~VALUATION LOGS ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 9, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3C-11 Dear Mr. Chatterton' Enclosed is a copy of the 3C-11 Well History to include with the Well Completion Report, dated 9/18/85. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU11/L142 Enclosure cc' 3C-11 Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Oi!' and Gas Company Well History - Initial Report - Daily Insb'uctions: Prepare and submit the "Initial Reporl" on the first Wednesday afte[ 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 Alaska I County. parish or borough J North~Slope Borough Field ILease or Unit ADL 25634 Kuparuk River Auth. or W.O. no. ~Title , - AFE 604909 I Drill Parker 191 API 50-029-21357 Jstate Alaska IWell no. 3C-11 Operator IARCO W,I. ARCO Alaska, Inc. Spudded or W.O. begUnspudded IDate 6/17/85 IHOur 1200 hrs. IPri°rstatusifaW'O' Date and depth as of 8:00 a.m. 6/18185 6/19/85 6/20/85 6/21/85 Complete record for each day reported 56.24% 16" @ 116' 2275', (2161'), DD Wt. 9.9, PV 22, YP 34, PH 10.5, WL 14, Sol 7 Accept rig @ 0730 hrs, 6/17/85. NU diverter sys. Spud well @ 1200 hfs, 6/17/85. Drl 12¼" hole to 978', DD to 2275'. 979', Assumed vertical 1134', 4.8°, 883.2E, 1134 TVD, 6 VS, IS, 6 1679', 18.8°, N84.3E, 1667 TVD, 115 VS, 6N, 115 1867', 24°, N85.6E, 1842 TVD, 183 VS, 12N, 184 16" @ 116' 4150, (1875'), Drlg Wt. 9.9, PV 23, YP 24, PH 10.0, WL 12, Sol 11 Drl & survey 12~' hole to 4150'. 2051', 28.9°, N83.0E, 2006 TVD, 264 SV, N20, 265E 2431', 37.5°, N85.0E, 2325 TVD, 470 VS, N39, 471E 3040'' 45,7~, N86.6E, 2762 TVD, 891VS, N66,- 894E 3988', 41.6°, N87.7E, 3456 TVD, 1535 VS, N92, 1538E 9-5/8" @ 4470' 4491, (341'), NU BOPE Wt. 9.2, PV 16, YP 6, PH 10, WL 14, Sol 4 Drl 4150'-4491', CBU, 15 std short trip, circ Hi-Vis sweep. POOH. RU & rn 103 jt~, 9-5/8", 36# J-55 BTC csg to 4470', FC @ 4381'. RU cmt head, circ, pmp 45 bbl wtr, 1360 sx Arctic Set III + ½#/sx cellophane flake @ 12.2 ppg, followed by 320 sx cl "G" + 29% D-46 @ 15.8 ppg. CIP 0200 hrs, 6-20-85, ND annular & diverter. 4233', 43.6°, N81.1E, 3636.58 TVD, 1700.52 VS, N98.71, E1704.14 4452', 45.5~, N88.6E, 3792.65 TVD, 1853.87 VS, N103.54, E1857.70 9-5/8" @ 4470' 5682', (1191'), Drlg Wt. 9.1, PV 12, YP 4,'PH 10.5, WL 12, Sol 4 NU BOPE & tst to 3000 psi. TIH w/BHA to FC @ 4381'. Tst csg to 1500 psi; OK. Drl FC, cmt, FS + 10' new hole. Perform leak off tst to 11.5 ppg EMW. Turbine drl & surv 8-½"~ho[e,~to .... 5682' ' The above is correct · IDate,~ For form preparation and distribution, see Procedures Manual, Section 10. Drilling, Pages 86 and 87. ITitle Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Inetrucfione: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report olficial or representative test on "Final" form. 1) Submit "lnlerim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of [he week in which oil string is set. Submit weekly for workovers and following setting of oil strin{;i until completion. District Field County or Parish~ ~State Alaska North Slope Borough Kuparuk River Lease or Unit ADL 35634 Alaska IWell no. 3C-11 Date and depth as of 8:00 a.m. 6/22/85 thru 6/24/85 The above is correct For ~rm preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Complete record for each day while drilling or workover in progress 9-5/8" @ 4470' 8859', (3177'), Drl'G Wt. 10.2, PV 12, YP 7, PH_9.5, WL 6.2, Sol 9 Drl f/5637'-8112'. Drl to 8322', POOH, LD MWD, TIH, drl to to 8859'. POH, RU SOS, rn DIL/SFL/SP/GR/CAL/FDC/CNL, f/8859'-4470'. RD SOS, RIH, C&C mud POOH, LD DP. 5776', 44,8°, S86.6E, 4764.43 TVD, 2849.21VS, N54.87, E283.06 6400', 46.9°, S86.7E, 5109.07 TVD, 3287.75 VS, N28.71, E3290.03 7676', 48.9°, S85.7E, 5967.17 TVD, 4231.41VS, N33.81, E4232.25 8242', 48.6°, S88.0E, 6339 TVD, 4658.09 VS, 51.58S, E4658.59 Drilling Super int ende{%~t ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday alter 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 Ihe entire operation if space is available. I Accounting District ICounty or Parish I State Alaska North Slope Borough Field ILease or Unit Kuparuk River ADL 256~4 Auth. or W.O. no. ITitle AFE 604909 I Drill Parker 191 API 50-029-21357 Operator IA.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Spudded 6 / 17/85 Date and depth Complete record for each day reported as of 8:00 a.m. 6/25/85 cOSt center code Alaska IWell no. 3C-ll 7/12/85 I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well I our I Prior status if a W.O. 1200 hrs. I 7" @ 8856' 8771' PBTD, (0'), Prepare to Skid Rig Wt. 10.2, PV 12, YP 7, PH 9, WL 6.2, Sol 10 RU & rn 7", 26#, J-55 HF-ERW BTC csg to 8856'. Mix & pmp 325 sx CL "G" cmt w/3% KC1 + 8%, D-60 & .2% D-46 @ 15.8 ppg. Displ w/10.3# brine. Bump plg, tst csg to 3000#. Full returns. Set slips, cut csg. Install & engerize packoff, tst same. RR @ 0600 hrs, 6-25-85. Well was arctic packed. Old TD Released rig 0600 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data INew TD PB Depth 8859' (6-22-85) 8856' PBTD Date K nd of rig 6/25/85 Rotary Type completion (single, dual, etc.) Single J Official reservoir name(s) I 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 % GOR Gravity Allowable Effective date corrected The above is correct ~,: $..~-,,~©,~ Drilling Superintendent see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Alaska, Inc. ' Post Office Bo,, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 18, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3C-11 Dear Mr. Chatterton: Enclosed are the Well Completion Report and gyroscopic survey for 3C-11. I have not yet received Copies of the Well Histories. When I do, I will forward them to you.' If you-have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/L65 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany -... ..... ~ " ~ STATE OF ALASKA ALASKA L _ AND GAS GONSERVATION GO. WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .. 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-102 ,, 3. Address 8. APl Number P, 0. Box 100360, Anchorage, AK 99510 50- 029-21357 4. Location of well at surface 9. Unit or Lease Name 1177' FNL, 876' FEL, Sec.14, T12N, RgE, UM . Kuparuk River Unit At Top Producing Interval L©C/-"~?iC~NS i 10. Well Number 1408' FNL, 1432' FEL, See.13., T12N, R9E, UM VERiRE,~ 3C-11 At Total Depth ~[ /~/ 11. Field and Pool 1445' FNL, 1028' FEL, Sec.13, T12N, R9E, UM ;. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 82' RKB - ADL 25634 ALK 2567 12. Date Spudded06/17/85 13. Date m.D. Reached06/23/85 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns06/25/85* N/A feet MS L 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 8859'MD,6729'TVD 8771 'MD,6671 'TVD YES [~X NO [] 1767 feet MDI 1700' (Approx) 22. Type Electric or Other Logs Run D I L/SFL/SP/GR/Ca 1/FDL/CNL, CET/Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 116' 24" 215 sx CS II 9-5/8" 36.0# J-55 Surf 4470' 12-1/4" 1360 sx AS III & 320 sx Class "G" 7" 26.0# J-55 Surf 8859' 8-1/2" 325 sx Class "G" 2'4. 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) 8595' - 8640' w/4 spf, 90° phasing 2-7/8" 8492' 8186' ~ 8457' 8582' - 8590' 26. ACID, FRACTURE, CEMENT SOUEEZEi ETC. 8400' - 8386' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8464' - 8466' 100 sx Clas~ G 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I1~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE S E ? 2 0 1985 Alaska O~i ~ b~ ~,,,~. ~ ........... -~;;)r'... Ai~chor~{j~ Form 10407 * NOTE: Tubing was run and the well perforated 7/21/85. TEMP2/WC01 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ':i~ !~;r-:~?.i -!'.ii'!.~/i!_~:Eo~::)~i'~.~F~i~EI~~' ~.'~L"i'~" 'i' ._'-:'~ ,;:::':~!i~~ i~'-i~;'; ::.]-'-'i"';;';~'!{~ -;'{;:.~.;j.:~ ~'~FOR'M~TibNLTES~S . NAME Include interval tested, pressure data, all fluids recovered'and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and.time of each phase. Top Upper Sand 8319t 6373~ N/A . Base Upper Sand 8395' 6423' Top Lower Sand -8565' 6535' - Base Lower Sand 8721' 6638' , . _ ..., 31. LIST OF ATTACHMENTS GvrOscooic Survey ~(2 copies). Addendum - . 32. I hereb{ certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~~ ~ Title Associate E~gineer 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: 7101185 3C-11 RU WL, log well w/gyro & CET. Drilling ~Superintendent · I SUB. SURFACE DIRECTIONAL SURVEY r~ UIDANCE [~ONTINUOUS ~']OOL Company Well Name Field/Location ATLANTIC RICHFIELD g0MPANY -- , 3C-11.(1177' FNL. 876'_FEL. RI&. T12N. RqR_ ,KU~,A~tTK, NORTH SL, OPE~ ALASK~ . Job Reference No_. 70680 Lo~aed 8~: LESNIE Oate m 25-JULY-1985 Comput~:l 8~. BOl.32q GCT iDI~ECTZONAL SURVEY ,CUSTOMER LISTING FOR. ARCO ALASKA, INC. 3C-11 KUPARU~ NORTH SLOPE,ALASKA SURVEY D,~TE: 29 JUN 85 :NGINEER' LESNIE METHGDS 3F COMPUTATION TD3L LOCATION: TANG:NTIAL- AVERAGED DEVIATION AND AZIMUTH INTERP'2LATION: LINEAR VERTICAL SECTION: HDRIZ. GIST. PROJECTED ONTO A TARGET AZIMUTH OF SgUEH 88 DES 1g MIN EASt ARCO &LAS,~Ae INC. 3C-11 KUPARdK NOR TH SLOPE,ALASK CgMPUTATI]N.DATE: 25-JUL-85 PAGE DATE OF SURVf,Y: 29 JJN 85 KELLY BUSHING ELEVATION:' ENGINEER: L~SNIE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED O~.PTH TRUE SUB-SEA CQURSE EASURED VERTICAL VERTICAL DEVIATION AZIMUTH 2EPTH DEPTH DEPTH DEG MIN D,:EG MZN 0.00 0.00 -82.00 0 0 N 0 0 E IO0.DO 100.00 1B.OO, 0 15 N 79 2L E 2.02.00 200.00 118.00 0 21 N $3 19 2 300.00 300.00 Z1a. OO 0 18 N ?0 51 ~ ~O0.DO 399.99 317-99 0 20 N 52 41 E 500.30 499.99 .417.99 0 29 N 59 ~5 E 600.00 599.9~ 517.99 0 35 N ~ 17 E 700.D0 699.98 617.98 0 37 N 52 9 E 800.DO 799.98 717.~8 0 4~ N 58 57 f ~00.00 899.95 817.96 0 49 N 51 50 E 3000.00 2727.25 26~5.26 65 57 3100.20 2797.23 2715,.23 45 17 3200,00 2868.0~, 2786.06. 46. 26 3300.00 2939.75 2857.75 43 52 3¢00.00 3012.25 2~30.26 ~3 1 3500.00 3159.g~ 3077, g~ ~1 ~2 3~00.~0 32~.73 3152.73 61 20 390~.D0 3335.70 3,303. ?0 ~1 d N 8o 50 E 877.82 N 86 59 E 949.01 N 57 9 ~ 1019.4,0 N B7 37 E 1088.88 N 88 ~ E 1157.61 N ~a 1Z E 1225.23 N B8 23 f 1292.22 N 88 28 f 135~.50 N 36 23 E l~Z~.lO a 88 63 E 1489.~8 2000.30 1960.59 1878,59 27 40 ZlO0.O0 Z0,~8.23 1966.23 29 54 2ZO0. O0 Z133.99 2051.99 31 56 2300.20 2217.91 2135.~1 33 55 2~00.00 2299.51 2217.51 36 2500.~0 2377.91 2295.91 *0 7 2600.~0 2452.09 2370.09 ~3 58 2'700.00 2521.68 2~39.5B 2800.00 2589.63 2507.69 %7 2 2900.00 2658.15 2576.15 4~ 33 N a3 51. f 250.28 N 83 13 f 297.89 N Be 50 f 348.86 N 85 15 f N c~5 30 E febO.30 N 85 6.5 E 522.00 N 86 ~ E 58~.69 N 86 30 ~ 659.97 N 86 33 f 733.18 N 86 5i f 805.80 lO00. O0 9'99.95 911.95 1 30 1100.00 1099.83 1017.83 3 58 1ZO0oO0 1199.38 1117.38 6 34 1300.00 1298.52 1215.52 8 6.1 1~00.00 1396.94 1316.94 Il 1~00.00 1494.45 1~12.%5 13 1600.00 1590.88 1509..~8 16 4.5 1700.00 1635.91 1603.91 19 26 ldO0.O0 1779.39 1697.39 22 6 1900.00 .1871.03 1789,03 25 5 N 81 57 E 1.96 1.5~ S 83 40 E 1Z.61 2'70 S 87 47 E 21.93 2.09 N 88 lO E 3~.99 2.86 N 86 2~ f 52..55 2.8~ N ~6. 7 E 7~.58 2.59 N 83 Z~ E 100.72 3.17 N 52 4L f 131.~8 1.96 N 83 23 E 16~.56 2.79 N ~ 19 f 205.19 2.88 4.00 N 8.08 E 9.02 N 63 40 E 3.81 N 12.7,3 E 13.2.8 N 73 20 E 3.11 N 22.03 E 22.24, N 81 56 f 3.08 N 35.10 f 35.13 N 86. .'.59 E 3.9? ~ 52.69 f 52.84, N 85 ~i E 5.83 N 7/+.79 E: 7'5.02 N 85 32 E 8.77 N 101-0~ E 101.41 N 85 Z ~ 12.59 N 131.90 E 132.50 N 85 32 E 16.97 N 157.13 E 167.99 N ~'~ Ii. f 21.15 N 206.90 E 207.9,9 N 8~ 8 E 2.48 2.45 2.13 2.0~ 2.93 4.16 3.77 1.73 O.Z1 0.42 25.66 t~ 251.1¢ E 252..45 N 8, 9 f 31.37 ~ 2'~8.96 E 300,58 N 8~, 0 E' 36.64 N 350.09 E 352.01 N 84 1. E.' ~1.22 ~ 4~.27 E 406.37 N 84 10 ~ ~5.88 ~ 461.86 E 46~.13 N 8~ I9 f 50.58 N 5Z3.72 E 516.Ib N 8~ 28 ~ 55.3,9 N 590.58 f 5~3.17 N 8~ 36 59.91 N 6~2.03 E 6~4.73 N 84 ~9 6~.30 ~ 735.~0 E 738.20 N 85 0 ~ 68.67 N 808.17 E 811-05 N 85 g E 0.8~ 0.71 1.13 1.11 1.35 0.52 0.78 0.65 0.41 0.87 72.42 N 890.3~ E ~83.31 N 85 17 E 76.27 ,~ 951.67 E 956..72 N 85 15 f 79.89 ,~ 1022.20 E 1025.3l N 85 31 f 83.15 N 1091.81 E 109¢.97 N 85 38 f 85.52 ~ 1160.63 f 1163.7~ N 85 ~7 E 87.7~ N 12~8.35 E 1231.,48 N 85 5~ E 89.76 N 1295.~3 E 1298.5~ N 85 2 E 91.47 N 1361.79 E /36~.85 N 86 9 E 93.33 ~ 1427.~ E 1430.52 N 86 i5 E 94.97 N 14~2.93 f 1495.94 N 8~ 21 E 0.00 0.00 0.00 N 0.00 0.2.8 0.16 0.19 ~ 0.2~l 0.74 0.10 0.34 ~i 0.75 L.29 0.0:~ 0.5.3 ~ 1.31 1.76. O.1Z 0.79 N 1.7'5 Z.34 0.0~ 1.20 N 2.37 3.15 0.03 1.6~ N 3.20 ,~.05 O.1l 2.12 N 4.12 5.04 0.29 2.72 ~ 5.13 6.24 0.11 3.41 ~ 6.36 VERTICAL O.OGLEG RECTANGULAR C20RDINATES HDRIZ. DEPARTURE SECTION SEVERITY NDR'TH/SDUTH E~ST/dEST DIS~' AZIMUT~ F,:ET DEG/IO0 FEET FEET FEET' D'EG MIN ~R£D ALASKA, tNg. 3g-ll ~UPAR~K N3RTH SLOP£,ALASKA CC~MPUTATI3N DATE: 25-JUL-85 DATE OF SURVEY.' Zg JJ:N 85 KELLY BUSHING ELEVATION:', ENGINEER: LESNIE INTERPOLATEg VALUES FOR EVEN 100 FEET DF MEASURED DEPTH TRUE SUB-SEA COURSE EASURED VERTICAL VERTICAL. DEVIA'TIDN AZIMUTH DEPT,t DEPTH DEPT~ DEG MIN 4.000. :)O 3`%60.63 3378.53 4,1 4,8 `%100.00 3534.69 3~,5 Z.69 ~2 .37 ~ZOO.~O 3607.73 3525.73 ~3 28 ~300,.00 3679.85 3597.95 ~ IZ 4~00.00 ~750.'99 3668.~39 45 10 ~500.~0 38,21.!3 3739.13 45 3~ 4600.~0 3890.80 3808.~0 ~6 3 4700.00 3959.70 3877.T0 4T ~ 4800.00 ~026.9,3 3'~4 ~. 93 48 18 4900.00 %093.0'~ 4011.09 48 47 .5000.00 4158.80 4076.80 48 58 5i00.00 %224.24 4147.24 5200.00 %289.24 4207.24 49 36 5'300.00 %353.77 4771.77 49 59 54.00°00 44.17.77 4'335.77 50 5500.00 ~481.22 4399.22 50 47 5700.00 %608.30 4526.30 %7 43 5800. D0 %677.89 4595.~9 44 56 5900.30 4748.62 4665.62 45 6 6000.00 ~818.91 4736.'~1 6100.00 %888.80 4805.80 %5 50 6ZOO.gO 49.58.23 4,~76.23 46 6.~00.00 50ZT.ZT 4945. 6400.~0 ~095.8~ 5013.88 46 6500.00 5163.87 5061.87 47 19 6~00.00 5231.56 5~49.56 6~00.~0 5299.03 5217.03 47 41 6800.~0 5366.15 5284.15 47 58 6~00.00 5433.~3 5351.13 DEG MiN PAGE ~ ~2. O~ FT' S 81 45 E S ;82 13 E 2343.80 S ~12 ICJ E 24'19.37 S 82 2~ E 2495.36 S 82 4~) E 2571.~1 S 82 5~ E Z6~6.75 S 83 5 E 2725.1.8 S B2 3 E 2~73.84 S 82 1'~ E 301q,.84 S ~12. 2.8 r:. 3085.99 S 82 23 ~ 3157.58 S 82, 2Z E 3229.54 S 82 27 E 3301.91 S 82 3~ E 337%.86 S 82 32 E 344B.09 S 8Z 35 E 3521.52 S 82 43 5 3595.29 S ~2 ~3 E 366~.21 S 62 43 E 3742.76 S B2 46 ?. 3816.35 S ~12 47 E 3590.14 S ~32 53 E 396~.00 S 83 9 E 4112.77 S B3 IL E 4187.72 S 83 3L ~ 4338.78 1.05 1.07 0.65 0.82. 0.8,% 0.63 0.61 5.68 1.89 0.66 O. 5.$ 0.77 0.39 0.36 0.55 0.52 0.15 4.6?,. 0.65 0.68 0.2,~ 0.11 0 0.40 0.33 0.04. 0 0 0.50 0.67 0.63 0.15 0 0.23 0.68 0.39 0.28 0.43 0.3~, 96.38 ly 1559.14 E 1562'I1 N,.: 85' 27 E 97.7:~ lY 1626.31 E 1629.24 N 86 33 E 99.17 N 16'94.6'3 E 1697'50 N 8~ 39 E 100.59 N 1763.86 E 1766.72 ,,N 85 44 E 102,.03 N 1834.1Z ~ /836.,95 'N 86 48 E 103.53 N 1905.3B f 1908,1'9 N 8~ 53 -~ 105.3~ ~ 1977.08 E 1979.89 N 86 56 ,105.74 ~ 1049.54 E 1052.27 N 87 2 ~ 98.33 N 21Z3.15 E 2125.43 N 87 ZO E 87.25 N 2197.37 E 2199.05 N ~7 ~3 E 76.21 N 22'71.88 ~ 2.2.73.15 N 8E! 4 ~: 65.64 N 23,%6.75 E 234.7.68 N 8a 23 E 55.4.0 ~ 2422.06 E 2/*22.70 N 88 41 E ~5.31 N 1497.76 E 7498.~9 N 8,a 57 E 35.41 N 2573.97 E 2574.22 N 89 1Z E 25.67 N 1650.66 E 2650.78 N 8~ 26 E 16.15 N 27~7.8~ E 2727.89 N 89 3'9 E' 6.71 ~ 2803.87 E 2803.88 N 89 51 E 3.10 S 2875.00 E 2875.00 S 89 56 E 12.80 5 29~5.02 E 29~5.05 S 8} ~5 E 22.36 S 3015.49 E 3015.58 S 69 34 E 31.80 S 3096.39 E 3086.5& S 89 2.4 E ~1,25 S 3157,?~. E 31.58,01 S 6~ 15 E 50.8~ S 3ZZ9.45 E 3129.85 S 83 5 E 60.~5 S 3301.55 E 3302.11 $ 8:3 57 E 70.07 S 3374.26 E 3374.99 S 8~ 48 :~ 79.6~ S 3~7.2~ E 3~8.16 S 83 ~0 89.17 S ]SZO.~3 E 3571.55 S 8~ 37 c 98.6Z S 3593.9~ E 3595.30 S 8~ 25 ~ 107.99 S 36~7.67 E 3669.2I* S 8~ 18 ~ 117.38 S 37%0.93 E 374.2.77 S 88 1Z E 116.69 S 38/4..25 E 3~16.38 S 88 5 E 135.98 S 38aT.8Z E 3890.20 S 87 59 e 145.13 S 3951.4~ E 3964.10 S 87 ~4 ',5, 154.39 S 4035.44 E 4038.39 S 87 48 E 163.37 S 41~9.7~ E %112.98 S 87 %3 E 172.35 S 418~.46 E ~188.01 S 87 38 E 181.28 S ~259.6~ e eg63.50 S 87 33 ~ 190.06 S ~3~.06 E ~339.23 S 87 2~ E 198.3l S 4410.37 ~ ~41~.83 S 87 25 E N ~8 43 ~ 1555.52 N 88 4'9 E 1622.72 N 88 48 E N 68 4~ E 1760.12 N ~8 39 ~ 1901.49 N 88 33 ~ 1973.12 S 87 37 E 2045.53 S 81 58 E 2119.~3 ~ 81 ~; 5 2~93.79 7000.00 5500.,%8 5418.~.8 47 7100.'~0 5567.81 5485.81 47 41 7ZO0.O0 5634.93 5552.93 ,%7 51 7300.~0 5701.9~ 561~.38 4T 5'=~ 7~00.00 5768.61 5685.51 48 l`% 7~00.~0 5834.93 5752.'~3 %8 37 7500.00 5900.78 5818.78 48 59 7700.00 ~9~6.11 5884.[1 49 19 7800.00 $031.1~ 59~9./8 49 2,0 7900.00 5096.46 6~14.46 49 9 VERTICAL :DOGLEG RECTANGULAR CDORDIN,'ATES H. EIRiZ. DEPARTURE S~CTIDN SEVERITY NDRTH/SDUTH EAST/WEST DIST. ,, AZIMUT~t FEET DEG/"IOO FEET FEET FEET~ ' ' D:EG M, IN kRC~ ALASKA, INC. )C-11 ~,LJP AR'JK qgRTH SLOPE,ALASK~ CgMPUTATIDN FATS: 25-JUL-85 PAGE DA~E OF SURVEY: 29 J~N'~5 KELLY BUSHIN~ ELEVATION: ENGINEER:' L~SNI~ INTERPOLATEO VALUES FOR EVEN 100 F,E!ET OF MEASURED DEPTH TRUE SUS-SE& COURSE =..ASUR~D VERTICAL VERTICAL DEVIA'TI2N AZIMUTH DEPT,9 DEPTH OEPTH Ding MIN DEG MIN VERTICAL DOGLEG RECTANGULAR C~O~OINATES HDRIZ. DEPARTURE S:ECTI3N SEVERITY NI3RTH/S~U'TH EAST./alEST DIST,. A"ZIMUTH FEE~ OEG/~O0 FEET FEET FEET, D,'E~ MIN 6000.DO 5161.92 .6079.92 49 9 6100ogO 522'7.50 6145.50 46 49 BZODoO0 52.'93.69 6211.59 8300.D0 5359.89 6177.89 ~8 24 B~O0.O0 5426.3L 634¢.3~ 48 27 8500.D0 54~2.23 6410.23 ~8 50 8500.~0 5558.20 6475.20 48 49 6700. g0 5613.90 65~,1.90 ~8 5,2 8800.00 5689.99 6607.99 48 36 885,~. O0 5729.00 6~47.00 ~8 0.35 0.72. 0. ~'3 0.40 0.73 0.51 0.94, 3.2.5 0.00 0.00 206.25 S ~485.5~ ~ ~490.~28 S 8'7 22 E 214..21 S 45b0.63 E 4565.65 $ 212.10 S 4635.16 E 4640.,~8 S 87 15 E 219.78 ~ ~709.7~ E 4715.31 S 8~' It E 236.98 5 4784.13 5 4789.99 S 87 9 E Z~4.0Z S ~858.99 E ~865.:11 $ 87 7 ~;: 250.90 ~ 4~33.83 E 4940.10 $ 87 . 5 257.46 S 5008.~.3 ~ 5015.5~ S 87 Zb~.O0 S 5083.6~ ~ 5090.5~ l,b7.87 S 5127.79 E 5134.78 S 87 0 E 3C-11 &UPARdK ~DRTN SLDPF,ALASKA T~UE SUB-SEA COURSE EASUR'ED VERTICAL VERTICAL DEVIA'TION AZI~qUTH DE PT :'1 DEPTH DEPTH DEG Hi.N £,3MPU'TATI]N DATE.: 'ZS-,JUL-85 PAGE DATE' OP SURVEY: 2g J~JN 8.5 KELLY ~USHI. NG EL~¥'ATZO~..'" ENG[N~i:[: LESNZE INTERPOLATED VALUES FOR EVEN LOOO F~.ET DF NEASURED ~EPT VERTZCAL DOGLEG RECTANGULAR C,30RD[NATES H~R['Z. DEPARTURE SECTION SEVERITY NDRTHt'SDU'TH E~ST/WF'ST DI. ST,. A'Z,[MUT~ FEET DEG/IO0 FEET FEET FEET ~ OEG RZN 0.00 1.05 0.58 0.67 0.35 0.00 62..,,00 FT' 0.00 O.OD -8Z.O0 O' 0 1900.~0 999.95 917o95 ' I 30 2.000.00 ).9b0.5~ 1875.59 2.7 ~,0 3000.gO Z727.26 26~5.Z6 45 57 ~000.00 3~0.63 3378.63 41 48 5000.00 ~158.80 4075.a0 ~8 5~ 6000.~0 ~818.~1 4736.91 45 ~9 700~.30 ~500.4a 5410.~8 ~7 4Z 8OOO.O0 5161.9Z 6~79.92 49 9 8859. DD 57Z9.03 6~4Z.00 ~8 3.6 0.00 N O.Og E 0,.00 N 0 0 E 4.0.0 N 8.00 E 9.,02,' N 63 ~,0 2.5.66 N 251.1~, E 2.52,.45 N 8q, '9 E 72.4Z N 880.3¢'E 8~3.,3! N' 85, 17 96.38 N 155g.1~. E .1.562.111 N 8,5 27 76.21 N 2271.88 E 2273,16 N 88 4 Z2..36 S 30[5.4'9 ~- 3015.58 S 8m9 34 117.38 S 37~0.93 E 37~Z.7'7 S 8~ 12 ,. 206.25 S ,~,~5.5~, E ~,~90.2..8 $ 87 Z2 267.87 S 51,27.79 E 513,~.78 S ~7 0 ARCO A'LAS~A~ [NC.. 3£-11 KUPARUK N,2RTH SLOPEs ALASKA CgMPUTATI3N DATE: 25-JUL-85 PAGE DATE DF SURVEY:' 29 J.~N 85 KELLY 8USHiN~ ELEVATION: ENGINEER: LESNIE iNT~RPDLA'TED VALUES F3R EVEN .LO0 EEET OF SUB-~EA DEPTH TRUE SU,'B-SEA COURS'E EASUR~:D VERTICAL VERTICAL DEVIATION AZIMU[H OE. PT~ DEPTH DEPTrl BEG MIN DEG MIN 0.00 -8Z.00 0 0 82.00 0.00. O' 16 122.00 100.. O0 0 20 2~Z.00 . 200.00 0 18 382.00 300.00 0.' 1'~ 482.00 400.00 0 28 582.00 500.00 0 3~ 682.00 600.00 O' 36 7~tZ.O0 700.00 0 42 88Z.00 800.00 0 ~9 0.00 82.00 182.~0 282".~0 382.~1 ~8Z.31 58Z,.01 782.02 882.03 82- O0 Fl VERTICAL DOGLEG RECTANGULAR C'2ORDINATES H:IRI'Z. DE. PARTJRC S~CTION :SEVERITY NORTH/SOUTH E,AST/~EST DIST., AZIMUT~ FEET ~EG/IO9 FEET FEET FEET OEG MIN N 0 0 E O.O0 0.00 N 70 ~ E 0.20 0.~3 N 51 2~ E 0.65 0.16 N 73 5 ~ 1.ZO 0.08 N 5~ 2'3 E 1.66 0.16 N 58 45 E 2.21' 0.17 N 63 50 E 2.98 O.Z~ N 61 '~ E 3.88 0.16 N 58 15 E ~.85 0.20 N 61 B f ~.OZ 0.07 N 77 52 E 7.54 1.17 S ~4 25 E 11.45 2.58 S 86 55 E 19.98 2.17 N 86 52 E 32.54 2.98 N ~6 3~ E 49.57 2.65 N ~ 15 E 71.52 2.~ N 83 2Z E 98.13 3.01 N 82 4L E 130.12 2.92 N 83 Z~ E 167.61 2.78 N U~ 25 E 211.27 2.76 982.05 982.00 900.00 I 17 1082.13 1082.00 1000..00 3 30 1182.50 11~2.00 llO0. O0 6 1Z83.~0 12~2.00 1200.00 8 13~.~..75 1382.00 1300.00 11 '7 1~87.17 1452.00 1~00.00 13 38 1590.7~ /582.00 1500.00 16 28 1695.36 [682.00 1600.00 19 1802.~2 1782.00 170~.00 22 1'91Z.11 /88£.00 1800.00 25 25 202~.Z6 1982.00 1900o00 28 13 2139.14 2082.00 2000.00 30 43 2256.92 ZlaZ.O0 2100.00 35 3 2378.20 2232.00 2200.00 36 9 2505.33 2392.00 2300.00 ~0 ZO 2542.09 2482.00 2400.30 ~5 29 278S.71 Z582.00 2500.a0 ~7 5 2934.64 2682.00 2500.00 46 22 3078.32 278Z.00 2700.00 45 24 3Z19.50 2882.00 2200.00 N 83 Z} E 261.56 N 83 55 E 317.47 N 25 13 E .379.24 N 85 47 E 525.41 N ~6 23 6 618.17 N 86 35 E 724.95 N 86 5Z E 83~.83 N ~6 57 E 93~.63 N ~7 It,.= 1032-97 , 3~58o~3 2982.00 2900.00 ~,5 31 3~9~,. 8~ 3082.00 3000.00 42 25 3529.57 3182.00 3100.00 ~1 40 3762.77 3282.00 3ZO0.O0 41 1 3895.09 3382.00 3300.00 41 4028.76 3482.00 3~00.00 ~2 2 ~16+.o $1 3582.0'~ 3500.g0 ~,3 12 4303..00 3682.00 3600.00 44 13 4 ~,4 ~,. 16 3782. O0 3700. O0 45 4587.32 3882.00 3800.00 ~,5 5'9 2.30 2.23 2.10 2.95 4.28 3.41 0.32 0 0.47 0.50 0.65 0.54 0.6'9 O.Z~ 0.80 0.62 0.88 0.87 0o72 0.46 0.00 N 0.00 0.1'7 N 0.20 0.29 N 0.66 0.50 N 1.21 0.72 N 1.6~ 1.12 N 2.2¢ 1.56 ~i 3.03 Z.03 ~1 3.95 2.60 ~ 4.93 3.28 N 6.12 3.92. N 7.65 3.93 ~ ii.57 3.20 hi ZO. 0~3 3.01 hi 32.65 3.78 N ~9.71 5.52 N 71.72 0'00' N 0 O' g 0 o, 2~"' N 0.7Z N 6~ 19 E 1.31 ,N 67 37 E 1.83 N 2'51 N 63 22' 4: N 62. ~5 5.5'B' N 62 12 6.94 N 61 8.47 N 98.42 E 98.79 N 85 5 E 12.42 N 130.55 E 131.13 N 8¢ 33 E 17.09 N 158.19 E 1.69.0~ N 8~, Il ~ 21.75 N ZLZ.O/ E 213.12 N 84 8 E 26.92 hi 252.4.7 E 263.8'~ N 8~ 8 E 33.58 N 318.60 ~ 320.37' N 83 58 e 39.25 hi 380.5,5 E 382..58 N 8~ 6 E 4,~.86 N 4~8.9Z E ~51.I'6 h 8~ L7 E 50.84 N 527.1~ E 529.5~ N ~ 29 a 57.32 N 620.13 E 622.77 N 8~ ~3 ~ 63.82 ~ 7Z7.15 E 729~9~ N 8~ 59 69.84 N 833.25 E 836.18 N 85 1Z 75.46 N 936.2b E 939.30 N 85 23 ~ 80.56 N 1035.80 ff 1038.92 N 85 33 ~ 84.62 & 1132.1~* E 1135.30 N 85 43 E 87.63 N 1224.88 i 1228.01 N 85 SA, E 90.29 N 1315.12 ~: 1318.22 N 86 4 E 92.63 N 1403.07 E 1406.13 N 85 13 E 94.90 N 1~69.70 E 1492.72 N 85 21' E 96.78 N 1578.3~ E 15~1.33 N 8S 29 E 98.67 N 1670.31 E 1673.22 N 8~ 37 E 100.63 N 17~5.91 E 1768.81 N 8~ *~ E 102.66 N 1~65.5~ E 1868.37 h 8~ ~1 E 105.12 N 19ST.96 E 1970.77 N 86 56 E 8.60 N 62 52 E 12.22 N 71 13 E 2.0.,,34 N 80 5'7 6 32.7'8 N 84, 43 E ~9.85 N 85 38 E 71.,93 N 85 36 E ARC3 AL~S[A~ .2. NC. 3C-11 KUFAR~JK NORTH SLOPE~ALASKA COMPU'TATI 3N .D~TE: ZS-JUL-85 PAGE DATE OF SURVEY: 2.9 JJN B5 ~ELL~ ~USH[NG ELEVATION: ENGINEER: L~SN[~ INTERPOLA'TE~ VALUES FOR EVEN LO0 FEET OF SUB-SEA DEPTH TRUE SUB-SEA CDURSE E&SURED VERTICAL VERTICAL DEVIATIgN AZIMUTH :3EPTH DEPTH DEPTH DEG M~N D~G MIN ~.732.90 3982.00 3900.00 47 33 4:18.3.20 B082.00 4000.00 ~,8 42. 5035.39 ~182.00 4:lO0.O0 49 7 5188.84 ~282.00 4200.00 49 3~ 53~3.98 ~382.08 4300.00 50 10 5560.'19 ~582.00 4503.00 49 45 5805.30 ~682.00 4600.00 44 55 5947.~1 ~7~2.00 ~700.00 ~5 19 6090. Z4 ~882.00 4~00.00 ~5 4~ 6234.31 f, 982. O0 4~00.00 ~,6 ].4 6579.?0 5082..00 5000.00 ,~6 49 6526.77 .~182.00 5100'00 , ~7 21 667~.?1 ,5282.00 5200.00 ~? 37 6823.58 5382.00 5300.00 ~7 58 6972.$6 5482.00 5400.00 47 3'/' 7121o10 55~2.00 5500*00 47 47 7~70.~9 5682.00 5600.00 47 53 7~20.L8 5782.00 5700.00 48 Z5 7571.~0 5882.00 5800.00 48 52 7724.~0 5982.00 5900.00 q, 9 23 7877.87 5082.00 6000.00 49 13 8030,. 57 SISZ.O0 6100.00 49 8182.$6 5222.00 5200°00 48 28 8333.30 5382.00 5300.00 ~8 25 8~8~.~4 5482.00 6400.00 ~8 8536.25 5582,00 6500.00 49 2 8787.92 5682.0~ 6~00.00 ~8 36 8B~9. DO 5729.03 65~7.00 8z.oo 5.54 0.50 0 0.35 0 0.53 5.72. 0.59 0.37 0.13 0.57 0.38 0.35 0 °30 0.13 0.60 0.60 0.38 0.18 0,.43 FEET FEET FEET ' · 10,~,22 N ZOZ3.68 E 2076.30 N 87 7' 89.13 N 21~3,~.83 E 21,86,;,65 N 87 39 72.4Z N 22:~8.35 E 22'gg',~g N 88 56.55 N 2413.65 E 2414',31 N 88 39 E ~0.9~ ~ ~53[.~Z ~ 253[.55 N 25.55 N 2651.6[ E ~65[.73 N 89 10.54 ~ 277~.~5; ~ 277~.,27 N 3.66 S 2879.05 E 28'79.05 ",,S 89 17.3~ ~ 29~8.3~ E 2978.42 30.88 S 3079.~6 E 3079.61 S 89 25 ~.53 S 31~Z-27 E 3182.,58 S 89 11 E 58.S1 S 3286-87 E 3287.39 S 72.63 S 3393.79 E 339&.57 S 88 ~6 E 86.76 S 3501.89 E 3502'97 S 88 100.88 S ,3611.~0 E 3612.81 S 11~.80 S ,3720-8t E 3722.5~ S 68 13 E 128.65 S 3~29.7'7 E 3831.93 S aa ~ E 1~Z.~8 S 3939.~& E ~9~2'.05 S 87 55 E 156.22 S ~050.~3 E ~053.~ S 87 ~7 E 169.78 S ~163.0~ E 8166.51 S 87 0.38 0.39 0.29 0.28 0.65 0.42 0.59 0.00 0.00 183.46 S 4278.02 E ½2~1.,96 S 8'7 32 E 196.54 S 43'93.72 E 4398.11 S 87 2.6 E 208.68 S 4508o6.1 E ~513.43 S 87 20 E 220.72 S 4622.03 F,, ½627.30 S 87 15 E 232.21 S ~734.50 E 4740.19 S 87 I1 E 242.94 $ 48~,7,,3! E 6853.40 S 87 7 r 253.30 S 496,1..07 E 4967°$3 S 87 4 263.21 S 5014.66 E 5081o48 S 87 1 r_ 2.67.87 S 5127.79 E 5134.78 S 87 0 E FEET DEG/IOO 'VE~T:CAL DOGLEG, RECTANGULAR C3ORDJ:NAT~.S H'DRIZ' DEPARTJR~ SECTION SEVERITY NORTH/'S:3UTH EAST/~EST DIST'. .!,, AZIMUT~ A~CO ALASN~A, INC.. KdPARdK NORTH SLQP~,ALASKA HA~K~R TOP UPPER SAND 6ASE UPPER SAND TOP LOWER SANO BAS~ LOgER SAND P~TO T2 COMPUTATION DATE.: 25-.JUL-B$ PAGE INTERPOLATED VALUES FCR CHOSEN ~ORIZONS MEASURED 3EPTrl 6319.00 53~5.00 6565.00 8721.00 8771.00 8859.00 DATE OF SURVEY: 2g JJN 85 &ELL¥ ~USHING ELEVATIQN: ENGINOER: LESNIE ~Z..O0 F~ S UR FA"C E LOCATION ORIGIN= ~177' FNL,. B?6' FEL~ SE.C~I'~. TZ2N, R~E' JM TVD R~C'TANGULAR 'COORDINATES FROM KB SUB-SEA NORTH/SOUT~,,'~'.EAS~'/~EST 6372.52 6290.52 6~22. ~19 $3~0.99 6535.09 ~,53.0~ 6537.76 ~55.5.76 6b70.81 6588.81 6129.00 5647.00 ARCO ALA$,(,A~ [NC. K~PARLJK NORTH SLDPf:~ALASKA TL~P t~A,S E TOP BASE PBT.~ TD UPPER SAND UPPER SAND LOWER SAND LOdER SAND COMPUTATION DATE: £5-.JUL-85 ~000~0~ STRRTIGRAPHIC SUMMARY PA~E ~ DATE OF SURVgY: 29 Jg!N,~5 KELL~ BUSH~N$ ELEVATION: 82.0~ ENG'iNEER: LESNIE MEASURED ~EPTH BELOW K~ FROM KB ORIGIN: 1177~ FNL, a76' TVD REC SUit-SEA NO 8319.0~ 6372.52 6290.52 8395-0D 6%2Z.99 63z~O.gg 85'55.00 6535.09 6453.09 $7Z!.00 6637.76 '6555.T6 8771.00 6670.81 6588.8[ ~859.00 6729.00 66~7.00 SURFACE LOC:ATIDN FEL~ SEC Z4 TlgN,, TANGULAR CO[RD1N.&'T ~S RT~t'SOUTt: ,EA:STI.~E'ST · , Z31.18 S 4'7'2:3.85 Z36.62 $ ~80. ~1 Z.8o53 $ ' &907.55 258.83 S 502,~. ~35 26Z.10 $ 5062.02. 267.67 S ' 5[27.79 FINAL WELL L~CATI@N AT TO: TRUE SU6-$EA MEASURE,,2 VERTICAL VERTICAL 'DEPTH D:'P[H DEPTH 8859.0:) 672.9.00 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET OEO MIN 513%.78 dM SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCo ALASKA INC WELL 3C- 1 1 F ! 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Reports and Materials to be received by: Date Required Date Received Remarks Completion Report Well History Samples Core Description fA/~~- __ ~ ., ~/~ . . / InclSnation Survey Directional Survey Drill Stem Test Reports Production Test Reports .. Log Run Digitized Data ARCO Alaska, Ir'-~--. Post Offk .)x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-30-85 TItANSMITTAL NO:5214 RETURN TO: A~CO aLASKA, INC. KUPARUK OPEkaTIuNb ~NGINEE~ING kE~,ORD5 CLERK ATO-1115B P.O. ]~OX 100360 ANCH(3kA~E, Al< 99510 TF, A['~blITTED HEREWITh Ak~ Till FOLLOWING ITEMS PLEASE ACKNO~LIJDGE tt~JCEIPT AND RETURN ONt3 SIGNED COPY t;F ThIS TIxANSMITTAL. t)PLi'~ hOLE FINALS/SCnL/ON~ * 3C- 1 ~---"-' 2" DIL/SFL-GR 07-02-85 RUN #1 1786-~962 ~ ~5" .DIL/SFL-GR 07-02-85 RUN #1 17~6-~962 ~-----2" DEN/NUU-GR RAW 07-02-~5 RUN #1 8290 8937 ~ - '~ ~5" DEN/NEU-GR RAW 07-02-85 RUN ~1 746~-8937 ~ -- 5" DEN/NEU-GR PORO 07-02-85 RUN #1 8290-8937 ~' --' 2" DEN/NEU-GR PO~O 07-0-2-85 ~UN ~1 8290-~937 ~ ~7 CYL~ERLOOK 07-02-85 RUN #1 8500-8900 .5" DIL/SFL-GR - 06-16-85 RUN ~1 3772-7569 2" DIL/SFL-GR 06-16-85 }{UN #1 3772-7569 5" DEN/NED PORO 06-16-85 RUN ~1 6000-7543 ~" ~/~.~u ~0~0 06-~6-~ ~UN ~ ~000-754~ 5" D~N/NEU RAW 06-16-85 RUN ~1 6000-7543 2" DEN/NED RAW 06-16-85 RUN ~1 6000-7543 CYBE~OOK 06-16-85 ~UN ~1 6000-7520 5" DEN/NEU-GR POaO 07-10-8 5 RUN ~1 4500-8279 2" bEN/NL~-GR PORO 07-10-85 RUN ~1 4500- ~279 3 C- 1 ~"'x'° 5'' DIL/SFL-GR 06-23-85 RUN #1 4473-8854 "~2" OIL/SFL-Gi< 06-23-85 RUN #1 4473-8854 ~"J5" DEN/NEU RAW 06-23-85 RUN #1 8100-8828 2" DEN/N~U RA~¢ 06-23-85 I~UN #1 8100-8828 5" DEN/NEU PORt; 06-23-85 RUN #1 8100-8828 2" DEN/NEU PORO 06-23-85 RUN #1 8100-~28 ~-- CYBERLOOK 06-23-85 R~CEIPT ACKNOWLEDGED: DI~'EixIi~ UTION: ~ BPAE DRILLING*BL W. PASHER B. CURRIER L. JOHNSTON EXXON CHEVRON MOBIL PHILLIPS OIL D & M*bL N~K CLERK*i~L J. RATHMELL*BL · #1 ~100-8~05 -'7"m"~ka 8;, ,',. ....... , ~ ' STATE O~n~,~'~K~KA* B L sohio UNION K.TULIN/~AULT*FILM ARCO Alaska. Inc. is a Subsidiary of AllanlicRichfieloCompany ARCO Alaska, In~~--'''~ Post Office'Y-~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-21-85 TRANSMITTAL NO: 5296 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK · ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETU~q ONE SIGNED COPY OF THIS TRANSMITTAL. SEQUENCE OF EVENTS FROM WELL SERVICE REPORTS PRESSURE DATA "~iC- 4 '~ 07-23-85 '-' 1C-5 ~ 07-29-85 '-'1C-5/ 07-30-85 '~iC- 6 ~ 07-25-85 ""-lC- 6 ~' 07-24-85 ~lD-8-~'-- 07-30-85 STATIC BHP PBU PBU STATIC BHP STATIC BHP STATIC BHP --~lH-3~ "07-30-85 · STATIC BHP "---1R-5~ 07-05-85 -"-'1~{- 6-' 07-06-85 --" 1R- 8-- 07-U~-85 ~' 1Y-10- 07-27-85 ~ 1Y-11 -- 07-28-85 -'" 2A-2 .~- 07-04-85 ~"' 2B-i3" 07-30-85 ~-"2U-14~ 06-30-85 ~ 2U-14~- 07-01-85 "' 2U-15~ 07-08-85 '" 2V-2 07-27-85 "' 2V- 2~- 07-28-85 "- 2W-7-~ 07-26-85 ~2W-7' 07-27-85 ~' 2X-15~ 07-09-85 "2X-15 '/ 07-U4-85 "2Z-l~ 07-05-85 ~2Z-6- U4-08-85 "3B-7 ~ 06-27-85 "3B~8-~ 06-28-85 --, 3B-8--" 06-27-85 '~ 3B-9 ~ U7-18-85 ~' 3B-11 07-20-85 "3B-12'- 07-21-85 ' 3C-11-" 07-29-85 ]~HP & MISC. BHP & MISC. STATIC BHP & t,~ISC. STATIC BHP END OF PBU 'C' SAND STATIC BHP PRESS UkE DATA 'A' SAND PBU 'A' SAND PBU PRESSURE TEST & ~IISC. 'A' SAND PBU 'A' SAND PBU 'A' SAND ONLY PBU 'A' SAND PBU FLO~ING BHP & FLUID I.D. FLOWING BHP & TEMPEKATURE BRP SURVEY & MISC. STATIC BHP STATIC BHP & MISC. STATIC BHP & MISC. BHP & MISC. STATIC BHP & MISC. BHP SURVEY & MISC. STATIC BHP & MISC. STATIC BHP ,~ MISC. RECEIPT ACKNO%{LSDGED: BPAE* B. CURRIER CHEVRON* D & M* DISTRIBUTION: DRILLING W. PASHER L. JOHNSTON EXXON MOBIL* PHILLIPS OIL* NSK CLERK J. RATHMELL* ' ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompanY CAMCO DRESSER ATLAS DRESSER ATLAS CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DRESSER ATLAS OTIS OTIS OTIS OTIS OTIS OTIS OTIS 'OTIS OTIS OTIS OTIS OTIS CAMCO CAMCO OTIS CAMCO CAMCO CAMCO CAMCO STATE OF "AL'A'SKA* SOHIO* UNION* K.TULIN/VAULT ARCO Alaska. in/ Post Office -ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-21-85 TRANSMITTAL NO: 5292 KETURN TO: ARCO aLASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED RECEIPT AND KUPARUK WELL ' lB-1 r- 05-3 lB-2.- 05-3 -~'lB-4- - 05-1 HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. PRESSURE REPORT--ENVELQPE FACE DATA 0-85 CAMCO ~3B-15 05-28-85 OTIS 0-85 CAMCO 3B-16- 05-28-85 OTIS 6-85 CAMCO ~ 3C-11-- 07-29-85 CAMCO 07-24-85 07-25-85 07-30-85 07-30-85 06'24-85 06-23-85 06-21-85 06-21-85 07-05-85 07-06-85 07-06-85 07-08-85 07-04-85 07-26-85 07-11-85 08-04-85 06-14-85 06-14-85 06-28-~5 06-15-85 06-15-85 06-26-85 06-26-85 06-28-85 06-27-85 06-28-85 07-18-85 07-20-85 07-20-85 07-21-85 05-29-85 05-29-85 CAMCO CAMCO CAMCO C~CO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO OTIS DRESSEI{ OTIS OTIS ???? CAMCO OTIS CAMCO CAMCO CAMCO CAblCO CAMCO CAMCO OTIS CASICO CA/rICO CAMCO CAMCO OTIS OTIS RECEIPT ACKNO~LEDGED: BPAE* B. CURRIER CHEVRON* D & M* DISTRIBUTION: DRILLING ¥'{. PAShER L. JOHNSTON EXXON bYOB IL* PHILLIPS OIL* NSK CLERK J. RATHMELL* STATE OF ALASKA* SOHIO* UNION* K. TULIN/VAULT ARCO Alaska. Inc. ~s a Subsidiary of AllanlicRichfieldCompany STATE OF ALASKA ~'. ALASKA oIL AND GAS CONSERVATION CO,MISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: S~a~e o£ Alask~ _,i/asia Oil and Gas CcnservatSon Cornrdssion 3001 Porcupine Drive Anchorage, Alaska 99501 Receipt of the following material whiCh was transmitted via /~// is hereby acknowledged: ~,UANTITY DATED: ,~--~ ~ ~ Copy sent to sender YES . NO _~ STATE OF ALASKA ALASKA oiL AND GAS CONSERVATION CO._.[ISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 T~':~a Oi] and Cas Conservaffon Commission 3001 Porcupine Dffve Anchorage, Alaska g9501 RE: Receipt of the following material whiCh was transmitted via ~i/ is hereby acknowledged: QUANTITY RECEIVED: DATED: Copy sent YES to sender No ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-0 8-85 TRANSNITTAL NO: 5285 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING ~xE CO~dJ~ CLEkK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. ~ ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED IN BOX 1 OF 2: OPEN ~OLE LIS TAPES PLUS LISr£INGS (ONE COPY OF EACH.) 3C-ll 06-23.-85 RUN #1 4427.5-8881.5 REF #70597 3C-10"' 07-02-85 RUN #1 1785.0-8987.5 F, EF #70620 3C-9f 07-10-85 RUN #1 3920.0-8332.5 REF #70642 3C-7" 07-31-85 RUN #1 4617.5-8747.5 REF #70706 3B-14-- 03-20-85 RUN #2 3280.0-6~03.5 RI,:F #70229 3B-12-' 07-03-85 RUN #1 4021.5-8261.5 REF #70641 3B-11~ 06-26-85 RUN #1 2190.5-9257.0 REF #70598 3B-10~ 06-17-85 RUN #1 3273.0-7270.5 F, EF #70555 3B-9----- 06-10-85 RUN #1 2092.0-8415.0 REF #70634 2Z-15"' 06-19-85 RUN #1 2658.0-6620.0 REF #70562 2Z-14/ 06-28-85 RUN #1 3876.0-8334.0 REF #70600 2Z-13'~' 07-05-85 RUN #1 4180.0-8538.5 REF #70639 2Z-i2~'- 07-20-85 RUN ~I 4409.0-9412.5 REF #70661 2Z-11.~' 07-27-85 I-<UN #1 3531.5-7534.0 REF #70704 COPY OF THIS TRANSMITTAL. IN SOX 2 OF 2: .OPEN___HOLE LIS TAPES PLUS LISTINGS (ONE COPY OF ' 2W-16~-~ 01-28-85 RUN #1 3116.0-7038.5 REF --2V-14'~/ 05-16-85 RUN #1 3047.0-7086.5 REF 2V-12t/ 04-22-85 RUN #1 3960.0-9265.0 REF 20-10/ 04-11-85 RUN #1 2972.0-7063.0 REF 20-7~/~ 03-1-9-85 RUN #1 3594.b-8179.5 REF 2A-13~'~ 07-16-85 RUN #1 7649.5-8160.0 1R-13'~'' 07-27-85 kUN #1 3940.0-8578.0 REF 1R-12 / 07-20-85 RUN #1 3935.0-8277.5 KEF 1R-11~'~ 07-13-85 RUN #1 3810.0-7213.5 1R-10~''~ 07-06-85 RUN #1 2991.0-8738.0 REF 1R-9"'.-~'~ 06-28-85 RUN #1 3991.5-8131.0 REF 1R-7/~ 06-04-85 RUN #l&3 0045.5-7103.0 kEF EA(Jit) # 70436---REVISED # 70614---REVISED # 70613---REVISED # 70612---NEVI :SED # 70505---REVISED #70645 #70702 #70660 #70643 #70640 #70601 ~70509 RECEIPT ACKNONLEDGED: DISTRIBUTION: BPAE DRILLING W. PASHER B. CURRIER L. JOHNSTON EXXON CHEVRON MOBIL PHILLIPS OIL D & M NSK CLERK J. RATHMELL AUG 1:5 DATE: ,~l.~qN_~ OJ! ~,~ ~s Cons. Commiss/oa ST~T~: OF ALAs~rx~Or8ge ~OHIO UNION K.TULIN/VAULT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: 8tat6 b~ A]~s~a Off ~ G~s Conservation Comm~ss~o~ 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Receipt of the following material which was transmitted via is hereby acknowledged: QUANT ITY DE S CR I PT I ON RECEIVED: DATED: Copy sent to sender YES NO ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COLu~ISSION 3001 Porcupine DriVe Anchorage, Alaska 99501 (907) 279-1433 TO: State of AIaska Alaska Oil and Cas Conservation Commission 3001 Porcupine Drive I/.;: Receipt of the following material which was transmitted via ~ is hereby acknowledged: _QUANTITY DESCRI PT ION RECEIVED: . - DA TED: Copy sent to sender YES --__ NO ~ '-'~ STATE OF ALASKA "--. ALASKA O,._ AND GAS CONSERVATION CON,.,,ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-102 3. Add~ess 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21357 1178' 4. Location of Well at surface FNL, 869' FEL, Sec.14, T12N, R9E, UM 6. Lease Designation and Serial No. ADL 25634 ALK 2567 For the Month of June ,19 85 5. Elevation in feet (indicate KB, DF, etc.) 83' RKB 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3C-11 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 ~ 1200 hfs, 06/17/85. Drld 12-1/4" hole to 4150'. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 8859'TD (6/23/85). Ran logs. Ran, emtd, & tstd 7" csg. PBTD = 8771'. Secured well & RR @ 0600 hfs, 6/25/85. 13. Casing or liner rgn and quantities of cement, results of pressure tests 16" 62 5#/ft, H-40, weld conductor set ~ 116' Cmtd w/215 ax CS' II 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 4470'. Cmtd w/1360 sx AS I II 7" 26 O#/ft, J-55, BIC csg w/shoe ~ 8859' Cmtd w/325 sx Class G & 320 sx Class G. 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/SFL/SP/GR/Cal/FDL/CNL f/8859' - 4470'. 6. DST data, perforating data, shows of H2S, miscellaneous data NONE Alaska Oil & Gas Cons, Co¥~mission 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Associate Engineer 7-11-~5' 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. ...... TEMP/MR71 Submit in duplicate ARCO Alaska, Inc'?'''-''~ Post Office ,..,ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 20, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3C Pad Wel 1 s 1-16 Dear Elaine: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L113 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Y = 5,995,8:55.1 5 Let. = 70°23'58.955'' sEc.~ WELL I x: 5?-8,205.68 Long.= 149°46'15.622'' ~ SEC. 14 596"FNL, 1366'FEL N O R T H - Y = 5,995,893.73 Lat. = 70023'59.532" WELL 2 x=528,19:5.14 Long.= 149°46'15.983' 537' FNL, 1378'FEL . Y = 5~995~952.43 Let. = 70°24~. I10" WELL 3 x= 528,180.60 Lon~= 149°46'14.343' 478'FNL~ 1390'FEL Y= 5~996~ 011.07 Let. = 70°~4'00.687' ~~ WELL4 X= 528,168.12 Long.= 149046'14.70~'' 420' FNL~ 1402'FEL ~ ~~ ~ ?~ ~ ,=~,~,o~.,~ ~,.= ~oo~,o,.~,~,, ~ '~W'~ ~ ~ ' ~ WELL 5 x=528,520.16 Long.=149°46'04.3~" 346' FNL, I050'FEL Y = 5,996,027.76 Let. = 70°24'00.~7' -WELL 6 ' X= 528,532.83 Long.-' 149°~'~.015" 404' FNL, 10~'FEL ~= 5,995,969.11 L~t. = 70°24'00.260'' WELL 7 x= 52e,~5. z4 Long.= 149°46'03.658'' 463'FNL, 1025' FEL ~ Y= 5,995,910.44 Lot. = 70°23'59.683'' ~ WELL 8 x= 5~e, 5~.7~ Lon~.= 5~'FNL , 1013' FEL ~ ,,y~ Y: 5,995,372.49 Lot.: 7~23'54.387" "~ ~ ~,'~ ~ WELL 9 x= 5.28,672.61 Long.--m49°45'59.993'' . WELL 10 x= 528,685.04 Lon~=149°45'59.6~" 1119'FNL ~ 889' FEL Y = 5~995,255.22 Lat. = ~°23'53.233" WELL '11 x=528,697.61 ~ng.= 149°45'59.274" 1177'FNL~ 876'FEL Y = 5~995~ 196.51 L~t. = 70°25'52.6~" WELL 12 x= 5z8,710.19 Lon~.= 14~45'58.912" DRILL SITE 3'C , .~:,'=.oo' ~'~.~, ~'~E~ AS-BUILT C0NDUCTOE LOCATIONS ~=5,995,121.33 L~I. = 70°25'51.929" WELL 13 x= 52e,358.~o ~ng.= 149°~'09.235' WITHIN SECTION 14~ TI2N~ 'E9E~ U.~.~ ALASKA 1310~FNL~ 1217'FEL Y= 5~995~180.01 Let = 70°23'52.5~" NOTE: WELL 14 x=528,3~.63 Long.=149°46'09.594" C00EDINATES ARE ALASKA STATE PLANE ZONE 4. 1251'~L ~ 1229' SECTION LINE DISTANCES ARE TRUE. Y = ~995~238.66 LoL = 7~23'53.084" HOEIZONTAL POSITION PER LHD ~ ASS~. MONUM~S 19-1 ~ 19-2. WELL 15 X= 528,333.07 Long.= 149°46'09.956" VERTICAL POSITION PER LHD 8 ASSOC. TBM OPI6~ 6 DOC. 125. 1193'FNL~ 1241'FEL *WELL NO. 6 INFOE~ATiON PER DWG. N0. NSE 9.05.303dl. Y= 5~5~297.32 Lot. = 70°23'53.661" WELL 16 x= 528,320.55 Long.=149°46'lO. 316" 1134' FNL~ IZ53' FEL CERTIFICATE OF ~U ~VEYO~; I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA ~D THAT , THI~ PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND ~ ~. THAT ALL DIMENSIONS AND OTHER DETAILS ' -. ~--~& ~.11 ~ SURVEYED FOR. A~U AI~SKG, I~C. p~n.~rT ': ~~~~ ,mil -" D~. UAY 14, 1985 ..... "': ' -: '~ ~ ~JUii ~ ~ .... ' DRAWN J. DAVIS PREPARED F~: ~L~S~ O/~/~L~ : ':-'.,r ~ - BS~BO, .,.~ ~. e5o, SERVICES '~"':'~ I.'~ '..........~*~' May 17, t985 Mr, J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 KUparuk River TJnit 3C-1-1 ARCO Alaska, Inc. Permit No. 85-102 Sur. Loc. l178'FNL, 869'FEL, Sec. 14, T12N, R9E, UM. Btmhole Loc. 1329'FNL, 988'FEL, Sec. 13, T12N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their, drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any Waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Fir. Jeffrey B. K~win Kuparuk River Unit 3C- 11 -2- May 17, 1985 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. ~nere 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. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly ~urs, /'"-L__, .>"-,,:":.. ×. C. 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 B. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 10, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3C-11 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 3C-11, along with a $100 application fee ° Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat ° A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment We estimate spudding this well on June 10, 1985. If you have any questions, please call me at 263-4970. Sincerely, Ar~e~ Dril<~r JBK/LWK/tw PD/L90 Enclosures RECEIVED Ataska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~' ..... ALASKA OiL AND GAS CONSERVATION CON, MISSION PERMIT TO DRILL 20 AAC 25.O05 la. Type of work. DRILL [~X REDRILL [] DEEPEN [] 1 b. TyPe of well EXPLORATORY [] DEVELOPMENT OIL [~(X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE [~]X MULTIPLE ZONE 9. Unit or lease ,am~, Kuparuk 2. Name of operator ARCO Alaska, Inc. 3. Address P, 0. Box 100:360, Anchorage, Alaska 99510 4. Location of well at surface 1178' FNL, 869' FEL, Sec.14, T12N, RgE, UM At top of proposed producing interval 1315' FNL, 1477' FEL, Sec.13, T12N, RgE, UM At total depth 1329' FNL, 988' FEL, Sec.13, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 83', PAD 48' 6. Lease designation and serial no. ADL 25634 ALK 2567 3C-ll 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 12. Bond information (see 20AAC25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 30 mi, NW of Deadhorse 3C-12well 60' (~ surface feet 16. Proposed depth (MD & TVD) 8857' MD, 6754' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 1000 feet. 21 14. Distance to nearest property or lease line miles 9887 @ TD feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 46 o (see 20AAC25.035 (c) (2) Proposed Casing, Liner and Cementing Program 18. Approximate spud date 06/10/85 2966 psig@__Sfl~ Surface 3/~05 psig@._6F~l_5_ft. TD (TVD) SIZE Hole Casing Weight ,24" 16" 62.5# 12-1/4" 9-5/8" 36.0# )8-1/2" 7" 26.0# 22. Describe proposed program: CASING AND LINER Grade Coupling H-40 Weld J-55 BTC HF-ERW J-55 BTC HF-ERW Length SETTING DEPTH MD TOP TVD 80' 36' I 36' I 4452' 36' 36' I I 35' I 35' 8822' MD BOTTOM TVD 1161 116' 4488] 3728' I 8857 i 6754' I I QUANTITY OF CEMENT (include stage data) ± 200 cf 820 sx Arctic Set III & 320 sx Class G blend 300 sx Class G blend ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8857' MD (6754' 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 DOPE stack will be installed on the 9-5/8" surf. ace_p.$1~e. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig or annu Expected maximum surface pressure is 2966 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 3000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3C-ll will be 60' away from 3C-12 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;j/The well will be,comPleted (see attached sheet) · 23.1 hereby certif, v~at the foregoing is true and correct to the best J'~kA~(F~[~''"'~'~ ~/'' ~l)/~ ~4)5-~-, f--~/~ ~.-~i~.(j.~ _~4~.~. SIGNED.///~' . ,/~/~'~~ ~' TITLE Area Dri ] ] i no Engineer DATE ~~~3~ The space bel~r ~m~io~e ~ t' ~ / Mud I°g required Samples required E-lYES ~ I-lYES Permit number ~)~ ~--~'-~F t '~"~°val d~J' 17-/85 ~PPROVED BY / Form 10~01 (LWK) PD/PD90 ' ' CONDITIONS OF APPROVAL Directional Survey required I APl number ~Y__ES I-]NO 50- 0 ~ l - 2~! .~ ~'"'.y SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE by order of the Commission _ May 17. 1995 Submit in triplicate PERMIT TO DRILL 3C-11 by the workover rig using 3-1/2", 9.2#/ft, J-55, 8rd tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED MAY l z~ 1,98~ Oil & GgS Cons. Co[;imission .pT---Ll'.VD-3728 1'HD-4488 DE:P-1993-- '--~. . . I i I ii .l . i i RECEIVED 0ii & Gas Cons. ' An~,,~or~/)e 7 6 5 4 '5 2 1:~/8" BCP STACK DIESI~ ~Y ~ ~T TEST ~ IN m~n~ TO O ~I. ~ 4. ~T ~~ T~.~ Ii. ~~]~~ ~~Z~ ~ ~ ~UZ~ ~ ~ V~ ~N ~3~ ~ZTZ~ ~ ~]. ~Y ~ F~I~Y ~~ ~ ~ILY. 13. A~ask'a Oil &'Gas 6ons.' Commission :. Anchorage .. : _ o 5, CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. /~ /i ~ ITEM APPROVE DATE 1. Is i 3. 4. 5. 6. 7. . ~.,~'~,~,. -: .-,.,,:~ ~ (8) (3) Admin ~ ~'~-~ ~'-~:r~ 9. (9' thru 12) 10. A"i..,,~,~: .: :'.' :":..:'":i? 11. (10 and 12)"' 12. (4) ,Cas,~ (13 thru 2'1)," 13. 14. 15. 1.6. 17. 18. 19. 20. 21. YES NO Is Is Is Is the permit fee attached .......................................... well to be located in a defi~ed pool ............................ well located proper distance from property line .................. ~ ~,~ ...... __ well located proper distance from other wells .................... ' sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ................ Is operator the only affected party ................................. Can permit be approved before, ten-day wait .......................... (' ~-~-. ?~ Does operator have a bond in force .................................. Is a conservation order needed ................... ................... Is administrative approval needed ................................... Is the lease number appropriate ....... · ,,.,,,,.,,..,...,,-,,,,,,.,',,..'..o- Is conductor string provided ................................. ? .... Is enough cement used to circulate on conductor and ~rface . ~r~ Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive, horizons ..................... Will surface casing protect fresh water zones ..................... Will all casing.give adequate safety in collapse, tension'a~d burst . ,, 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 ............................ REMARKS (5) BOPE -~.u , (22 thru 26) (6) Add: 22. 23. 24. 25. 26. 27. Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to,~, :~ .... ~":~ psig .. '.~ ' Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. ~ Additional requirements .............................................. ~.~{' Geology: En~ineering:£, ~wx ~--= LCS ~z-. ~EW WVA~ MTM~'' ~ HJH ~'-:..X JAL~ rev: 03/13/85 6.011 ... INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ~",? ~ ,~ ~ o ~.~ .! -~ ~!' ~ ~ ,,~,:,,',: ~ o ~ ,>,~ Well Histo.ry 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. .o .VP OiO.'HO2 V~RiFIGA'TIO~ LISTING PAS~ i TAPE ME~O,~R ** )ATE :85/0'7/ 2 ~RIG.iN :OOO0 'AP~ N~M~ :0597 :ONTINUATIDN ~ :01 ~REViOUS T~P~ : ~OMM~N/S :, :* FiLE HE~OER :ILE NAM~E .: 2DIT .OOl ~ERV'ICE NAME : IERSION 'm )ATE : ~A~IMUM LENGTH : : i U E T Y P ~ ~REVIO~S EILE : ',-~ INF2RMATION R~.CDRDS x-'~. 4N EM CO ,'~T .~ZN TS 4NEM F..O ~T.=NTS ~R~.S: ;:x; C 3MMENT S-,--,- 0 N ,l T T Y P E ,~" A 'T E S I -~ E ~ ~ O 2. 0.00 000 015 065 000 000 005 000 GOO 007 0o5 000 OgO 002 000 OOO 003 OaS 000 000 002 055 000 000 007 005 OOO 000 006 065 OOO 000 003 055 000 000 031 055 VP OlD.HO~. VERi~Ir~T!"'N~ ~ LZSTING, PAG~- 2 S C H L LJM ALASKA C~M?UTiNG ~,~PANY -'- A'T,LANT~C R~CHF~'~:LD~ O~NTY = NORTH SLOPE BOROUGH T,4TE : .ALASKA UN ~1, DATE LOGGED': 2"3 jUN 85 DP: L. S. CUDNE¥ ASING YPE FLUID ENSZT~ 'ISC~SiT¥ 'H ~L~I5 LOSS = 9.625 :" @ z,.~'TO., = LSN~/POL¥ : 12.2 C6/G = 40.,0 S = 6.2 C'3 - 6:iT SiZ~ .: 2.5" R RF RMC R q .AT ~HT : 1.620 ~ 160. DP iA'TRiX SANDS'TONE VP O13.HO~ ¥'ERIFI~.ATIgN LISTING PA~5 ~3 DATA FO~M&T R,EC~R~ *'* :NTRY 5L, gC ~S 'TYPE SIZE R~PR CgD:E EN'TRY 2 1 6 5 0 4 1 ,55 1 8 ~ ~3 50 9 4 6:5 . lin !6 I 65 1 0 i 6a 0 VP OID.HO',Z VERIFiCAT'i3N'LISTiNG PA&E 4 ATUM SP 6CIF ZC ='~T iO,~ NEM SisRvICE SERVICE LJNI'T i'D ORDF. R ~ LOG TYPE E P T F'T FLU DIL OHMM O0 ~ZO L .~ D I L g H M M 00 1 Z 0 L~ OIL OHMM OD P O I c M V 00 010 R OIL .~API O0 ~I~ , R F O N ~ ~ P I O 0 3,1 O Au.i FDN IN OC 280 :~06 FDN ~/C3 O0 350 )RHO FDN G/C3 O0 355 I.R a T ~ O N 0 :NRA FDN O0 OOO iPMI FDN PU t CNL ~D~ CPS 00 3~0 :CNL FDN CPS O0 APl O0 Ol Ol OI Ol O1 O1 O0 O0 31 30 0 0 0 0 0 0 0 0 C; 0 0 0 ,O 0 0 FiLE .SIZE SPL NO. 0 ~ 1 0 ~ 1 0 ~ 1 0 ~ 1 R~P'R PRDCESS CgD~ (gCTAL.) 65 O000OO0000000O 68 O00000000OO00O 68 O00~O0000000OO 68 O0000OO0000000 6,8 OOOO000000000~ 58 O000000000000O 68 0000000000000~ ~8 OO00000OOOOOO0 5800000000,000000 68 00000000000000 58 O00.O000000OOOD 68 O0000OOOO:OO00D 68 O0000.OOO0000~ 68 O00000'O000000O 68 00000000000000 :*. DATA i~PT 8500..0000 SFaU ;P -4,2..4688 GR I01. :HgB ,2,.~9,41 ORH~ iPHI 3~.~66 NCNL Z16~. )EP'T 8700.0000 S~LU 3 ;P -42.Z500 ~R 106 :MO8 2.45!51 ,ORMO 0 ~P~i 34.~Tg'? 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