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Phone:907-670-3097 Rep.: E-Mail Well Name: PTD #11861480 Sundry #322-163 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:2493 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.p Well Sign P Upper Kelly 0NA Housekeeping p Rig p Lower Kelly 0NA PTD On Location p Hazard Sec.p Ball Type 2p Standing Order Posted p Misc.NA Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 2" P Trip Tank pp Annular Preventer 1 7-1/16" GK FP Pit Level Indicators pp #1 Rams 1 Blind / Shear P Flow Indicator pp #2 Rams 1 2" Pipe / Slip p Meth Gas Detector pp #3 Rams 1 2-3/8" Pipe/ Slip p H2S Gas Detector pp #4 Rams 1 2" Pipe / Slip p MS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 2-1/16"p Inside Reel valves 1p HCR Valves 2 2-1/16"FP Kill Line Valves 1 2-1/16"p Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 2 2.0" Piper P Time/Pressure Test Result System Pressure (psi)2900 p CHOKE MANIFOLD:Pressure After Closure (psi)2200 p Quantity Test Result 200 psi Attained (sec)18 p No. Valves 12 P Full Pressure Attained (sec)50 p Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 10 @ 1955 p CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:2 Test Time:25.0 Hours Repair or replacement of equipment will be made within 0 days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 6/22/22 06:24 Waived By Test Start Date/Time:6/24/2022 4:30 (date) (time)Witness Test Finish Date/Time:6/25/2022 5:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Nabors Initial first 3 tests had a slow bleed off with no visual leaks found, annular also failed on test #3. Replaced annular element, purged all surface lines and restarted test from test #1. F/P on B1 (HCR) regrease and passed. Lower 2" Pipe Slip Ram Auto-Lock would not disengage after testing, replaced bonnet, function & shell tested then pressure tested the 2" Pipe slips again, auto-lock released and all passed. Coyne/Williams Hilcorp Igtanloc/Kavanagh DS 11-27A Test Pressure (psi): alaskans-ctd-dsm@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0625_BOP_Nabors_CDR2AC_PBU_11-27 +LOFRUS1RUWK6ORSH//& 3%89 9 9999 9 9 9 9 9 9 9 -5HJJ FP p FP annular also failed on test #3. 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Received By: 10/13/2021 37' (6HW By Abby Bell at 5:21 pm, Oct 13, 2021 „�� 1861:4. 8 BA ER PRINT DISTRIBU ON LIST 2 9 2 8 4 UGHES a GE company Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc. BP Exploration(Alaska)Inc. Petrotechnical Data Center,LR2-1 WELL NAME 11-27 900 E.Benson Blvd. Anchorage,Alaska 99508 or AKGDMINTERNAL@bp.com FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY PRUDHOE BAY LOG TYPE RPM:PNC3D BHI DISTRICT Alaska --- LOG DATE April 15,2018 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares(a�bhge.com TODAYS DATE May 23,2018 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #OF I'hIIN IS #OF COPIES #OF COPIES #OF COPIES � V V L L L 4 1 BP North Slope. 0 1 1 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aides Attn:Benda Glassmaker&Peggy O'Neil 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 1 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99501 JUN 1 9� LU�� F.14416) 3 ExxonMobil,Alaska 0 � I 1 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 1 1 Attn:NIakana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division ofOil&Gas *** 0 0 1 Attn:Garret Brown 550 West 7th Avenue,Suite 1100 Anchorage,Alaska 99501 **Stamp"confidential”on all material deliver to DNR '11 6 BP Exploration(Alaska)Inc. rn Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. /, 2018 Anchorage,AlaskaMAY 4 99508 Attn:Gerardo Cedillo fkoGcp TOTALS FOR THIS PAGE: 0 2 5 i STATE OF ALASKA ' f OSKA OIL AND GAS CONSERVATION C MISSION Al)I i .g o L) ' REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Performed: ❑Abandon ®Repair Well ❑Plug Perforations ❑ Perforate ❑Re-Enter Suspended Well 0 Alter Casing ®Pull Tubing ❑Stimulate-Frac ❑Waiver ❑Other ❑Change Approved Program ❑Operation Shutdown ❑Stimulate-Other ❑Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑Exploratory ❑Stratigraphic '- 186-148 3. Address: ®Development ❑Service 6. API Numbe - P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-21638-00-00 7. Property Designation(Lease Number): 8. Well Name and Number: - ADL 028325&028322 PBU 11-27 9. Logs(list logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Prudhoe Bay Field/Prudhoe Bay Oil Pool 11. Present well condition summary: Total depth: measured 12210' feet Plugs:(measured) None feet true vertical 8892' feet Junk:(measured) None feet Effective depth: measured 12065' feet Packer: (measured) 10613',10782,10944,11026 feet true vertical 8789' feet Packer: (true vertical) 7776',7890'8000',8057' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 2525' 13-3/8" 30'-2555' 30'-2518' 4930 2670 Intermediate 11342' 9-5/8" 26'- 11368' 26'-8298' 6870 4760 Production Liner 1164' 7" 11046'- 12210' 8071'-8892' 8160 7020 Scab Liner 7731' 7" 3054'- 10785' 2954'-7892' 7240 5410 Tieback Liner 920' 3-1/2" 11015'- 11935' 8050'-8698' 10160 10530 Perforation Depth: Measured Depth: 11985'- 12062' feet SCANNED AU G 0 1 2013 True Vertical Depth: 8733'-8787' feet Tubing(size,grade,measured and true vertical depth): 4-1/2", 12.6#; 13Cr80/13Cr85; 10902'; 7972' 5-1/2", 17# x 5", 15# L-80 10896"-11115' 7968'-8119' 7"x 4-1/2"HES TNT Packer 10613' 7776' Packers and SSSV(type,measured and true vertical depth): 9-5/8"x 5-1/2"Baker S-3 Packer, 10782' 7890' 9-5/8"x 5-1/2"Baker S-3 Packer, 10944' 8000' 9-5/8"x 5-1/2"Baker SB-3 Packer 11026' 8057' 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment description including volumes used and final pressure: Cut and pull 4-1/2"tubing at 10773', Set 7",26#, L-80 Scab Liner from 3054'- 10785'cement 7"with 220 Bbls(1056 sx)Class'G'with 1.17 yield. 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 1 Tubing Pressure • Prior to well operation: 935 38179 637 1260 826 Subsequent to operation: 1033 25382 1277 1800 0 14.Attachments: ❑Copies of Logs and Surveys run 15.Well Class after work: ❑Exploratory ❑Stratigraphic ®Development ❑Service 0 Daily Report of Well Operations 16. Well Status after work: it 0 Oil ❑Gas ❑WDSPL ®Well Schematic Diagram ❑GSTOR ❑WINJ ❑WAG ❑GINJ ❑SUSP ❑SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact: Sean McLaughlin,564-4387 312-446 Email: Sean.McLaughlin @bp.com Printed Na e. Jo ufk Title: Drilling Technologist Signature: Phone: 564-4091 / Date: 3111.1 Form 10-404 Re sed 10/201 DMS MAR 12 �0 01'g V f- �7,5"`/ 3 Submit Original Only • 11 -27, Well History (Pre Rig Workover) Date Summary 12/01/12 SET 4 1/2"WHIDDON CATCHER @ 10,837'SLM. PULLED STA#1 RK-CIRC @ 10,708'SLM/10,731' MD. ATTEMPT TO SET STA#1 RK-DGLV @ 10,708'SLM. 12/02/12 SET STA#1 RK-DGLV @ 10,708' SLM (10,731' MD). PERFORMED PASSING MIT-T TO 3500 PSI. PULLED EMPTY WHIDDON CATCHER SUB FROM 10,837'SLM. DUMP BAILED—15' OF SLUGGITS ON TOP OF PXN PLUG @ 10,870'MD. SET JUNK CATCHER ON TOP OF SLUGGITS @ 10,828'SLM. ESTIMATE TOP OF JUNK CATCHER AT 10,845' MD. 12/03/12 INITIAL T/I/O 150/300/0. RIH WITH 3.65 POWERCUTTER. LOG TIE IN PASS, CORRELATE TO TBG TALLY. CCL STOP DEPTH = 10766.8', CCL TO CUTTER=6.3'. PUMP METH BRING TBG UP TO 500 PSI, CUT TBG AT 10773'. TBG PSI DROP 100 PSI & IA INCREASED 30 PSI. FINAL T/I/O 250/250/0. 12/13/12 T/I/O=SSV/300/0 Temp= SI PPPOT-T(PASS) PPPOT-IC (PASS) Pre RWO. PPPOT-T: Stung into test void (0+ psi.). Bled void to 0 psi. Pumped through void, good returns. Functioned LDS all moved freely (2.5"). Pressured void to 5000 psi.for 30 min.test. Lost 50 psi. in 15 min. Lost 0 psi. in second 15 min. (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test void (0+ psi.). Bled void to 0 psi. Functioned LDS all moved freely(2.5"). Single port.. Pressured void to 3500 psi.for 30 min.test. Lost 0 psi. in 30 min. (PASS). Bled void to 0 psi. 12/16/12 T/I/0=13/299/6,Temp=S/I, MIT-OA PASSED to 2000 psi (Pre RWO) Pumped 2.6 bbls of crude to reach 2000 psi. MIT-OA lost 104 psi in 1st 15 minutes and 26 psi in 2nd 15 minutes for a total loss of 130 psi in a 30 minute test. Bled OAP. SV,WV,SSV=SHUT/MV,IA,OA=OPEN. FWHP's=14/302/0. 12/20/12 T/I/O =255/500/0. Barriers=SSV, MV. Start barriers list. Conducted PJSM. Bumped pressure on tubing to 255 psi before tree cap removal to ensure BPV holds pressure. SI in SSV and MV, bled to 0 psi.and performed LTT for 5 min. (passed). RU lubricator with 6"CIW J BPV#419. PT lubricator to 300 psi and 3500 psi. independently for 5 min. (passed). Set BPV tagging at 135". bled to 0 psi. and performed LTT for 5 min. (passed). RDMO. Pt'd tree cap to 500 psi for 5 min. (passed). 12/27/12 T/I/O=0/240/0 Conducted PJSM. Barriers= Master(w/WSL approval)&SSV. Start barriers list. PT'd thru tree cap against SSV&Master 500 psi./5 min..pass. Removed tree cap, attached lubricator, PT'd 250/Iow..3500/high..5 min. each..pass. PULLED 6"CIW"J" BPV#419 thru tree using 1-2'ext.Tagged @ 112". Shut barriers, removed lubricator, installed tree cap, PT'd 500 psi./5 min..pass. 12/27/12 T/I/O =0/250/0.Temp=SI. U-Tube TxIA,then bleed TxIAP to 0 psi (Pre RWO).AL spool dropped& blinded.ALP= 1100 psi. Opened MV(w/WSL approval).TBG FL near surface, IA FL @ surface. U- Tubed TxIA for 3.5 hrs until equalized @ 20 psi. Bled TP& IAP in tandem from 20/20 psi to 0/0 psi in 15 min(.5 bbls fluid returned). Monitored 30 min.TP unchanged, IAP increased 6 psi,TBG &IA FL unchanged. Final WHP's=0/6/0. SV,WV, SSV=C. MV=0. IA, OA=OTG. NOVP. 1630. 12/30/12 T/I/O=0/100/0. Conduct PJSM. Barriers= MV&SSV. Start Barrier List.Verified by applying 500 psi. against SSV through tree cap. LTT passed. Removed tree cap and rigged up lubricator with 6"CIW BPV #421.Attached lubricator and pt'd to 200-300 psi. low and 3500 psi high for 5 min. each (passed). Set BPV using 1-2' ext.tagging @ 112". Bled off tree to verify integrity of plug. Rigged down lubricator and tested tree cap to 500 psi.(passed). 01/03/13 T/I/O= SSV/100/20.Temp=SI.WHP's(Pre RWO).AL spool dropped&blinded. OAP increased 20 psi since 12/30/12. SV, WV, SSV= C. MV=0. IA, OA=OTG. NOVP. 1100. Page 1 of 2 • • 11 -27, Well History (Pre Rig Workover) Date Summary 01/06/13 T/I/0=SSV/110/20.Temp=SI. Bleed IA&OA to 0 psi (Pre RWO).AL spool removed. IA&OA FLs @ surface. Bled IA from 110 psi to 0 psi in 30 mins(<1 bbl fluid). Bled OA from 20 psi to 0 psi (-5 gals fluid) in 20 mins. Monitor for 30 mins. IAP increased 20 psi &OAP @ 0+ psi.Job complete. Final WHPs= SSV/20/0+. SV,WV&SSV=C. MV=0. IA&OA=OTG. NOVP.0030 hrs. 01/08/13 T/I/O=0/0/0. Conducted PJSM. Barriers= BPV&MV. Varified by bleeding TBG pressure off BPV& pumped down I/A up TBG to 585 psi against BPV for 5 minutes(Passed), charted and documented in TRP folder. Bled I/A top 0 psi. PT'd down on MV with 500 psi for 5 minutes(Passed). Bled TBG to 0 psi. N/D 6-3/8"x 7-1/16"CIW"FLS"upper tree with Baker actuator. N/U 6-3/8"x 7-1/16"CIW"FLS" HWO SV to MV. PT MV x SV through tree cap 200-300 psi low&5000 psi high for 5 minutes each (Passed). Page 2 of 2 • • Operation sum mary„Re Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27/2013 X4-00WXH-E:DRILL(3,404,000 00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°16'21.894"4 Long: 0148°19'23.026"W Active datum:Kelly Bushing/Rotary Table @90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1/9/2013 21:30 - 00:00 2.50 MOB P PRE MOBILIZE RIG TO 11-27A -PJSM ON MOVING RIG -MOVE RIG OFF OF 11-01AAND OFF OF MATS TO 11-27A. 1/10/2013 00:00 - 03:00 3.00 MOB P PRE MOBE RIG ONTO LOCATION 11-27 -PJSM WITH CREW MEMBERS WADER SPOTTED MATS FOR RIG MANEUVERABILITY IN FRONT -SPOT RIG OVER WELL AT 02:00 AM AND SET RIG DOWN. -SHIMMED RIG 03:00 - 08:30 5.50 MOB P - PRE PJSM SKIDI RIG FLOOR -SKID RIG INTO DRILLING POSITION -SIM-OPS:LAY OUT HERCULITE FOR ROCK WASHER ANDvSPOT ROCK WASHER ON MATS -RIG UP RIG SERVICE LINES TO RIG FLOOR (STEAM,AIR,WATER,CHOKE LINE,GAS 1 BUSTER,HIGH PRESSURE MUD LINE,VAC LINE,BLEED OFF LINE.) -PREPARE PITS TO TAKE ON 9.8 BRINE. . -SPOT DIESEL FUEL TANK TRAILER. ` -SPOT DDI LUNCH TRAILER. -SPOT FLOWBACK TANK AND INSTALL AND TEST 2"HARD LINE FROM TANK TO RIG AT 4000 PSI. *TOOK ON 9.8 BRINE INTO PITS AT 06:00. *RIG ACCEPTED AT 06:00 FOR WELL DS11-27. ***NOTIFIED AOGCC VIA EMAIL @ 03:17 WITH 24 HR NOTICE OF INTENT TO TEST BOPE'S*** ***JOHN CRISP(AOGCC)NOTIFIED US VIA EMAIL WAIVING WITNESS OF BOP TEST @ 05:59 AM 01/10/2013*** 08:30 - 11:30 3.00 MOB P PRE INSTALL DOUBLE ANNULUS VALVE ON I/AAND 0/A. 11:30 - 12:00 0.50 MOB P PRE INSTALL CIRCULATING LINE TO FLOWBACK TANK. *CALIBRATE AND TEST COMBUSTABLE AND H2S GAS ALARM SYSTEMS 12:00 - 15:00 3.00 RIGU P PRE PJSM RIG UP CIRCULATING LINES TO DISPLACE FREEZE PROTECTION FROM TUBING AND TUBING ANNULAS TO FLOWBACK TANK 15:00 - 16:00 1.00 RIGU P PRE PRESSURE TEST LINES 250 PSI LOWAND 3500 PSI HIGH WITH DIESEL-GOOD TEST. -BLOW DOWN ALL LINES. 16:00 - 19:00 3.00 RIGU P PRE PJSM-PICK UP BACK PRESSURE VALVE LUBRICATOR AND TEST -TEST LUBRICATOR 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES ON CHART-GOOD TEST Printed 2/25/2013 10:30 29AM • • . n nca-ALASKA 41.•Waburl Summary Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27/2013 X4-00WXH-E:DRILL(3,404,000.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°16'21.894"4 Long: 0148°19'23.026"W Active datum:Kelly Bushing/Rotary Table @90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:00 - 20:00 1.00 RIGU P PRE BLEED OFF TUBING AND IA -OFFSEAT BUTTON ON BACK PRESSURE VALVE AND WELL HAD 150 PSI UNDER BACK PRESSURE VALVE. -LINED UP IA TO BLEED BACK TO OPEN TOP TANK ---BLEED BACK PRESSURE TO OPEN TOP TANK PRESSURE IMMEDIATELY BLED DOWN. -MONITOR FOR 10 MINUTES WITH NO BUILDUP -PULL BACK PRESSURE VALVE -RIG DOWN BACK PRESSURE VALVE LUBRICATOR 20:00 - 21:00 1.00 WHSUR P -.- DECOMP CIRCULATE OUT FREEZE PROTECT(50 BBLS DIESEL IN WELL.(10 BBLS IN TUBING/40 BBLS IN IA)) -LINE UP AND REVERSE CIRCULATE DOWN IA TAKING RETURNS THRU TUBING,PUMPED 20 BBLS @ 3 BBLS/MINUTE @ 1200 PSI MAX PRESSURE -LINE UP AND CIRCULATE DOWN TUBING -`TAKING RETURNS THRU IA PUMPED 80 BBLS 5 BBUMINUTE @ 1260 PSI MAX. 21:00 - 21:30 0.50 - WHSUR P DECOMP"FLOWCHECK WELL FOR 10 MINUTES -SIMOPS:BLOW DOWN LINES BACK TO OPEN TOP TANK -NO-FLOW ON FLOWCHECK.0 PSI ON TUBING AND IA. 21:30 - 00:00 2.50 WHSUR P DECOMP PJSM-RIG UP BACK PRESSURE VALVE LUBRICATOR -RIG UP LUBRICATOR ON TREE TO INSTALL TWO WAY CHECK VALVE -PRESSURE TEST LUBRICATOR TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES ON CHART. -INSTALL TWO WAY CHECK IN HANGER -RIG DOWN BACK PRESSURE LUBRICATOR 1/11/2013 00:00 - 01:00 1.00 WHSUR P DECOMP PJSM-TEST TWO WAY CHECK -LINE UP AND PUMP THRU IA TO TEST TWO WAY CHECK.PUMPED 23 STROKES.TUBING PRESSURE WAS 520 PSI. -OA PRESSURE WENT FROM 100 PSI TO 150 PSI DURING PRESSURE UP. -TUBING PRESSURE HELD FOR 10 MINUTES WITH NO BLEED OFF.OA PRESSURE INCREASED TO 200 PSI DURING WAIT. -BLEED PRESSURE OFF THRU IA TO OPEN TOP TANK.OA PRESSURE CAME BACK DOWN TO 100 PSI. -BLOW DOWN LINES FROM RIG TO OPEN TOP TANK. 01:00 - 02:00 1.00 WHSUR P DECOMP RIG UP TO TEST TWO WAY CHECK FROM ABOVE -TEST TWO WAY CHECK AT 250 PSI LOW/3500 PSI HIGH FOR 5 CHARTED MINUTES-GOOD TEST. Printed 2/25/2013 10:30:29AM • �t',rt�`4rl�enca'-ALAS ,operation Summary Report Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27/2013 X4-00WXH-E:DRILL(3,404,000.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°16'21.894"4 Long: 0148°1923.026"W Active datum:Kelly Bushing/Rotary Table @90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:00 - 04:00 2.00 WHSUR P DECOMP PJSM-NIPPLE DOWN TREE -NIPPLE DOWN TREE AND ADAPTER FLANGE AND REMOVE FROM CELLAR -TEST CROSS-OVER THREADS IN HANGER -- — PROFILE-7 3/4 TURNS-INSPECT THREADS-GOOD -ENERGIZE LOCKDOWNS -RIG DOWN CIRCULATING LINES IN THE CELLAR 04:00 - 06:00 2.00 BOPSUR P DECOMP PJSM-NIPPLE UP BOPE'S -INSTALL BOPE'S ONTO WELLHEAD -HOOK UP`HYDRAULIC KOOMEY HOSES TO BOPE'S NIPPLE UP FLOWLINE,HOLE FILL -INSTALL FLOW LINE COVERS AND TURN BUCKLES TO CENTER BOP STACK 06:00 - 08:30 2.50 BOPSUR P DECOMP HELD SPILL DRILL,RESPONSE TIME 1 MIN 27 SECONDS. : -,PJSM.RIG UP TO TEST BOPE.ENSURE TWC -- IS HOLDING. TEST(2)4"FULL OPEN SAFETY VALVES& bART VALVE. TEST TOP DRIVE IBOP.ALL TESTS @ 250/ 3500 PSI,5 MIN/CHARTED. 08:30 - 18:00 9.50 j BOPSUR - 'P DECOMAP PJSM.CONTINUE TO TEST BOPE AS PER STATE AND BP REQUIREMENTS. -TEST TOP 7"RAMS WITH 7"TEST JT. -TEST LOWER VBRS W/4"AND 4 1/2"TEST JTS. -TEST ANNULAR PREVENTOR W/4"TEST JT. -TEST ALL VALVES ON CHOKE MANIFOLD AND MUD CROSS. -PERFORMED KOOMEY DRAW-DOWN TEST -ALL TESTS @ 250/3500 PSI,5 MIN EACH/ CHARTED. 18:00 - 20:00 2.00 BOPSUR P DECOMP MOBILIZED EQUIPMENT TO RIG FLOOR FOR PULLING TUBING. -PICK UP CROSS OVERS FOR PULLING HANGER. -PICK UP LONG BALES FOR REVERSE CIRCULATING WELL THRU CHOKE. -MAKE UP SAFETY JOINT WITH CROSS OVER AND FULL OPEN SAFETY VALVE,WITH HEAD PIN ON TOP OF JOINT. -INSTALL DUTCH RISER ON BOP STACK 20:00 - 21:00 1.00 BOPSUR P DECOMP PJSM-PICKUP LUBRICATOR WITH EXTENSIONS,MAKE UP TO RETRIEVE TWC. -RIG UP TO TEST LUBRICATOR. 21:00 - 22:00 1.00 WHSUR P DECOMP TEST LUBRICATOR. -TEST LUBRICATOR TO 300 PSI LOW/3500 PSI HIGH FOR FIVE CHARTED MINUTES EACH. 22:00 - 23:00 1.00 WHSUR P DECOMP PULL TWC. -RIG DOWN LUBRICATOR AND DUTCH RISER. 23:00 - 00:00 1.00 PULL P DECOMP RIH WITH LANDING JOINT. -DRAIN STACK AND SCREW INTO HANGER WITH LANDING JOINT,7-3/4 TURNS. -BACK OUT LOCK DOWN SCREWS AND PULL TUBING HANGER TO RIG FLOOR. -BROKE OVER AT 155KAND PICK UP WEIGHT=150K(STRING WEIGHT) Printed 2/25/2013 10:30:29AM • ! s Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27/2013 X4-00WXH-E:DRILL(3,404,000.00) Project Prudhoe Bay Site:PB DS 11 Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°16'21.894"4 Long: 0148°19'23.026"W Active datum:Kelly Bushing/Rotary Table @90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1/12/2013 00:00 01:30 1.50 PULL P DECOMP CIRCULATE BOTTOMS AFTER LANDING JOINT AND HANGER UP THRU RIG PULLING FLOOR. CATE BOTTOMS R CO MANIFOLD(610 OT BBLS TOTAL CIRCULATEU HKE -CIRCULA-CIRULTE AT 7 BPM O AT UP 450 TH PSI-NO LOSSD)ES ENCOUNTERED. 01:30 - 02:30 1.00 PULL p DECOMP FLOWCHECK WELL-NO FLOW -BLOW DOWN LINES FOR WINTERIZING LAY iDOWN LANDING JOINT AND 13"X 7"TCII TUBING HANGER(NO DAMAGE FOUND ON HANGER) '. -RIG UP POWER TONGS TO PULL TUBING 02:30 11:00 8.50 PULL P DECOMP LAY DOWN 13CR VAM TOP 4 1!2"12.6#TBG. L/DTOTALOF255JTS&3.13'OFCUTOFF JT. -OD OF JET CUT=43/4"MIN&5"MAX. - KICK LE -2 Dl MIUN 30 SEC RESPONSE TIME,WELL SECRED,ALL DRILL HANDS WHI AT POOH.STATIONS. 11:00 12:00 1.00 PULL P DECOMP -CLEAR/CLEAN RIG FLOOR. CHANGE OUT BALES ON TOP DRIVE. 12:00 - 13:30 1.50 CLEAN P DECOMP PJSM.CONTINUE TO CHANGE OUT BALES. -INSTALL WEAR BUSHING. -ID OF.WEAR BUSHING 12-1/4" 13:30 - 16:00 2.50 CLEAN P DECOMP PJSM.PICKUP BHA FOR DRESSING OFF 4 1/2"TBG STUB AND SCRAPING CSG. -BHA CONSISTS OF DRESSOFF SHOE,BOOT BASKETS,BUMPER SUB,OIL JARS,AND STRING MILLS WITH GRABITZ MAGNETS 16:00 - 00:00 8.00 CLEAN P DECOMP RUN IN HOLE FROM 272'WITH 4"DRILL PIPE 1X1 FROM PIPE SHED TO 9769' -NO FLUID LOSSES WHILE RUNNING IN HOLE. 1/13/2013 00:00 - 00:30 0.50 CLEAN P DECOMP LUBRICATE RIG 00:30 - 01:30 1.00 CLEAN P DECOMP CONTINUE TO RUN IN HOLE FROM 9769'TO 10610' -RUNNING IN SINGLES FROM PIPE SHED 01:30 02:30 1.00 CLEAN P DECOMP DRESS OFF 4.5"TUBING STUB PARAMETERS BEFORE TAGGING STUB:PICK UP WT 210K,SLACK OFF WT 150K(NO ROTATION),ROTATING PICK UP WT 175K, SLACK OFF WT 175K @ 40 RPM AND 7K OFF BOTTOM TORQUE,PUMP PRESSURE 1850 PSI OFF BOTTOM(10 BBL/MIN FLOWRATE) -RUN INS HOLE AND TAGGED AT 10,777' -DRESS OFF STUB(5.5'SWALLOW)TO 10,782.5'.PARAMETERS:6-7 WEIGHT ON BIT, 1900 PSI PUMP PRESSURE,6-8K ROTATING TORQUE -PULLED UP 15'ABOVE STUB AND RAN BACK DOWN 2 TIMES(WHILE ROTATING)TO ENSURE CLEAN STUB. -PULLED UP 15'AND STOP ROTATING AND RAND BACK DOWN OVER STUB 2 TIMES WITH NO PROBLEMS. 1 Printed 2/25/2013 10:30:29AM • '', Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27/2013 X4-OOWXH-E:DRILL(3,404,000.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°16'21.894"4 Long: 0148°19'23.026"W Active datum:Kelly Bushing/Rotary Table @90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:30 - 03:30 1.00 CLEAN P DECOMP PUMP HI VIS SWEEP(200 VIS) -CIRCULATE 35 BBL SWEEPAROUND WHILE RECIPROCATING PIPE AT 20 RPM WITH 7K TORQUE,1850 PSI PUMP PRESSURE @ 10 BBL/MIN FLOWRATE -TOTAL CIRCULATING 665 BBLS(6650 STROKES) -ACQUIRED SLOW PUMP RATES @ 10,773'. 9.8 PPG BRINE. -PUMP#1,20 SPM @P 120 PSI,30 SPM @ 230 PSI. -PUMP#2 20 SPM @ 120 PSI,30 SPM @230 PSI. 03:30 - 04:30 1.00 CLEAN P DECOMP OR.R M FLOW FLOWCHECK -RACK BACK 1 WELD STAND,RECIPROCATE INUTES-NO STRING MILLS ACROSS DEPTH OF 10,610'© 60 RPM AND 8-9K ROTATING F TORQUE. 04:30 - 08:30 4.00 CLEAN P DECOMP FLOWCHECKWELL FOR 10 MINUTES-NO FLOW TRIP 4"DRILL PIPE OUT OF THE HOLE FROM 10,670'TO 7,500" 08:30 - 09:30 1.00 CLEAN P DECOMP .POLISH 9 5/8"CASING @ 3055'. iP60-0-"U. RPM @2000-3004000FTP/SLBS(FOLLIFITDORQUE, NO DRAG. TER ANNULUS PACKED). 09:30 10:00 0.50 CLEAN P DECOMP PJSM.SLIPAND CUT DRILLING LINE. @ 10:00 HRS,PHASE III DRIVING CONDITIONS ANNOUNCED. SHUT DOWN OPERATIONS AND ALERT ALL PERSONEL ON LOCATION. -CONFER WITH BE SAFETY AND INCIDENT MANAGEMENT TEAM. 10:00 - 18:00 8.00 CLEAN N WAIT 3,055.0 DECOMP WAIT ON PHASE III CONDITIONS. MINIMAL OPERATIONS ON THE RIG. -PERMISSION GRANTED TO CONDUCT CREW CHANGE OUT@ 12 NOON. -C (10)PEOPLE CHANGED OUT,15 MINUTES EACH WAY,LOADER ASSISTED. -REPORTED TO INCIDENT MANAGEMENT TEAM WHEN EACH ESCORTED PARTY ARRIVED. RADIO CHECKS CONDUCTED PRIOR TO TRAVEL. 18:00 - 23:00 5.00 CLEAN N WAIT 3,055.0 DECOMP CONTINUE TO WAIT ON PHASE III WEATHER CONDITIONS. -PERMISSION GRANTED TO CONDUCT 18:00 HRS CHANGE OUT. -(4)PEOPLE FROM CAMP TO RIG AND(5) PEOPLE FROM RIG TO CAMP. APPROXIMATE TRAVEL TIME=15 MINUTES, LOADER ESCORTED. -PJSM,RADIO CHECK AND CALL IN REQUIRED. Printed 2/25/2013 10:30:29AM • • six . . . Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27/2013 X4-00WXH-E:DRILL(3,404,000.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°16'21.894"4 Long: 0148°19'23.026"W Active datum:Kelly Bushing/Rotary Table @90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 23:00 - 00:00 1.00 CLEAN N WAIT 3,055.0 DECOMP CONTINUE TO WAIT ON PHASE III WEATHER CONDITIONS. -PERMISSION GRANTED TO CONDUCT 00:00 HRS CHANGE OUT -(10)PEOPLE FROM CAMP TO RIG AND(11) PEOPLE FROM RIG TO CAMP. APPROXIMATE TRAVEL TIME=15 MINUTES, LOADER ESCORTED. -PJSM,RADIO CHECK AND CALL IN REQUIRED. -OUTER ANNULUS=300 PSI,(FLUID PACKED) 1/14/2013 00:00 - 12:00 12.00 CLEAN N WAIT 3,055.0. DECOMP CONTINUE'TO WAIT ON PHASE III WEATHER CONDITIONS. -PERMISSION'GRANTED TO CONDUCT 06:00 HRS CHANGE OUT. .. -(5)PEOPLE FROM CAMP TO RIG AND(4) PEOPLE FROM RIG TO CAMP. -APPROXIMATE TRAVEL TIME=15 MINUTES, LOADER ESCORTED. -PJSM,RADIO CHECK AND CALL IN REQUIRED. 12:00 - 17:00 5.00 CLEAN N WAIT 3,055.0 DECOMP CONTINUE TO WAIT ON PHASE III WEATHER CONDITIONS. -PERMISSION GRANTED TO CONDUCT 12:00 HRS CHANGE OUT. -(11)PEOPLE FROM CAMP TO RIG AND(8) PEOPLE FROM RIG TO CAMP. -APPROXIMATE TRAVEL TIME=20 MINUTES, LOADER ESCORTED. -PJSM,RADIO CHECK AND CALL IN REQUIRED.NO ISSUES. 17:00 - 00:00 7.00 CLEAN N WAIT 3,055.0 DECOMP INCIDENT MANAGEMENT TEAM ADVISES NO CHANGE OUT. -NO VEHICLE TRAVEL ALLOWED,NO CHANGE OUT @ 18:00. -CONTINUE TO STAND BY DUE TO WEATHER. 1/15/2013 00:00 - 06:00 6.00 CLEAN N WAIT 3,055.0 DECOMP CONTINUE TO WAIT ON PHASE III WEATHER CONDITIONS. -PERMISSION GRANTED TO CONDUCT CHANGE OUT AT 02:15 AM HRS. -(11)PEOPLE FROM CAMP TO RIG AND(14) PEOPLE FROM RIG TO CAMP. -APPROXIMATE TRAVEL TIME=35 MINUTES, LOADER ESCORTED. -PJSM,RADIO CHECKAND CALL IN REQUIRED.NO ISSUES. Printed 2/25/2013 10:30:29AM • • • Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27/2013 X4-00WXH-E:DRILL(3,404,000.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°16'21.894"4 Long: 0148°19'23.026"W Active datum:Kelly Bushing/Rotary Table @90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 10:00 4.00 CLEAN N WAIT 3,055.0 DECOMP CONTINUE TO WAIT ON PHASE III WEATHER CONDITIONS. -WEATHER CONDITIONS IMPROVED.PHASE 2 WEATHER LEVEL 3 ROAD CONDITIONS ANNOUNCED @ 0700. -CONTINUE MONITORING WELL -NO PERSONNEL MOVEMENT ON ROADS -LOADER AND ROUSTABOUT TRAVELED FROM CAMP TO RIG AT 08:15.PJSM,RADIO COMMUNICATIONS CHECK BEFORE DEPARTING. -LOADER STARTED BLADING AND CLEANING UP ON PAD -SHOVEL OUT ENTRY WAYS,CHINK CRACKS IN RIG -TABLETOP RIG EVACUATION 10:00 - 11:00 1.00 CLEAN P DECOMP INCIDENT MANAGEMENT TEAM CALLED OUT. -INFORMED US THAT WELL CONTROL EQUIPMENT,SPILL RESPONSE EQUIPMENT IS DUG OUT AND READY TO BE MOBILIZED IF NEED BE.PLANES ARE FLYING.WELL TEAM LEADER JAMES WILLINGHAM NOTIFIED, PERMISSION GRANTED TO GO BACK TO WORK. PJSM-SLIP AND CUT DRILL LINE -59.5'OF WIRE ROPE CUT OFF OF DRILL LINE. -MONITOR WELL FOR GAINS/LOSSES 11:00 - 11:30 0.50 CLEAN P. DECOMP RIG SERVICE -GREASE TOP DRIVE -INSPECT DERRICK-NO DEFICIENCIES FOUND 11:30 - 12:30 1.00 CLEAN P DECOMP TRIP OUT OF THE HOLE WITH 4"DRILL PIPE AND STRING MILL ASSEMBLY -TRIP OUT FROM 3,053'TO 300'STANDING BACK DRILL PIPE IN DERRICK 12:30 - 14:30 2.00 CLEAN P DECOMP FLOW CHECK WELL FOR 10 MINUTES-NO FLOW -CHANGE OUT4"DRILL PIPE ELEVATORS TO 4.5"ELEVATORS. -LAY DOWN 6 1/4"DRILL COLLARS AND BAKER STRING MILL BHA -INSPECT INNER MILL AND FOUND SIGNS OF MILLING ON 4.5"STUMP 14:30 - 15:30 1.00 CLEAN P DECOMP LAY DOWN BHATHRU BEAVER SLIDE -LAY DOWN BAKER OVERSHOT WITH INNER MILL,MAGNETS,OIL JARS AND BUMPER JARS OFF OF RIG FLOOR -CLEAR FLOOR OF ALL CROSSOVERS NOT NEEDED 15:30 - 18:30 3.00 CASING P DECOMP PJSM WITH HES ON MAKE UP OF 9 5/8"HES RTTS PACKER -MAKE UP 9 5/8"HES CHAMP PACKER ON DRILL PIPE AND RUN IN HOLE TO 4,000' Printed 2/25/2013 10:30:29AM i • . _ :: fi��rlCa-ALASKA- e =ration Summary Rep Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27/2013 X4-00VVXH-E:DRILL(3,404,000.00) Project:Prudhoe Bay Site:PB DS 11 • Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UVVI:/Lat:070°16'21.894"4 Long: 0148°19'23.026"W Active datum:Kelly Bushing/Rotary Table @90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:30 - 21:00 2.50 CASING P DECOMP TEST 9 5/8"CASING -ESTABLISH PARAMETERS BEFORE SETTING PACKER(PICK UP WEIGHT 107K,SLACK OFF WEIGHT 104K) -RIG UP TO PUMP DOWN IA -PUT 1 TURN TO RIGHT ON PACKER,SLACK -,OFF 20K -CONFIRM PACKER IS SET AT 4,000'(CENTER ELEMENT) -R$RESSURED UP ON IA29 STROKES TO 3,530 PSI -CLOSE OFF PUMP AND KILL LINE HCR TO TRAP PRESSURE FOR TEST -15 MINUTE PRESSURE WAS 3,505 PSI,30 MINUTE PRESSURE WAS 3,500 • PSI-SUCCESSFUL TEST -OBTAINED APPROVAL FROM JAMES WILLINGHAM TO MOVE FORWARD AT 20:45 1/15/2013 -RELEASE,PRESSURE AND BLOW DOWN LINES IN PREPARATION TO TRIP OUT OF THE HOLE. -RELEASE PACKER 21:00 - 22:30 1.50-- -. CASING P DECOMP -PULL OUT OF THE HOLE WITH 9 5/8"HES • • RTTS PACKER -PULL OUT OF THE HOLE FROM 4,000'TO SURFACE -LAY DOWN HES PACKER AND RUNNING TOOL 22:30 - 00:00 1.50 CASING P DECOMP PICK UP CASING TONGS FOR 7"SCAB LINER RUN -PICK UP CASING TONGS AND 7"SIDE DOOR ELEVATORS TO RIG FLOOR AND RIG UP 1/16/2013 00:00 - 00:30 0.50 CASING P DECOMP RIG SERVICE -LUBRICATE TOP DRIVE AND DRAWWORKS 00:30 - 09:00 8.50 CASING P DECOMP CONTINUE RIG UP TO RUN 7"SCAB LINER RUN ON TORQUE TURN. -SIM-OPS:STRAPPING 7"CASING AND ORGANIZING 7"JEWLRY FOR RUN IN HOLE. ***24 HOUR NOTIFICATION GIVEN TO AOGCC @ 08:30 AM VIA WEB.ACKNOWLEGMENT EMAIL RECIEVED @ 08:37 VIA EMAIL **RIGHT TO WITNESS BOPE TEST WAIVED BY AOGCC REP.JOHN CRISP(08:51 1/16/13** 09:00 - 12:00 3.00 CASING P DECOMP PJSM,RUN 7"SCAB LINER _ -RUN BAKER WLSRBP RETRIEVABLE BRIDGE PLUG IN 7"CASING AND SET,TOOK 4000 PSI TO SET.TOP OF RBP SET AT 10,750' -DUMP SAND ON TOP OF BRIDGE PLUG, FILLING ONE JOINT OF CASING TO 6'FROM TOP OF CASING.TOP OF SAND AT 10,711' -OUTER ANNULUS PRESSURE=0 PSI 12:00 - 13:00 1.00 CASING P DECOMP CLEAR RIG FLOOR -MOBILIZED CASING TOOLS AND TOOLS NOT NEEDED FOR FURTHER OPERATIONS OFF OF RIG FLOOR - Printed 2/25/2013 10:30 29AM • • o i re��ca A[ ,S A 43P ti P Operation Summary R •, Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date 1/27/2013 X4-00WXH-E:DRILL(3,404,000.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°16'21.894"4 Long: 0148°19'23.026"W Active datum:Kelly Bushing/Rotary Table @90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:00 - 20:30 7.50 CASING P DECOMP RUN IN HOLE -MAKE UP CROSS OVER FOR PACKER RUNNING TOOL TO 4"XT-39 DP. -RUN IN HOLE FROM 115'WITH DRILL PIPE TO 10656' -FILLING EVERY 5TH STAND ON THE FLY. 20:30 - 21:30 1.00 CASING P DECOMP PIPE UP SINGLES&(1)15 FT.PUP JOINT FROM SHED -SINGLE IN FROM 10656'TO 4.5 TUBING STUB 10780' 21:30 - 22:30 1.00 CASING P DECOMP SET CASING PATCH t , -OBTAIN PARAMETERS c 10770'.PICK UP WEIGHT 200K;SLACK OFF WEIGHT 151K TAGGED STUB AT 10780','SWALLOWED 5 FT. DOWN TO 107$,5'. -PUT 10K DOWN,PULL 15K OVER,PUT STRING IN NEUTRAL WEIGHT(175K). -PRESSURED')JPTO 2800 PSI,SET PACKER. -SLACK OFF TO140K. -CONT.TQ PRESSURE UP TO 3500 PSI TO RELEASE PACKER(SHEARED AT 3050 PSI). -BLEED OFF,PICKED UP 5 FT.,SET LINER TOP PACKER 50K. -CONFIRM WITH ROTATION,SET BACK DOWN WITH 60K. -PICKED BACK UP,TURNED OFF ROTATION, PRESSURED UP TO 500 PSI,PULLED OUT OF LINER.PRESSURE DROPPED TO 350 PSI. -BLEED OFF PRESSURE,MONITOR WELL. -PUMPED STRING VOLUME TO REMOVE AIR BUBBLE FROM STRING,WELL STATIC AFTER 10 MINUTE FLOW CHECK. -IA-OA PRESSURES:0-0 22:30 00:00 1.50 CASING P DECOMP LAY DOWN(1)SINGLE&(1)15 FT.DRILL PIPE PUP JOINT. -PULL OUT OF HOLE FROM 10656'TO 7237' 1/17/2013 00:00 - 00:30 0.50 CASING P -_ DECOMP RIG SERVICE -LUBRICATE TOP DRIVE AND DRAW-WORKS 00:30 - 03:30 3.00 CASING P DECOMP PULL OUT OF HOLE FROM 7237'TO 146' -10 MINUTE FLOWCHECK BEFORE COMING THRU STACK WITH NON-SHEARABLES-NO FLOW -LAY DOWN RUNNING TOOL 03:30 - 04:00 0.50 CASING P ■- DECOMP MOBILIZE RUNNING TOOL AND SAND OFF OF RIG G FLOOR -PULL WEAR RING 04:00 - 12:00 8.00 BOPSUR P DECOMP RIG UP AND TEST BOP EQUIPMENT -TEST VBR'S WITH 4"AND 4.5"DRILL PIPE -TESTANNULAR WITH 4"DRILL PIPE AND 7" TEST JOINT -TEST UPPER PIPE RAMS WITH 7"TEST JOINT -TEST 2 XT39 FULL OPEN SAFETY VALVES. -TEST 1 XT39 DART VALVE -TEST 1 4-1/2"IF FULL OPEN SAFETY VALVE. -ALL TESTED 250 PSI LOW/3500 PSI HIGH FOR FIVE CHARTED MINUTES EACH. -OUTER ANNULUS PRESSURE=0 PSI Printed 2/25/2013 10:30:29AM • +i brtn A rletr a=AtAskA vi ° Summary Repo `'' Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27/2013 X4-O0WXH-E:DRILL(3,404,000.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.•DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°16'21.894"4 Long: 0148°19'23.026"W Active datum:Kelly Bushing/Rotary Table @90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 15:00 3.00 BOPSUR P DECOMP TEST BOP EQUIPMENT CONT. -TEST CHOKE MANIFOLD VALVES 1 THRU 14. -TEST MANUAL CHOKE&HYDRAULIC CHOKE. -TEST MANUAL IBOP&HYDRAULIC IBOP. -PERFORMED KOOMEY DRAW-DOWN AS PER PROCEDURES. 15:00 - 15:30 0.50 BOPSUR P DECOMP`—RIG DOWN BOP TEST EQUIPMENT. -PULL TEST PLUG. BOW DOWN CHOKE MANIFOLD&KILL LINE. 15:30 - 20:30 5.00 CASING P DECOMP RING UP CEMENT HEAD FOR UP COMING CCC=ME,NT JOB. -PICK Up 15 FT.PUP JOINT,MAKE UP ALL CROSSOVERS BACK TO XT-39 FOR DRILL PIPE -PICK UP 7"CENTRALIZER'S. -CHANGE OUT SHORT BALES WITH LONG BALES. -PICK OP CASING TONGS,RIG UP FOR TORQUE TURN. -INSTALL 7"SIDE DOOR ELEVATORS 20:30 - 00:00 3.50 CASING P DECOMP PJSM WITH CASING&BAKER LINER REP. RUN IN HOLE WITH 7"VAM TOP 26#HC L-80 CASING. C-2HRD-E ZXPN LINER TOP PACKER,7.5 PORTED TIEBACK SEAL ASSEMBLY, -7"HES PORTED FLOAT COLLAR -TESTED FLOATS AFTER 2ND JOINT IN. FLOATS ARE CLEAR. -RUN IN HOLE WITH 7"CASING TO 2595', FILLING CASING EVERY 5TH JOINT. INSTALLING CENTRALIZER ON EVERY JOINT ' OF VAM-TOP CASING AND 1 CENTRALIZER ON BTC-M X VAM-TOP CROSSOVER -MAKE UP TORQUE=11,9500 FT/LBS.MAKE UP WITH TORQUE TURN TOOLS. -OUTER ANNULUS PRESSURE=0 PSI 1/18/2013 00:00 - 08:30 8.50 CASING P DECOMP RUN IN HOLE WITH 7"VAMTOP SCAB LINER FROM 2,595'TO 6,700' -FILL PIPE EVERY 5 JOINTS -INSTALL CENTRALIZERS ON EVERY VAM-TOP JOINT 08:30 - 11:00 2.50 CASING P DECOMP MAKE UP TOP HANGER AND PACKER. -RUN PAUMIX IN TIE BACK SLEEVE. -SET FOR 30 MINUTES. -LAYDOWN 7"HANDLING TOOLS. -CHANGE OUT BALES. 11:00 12:30 1.50 CASING P DECOMP CIRCULATE LINER VOLUME. -PICK UP WEIGHT=205K,SLACK OFF WEIGHT=170K,5 BPM @ 250 PSI. -FIRE DRILL=1:45 RESPONSE -OUTER ANNULUS PRESSURE=0 PSI. 12:30 - 15:30 3.00 CASING P DECOMP RUN IN HOLE WITH 4"HWDP AND 4"DRILL PIPE -FROM 8337'TO 10617' -PICK UP WEIGHT=255K,SLACK OFF WEIGHT=180K Printed 2/25/2013 10:30.29AM • • • • ,zr Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27/2013 X4-00WXH-E:DRILL(3,404,000.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°16'21.894"4 Long: 0148°19'23.026"W Active datum:Kelly Bushing/Rotary Table @90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:30 - 16:00 0.50 CASING P DECOMP RUN IN HOLE WITH STAND#25,ESTABLISH CIRCULATION. -PUMP 0.7 BPM(7 SPM)@ 60 PSI. -RUN IN THE HOLE AND PRESSURE UP 80 PSI 69'DOWN ON STAND#25. -PUMP OFF AND CONTINUE RIH TO NO GO 77' DOWN(10683.66') PULL OUT OF HOLE AND LAY DOWN TOP JOINT FOR SPACE OUT. -BLOW DOWN TOP DRIVE. 16:00 - 16:30 0.50 CASING P DECOMP PJSM ON MAKING UP CEMENT HEAD TO STRING. -MAKE UP 15'PUP UNDER CEMENT HEAD. -HOOK UP HOSES,SHACKLES,SLINGS NEEDED FOR ROTATION CEMENT HEAD. -TOP TIW SHUT IN,BOTTOM TIW OPEN. 16:30 - 17:00 0.50 CASING P DECOMP CIRCULATE 0.9 BPM(9 SPM)240 PSI. -RUN IN HOLEAND TAG AGAIN. -PRESSURE UP TO 100 PSI,PUMPS OFF. -CONTINUE RUN IN HOLE AND HIT NO GO. -PULL OUT OF HOLE 10'AND CIRCULATE LINE VOLUME. 17:00 - 19:30 2.50 CASING P DECOMP CIRCULATE 5 BPM(50 SPM)@ 520 PSI. -HOOK UP INNTER ANNULUS LINES IN CELLAR TO OPEN TOP TANK. -BLOW DOWN LINES TO CEMENT TRUCK. 19:30 - 21:00 1.50 CASING P DECOMP PJSM ON PRESSURE TESTING CEMENT LINES. -PRIME PUMPS WITH 5 BBLS WATER. -PRESSURE TEST 300 PSI LOW FOR 5 MINUTES. -PUMP 5 BBLS WATER THRU LINES. -PRESSURE TEST 4000 PSI HIGH. 21:00 - 00:00 3.00 CASING P DECOMP PUMP CEMENT. -PUMP 2 BBLS OF WATER FOLLOWED BY 220 BBLS OF 15.8#CEMENT. -LAUNCH PLUG.PUMP 5 BBLS WATER, SWITCH OVER TO THE RIG TO DISPLACE. -PLUG BUMPED AT 313.4 BBLS @ 2400 PSI (FINAL DISPLACEMENT PRESSURE 2300 PSI) (SPOKE WITH SEAN MCLAUGHLIN TO INCREASE MAXIMUM PRESSURE TO 2400 PSI DUE TO SHEAR SCREWS ON HANGER SET AT 3060 PSI-BOT'S 15%=2600 PSI). CALCULATED VOLUME WAS 318.7 BBLS ***BUMPED PLUG AT 23:18 -SLACK OFF AND BLEED OFF PRESSURE TO SET STINGER. -PRESSURE UP TO 3500 PSI,BLED OFF TO 500 PSI.PICK UP TO 240K,SLACK OFF TO 165K TO SET HANGER -ROTATED 5 TURNS TO THE RIGHT,ROTATED 10 MORE TURNS TO THE RIGHT. -BLOW DOWN CEMENT HOSE AND KNOCK OFF HOSE. Printed 2/25/2013 10:30:29AM • • 0 •n Summary R= • Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27/2013 X4-00WXH-E:DRILL(3,404,000.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°16'21.894"4 Long: 0148°19'23.026"W Active datum:Kelly Bushing/Rotary Table @90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations hr) (ft 1/19/2013 00:00 - 00:30 0.50 CASING P DECOMP SET PACKER. -SET DOWN TO 50K PUMPING 1 BPM 280 PSI,GOOD SURFACE INDICATION IT SHEARED. -PICK UP AND ROTATED 25 RPM,SET DOWN 50K,INSURING WEIGHT GOT TO PACKER. --INCREASED PUMP RATE TO 8 BBUMIN WHILE PULLING UP 31'TO CLEAR RUNNING TOOL FROM PACKER. 00:30 - 01:00 0.50 CASING P DECOMP CIRCULATE 125;BBL,10 BPM©1000 PSI. -SHUT IN BOTTOM RAMS AND CIRCULATE OUT 99 BBLS TO OPEN TOP TANK,7 BPM 2500 PSI. -CEMENT OBSERVED AT TANK AT 137 BBLS (125 BBLS+12 BBLS).CEMENT CLEARED UP AT 215 BBLS. 01:00 - 01:30 0.50 CASING P DECOMP RIG DOWN CEMENT HEAD OFF OF RIG FLOOR TO RIPE SHED -BREAK OUT-AND LAY DOWN SINGLE AND 15' PUP JOINT UNDER CEMENT HEAD 01:30 - 02:00 0.50 CASING "P DECOMP LINE UP AND TAKE RETURNS TO ROCK WASHER. -CIRCULATE 150 BBLS WHILE RECIPROCATING PIPE 60'UP AND DOWN -CIRCULATE AT 10 BBL/MIN AT 800 PSI -NO CEMENT DETECTED 02:00 - 04:00 2.00 CASING P DECOMP FLOW CHECK WELL FOR 10 MINUTES-NO FLOW -PULL OUT OF HOLE RACKING BACK DRILL PIPE AND LAYING DOWN 4"HWDP TO PIPE SHED -PULL OUT OF HOLE FROM 3020'TO SURFACE(FLOWCHECK BEFORE BHA ENTER BOP STACK) 04:00 - 05:30 1.50 CASING P DECOMP BREAK OFF CROSSOVERS AND UPPER PUP JOINT FROM CEMENT HEAD. -USE STACK WASHER AND CLEAN OUT BOP STACK -INSTALL WEAR RING 05:30 - 06:30 1.00 CASING P ■- DECOMP LAY DOWN O OVERLAND PUP JOINT OFF RIG FLOOR OR FROM 7"LINER RUN. -MOBILIZE DRILL OUT BHA TO RIG FLOOR 06:30 - 09:30 3.00 CASING P DECOMP MAKE UP DRILL OUT BHA. -RUN IN HOLE TO 2987' -RAN HUGHES 6 1/8"RC216(IADC 216)BIT WITH 3-20'S ON JETS BIT -KICK WHILE TRIPPING DRILL=2:10 RESPONSE TIME. 09:30 - 11:00 1.50 CASING P ._ DECOMP SLIP AND CUT DRILL LINE. -REMOVED 59.5',1881'LEFT ON SPOOL 11:00 - 11:30 0.50 CASING P DECOMP LUBRICATE RIG 11:30 - 12:00 0.50 CASING P -_ DECOMP RUN IN HOLE FROM 2987'TO 3272' -OUTER ANNULUS PRESSURE=350 PSI 12:00 - 16:00 4.00 CASING P DECOMP RUN IN HOLE FROM 3272'TO 10015' Printed 2/25/2013 10:30:29AM • • / Ids , <s;, \vgn4iskIaW:Musw Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27/2013 X4-00WXH-E:DRILL(3,404,000.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°16'21.894"4 Long: 0148°19'23.026"W Active datum:Kelly Bushing/Rotary Table©90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:00 - 21:00 5.00 CASING P DECOMP CIRULATE 7 BBL/M,284 GPM,1310 PSI,RPM= 30,8K FT-LBS ROTARY TORQUE -PICK UP WEIGHT=212K,SLACK OFF WEIGHT=135K,ROTATE=135K. -CIRULATE TO HELP CEMENT SET UP. -TEMP GOING IN @ 78 DEG.,RETURN TEMP @ 57 DEGREES. -TEMP IN 74 DEG.,TEMP OUT 64 DEG.AFTER 600 BBLS PUMPED. -FINAL TEMP OUT 68 DEGREES. 21:00 - 21:30 0.50 CASING P DECOMP PJSM ON DRILL OUT SHOE TRACK&PLUGS -RUN IN HOLE FROM 10015'TO 10544' -START PUMPS AT TOP OF STAND AT 10,490'. PUMPAT7 BBL/MIN @ 1300 PSI PUMP PRESSURE -ESTABLISH PARAMETERS:PICK UP WEIGHT 218K,SLACK OFF WEIGHT 128K 21:30 - 00:00 2.50 CASING P DECOMP TAG AND DRILL CEMENT -TAGGED CEMENT STRINGERS AT 10543' -TAGGED TOP OF CEMENT AT 10,564' -INCREASE PUMP RATE TO 11 BPM,447 GPM @ 3100 PSI. -PUW=218K,SOW=128K,ROT=165K,100 RPM WITH 11KTORQUE. -DRILL OUT CEMENT AND STRINGERS FROM 10544'TO 10580',CONTROLLED RATE OF 3 MINUTE PER FOOT AND 1-3K WEIGHT ON BIT. OA PRESSURE-300 PSI 1/20/2013 00:00 - 08:00 8.00 CASING P DECOMP CONTINUE CONTROLLED DRILL CEMENT, PLUG,SHOE TRACK @ FOLLOWING PARAMETERS:PUMP RATE 11 BBL/MIN,TOP DRIVE RPM'S 100 @ 9-11K FT-LBS TORQUE, PUMP PRESSURE 3050 PSI,WOB 1-3K -DRILL FROM 10580'TO 10,615' -TAGGED PLUG AT 10,613'(02:00 AM).PLUG SPINNING ON BOTTOM.INCREASE WEIGHT ON BIT TO 12-15K. -DRILLED THRU PLUG AT 10,615 @ 04:50 AM -TEMPERATURE IN 88 DEGREES, TEMPERATURE OUT 102 DEGREES -OA PRESSURE @ 0300-800 PSI -OA PRESSURE @ 0400-800 PSI -OA PRESSURE @ 0500-950 PSI -OA PRESSURE @ 0600-1100 PSI -SPOKE WITH J.WILLINGHAM AND RECEIVED PERMISSION TO BLEED DOWN OA(THERMAL EXPANSION SUSPECTED) -TOOK 30 SECONDS TO BLEED TO 0 PSI., ONLY FLUID CAME OUT DURING BLEED OFF NO GAS. 08:00 - 10:00 2.00 CASING N RREP DECOMP TOP DRIVE ROTARY FAILURE -TROUBLESHOOT AND REPAIR(OIL LEVEL IN GEARBOX) Printed 2/25/2013 10:30:29AM • r S ' it4t Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27/2013 X4-00VVXH-E:DRILL(3,404,000.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°16'21.894"4 Long: 0148°19'23.026"W Active datum:Kelly Bushing/Rotary Table @90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 11:00 1.00 CASING P DECOMP CONTINUE DRILLING CEMENT WITH PARAMETERS OF PUMP RATE 11 BBL/MIN, 100 RPM'S,9-11K FT-LBS TORQUE,PUMP PRESSURE 3050 PSI,WOB 1-3K -DRILL FROM 10,615'MD TO 10,693'MD-BOTTOM OF TIE-BACK SLEEVE -ATTEMPED TO PUSH DOWNHOLE WITHOUT SUCCESS WITH 2OKL WEIGHT ON BIT -ROTATE TO TOP OF SAND AT 30 RPM ON TOP DRIVE TO 10,712'-TOP OF SAND -WASH/REAM 10'OF SAND FROM 10,712'TO 10,722' 11:00 - 11:30 0.50 CASING P DECOMP CIRCULATE BOTTOMS UP AT 10.5 BBL/MIN AT 3100 PSI.PUMP PRESSURE 11:30 - 12:30 1.00 CASING P DECOMP DRY DRILL SAND @ BO RPM'S WITH 11K TOP DRIVE TORQUE. -OA PRESSURE AT CREW CHANGE AT NOON ISO PSI. 12:30 - 13:30 1.00 CASING P DECOMP PULL OUT OF HOLE TO 10,691'MD AND CIRCULATE 20 BBL HI-VIS SWEEP SURFACE TO SURFACE WITH 450 BBLS,CIRCULATE AT 11 BBLS PER MINUTE, WITH 2940 PSI.PUMP PRESSURE.TOTAL PUMPED 574 BBLS. 13:30 - 14:00 0.50 CASING P DECOMP OBTAIN SLOW PUMP RATES AT 10,691'MD -PUMP 1-150 PSI AT 20 STKS/MIN AND 290 PSI AT 30 STKS/MIN -PUMP 2-150 PSI AT 20 STKS/MIN AND 290 PSI AT 30 STKS/MIN PERFORM 10 MINUTE FLOW CHECK,WELL STATIC 14:00 - 18:30 4.50 CASING_ P DECOMP PULL OUT OF HOLE F/10,691'MD T/233'MD -KICK WHILE DRILLING DRILL -10 MINUTE FLOW CHECK ON LAST STAND OF DRILL PIPE-WELL STATIC. 18:30 - 19:30 1.00 CASING P DECOMP STAND BACK 2 STANDS OF DRILL COLLARS AND LAY DOWN BHA#3 19:30 - 20:00 0.50 CASING P DECOMP PJSM ON LINING UP AND PRESSURE TESTING CASING TO 3500 PSI. 20:00 - 22:00 2.00 CASING P DECOMP TEST CASING TO 3500 PSI -CIRCULATE AIR OUT OF KILLAND CHOKE LINES. -PRESSURE UP TO 3500 PSI.TOOK 5 BBLS. 50 STROKES) -HOLD FOR 30 MINUTES AND CHART. -0 PSI.ON OA DURING TEST. -BLEED OFF AND WAIT ON APPROVAL FROM WTL.TEST APPROVED BY J.WILLINGHAM 22:00 1/20/13 22:00 - 23:00 1.00 CASING P DECOMP FLUSH OUT STACK -BLOW DOWN LINES. -PULL WEAR BUSHING. -FLUSH BOPE STACKAT9 BBL/MIN WITH 60 PSI.AND 50 RPM'S Printed 2/25/2013 10:30:29AM • • a Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27/2013 X4-00WXH-E:DRILL(3,404,000.00) Project Prudhoe Bay Site:PB DS 11 Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UWI•/Lat:070°16'21.894"4 Long: 0148°19'23.026"W Active datum:Kelly Bushing/Rotary Table @90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 23:00 - 00:00 1.00 CASING P DECOMP PULL 9 5/8 MANDREL PACKOFF -PJSM WITH CAMERON REPRESENTATIVES ON PULLING PACK-OFF THROUGH BOPE STACK -MAKE UP RETRIEVING TOOL AND LATCH INTO PACK-OFF -REMOVE OLD PLASTIC PACKING FROM MANDREL VOID. -0 PSI.ON OAAND OA VENTED TO OPEN TOP TANK DURING RETRIEVAL OF PACK-OFF. 1/21/2013 00:00 - 02:30 2.50 WHSUR P DECOMP REMOVE 9-5/8"MANDREL PACK-OFF THROUGH BOPE STACK. -BROKE FREE AT 23K OVER -INSTALL NEW 9-5/8"MCEVOY MANDREL PACK-OFF TYPE YBT. -SQUEEZE NEW GRAPHITE-PLASTIC PACKING INTO PACK-OFF VOID. 02:30 - 04:00 1.50 WHSUR P' DECOMP TEST VOID AND SEALS ON 9-5/8"MANDREL PACKOFF -TEST TO 5000 PSI FOR 30 CHARTED MINUTES -TEST GOOD 04:00 - 04:30 0.50 WHSUB P DECOMP INSTALL WEAR BUSHING -WEAR BUSHING I.D.=12.25" 04:30 - 10:00 5.50 CLEAN` P DECOMP RUN IN HOLE WITH CLEANOUT BOTTOM HOLE ASSEMBLY#4 -MA W CIRCULATING AKE UP CLE JUNK NOUT BASKETAND BHA ITH BOOT BASKETS -RUN IN HOLE WITH CLEAN OUT BOTTOM HOLE ASSEMBLY TO 10,722'MD -PERFORM FIRE DRILL,RESPONSE TIME 1 MINUTE 45 SECONDS 10:00 - 10:30 0.50 CLEAN P DECOMP BREAK CIRCULATION AND DROP DIVERTER BALL -CIRCULATE AT 7 BARRELS PER MINUTE WITH 1750 PSI.PUMP PRESSURE -ESTABLISH CIRCULATION AND SHUT DOWN PUMPS -DROP DIVERTER BALL AND CONTINUE CIRCULATING AT 7 BARRELS PER MINUTE WITH 1750 PSI.PUMP PRESSURE -PUMP PRESSURE CAME UP TO 2390 PSI. WHEN BALL LANDED ON SEAT 10:30 - 12:30 2.00 CLEAN P DECOMP O SLOW DOWN BTAIN WITH REVERSE PUMP CIRCULATING RATESAND WASH JUNK BASKET FROM 10,723'MD TO 10,733'MD -PICK UP WEIGHT 220K,SLACK OFF WEIGHT 135K,ROTATING WEIGHT 155K,WEIGHT ON BIT 15K -PUMP RATE 7 BARRELS PER MINUTE PUMP PRESSURE ON BOTTOM 3100 PSI,PUMP PRESSURE OFF BOTTOM 2390 PSI. -ROTATIONS PER MINUTE 100,ROTARY TORQUE OFF BOTTOM 11K,ROTARY TORQUE ON BOTTOM 12-13K -CONTINUE MILLING AND CYCLING PUMPS TO LOAD REVERSE CIRCULATING JUNK BASKET OA=OPSI Printed 2/25/2013 10:30:29AM • w 1 ' en Summary Re Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27/2013 X4-00WXH-E:DRILL(3,404,000 00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°16'21.894"4 Long: 0148°19'23.026"W Active datum:Kelly Bushing/Rotary Table©90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:30 - 13:00 0.50 CLEAN P DECOMP 10 MINUTE FLOW CHECK -9.8 PPG BRINE IN AND 9.8 PPG BRINE OUT -WELL STATIC -STAND BACK ONE STAND AND BLOW DOWN TOP DRIVE 13:00 - 17:00 4.00 CLEAN P DECOMP PULL OUT OF HOLE WITH REVERSE `CIRCULATING JUNK BASKET BOTTOM HOLE ASSEMBLY -P JLL FROM 10,700'MD TO 66'MD -PERFORM SPILL DRILL 17:00 - 18:00 1.00 CLEAN P DECOMP 10 MINUTE FLOW CHECKAT BOTTOM HOLE ASSEMBLY -WELL STATIGAND PROPER HOLE FILL ACHIEVED -PULL REVERSE CIRCULATING JUNK BASKET TO RIG FLOOR -CLEAN'OUT REVERSE CIRCULATING JUNK BASKET. -NO.JUNK OR CEMENT IN BOOT BASKETS -RETRIEVED 3.5 GALLONS CEMENT(RANGE FROM FINE POWDER TO PIECES 1"TO 3") AND TWO LARGE PIECE WEDGED IN BOTTOM OF JUNK BASKET(SEE ATTACHED PICTURES WITH THIS REPORT) 18:00 - 22:00 4.00 CLEAN` P DECOMP RERUN BOTTOM HOLE ASSEMBLY#4 -MAKE UP BOTTOM HOLE ASSEMBLY#4 -RUN IN HOLE FROM 66'MD TO 10,035'MD OUT OF DERRICK -PERFORM KICK WHILE TRIPPING DRILL 22:00 - 00:00 2.00 CLEAN P DECOMP PRE JOB SAFETY MEETING AND SLIP AND CUT DRILLING LINE -CUT 59'OFF OF DRILLING LINE AND SLIP ON 59'OF DRILLING LINE,PRESENT LENGTH OF DRILLING LINE 1881' OA=0 PSI 1/22/2013 00:00 - 00:30 0.50 CLEAN P DECOMP RIG SERVICE 00:30 - 01:00 0.50 CLEAN P DECOMP TRIP PIPE IN HOLE FROM DERRICK -RUN IN HOLE FROM 10,035'TO 10,735' 01:00 - 01:30 0.50 CLEAN P DECOMP -OBTAIN REAMING PARAMETERS -TAGGED SAND AT 10,735'(NO ROTATION) -PICK UP TO 10,723' -BREAK CIRCULATION FOR 15 MINUTES:7.5 BBLS PER MINUTE @ 2490 PSI -PICK UP WEIGHT 205K,SLACK OFF WEIGHT 135K(NO ROTATION) -ROTATE AT 80 REVOLUTIONS PER MINUTE @ 7K FT-LBS TORQUE(OFF BOTTOM) Printed 2/25/2013 10:30:29AM ! ! Am-h America-ALASKA 2. •e a i•tisummary Report s` Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27/2013 X4-00WXH-E:DRILL(3,404,000.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UVN:/Let 070°16'21.894"4 Long: 0148°19'23.026"W Active datum:Kelly Bushing/Rotary Table @90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:30 - 02:00 0.50 CLEAN P DECOMP MILL WITH REVERSE CIRCULATING JUNK BASKET FROM 10,733'(ROTATING)TO 10,738' (ROTATING) -RUN IN HOLE AND TAG WHILE ROTATING AT 10,733' -MILL WITH FOLLOWING PARAMETERS: ROTATING WEIGHT 155K,80 REVOLUTIONS PER MINUTE @ 11K FT-LBS TORQUE OFF BOTTOM,13K FT-LBS ON BOTTOM,PUMP AT 7 dBL/MIN-2940 PSI OFF BOTTOM,3000 PSI ON BOTTOM,WEIGHT ON BIT=5K -MILLED 5',SAN D -PICK BACK UP 10'AND WORK UP AND DOWN AND CYCLE PUMPS TO LOAD BOOT BASKETS 02:00 - 07:00 5.00 CLEAN P DECOMP PULL OUT OF HOLE STANDING BACK DRILL PIPE IN DERRICK _ FLOWCHECK VVEI,L -WELL STATIC(9.8 PPG BRINE IN/OUT) 07:00 - 08:00 1.00 CLEAN P 4DEOOMP EMPTY REVERSE CIRCULATION JUNK BASKET. RETRIEVED 1 GALLON OF CEMENT CHUNKS, NO OTHER DEBRIS FOUND IN BASKET 08:00 - 12:00 4.00 CLEAN P DECOMP RUN IN HOLE WITH SAME BHA#4,REVERSE CIRCULATING JUNK BASKET. -TO 10,147' -OUTER ANNULUS PRESSURE=0 PSI -FLUID LOSSES TO WELL=0 12:00 - 12:30 0.50 CLEAN P` - DECOMP LUBRICATE RIG 12:30 - 13:00 0.50 CLEAN P DECOMP RUN IN HOLE CONTINUE -FROM 10147'TO 10700' 13:00 - 13:30 0.50 CLEAN P- DECOMP OBTAIN PARAMETERS. 9 BARRELS PER MINUTE WITH 3420 PSI WITH 11-12K TORQUE. -WEIGHT ON BIT=5K,ROTATE=161K,SLACK OFF WEIGHT=131K,PICK UP WEIGHT=22K -WASH DOWN FROM 10738'TO 10743' 13:30 - 14:00 0.50 CLEAN P DECOMP 10 MINUTE FLOW CHECK. -RACK BACK 1 STAND. -BLOW DOWN TOP DRIVE 14:00 - 19:00 5.00 CLEAN P DECOMP PJSM ON PULLING OUT OF HOLE. PULL OUT OF HOLE FROM 10700'TO 66'. -KICK WHILE TRIPPING DRILL. 19:00 - 21:00 2.00 CLEAN P DECOMP 10 MINUTE FLOW CHECK,BREAK OUT BHA #4. -BREAK OUT REVERSE CIRCULATION JUNK BASKET,NO DEBRIS INSIDE. -LAY DOWN BHA#4. -MOBILIZE PLUG RETRIEVAL ASSEMBLY TO RIG FLOOR. -FIRE DRILL **PRUDHOE BAY RADIO ANNOUNCED ROAD PHASE 2/LEVEL 2 ROAD CONDITIONS AT 19:30** Printed 2/25/2013 10:30:29AM • Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27/2013 X4-00WXH-E:DRILL(3,404,000.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°16'21.894"4 Long: 0148°19'23.026"W Active datum:Kelly Bushing/Rotary Table @90.1ft(above Mean Sea Level) -Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:00 - 00:00 3.00 CLEAN P DECOMP PJSM ON RUN IN HOLE WITH BRIDGE PLUG RETRIEVAL TOOL. -MAKE UP BHA#5. -RUN IN HOLE FROM 5'TO 6500' -OUTER ANNULUS PRESSURE=0 PSI. -FLUID LOSSES TO WELL=0 1/23/2013 00:00 - 00:30 0.50 CLEAN P • DECOMP SERVICE TOP DRIVE,BLOCKS AND DRAW WO R KS. 00:30 - 02:00 1.50 CLEAN P DECOMP CONTINUE RUN IN HOLE WITH BHA#5 ON 4" DRILL PIPE FROM DERRICK -RUN IN THE HOLE WITH BRIDGE PLUG RETRIEVAL TOOL FROM 6500'TO 10736' 02:00 - 02:30 0.50 CLEAN P DECOMP REVERSE CIRCULATE TO WASH SAND OFF OF 7"RETRIEVABLE BRIDGE PLUG. -PJSM WITH RIG CREW,BAKER FISHING REP AND WSL. -RIG UP TO REVERSE SAND OFF OF RETRIEVABLE BRIDGE PLUG. -OPEN KILL LINE HCR AND CLOSE ANNULAR PREVENTER. -REVERSE CIRCULATE AT6 BARRELS PER MINUTE. -WASH SAND FROM 10743'TO 10750'. -PICK UP WEIGHT=215K LBS;SLACK OF WEIGHT=130K LBS. 02:30 - 05:00 2.50 FISH P DECOMP ENGAGE AND RELEASE 7"RETRIEVABLE BRIDGE PLUG. -OPEN ANNULAR PREVENTER AND CLOSE KILL LINE HCR. -WASH DOWN OVER BRIDGE PLUG AT6 BARRELS PER MINUTE AND 890 PSI. -FROM 10750'TO 10753'. -PRESSURE INCREASE TO 1000 PSI AT 10753'. -SHUT DOWN PUMPS AND SET DOWN 15K LBS TO ENGAGE BRIDGE PLUG. -PICKED UP TO 225K LBS AND RELEASED BRIDGE PLUG. -PICKED UP 10'AND FLOW CHECKED WELL FOR 10 MINUTES. -WELL STABLE. -SLACK OFF TO 10763'AND VERIFY BRIDGE PLUG IS RELEASED. -BLOW DOWN LINES. **PRUDHOE BAY RADIO ANNOUNCED PHASE 1 WEATHER CONDITIONS AT 04:30** 05:00 - 10:30 5.50 FISH P DECOMP PULL OUT OF THE HOLE WITH 7" RETRIEVABLE BRIDGE PLUG,STANDING BACK4"DRILL PIPE. -FROM 10763'. -LAY DOWN RETRIEVABLE BRIDGE PLUG AND RETRIEVAL TOOL. **AOGCC,LOU GRIMALDI,WAIVED BOPE TEST WITNESS** Printed 2/25/2013 10:30:29AM • • I Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27/2013 X4-00WXH-E:DRILL(3,404,000.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°16'21.894"4 Long: 0148°19'23.026"W Active datum:Kelly Bushing/Rotary Table @90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:30 - 11:30 1.00 FISH P DECOMP RIG UP TO HANDLE 2-7/8"PAC DRILL PIPE. -PJSM WITH RIG CREW. -MOBILIZE TONGS TO RIG FLOOR. -RIG UP TONGS FOR MAKING UP 2-7/8"PAC DRILL PIPE. -CHANGE ELEVATORS TO HANDLE 2-7/8"PAC DRILL PIPE. 11:30 - 13:00 1.50 FISH P DECOMP MAKE UP BHA#6,JUNK CATCHER SPEAR ASSEMBLY. -PJSM WITH RIG CREWAND BAKER FISHING REPRESENTATIVE. -PICK UP ITCO SPEAR DRESSED WITH 2.933 NOMINAL GRAPPLE. -MAKE UP 5 JOINTS OF 2-7/8"PAC DRILL PIPE. -BHA OVERALL LENGTH IS 366.67' 13:00 - 14:00 1.00 FISH P DECOMP RUN IN THE HOLE WITH BHA#6,JUNK CATCHER ASSEMBLY ON 4"DRILL PIPE OUT OF THE DERRICK. -FROM 366'TO 2930'. -FILL PIPE EVERY 20 STANDS. 14:00 - 16:00 2.00 FISH P DECOMP SLIP AND CUT DRILL LINE. -PJSM WITH RIG CREW. -SLIP AND CUT 59.5'DRILL LINE. -SERVICE TOP DRIVE,BLOCKS,AND DRAW WORKS. 16:00 - 20:00 4.00 FISH P DECOMP CONTINUE TO RUN IN THE HOLE WITH THE JUNK CATCHER ASSEMBLY ON 4"DRILL PIPE OUT OF THE DERRICK. -FROM 2930'TO 10710'. -FILL PIPE EVERY 20 STANDS. 20:00 - 21:30 1.50 FISH P DECOMP ESTABLISH FISHING PARAMETERS AND ENGAGE JUNK CATCHER. -MAKE UP TOP DRIVE AND ESTABLISH PARAMETERS. -PICK UP WEIGHT=233K LBS;SLACK OF WEIGHT=140K LBS. -ROTATING WEIGHT=180K LBS;20 RPM; 11K FT-LBS TORQUE. -RUN IN ONE STAND FROM 10718'TO 10813'. -WASH DOWN FROM 10813'AND TAG JUNK CATCHER AT 10858'. -2 BARRELS PER MINUTE AND 390 PSI. -PRESSURE INCREASED TO 500 PSI AS SPEAR ENTERED JUNK CATCHER. -SHUT DOWN PUMPS -SET DOWN 10K LBS TO ENGAGE SPEAR IN JUNK CATCHER. -PICKED UP TO STRING WEIGHT AND SET DOWN ON JUNK CATCHER WITH 10K LBS 2 TIMES. -PICKED UP TO 10713'. -PULLED 40K LBS OVER AT 10827'. -OBSERVED 5K LBS DRAG TO 10713'. 21:30 - 22:00 0.50 FISH P DECOMP DROP DART AND OPEN PUMP OUT SUB. -DROP DART AND WAIT 10 MINUTES FOR DART TO FALL. -PUMP 1 BARREL PER MINUTE AND PRESSURE UP TO OPEN PUMP OUT SUB. -PUMP OUT SUB OPENED AT 2000 PSI. Printed 2/25/2013 10:30:29AM • . • Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27/2013 X4-00WXH-E:DRILL(3,404,000.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°16'21.894"4 Long: 0148°19'23.026"W Active datum:Kelly Bushing/Rotary Table©90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 00:00 2.00 FISH P DECOMP DISPLACE WELL TO 8.5 POUND PER GALLON SEAWATER. -PJSM WITH RIG CREW,CH2MHILL TRUCK PUSHERS AND WSL. -PUMP 30 BARREL 9.8 POUND PER GALLON HIGH-VIS SWEEP. -7 BARRELS PER MINUTE AND 400 PSI. -CHASE SWEEP WITH 8.5 POUND PER GALLON SEAWATER. -7 BARRELS PER MINUTE AND 1450 PSI. 1/24/2013 00:00 - 01:30 1.50 FISH P DECOMP CONTINUE DISPLACING 9.8 POUND PER GALLON BRINE TO 8.5 POUND PER GALLON SEAWATER. -DISPLACING AT 7 BARRELS PER MINUTE WITH 175 PSI PUMP PRESSURE. -PUMPED 480 BARRELS OF 8.5 POUND PER GALLON SEAWATER. -COMPLETE DISPLACING WELL TO 8.5 POUND PER GALLON SEAWATER. -CONFIRM DENSITY IN AND OUT EQUAL 8.5 POUND PER GALLON. -OBTAIN SLOW PUMP RATES. -RIG DOWN CIRCULATING EQUIPMENT. -BLOW DOWN TOP DRIVE AND CIRCULATING EQUIPMENT. -FLOW CHECK WELL,STATIC. 01:30 - 10:00 8.50 FISH P DECOMP PULL OUT OF HOLE WITH SPEAR FISHING ASSEMBLY AND JUNK CATCHER LAYING DOWN 4"DRILL PIPE. -FROM 10,718'MD TO 9000'. 10:00 - 11:00 1.00 FISH P DECOMP FLOW CHECK FOR 10 MINUTES. -LAY DOWN BOTTOM HOLE ASSEMBLY#6 -WELL STATIC WITH PROPER DISPLACEMENT ON TRIP SHEET. -LAY DOWN LAST JOINT OF DRILL PIPE IN STRING. -LAY DOWN COMPONENTS OF SPEAR FISHING BOTTOM HOLE ASSEMBLY(#6) INCLUDING JUNK CATCHER. 11:00 - 12:00 1.00 FISH P DECOMP RUN IN THE HOLE WITH REMAINING DRILL PIPE. -FROM DERRICK TO 475'FEET. -PULL OUT OF THE HOLE LAYING DOWN DRILL PIPE. `OUTER ANNULUS REMAINS AT 0 PSI. 12:00 - 14:00 2.00 BOPSUR P DECOMP PREP AND RIG UP TO PERFORM WEEKLY BLOW OUT PREVENTER EQUIPMENT TEST. -PULL WEAR BUSHING. -BLOW DOWN CHOKE LINES AND KILL LINES. -FILL STACK WITH RIG WATER. Printed 2/25/2013 10:30:29AM • • ,,,N4-,...v.i.,.,,\.:,...,,,,: `,,,a,,,,,,N4.:..._ '..,,,,k, ,,::, \,,\.,:;‘--'•, ,;,,,\,k\,,,v**:..t.,.::,,,,,a4,. c e Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27!2013 X4-OOWXH-E:DRILL(3,404,000.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070"16'21.894"4 Long: 0148"19'23.026"W Active-datum:Kelly Bushing/Rotary Table @90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:00 - 22:30 8.50 BOPSUR P DECOMP PERFORM WEEKLY BLOW OUT PREVENTER EQUIPMENT TEST. -PRE JOB SAFETY MEETING ON TESTING BLOW OUT PREVENTER EQUIPMENT. -OPEN INNER ANNULUS TO ATMOSPHERE AND MONITOR SAME CONTINUOUSLY. -TEST BLOW OUT PREVENTER EQUIPMENT TO 250 PSI LOWAND 3500 PSI HIGH. TESTING UPPER FIXED RAMS WITH 7"TEST JOINTAND LOWER VARIABLE RAMS WITH 4" AND 4-1/2"TEST JOINTS. -TESTANNULAR WITH 4"TEST JOINT. **AOGCC LOU GRIMALDI WAIVED WITNESS OF TEST** 22:30 00:00 1.50 WHSUR P DECOMP RIG DOWN TEST EQUIPMENT. -DUMMY RUN TUBING HANGER.AND RIG UP TUBING RUNNING TOOLS. -BLOW DOWN THE CHOKE AND MUD CROSS LINES. -CLOSE INNER ANNULUS VALVES AND PULL THE TEST PLUG. -DRAIN STACK THROUGH INNER ANNULUS VALVE AND RUN TUBING HANGER IN HOLE ON LANDING JOINT. -LAND AND MARK LANDING JOINT FOR TUBING HANGER. PULL LANDING JOINT AND LAY DOWN SAME. CLOSE INNER ANNULUS VALVE AND FILL HOLE WITH 8.5 POUND PER GALLON SEA WATER. -RIG UP TO RUN 4-1/2"12.6 POUND PER FOOT 13CR-85 VAM TOP TUBING COMPLETION ASSEMBLY. -REMOVE SHORT BALES FROM TOP DRIVE. 1/25/2013 00:00 02:30 2.50 RUNCOM P RUNCMP CONTINUE RIGGING UP TO RUN 4-1/2 INCH 12.6 POUND PER FOOT 13CR-85 VAM TOP TUBING COMPLETION ASSEMBLY -INSTALL LONG CASING BALES ON TOP DRIVE AND SECURE SAME -TORQUE UP COMPENSATOR SUB TO SAVER SUB ON TOP DRIVE BRING UP HYDRAULIC TONGS,HAND SLIPS, AIR SLIPS,YC ELEVATORSAND BASKET OF TORQUE AND TURN TOOLS TO RIG FLOOR THROUGH BEAVER SLIDE REMOVE TOOLS AND LOWER BASKET TO GROUND BACK DOWN BEAVER SLIDE -HANG HYDRAULIC TONGS AND ASSEMBLE TORQUE AND TURN ASSEMBLY TO TONGS AND COMPUTER IN DOGHOUSE -INSPECTAND FUNCTION TEST STABBING BOARD WHILE RIGGING UP. Printed 2/25/2013 10:30:29AM • • e Common Well Name:11-27 AFE No Event •Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27/2013 X4-0OWXH-E:DRILL(3,404,000.00) Project Prudhoe Bay Site:PB DS 11 Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°16'21.894"4 Long: 0148°19'23.026"W Active datum:Kelly Bushing/Rotary Table @90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:30 18:30 16.00 RUNCOM P RUNCMP PRE JOB SAFETY MEETING WITH DOYON CASING CREW,HALLIBURTON COMPLETIONS CREW AND RIG TEAM OIN RUNNING CHROME TUBING COMPLETION ASSEMBLY. *4-1/2"12.6#13Cr-85 VAM TOP TUBING. PICK UP AND BAKERLOK ALL CONNECTIONS BELOW HALLIBURTON TNT PACKER CONTINUE RUNNING IN HOLE WITH COMPLETION ASSEMBLY AS PER TUBING SUMMARY AND RUNNING PIPE TALLY TO 10,649 FEET MEASURED DEPTH -MAKE UP TORQUE AT 4400 FT-LBS W/ TORQUE TURN. RUN W/STABBING GUIDE AND COMPENSATOR. -JET LUBE SEA AND THREAD COMPOUND. OBTAINING PICK UP WEIGHTS AND SLACK OFF WEIGHTS EVERY 10 JOINTS. 18:30 21:00 2.50 RUNCOM P RUNCMP -OBTAIN PARAMETERS ON JOINT#252 BEFORE TAGGING CROSSOVER ON CASING PATC H -PICK UP WEIGHT:169K,SLACK OFF WEIGHT:117K -RUN IN HOLE FROM 10,649 AND TAG CROSSOVER AT 10,771 CONFIRM TAG WITH 10K DOWN,MARK PIPE AND PICK UPAND RETAG AT SAME SPOT PULL OUT OF HOLE FROM 10,771 TO 10,726 AND MAKE UP HANGER AND LANDING JOINT ASSEMBLY -INSTALL THREE PUP JOINTS ON TOP OF JOINT NUMBER 249,MAKE UP JOINT NUMBER 250,TUBING HANGER AND LANDING JOINT DRAIN STACK AND LAND TUBING -DRAIN STACK FROM INNER ANNULUS VALVE -GUIDE HANGER THROUGH STACK -LAND TUBING AT A FINAL DEPTH OF 10,757.38 FINAL PICKUP WEIGHT 170K,SLACK OFF WEIGHT 119K 21:00 - 23:00 2.00 RUNCOM P RUNCMP RUN IN LOCK DOWN SCREWS. -BACK OUT LANDING JOINT. -PJSM ON GAS BUSTER,PREP FOR USE. 23:00 00:00 1.00 RUNCOM P RUNCMP PJSM REVERSE CIRCULATE 160 BBLS 8.5 PPG SEAWATER. 1/26/2013 00:00 02:30 2.50 RUNCOM P RUNCMP CONTINUE TO REVERSE CIRCULATE 160 BBLS OF 8.5 PPG SEAWATER. -FOLLOWED BY 290 BBLS OF 8.5 PPG SEAWATER WITH CORROSION INHIBITOR. *AT4 BPMAT480 PSI. Printed 2/25/2013 10:30:29AM • A: at, v, . �.. Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27/2013 X4-00WXH-E:DRILL(3,404,000.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°16'21.894"4 Long: 0148°19'23.026"W Active datum:Kelly Bushing/Rotary Table @90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:30 06:00 3.50 RUNCOM P RUNCMP PJSM ON SETTING HALLIBURTON TNT PACKER. -INSTALL LANDING JOINT. -DROP BALL AND ROD,REMOVE LANDING JOINT. -CLOSE BLIND RAMS. `WELL KILL DRILL HELD,RESPONSE TIME 2:10. PRESSURE UP ON TUBING TO 3500 PSI FOR 30 MINUTES WITH 2.5 BARRELS PUMPED. -BLEED TUBING PRESSURE TO 1500 PSI AND PRESSURE UP ON THE ANNULUS TO 3500 PSI WITH 4.8 BARRELS PUMPED. -TEST FOR 30''MINUTES,.BLEED PRESSURE OFF TOO PSI. BI -FINAL LEED PRESSTUBING URE DROPPED PRESSURE OFF TO TO 3490PSI0 PS.. -RE-PRESSURE TUBING TO 1500PSI, PRESSURE UP ON ANNULUS TO 3700PSI AND HOLD -VERIFY FOR COMPETENCY 30 CHARTED OF TESTS MINUTES.WITH WTL JAMES WILLINGHAM. -PRESSURE UP ANNULUS TO 2900 PSI,DCK DID NOT SHEAR. -BLEED PRESSURE TO 0 PSI,THEN BACK UP TO 2950 PSI,DCK SHEARED. -CONFIRMED BY PUMPING 2 BBLS DOWN IA AND UP TUBING AT 2 BPM AT 850 PSI. -PUPSI.MP DOWN TUBING UP IAAT 2 BPM AT 600 06:00 - 06:30 0.50 WHSUR P RUNCMP PJSM STACK. INSTALL DRAIN TWC. 06:30 - 09:30 3.00 WHSUR P RUNCMP PJSM TO W 250 PSI LINE LOWAND UP 1000 TEST PSI T C HIGH FROM BOTH BELOW FOR 10 MINUTES-GOOD. O TS AND-LINE 3500 UP T PSI EH IGH T BOTH FROM TESTED ABOVE FOR 250 PSI 10 LOW MINUTES-GOOD. BLOW DOWN THE CHOKE LINE,CHOKE MANIFOLD AND KILL LINE 09:30 - 12:00 2.50 BOPSUR P RUNCMP CHANGE OUT TOP RAMS TO 4-1/2"x 7"VBR'S. 12:00 - 13:00 1.00 BOPSUR P RUNCMP RIG DOWN THE FLOW LINE,PULL THE RISER. -PULL BELL NIPPLE. -MOBILIZE ANNULAR ELEMENT TO CELLAR -HANG WELL TREE. -MAKE UP SUPER CHOKE -BRING ADAPTER FLANGE INTO CELLAR. 13:00 - 18:30 5.50 BOPSUR P RUNCMP PJSM ON CHANGING OUT ANNULAR ELEMENT ON 13-5/8"GK HYDRILANNULAR. PJSM ON SUCKING IN CONVEYOR#2. -SEAL UPANNULAR CAP. 18:30 - 22:00 3.50 BOPSUR P RUNCMP PJSM ON NIPPLING DOWN BOPE STACK AND RACKING BACK ON STUMP. PULL AND LAY DOWN MOUSE HOLE -MAKE UP THE BELL NIPPLE BACK TO TOP OF ANNULAR. -REMOVE BOPS STACK AND RACK BACK SAME ON STUMP. REMOVE SPACER SPOOLAND STAGE IN CELLAR. Printed 2/25/2013 10:30:29AM • I Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27/2013 X4-00WXH-E:DRILL(3,404,000.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°16'21.894"4 Long: 0148°19'23.026"W Active datum:Kelly Bushing/Rotary Table @90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 00:00 2.00 WHSUR P RUNCMP CLEAN AND PREP HANGER VOID -INSTALL AND TIGHTEN ADAPTER FLANGE. -TEST HANGER VOID TO 5000PSI.FOR 30 CHARTED MINUTES 1/27/2013 00:00 - 01:00 1.00 WHSUR P RUNCMP PJSM,CONTINUE TO TEST HANGER VOID TO 5000PSI. -CHART TEST FOR 30 MINUTES 01:00 - 02:00 1.00 WHSUR P RUNCMP PJSM,NIPPLE UP TREE AS PER CAMERON. -INSTALL TREE ON ADAPTER FLANGE AND TIGHTEN SAME. 02:00 - 03:30 1.50 WHSUR P RUNCMP PJSM,TEST TREE. -TEST TO 250 PSI LOWAMD 5000 PSI HIGH 5 MIN EACH CHARTED AS PER PRESSURE TEST PASS/FAIL CRITERIA. 03:30 - 09:30 6.00 WHSUR P RUNCMP PJSM WITH DRILL SITE MAINTENANCE ON TESTING LUBRICATOR AND PULLING TWO WAY CHECK. -INSTALL LUBRICATOR ON TREE. -FILL LUBRICATOR AND TEST 250 PSI LOW AND 3500 PSI HIGH FOR 5 MINUTES EACH X 3. -OPEN TREE AND PULL TWO WAY CHECK. -THREE RUNS WERE MADE TO RETRIEVE TWC 09:30 - 13:00 3.50 WHSUR P RUNCMP PJSM RIG UP AND PRESSURE TEST LINES TO 250 PSI LOWAND 3500 PSI HIGH -START PUMPING 160 BBLS DIESEL 60 DEGREE AT 2 BPM AT 1150 PSI. OA PRESSURE=14 -CREW CHANGE,CONTINUE FREEZE PROTECTION. -MAX PSI WHILE PUMPING IS 1200 PSI. PSI ON IA BEFORE U-TUBE OPERATION 260 PSI. -TUBING AT 180 PSI. *SPILL DRILL HELD*. 13:00 - 14:00 1.00 WHSUR P RUNCMP U-TUBE OPERATIONS FOR 1 HOUR. -CLOSE WELL IN AND BLEED OFF PRESSURE FROM LRS HOOK UP AND WING VALVE HOSE TO CHOKE -INSTALL JUMPER HOSE FROM INNER ANNULUS TO TUBING BY WAY OF WING VALVE. -ENSURE NO PRESSURE ON WELLAND REMOVE JUMPER HOSE AND SUCK BACK SAME. 14:00 - 15:30 1.50 WHSUR P RUNCMP PJSM ON INSTALL AND TEST LUBRICATOR. -TEST LUBRICATOR 250 PSI LOWAND 3500 PSI HIGH FOR 5 MINUTES-TEST GOOD. 15:30 16:30 1.00 WHSUR P RUNCMP INSTALL BACK PRESSURE VALVE. -LITTLE RED TO TEST FROM BELOW AT 250 PSI LOWAND 1000 PSI HIGH FOR 10 MINUTES EACH. -TOOK 2.7 BBLS TO PRESSURE UP TO 1000 PSI AND 2.0 BBLS WERE BLED OFF TO 0 PSI. -TESTED GOOD. -SUCK BACK LINES TO CLEAR THEM OF DIESEL. Printed 2/25/2013 10:30:29AM • • Common Well Name:11-27 AFE No Event Type:WORKOVER(WO) Start Date:1/9/2013 End Date:1/27/2013 X4-00WXH-E:DRILL(3,404,000.00) Project Prudhoe Bay Site:PB DS 11 Rig Name/No.:DOYON 14 Spud Date/Time:12/27/1986 12:00:00AM Rig Release:1/27/2013 Rig Contractor:DOYON DRILLING INC. UWI:/Lat:070°16'21.894"4 Long: 0148°19'23.026"W Active datum:Kelly Bushing/Rotary Table @90.1ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:30 - 20:00 3.50 WHSUR P RUNCMP SECURE THE TREE. -PJSM ON RIGGING DOWN THE HOSES. -PUT BLANK FLANGES ON OUTER ANNULUS VALVE AND INNER ANNULUS VALVE WITH MANIFOLDS CONSISTING OF GAUGES, BLEED TEES AND WHITEY VALVES AND CAP SAME. -REPLACE PLUG IN WING VALVE BLIND WITH WHITEY VALVE AND CAP SAME. CLEAN UP CELLAR. *FIRE DRILL* -RIG RELEASED AT 20:00. **TUBING 0 PSI,INNER ANNULUS 0 PSI, OUTER ANNULUS 0 PSI** Printed 2/25/2013 10:30:29AM • • 11 -27, Well History (Post Rig Workover) Date Summary 02/01/13 T/I/O=Vac/0/0; Conduct PJSM; Start barriers list= SV and SSV independently tested for leak tight, LTT passed; R/U lubricator w/pulling tool and test against SV to 300 and 3500 psi for 5 min. LTT passed; Pull 4-1/16"CIW"H" BPV#254 thru tree for Doyon 14 post rig work-over, 1-1'ext. used,tagged at 114"; S/I barriers, RDMO; Install tree cap and test to 500 psi, LTT passed. 02/03/13 PULL BALL&ROD FROM 10,659'SLM. PULL BK-DGLV FROM STA#3(7764'SLM/7786' MD). 02/04/13 PULL BK-DCK GLV FROM STA#4(4202' SLM/4223' MD). SET BK-LGLV IN STA#4(4223' MD). SET BK-LGLV IN STA#3(7786' MD). PULL 4-1/2" RHC PLUG BODY FROM 10,660' SLM/10,690' MD. MAKE MULTIPLE RUNS W/10'x 2.25" PUMP BAILER TO 10,843'SLM(fluid recovered). RUN 2'x 1-7/8" STEM, 3.80"CENT,3.70" LIB TO 10,814' SLM(impression inconclusive). RUN 3.62"CENT,2'x 1-7/8" STEM, 3.50" LIB TO 10,840'SLM(impression of sluggits). RUN 3.25"CENT, 10'x 2.25" PUMP BAILER w/mule shoe flapper bottom from 10,840'SLM TO 10,842' SLM. 02/05/13 BAIL W/3.25"CENT, 10'x 2.25" PUMP BAILER TO 10,842' SLM. ATTEMPT TO PULL P- PRONG(unable to latch). 02/09/13 RAN 10'x 3-1/2" PUMP BAILER TO 10,845' SLM(recovered 3-1/2 gal. sluggits&plastic). RAN 3.60" BELL GUIDE&2"JUC, UNABLE TO LATCH AND PULL P-PRONG @ 10,870 MD. RAN 10'x 3-1/2" PUMP BAILER 2 TIMES, RECOVERED4 GAL. SLUGGITS FROM 10,842' SLM TO 10,846' SLM. JOB INCO,PLETE, PXN PLUG STILL IN HOLE. 02/10/13 RAN 10'3-1/2" P. BAILER TO 10,845'SLM W/NO RECOVERY. 02/11/13 RAN 3.25"CENT.,2-1/2"JUC TO 10,847' SLM(unable to latch prong). RAN 10'x 3-1/2" PUMP BAILER(no recovery). RAN 3"CENT,2-1/2"JUC TO 10,847' SLM (unable to latch). RAN 3.6" BELL GUIDE, 2.25" LIB TO 10,846' SLM (impression of china cap). PULLED P-PRONG @ 10,846' SLM. BAILED 1/4 GAL SLUGGITS FROM PX PLUG BODY @ 10,848'SLM. ATTEMPTED TO PULL PXN PLUG BODY @ 10,848'SLM. MADE 2 RUNS W/10'x 2.25" PUMP BAILER(recovered—1/2 gal. of sluggits). 02/12/13 BAILED 3-1/2 GAL SLUGGITS TO 10,853' SLM. PULLED 4-1/2" PXN PLUG BODY FROM 10,853'SLM. Page 1 of 1 i TREE= SA NOTES: ""4-112"TBG& 3-112"CHROME LNR 'iIVELHEAD= MCEVOY 11 ��� '" CHROME ABRASIVE-SEE 04/09/05AWGRS ACTUATOR= BAKER PJC DRAFT REPORT INITIAL KB.H EV= 20°CONDUCTOR, - ^-110 �� INI ��= 2491 4-1/2"FLS X NP,D=3.813" KOP= 1900' 91.5#,H-40, GAS LFT MANDRELS Max Angie= 56°@ 7400' 13=19.124" ST MD ND DEV TYPE VLV LATCH PORT DATE Datum M3= 12162' 13-3/8"CSG,72#, -I 2555' 4 4423 3757 49 KBG2 DOME BK 16 02/04/13 Datum ND= 8800'SS =I I �= 3 7786 5995 55 KBG2 DOME BK 16 02/04/13 L-80 BTC, D=12.347" X 2 9107 6793 50 KBG2 DMY BK 0 01/20/13 9-5/8"X 7"BKR LTP w/FLEX LOCK HGR,13=6.20" 3054' oil k. 1 10093 7432 48 KBG2 DMY BK 0 01/20/13 9-5/8"CSG,47#,L-80 NSCC XO TO BTC -[ 5331' 140 10585' H4-1/2"HES X MP,13=3.813" I ri 7"HES PORT®COLLAR,D=6.260" H 10661' { 4''_ VI 10613' _I--1 7"X 4-1/2"HES TNT PKR,D=3.856" 7-1/2"PORTED T1ESACK SEAL ASSY,ID=6.18" -I 10682' ► 9-5/8"X 7"BKR ZXPN LTP w/I-NIC HGR,D=6.18" - 10683' €: I 10690' �4-1/2"HES X NIP,D=3.813" I 4-1/2"TBG,12.6#,13CR 85,.0152 bpf,D=3.958" 10757' 1 r 10757' 1-I4-1/2"WLEG,ID=3.958" 7"SCAB LNR,26#,L-80 VAM TOP, --f 10779' 10780' H4-1/2"x 5-1/2"XO,D=3.958" I .0383 bpf,D=6276" JJ 10782' I-9-5/8"X 5-1/2"BKR S-3 PKR,D=4.75" I 10786' 5-1/2"X 4-1/2"XO,D=3.958" 4-1/2"TBG STUB(12/03!12) H 10773' I I� 7"BOWEN CSG PATCH,13=3.95" -I 10779'-10785 10849' -I4-1/2"FES X NP,D=3.813" 10870' HI4-1/2"FES XN NP,D=3.725" I 4-1/2"TBG,12.6#,13CR-80,.0152 bpf,ID=3.958" 10892' 10891' I- 14-1/2"x 5-1/2"XO,D=3.958" I 5-112"TBG STUB(03/26/05) 10896' . 10902' H 9-5/8"X 5-1/2"UNIQUE OVERSHOT � � 10944' H 9-5/8"X 5-1/2"BKR S-3 PKR,D=4.750" Minimum ID =2.75" @ 11034' . 10978• I-I5-1/2"FIESX NP,D=4.562" MILLED C-Z TIEBACK SLEEVE 5-1/2"TBG,17#,L-80 NSCC,.0232 bpf,D=4.892" H 10999' I 11006' -�9-5/8"X 5-1/2"UNIQUE OVERSHOT 11015' I-{STINGER TIEBACK SLV 08/08/04 I 5-1/2"TBG STUB(06/24/98) 11001' 11026' -I 9-5/8"X 5-1/2"BKR SB-3 PKR,D=4.84" I ■--xli) 11--x. J, 11034' -I C-Z TRACK SLV,MLLED TO 2.75"(04/14/05) 9-5/8"X 7"SHORTY LNR HGR,D=? -I 11046' 11040• H 3.70"DEPLOY SLV,13=3.00" 5-1/2"TBG PC,17#,L-80,.0232 bpf,ID=4.892" -I 11048' 11048' I- 15-1/2"X 5"XO(BEHIND PIPE) I 11060' -13-1/2"OTIS X NP,D=2.813" 02/23/04 5"TBG-PC,15#,L-80 RFC,.0232 bpf,D=4A06" -I 11115' 11094' I--I5"OTIS X NP,ID=4.312" / I L 11114' -15"BKR SHEA ROUT SUB BEHIND 1 9-5/8"CSG,47#,L-80 BTC,13=8.681" I- 11368' 11115' I-I5"WLEG,ID=4.337" 3-1/2"LNR 9.3#,13CR STL.0087 bpf,D=2.992" -I 11935' 11394, --17"MARKER JONT I PERFORATION SUMMARY 11901'-11998'ctmd CEN/ENT SHEATH, FLOG: BHCS ON 01/10/87 *' IV, .4 4 ,*f MLLED D=2.75"(04/14/05) ANGLE AT TOP FERR 46°@ 11985' 4.4.4 .411. Note:Refer to Production DB for historical perf data I SIZE SPF MERVAL Opn/Sqz SHOT SOZ 2-1/2: 6 11985-11998 0 01/11/06 ' 3-3/8" 4 11998-12029 0 07/30/87 3-3/8" 4 12048-12062 0 09/03/89 1 12065'CTMD HTOP OF SAND(08/04/05) I ,�������, PBTD -I 12100' I 7"LNR,29#,L-80 BTC,.0371 bpf,D=6.184" - 12210' (,��������������*7 .44.41.41.41.4.41.41.■ DATE REV BY COMAIENTS DATE REV BY COMi1341S PRUDHOE BAY UNIT 07/31/87 PKR 141 IMTIAL COMPLETION 02/25/13 Anid PJC PULL CS(1/24/13) WELL: 11-27 06/24/98 D14 RWO 02/25/13 AMk/PJC SLUGGTrS/PULL PXN(2/12813 PERMT No: 1861480 03/27/05 D16 IWIYO 03/05/13 JNL/JMD CORRECTE)4-1/2"a-RONETBG AIR Mc 50-029-21638-00 01/27/13 D-14 RHO SEC 28,T11 N,R15E,452'FSL&228'FEL 01/29/13 PJC DRLG DRAFT CORRECTIONS 02/11/13 SWC/PJC GLV C/O(214/13) BP Exploration(Alaska) PROF D • • s THE STATE Alaska Oil and Gas A As Conservation Commission c GOVERNOR SEAN PARNELL . 333 West Seventh Avenue p4t, Anchorage, Alaska 99501 -3572 AL . Main: 907.279.1433 SCANNED JAN 2 5 2013 Fax: 907.276.7542 David Reem Engineering Team Leader I 14 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 11 -27 Sundry Number: 312 -446 Dear Mr. Reem: 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 Chaff DATED this �iay of December, 2012. Encl. , irtk VI/ l ' I r W STATE OF ALASKA • ALAS OIL AND GAS CONSERVATION COMM SION ®C APPLICATION FOR SUNDRY APPROVAL ) fzl - ► Z 20AAC25.280 NOV 2 8201 1. Type of Request: ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool 0 Repair Well - ❑ Change Approved Progr ❑ Suspend ❑ Plug Perforations ❑ Perforate ® Pull Tubing • ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ® Alter Casing • ❑ Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 186 - 148 • 3. Address: ® Development• ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 -6612 50.029 21638 - 00 - 00 • 7. If perforating: 8. Well Name and Number: What Regulation or Convervation Order governs well spacing in this pool? PBU 11 -27 Will planned perforations require a Spacing Exception? ❑ Yes No . 9. Property Designatior 10. Field / Pool(s): ADL 028325 & 028322. Prudhoe Bay Field / Prudhoe Bay 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): 12210' . 8892' 12065' 8789' 10870' None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 2525' 13 -3/8" 30' - 2555' 30' - 2518' 4930 2670 Intermediate 11342' 9 -5/8" 26' - 11368' 26' - 8298' 6870 4760 Production Liner 1164' 7" 11046' - 12210' 8071' - 8892' 8160 7020 Tieback Liner 920' 3 -1/2" 11015' - 11935' 8050' - 8698' 10160 10530 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11985' 12062' • 8733' 8787 4-1/2", 12.6#; 1 L-8 00; 10902'; 5-1/2", 17# x 5 ", 15# L�0 10896" - 11115' Packers and SSSV Type: 9 -5/8" x 5-1/2" Baker S -3 Packer; Packers and SSSV 10782' / 7890' 9 -5/8" x 5 -1/2" Baker S -3 Packer; MD (ft) and TVD (ft): 10944' / 8000' 9 -5/8" x 5 -1/2" Baker SB -3 Packer 11026' / 8057' 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal' ® BOP Sketch - ❑ Detailed Operations Program ❑ Exploratory ❑ Stratigraphic ® Development. ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation December 15, 2012 ■ ® Oil. ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Sean McLaughlin, 564 -4387 Printed Name: D id Reem Title: Engineering Team Leader Email: Sean.McLaughlin @bp.com Signature: C /2 � - Phone: 564 - 5743 Date: / / . 28 L„i 2. Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number �� ( � ❑ Plug Integrity 1:1140P Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: If 2 560 ,pS c: 1 .„& P --- (, --- 5 .(---- Spacing Exception Required? ❑ Yes No Subsequent Form Required: /o _ 'l0 ( f i ✓ 1 # / APPROVED BY A roved y �L. COMMISSIONER THE COMMISSION Date: 12 ‘t--/ 2_ - s F - 1� Submit In Duplicate ' f"'�', \ �Ged a�ci6/ �)�; / or 12 months t date of approval r// p�- bp • • Sundry Request for casing repair rY Q 9 p Well: 11 -27 Date: 11/26/2012 Engineer: Sean McLaughlin MASP: 2420 psi Well Type: Producer Estimated Start date: December 15 2012 History: Well 11 -27 was completed in the 14P in July, 1987. An additional 14' of 13P was perforated in September 1989. In November 1997 the tubing failed a MIT and a LDL run in December 1997 identified leaks at 4508', 7840' and GLM #7 (9218'). A RWO was performed in June 1998 to replace the tubing. A PPROF run in March 2002 indicated holes in the 7" liner at 11446' and 11514'. A LDL also found a hole in the tubing at 10920'. An unsuccessful cement squeeze was performed in June 2002 to eliminate the leaks in the 7" liner. A subsequent PPROF run in September 2002 found holes in the liner at 11424' and 11441', and a gas jet at 11470'. Holes were also found in the tubing at 7846' and 10926'. The lower half of the tubing also had extensive corrosion (45 -80% wall loss). A 3.5" liner was installed in February 2004 to isolate the Teaks in the 7" liner. However, attempts to sting into the liner top packer in order to run the tubing patch were unsuccessful. Well operations were suspended and after re- evaluating the caliper results, the plan for the well was changed to replace the L- 80 tubing with 13Cr tubing. The change in the well plan was due to the severity of the tubing corrosion, maximizing the longevity of the completion and to minimize the cost variability associated with running the long patch. The RWO was completed with the running of a 13 Cr tubing string in March 2005. On 5/01/2011, a MIT -T to 3000 -psi passed, but a CMIT -TxIA failed to 3000 psi after multiple attempts. On 5/7/2011 the IAP was bled to 230 psi and would not go lower. On 5/8/2011 another CMIT -TxIA attempt also failed with LLR of 4.72gpm at 3000 psi. A TecWel LDL confirmed a PC leak at 7829' MD. Interestingly, this depth is in close proximity with some of the depths where tubing holes were found prior to the previous two RWOs in 1997 and 2002 . Scope of Work: Pull 4 -1/2" 13Cr completion. Run 7" scab liner. Run 4 -1/2" chrome completion. Pre Rig Prep Work: S 1 Pull PXN plug from 10,870' S 2 Reset PXN plug at 10,870. MIT -T to 3,500 psi. • S 3 Dump -10' of sluggits above PXN, Set 4 -1/2" junk catcher S 4 Drift for 4 -1/2" Jet Cutter E 5 Jet cut tubing @ 10,773'. Reference tubing tally 3/26/05. Cut desired to be 3' from top of 10' pup above the packer. F 6 Circulate well through the cut with 9.8 ppg brine and diesel freeze protect to 500' MD. W 7 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT -T & IC. ✓ 8 Set TWC in the tubing hanger about 3 days prior to rig arrival. O 9 Remove the wellhouse & flow line. Level the pad as needed for the rig. • • Proposed RWO Procedure: 1. MIRU Doyon 14. ND tree. NU and test BOPE with four preventers configured top down (annular, 7" fixed, blind shears, mud cross' and 3 -1/2" x 6" VBR's). Test the VBR's and annular to 3,500 psi. 2. Pull and lay down tubing to the jet cut 3. Scrape 9 -5/8" casing and dress -off 4.5" tubing stub. 4. Run 9 -5/8" test packer to 4,000' and test casing to 3,500 psi. *--- f'c. - �7gZ9 'lac, 5. Run 4 -1/2" overshot, 7" pup joint with plug pre - installed, Baker HMC Liner hanger, and C -2 ZXP Liner top Packer. 6. Run and cement 7" scab liner to 3,055'. 7. Drill out 7" shoe to the 7" plug that was pre - installed. Pressure test casing to 3,500 psi. 8. Change out inner casing pack -off. 9. Pull 7" HES TW plug 10. Pull 4 -1/2" junk catcher. 11. Run new 4.5" 13Cr completion with 7" x 4 -1/2" HES TNT packer. MIT -T & MIT -IA to 3500 psi. 12. Set a BPV and RDMO. Post ri Work V 1 Pull BPV S 2 Pull ball and Rod, Pull RHC seat, Bail siuggits, Pull PXN plug, Install dummy GLV's TREE= 6" CIW FLS WELLHEAD = MCEV II NOTES: '*•4 -1/2° & 3 -1/2" CHROME LNR"' _ACTUATOR= , BAKER 1 -27 AWGRSREPORV ERYABRASIVE -SEE 04/09/05 KB. EL1/= 58' EF BF.EV= KOP = 1900' I I 23' H 7" X 4 - 1/2" XO, D= 3.958" I Max Angle = 56° @ 7400' Datum MD = 12162' 1 2501' H4-1/2" HES X NP, D = 3.813" 1 Datum TV D = 8800' SS GAS LIFT MANDRIiS 1 13 - 3/8" CSG, 72#, L - 80, D = 12.347" H 2656' 1--Al ■ ST 1 MD 1 TV D DEV TYFE VLV LATCH PORT DATE 4 3434 3242 46 WAG DMY RK 0 08/17/05 3 7070 5589 53 MMG DMY RK 0 08/17/05 2 9582 7097 50 WAG CMY RK 0 03/26/05 r 1 10731 7855 47 WAG CRC RKP - 10/15/12 WOO ' -1 10769' H4-1/2" FES X NP, D = 3.813" I Minimum ID = 2.75" @ 11901' �� 10780' H4 -1'2" x 5 -1/2" XO, D = 3.958" 1 3 -1/2" LNR LANDING COLLAR (MILLED) I 10782' H9-5/8" X 5-112" S-3 PKR, D = 4.75" 1 1 10786' 1 X 4 -1/2" XO, D= 3.958" 1 4-1/Z' PXN PLUG (05/01111) —1 10870' I 10849' H4 -1/2" I-ES X NP, D = 3.813" I 10870' — 14 - 1/2" HES XN NP, D = 3.725" I4 -1/2" TBG, 12.6#, 13CR80, .0152 bpf, D = 3.958" H 10891' i I 10891' —14-1/2" x 5-1/2" XO, D = 3.958" 1 1 10896' HTOP OF 5 -1/2" TBG STUB (3/26/05) 1 Z _ 10902' H9 -5/8" x 5- 112" UNIQUE OVERSHOT 1 � IN 10944' 1 -19 -5/8" X 5-1/2" BAKER S-3 PKR 1 1 10978" H5-1/2" 1-ES X NP, D = 4.562" 1 TOP OF 5 1/2" TBG 1--I 11001' ' ( 10998' H5-1/2" UNIQUE OVERSHOT 1 1 5 TBG, 17 #, L - 80, .0232 bpf, 13= 4.892" 1 11006' —� is 11016' I-1 STidGER TACK SLV 08108/04 1 11026' H9 -5/8" X 5-1/2" BAKER SB-3 PKR 1 TOP OF 7" LNR H 11046' 11034' H C-Z TIEBACK SLV, WILLED ID = 2.75" (04/14/05)1 1 5-1/2" TBG -PC, 17 #, L -80, .0232 bpf, D = 4.892" H 1 1048" I / (BUM 5-1/2" X 5" XO (B9 PIPE) I I 11048' ( 11oso• H3-1r2" OTIS X NP, D = 2.813" 02/23/04 I 11094' H 5" OTIS X MP, D = 4.312" (BRAM PIPE) 1 11114' H5- BAKER SHEAROUT SUB (B98t) PIPE) 1 15" TBG -PC, 15#, L -80, .0232 bpf, D = 4.406" H 11116' I r I 11116' 1—L" VVLEG (BENND PIPE) 1 1 9-5/8" CSG, 47 #, L -80, ID = 8.681" H 11368' 1 . 1��' � 1 �1�/ ■•4 Ito 3 1/2" LNR 9.3#, 13 -CR .0087 bpf, D = 2.992" 11 935' I,* ■ ' i e 11901' H CMT SI -EATH, MLLED D = 2.75" (04/14/05) 1 H 1 �'u 1V1 *14 1* PERFORAT1ON SUNAARY 1�1 1 1 11998' CTM H BIM OF CMT SHEATH (04/16/05) 1 REF LOG: BHCS ON 01/10/87 ANGLE AT TOP PERF: 46° @ 11985' I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2 -1/2: 6 11985 - 11998 0 01/11/06 I 3-3/8" 4 11998 - 12029 0 07/30/87 3-3/8" 4 12048 - 12062 0 09/03/89 1 12066' CTMD H TOP OF SAND (08/04/05) 1 1 FBTD H 12100' 1 •1.1...1'1*1'1V 1 7" LNR, 29#, L -80, .0371 bpf, D = 6.184" H 12210" DATE REV BY COMMENTS DATE REV BY COMENTS PRUDHOE BAY UIT 07/31/87 ORIGINAL COMPLETION 05/16/12 SV YJMD GLV CIO (05/14/12) WELL 11 -27 06/23/98 RWO 06/11/12 Iil1NJMD TREE CIO (05/25/12) REFMT No: 1861480 03/27/05 WJHITLH RWO 10/19/12 DJS/ PJC CRC OUT VALVE (10/15/12) API No: 50- 029 - 21638 -00 04/05/12 DIF /JMD TREE CIO (04/04/12) SEC 28, T11N, R15E, 4134.88' FEL & 3838.25' FN. 04/22/12 BSE/ PJC SET PXN (05/01/11) 04/30/12 LECIJMD GLV CJO (04/30/12) BP Exploration (Alaska) • WELLFEAD" 6 "MCEVOY P ro p o 1 1 27 SA NOTES: ""4 -1I2 "& 3- 1 /2 "CIROMELNR"' 4 -1 HROM E VERY ABRASIVE - SEE 04/09/05 ACTUATOR= ' BAKER Scab liner KB. R = 58' AWGRS REPORT BF. REV = KOP = 1900' Max Angle = 56° @ 7400' Datum MD = 12162' Datum ND = 8800' SS / 13 -3/8" CSG, 72#, L -80, D= 12.347" I—{ 2555' - — Baker C2 LTP and Flexlock Ill Liner / Hanger @3,055' 7 ", 26 #, L -80 VamTOP HC — ,=== Landing Collar r ( B KR C2 ZXP LTP and HMC Liner Ported float collar ._ _--- Hanger @ 10,720' Ported tie back seal assembly `"- ` HES 7" TW "shorty" plug w/ sand above Baker 4-1/2" overshot at 10,773' Minimum ID = 2.76" @ 11901' M K A 10780' —14 -1/2" x 5 -1/2" XO, D= 3.958" 3 -1/2" LNR LANDING COLLAR ( M I L L E D ) 1 0 7 8 2 ' D mill I 10786' —15 -1/2w X 4 -1/2" XO, D = 3.958" 4-1/2" Junk catcher and Sluggits I 10849' H4-1/2" FES X NIP, D= 3.813" 4-1/2" PXN RUG (05/01/11) H 10870" 1111 10870' H 4 - 1/2" HES XN NP, D = 3.725" I4 -1/2" TBG, 12.6#, 13CR80, .0152 bpf, D= 3.958" H 10891' 1111 M 10891' — 14 - 1/2" x 5 - 1/2" XO, D= 3.958" 10896' H TOP OF 5-1/2" TBG STUB (3/26/05) i 1v I 10902' —19-5/8" X 5-1/2" UNIQUE OVERSHOT 10944' H9 -5/8" X 5-1/2" BAKER S-3 PKR 10978' H I 5 -1/2" HES X NP, D = 4.562" TOP OF 5-1/2" TBG I 11001' I 10998' —15-1/2" UNIQUE OVERSHOT 5 -1/2" TBG, 17 #, L -80, .0232 bpf, D = 4.892" 11006' - I 11015' H STINGER TEBACK SLV 08/08/04 &'A i I 11026' H9 - 5 /8" X 5 BAKB2 SB - 3 PKR I TOP OF 7" LNR —I 11046' ■ 11034' H C - Z TRACK SLV, KILLED ID = 2.75" (04/14/05) 5-1/2" TBG -PC, 17 #, L -80, .0232 bpf, ID = 4.892" H 11048' , ii 11034' TBG -PC, 15#, L -80, .0232 bpf, D = 4.406" — I 11115' I 11060' H3-1/2" OTIS X NP, D = 2.813" 02/23/04 I 9-5/8" CSG, 47 #, L -80, ID = 8.681" —I 11368' 3 -1/2" LNR, 9.3#, 13 -CR, .0087 bpf, D = 2.992" 11935' PERFORATION SUMMARY REF LOG: BI-ICS ON 01/10/87 W. ■ Vf A NGLE AT TOP PERF: 46° @ 11985' * i,� 11901 I— CMT SHEATH, MLLED D = 2.75" (04/14/05) WO Note: Refer to Production DB for historical pert data .•.. la 11998' CTM — i BTM OF CMT SHEATH (04/16/05) SIZE SPF NTERVAL Opn /Sqz DATE I 2 -1/2: 6 11985 - 11998 0 01/11/06 3 -3/8' 4 11998 - 12029 0 07/30/87 . 3 -3/8" 4 12048 - 12062 0 09/03/89 PBTD — 12100' 1 12065' CTMD H TOP OF SAND (08/04/05) _ 7" LNR, 29#, L -80, .0371 bpf, D = 6.184" — 12210' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07131187 ORIGINAL COMPLETION 05/16/12 SWC/JMD GLV C/O (05/14/12) WELL: 11 -27 06/23/98 RWO 06/11/12 RM+JMD TREE C/O (05/25/12) PERM\ D: 1861480 03/27/05 WJHITLH RWO 10/19/12 DJS/ PJC CIRC OUT VALVE (10/15 /12) AR No: 50- 029 - 21638 -00 04/05/12 D JF /JMD ' TREE C/O (04/04/12) SEC 28, T11 N, R15E, 4134.88' FEL & 3838.25' R'L 04/22/12 BSE/ PJC SET PXN (05/01/11) 04/30/12 LEC/JMD GLV CIO (04/30/12) BP Exploration (Alaska) tH LI 6" -• VVJ3LH . 11 2 7 EAD MCEVOY VOY SA NOTES: ""'4 -1/2" 3 -1i2" CHROMELNR"' P ropo 4 -1 & HROMEVERYABRASIVE- SEE04/09/05 ACTUATOR = • BAKER C AWGRS REPORT KB. REV = 58' BF. ELEV = _ - KOP = --- .1900' J Max Angle = 56° © 7400' I ■ 2601' I- 14 -1/2" FES X NIP, D = 3.813" Datum MD = 12162' , . Datum TVD = 8800' SS / 13 -3/8" CSG, 72 #, L -80, D= 12.347" H 2556' ' =4 in —Baker C2 LTP and Flexlock III Liner Hanger at 3,055' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 4212 3750 KBG-2 3 7795 6000 KBG-2 oi,i/(, 4 -1 /2 ", 12. #, 13 Cr -85 VamTOP 2 9119 6800 KBG-2 1 10100 7436 KBG-2 1 1 / 4 -1/2" HES X NIP, ID =3.813 7 ", 26 #, L -80 VamTOP HC IS ®/ 7" x 4 -1/2" HES TNT 13Cr Packer @10,620' Landing Collar 1 1 -L 4 -1/2" HES X NIP, ID =3.813 Ported float collar El —BKR C2 ZXP LTP and HMC Liner Hanger Ported tie back seal assembly I @10,720' 4 -1/2" WLEG ( Baker 4 -1/2" overshot at 10,773' Minimum ID = 2.76" @ 11901' I 10760• -I 4-1/T x 5-1/2" XO, D= 3 -958" 3-1/2" LNR LANDING COLLAR (MILLED) 10782' I -19- 5/8 "X5- 1 /2"S- 3 PKR, D =4.75" 10786' -15-1/2" X 4 -1/2" XO, D = 3.958" Sluggits "1:: 10849' - 14 -1/2" FES X MP, D= 3.813" I 4-1/2" PION PLUG (05/01/11) H 10870' 10870' I- 14 -1/2" HES XN NP, D = 3 -725" 4-1/2" TBG, 12.6#, 13CR80, .0152 bpf, ID= 3.958" -I 10891' 10891' -14-1/2" x 5-1/2" XO, D = 3.958" I 1 0896' -I TOP OF 5 -1/2" TBG STUB (3/26/05) _I 10902' - I9 -5/8" X 5-1/2" UNIQUE OV ERSHOT ►M/ 10944' I� 9- 518" X 5 -112" BAKER S-3 PKR I 10978' I -15 -1/2" FES X NP, D = 4.562" TOP OF 5-1/2" TBG I--1 11001' \ / I 10998' 1-.15-1/2" UNIQUE OVERSHOT 5 -1/2" TBG, 17 #, L -80, .0232 bpf, D = 4 -892" - 11006' ---- 11015' - STINGER TACK SLV 08/08/04 ►�� Z I 11026' -I 9 -5/8" X 5 -1/2" BAKER SB -3 PKR I ITOP OF 7" LNR 11046' 11034' -1 G-Z TEBACK SLV, MLL ®ID = 2.75" (04/14/05) 5-1/2" TBG -PC, 17 #, L -80, .0232 bpf, D = 4.892" H 11048' N i 5" TBG-PC, 15#, L -80, .0232 bpf, D = 4.406" -1 11115' I 11060' I-13-1/2" OTIS X NP, D = 2.813" 02/23/04 I 9-5/8" CSG, 47 #, L -80, ID = 8.681" I- 11368' I 3 -112" LNR, 9.3#, 13 -CR, .0087 bpf, D.= 2.992" -1 11935' PERFORATION SUMMARY REF LOG: BHCS ON 01/10/87 WI ' f�` ANGLE AT TOP PERF: 46° @ 11985' o�t,� � ,- 11901' I - 1 CMT SHEATH, MLLED D = 2.75" (04/14/05) ot Note: Refer to Production DB for historical pert data ..al ! a 11998' CTM - BTM OF CMT SHEATH (04/16/05) SIZE SPF INTERVAL Opn/Sqz DATE 2 -1/2: 6 11985 - 11998 0 01/11/06 1 3 -3/8' 4 11998 - 12029 0 07/30/87 . 3 -3/8' 4 12048 - 12062 0 09/03/89 J 1 12065' CTMD - TOP OF SAND (08/04/05) PBTD ___ 12100' 7" LNR, 29#, L -80, .0371 bpf, D = 6.184" H 12210' DATE REV BY COMMENTS .. DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/31/87 ORIGINAL COMPLETION 05/16/12 SVVC/JMD GLV C/O (05/14/12) VVELL: 11 -27 06/23/98 RWO 06/11/12 RM/JMD TREEC/O(05/25/12) PERM No: 1861480 03/27/05 WJHITLH RWO 10/19/12 DJS/ PJC CIRC OUT VALVE (10/15/12) AFI No: 50- 029 - 21638 -00 04/05/12 DJF /JMD TREE C/C (04/04/12) SEC 28, T11 N, R15E, 4134.88' FEL & 3838.25' FM_ 04/22/12 BSE' PJC SET PXN (05/01/11) 04/30/12 LECJJMD GLV C/O (04/30/12) BP Exploration (Alaska) RIG FLOOR 33.7 ' AGL O 1 5 VALVE LEGEND I r ©= © =Q1 +71M � 1 BYPASS 2 C I I 3 CHOKE ,9 4 BOTTOM RAMS 5 BLIND RAMS IMMO \ 1 6 TOP PIPE RAMS • le ACCUMULATOR: NL SHAFFER, 180 GAL, 6 STATION 7 ANNULAR 13 5/8', 5000 PSI, HYDRA ANNULAR BOP, TRIPLEX PUMP: 575 VAC, 30 HP STUDDED r000 PSI, BOTTOM AIR PUMP: 1, NL SHAFFER N -__ RANGED TOP O O 'C 41 0111 . I • 50 13 5/8", 00 PSI, 10" MPL OPERATORS, i HYOWL PIPE RAN 3 1/8" 5000 PSI SIDE OUTLET \ i J' CHOKE UNE 13 5/8 PSI. 14 MPL OPERATORS, [ — a T! * 'MI BLIND L BUNG SHEAR RAM 0 C ] BY PASS • • • STUDDED BOTTOM BX 180 ♦ . ■•■• ■ 3 1/8" 5000 PSI MCR VALVE • 1800 3000 ■IN 4II■//III / ■/IIIII■/II■/II■ 2" KILL UNE 3 1/8' 5000 PSI HCR VALVE) / N 3 1/8' 5000 PSI GATE VALVE • • 3 1/8" 5000 PSI GATE VALVE _ _ ••E MIA •M I M-• SINGLE 13 5/8", 5000 PSI, 10' API OPERATORS, HTD 0 ' ' i 'l Rl `a „ RL I n n n n n n �n I • • _m. STUDDED eoTroM /FANGED TOP Bx 180 ACCUMULATOR MANIFOLD 1 D :. .. h 4 441 18 BOTTLES, 10 GALLONS EACH mamma Naimoli U L.L �R� • • 14 CHOKE BOP STACK ELEVATION E : : - ] • REMOTE PANEL IN DOGHOUSE I AND UTILITY MODULE ilia El 1 \ 11-' \ 11- 1 \ ir i `lr NITROGEN BACKUP BOTTLES 21 1/4', 2000 PSI, ' 150 PSI MR. HYDRIL BOP /DIVERTER 18 OPERATED KNIFE GATE VALVE ■■= STUOOED TOP /FLANGED BOTTOM 1' C/14 PLUG ■RI■ FLANGE /FLANGE RX 73 ALMS s oT9M1 W W1E11pNyBN, NBrIpplCll011 ON ua a o,sBl N= OBLr P NB om7FD N ,IMP Brat ort& IB' FLGTI VENT UNE ///'�� \� Ip - -- - -- --- Mn�n� - -- -- -- 1 \ I J f o1 /le /aa s DNB LEA UMW BOP STACK RIG 14 �� ABG, -- FI/NCE 03/05/01 4 OM LEA UNITE BOP 512(12 i , 01/31/00 3 ONB LEA MOW 131013/NLL 1A6 TILE BOP SYSTEM 12 -20-00 2 ROB LEA IA>aa BOP RACI1 AND CONTROL SURFACE DIVERTER CONFIGURATION 11 -28 -BB 1 .1111 LEA °MANNA 15 NIIOGIO 11 11 /28/98 R® Br '4'w° BY LEA rev' 5 s 0N0 gyp' 1r V- oT3217153011 A NTS O 4THH BY ON. R14BOPSYSB:CONTROL 1 Y f y wl, \\ 1 j� THE STATE Alaska Oil and Gas ° fALAS� Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue p . Q. Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 (1, !+ , Bernhard Stechauner Production Engineer BP Exploration (Alaska), Inc. q(C) P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 11 -27 Sundry Number: 312 -365 Dear Mr. Stechauner: 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, J I Cathy P Foerster Chair DATED this 5 a of October, 2012. Encl. I III Om ... ivRE EIVE r STATE OF ALASKA S E P 2 5 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well Ei • Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other SCE ( 1-1- 2. Operator Name: 4. Current Well Gass: 5. Permit to Drill Number: v rt'l% t V BP Exploration (Alaska), Inc. Development Q • Exploratory ❑ 186 -148-0 • 1.'"1.'" 3. Address: Stratigraphic p Service ❑ 6. API Number. P.O. Box 196612, Anchorage, AK 99519 -6612 50 -029- 21638 -00-00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No IS PBU 11 -27■ 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0028322 • PRUDHOE BAY, PRUDHOE OIL - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 12210 • 8892 _ 10870 7950 10870 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.5# H-40 31 - 111 31 - 111 Surface 2525 13 -3/8" 72# L -80 30 - 2555 30 - 2517.96 4930 2670 Intermediate None None None None None None Production 11340 9 -5/8" 47# L -80 28 - 11368 - 28 - 8298.32 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and ND (ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development El Service ❑ 14. Estimated Date for ^� ��rr 15. Well Status after proposed work: Commencing Operations: 1.77 k 2/ 2 (2 2, Oil 0 • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bernhard Stechauner Prepared by Garry Catron 564 -4424 Printed Name Bernhard Stecha er Title Production Engineer Signature `7 / Phone 564 459 Date fJ 4 9/ �^ / n J/L COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3) Z ' 3 to 5 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: 1 0 7 — 4-64 / APPROVED BY Approved by: / 9 COMMISSIONER THE T COMMISSION Date: /3 -- 5 / Form 10 -403 R 1/2010 '/ �F� / t J • O I 9 2012 p _,Submit in Duplicate �.�� l Z r 6 Z f � � �cl ` Al � /2i l t�� R � 1 Casing Summary ADL0028322 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade CONDUCTOR 80 20" 91.5# H -40 31 111 31 111 1490 470 H -40 LINER 901 3 -1/2" 9.2# 13Cr80 11034 11935 8063 8698 10160 10530 13Cr80 LINER 27 3 -1/2" 9.3# L -80 11015 11042 8050 8068 10160 10530 L -80 LINER 1164 7" 29# L -80 11046 12210 8071 8892 8160 7020 L -80 PRODUCTION 11340 9 -5/8" 47# L -80 28 11368 28 8298 6870 4760 L -80 SURFACE 2525 13 -3/8" 72# L -80 30 2555 30 2518 4930 2670 L -80 TUBING 10863 4 -1/2" 12.6# 13Cr8( 28 10891 28 7964 8430 7500 13Cr80 • TUBING 152 5 -1/2" 17# L -80 10896 11048 7968 8072 7740 6280 L -80 TUBING 67 5" 15# L -80 11048 11115 8072 8119 8290 7250 L -80 TUBING 6 7" 26# L -80 22 28 22 28 7240 5410 L -80 • Perforation Attachment ADL0028322 Well Date Perf Code MD Top MD Base TVD Top TVD Base 11 -27 5/1/11 BPS 11984 11997 8732 8741 11 -27 5/1/11 BPS 11998 12029 8742 8764 11 -27 5/1/11 BPS 12048 12058 8777 8784 11 -27 5/1/11 BPS 12058 12062 8784 8787 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED • APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • Packers and SSV's Attachment ADL0028322 Well Facility Type MD Top Description TVD Top 11 -27 PACKER 10782 5 -1/2" Baker S -3 Packer 7890 11 -27 PACKER 10944 5 -1/2" Baker S -3 Packer 8000 11 -27 PACKER 11026 5 -1/2" Baker SB -3 Packer 8057 • • • • 0 To: J.Bixby /R. Liddelow Date: 15 August 2012 AK, D &C Wireline Operations Team Leads Clark Olsen /Tyler Norene AK, D &C Well Services Team Lead From: Bernhard Stechauner Code: DS 11 Pad Engineer, (0) 907 - 564 -4594, (C) 360 -7485 Neil Cary, Seal -Tite Engineer, 985 - 875 -1292 Subject: 11 -27 Repair PC leak using Seal -Tite IOR: 300 bopd Est. Cost: 1. S Set circ valve in Sta #1 2. F Circulate out the wellbore with KCL & displace sealant to leak site 3. S Pull circ valve and DGLV #1 4. O/D Pump and activate sealant 5. D MIT -IA to 3000 psi 6. SP Pull TTP if repair is successful, SBHPS Current Status: SI and Not Operable for a PC leak Last Test: 4/26/11 797 BOPD, 590 BWPD, 30 MMCFD gas, 258 IOR Max Deviation: 56° @ 7400' MD Minimum ID: 2.75" @ 11901' cement sheath Est BHP 3264 psi @ 8800' TVD (2010 BHP Map) SSSV No Last H2S 01/24/11 20 ppm Objective: •This •ro•ramistore•air- • •• _ ' • - • ' -'•• -•• • -- '1• - -- • - pill" in the IA. A circulation valve will be used to circulate brine and sealant through the lowest mandrel. A MIT -IA will be performed to confirm operability of the well post repair. Well Events Summary: 11 -27 is a naturally flowing gas lifted producer last completed with 4.5" chrome tubing in 2005 RWO for TxIA communication. A TTP was set 05/01/11 and the well passed a MIT -T and failed a CMIT -TxIA with a LLR of 4.72 gpm at 3000 psi. A production casing leak was confirmed at 7829' with an LDL run 05/28/11. The well has no other known integrity issues. A PPPOT -T & PPPOT-IC both passed 7/21/11. Please call Bernhard Stechauner (APE) at 564 -4594 or Neil Cary (Seal -Tite Engineer) at (985) 875 -1292 with any questions or concerns regarding this program. Tiffany Quy was the WIE for Page 1 of 9 • the first two attempts at Seal -Tite, 253 - 576 -6153. Mel Iveson is now the current WIE contact 907 - 659 -5098. Cc: Well File AK, D &C Well Integrity Engineer Discussion: • This is the third sealant treatment to repair this leak. The first treatment was executed 1/15/12. That job failed to see any pressure increase indicating the sealant was trying to set. The second treatment was designed with a greater density difference to help ensure the sealant pill stays in position as well as placing the pill higher in the annulus initially to make sure it is not accidentally placed below the leak site. The second job again did not see any pressure increase indicating sealant contact at the expected location of 7829' MD. The LDL again located a leak at 7829' MD. Displacement of the sealant pill continued with almost no change in leakoff rate until it was just above the packer. It was concluded that a major portion of the leak was at the packer all along and the contact time for the sealant across the upper leak was insufficient to effect a repair. The leak at the packer is now sealed. with still a smaller leak remaining at 7829' MD. This third seal tite job will target the production casing leak at 7829'MD. • The IA was completed with 8.65 ppg inhibited seawater. This repair attempt will follow the same basic procedure as the second job. The lower GLM #1 will be used to circulate and displace the tubing and IA. • The original leak rate from pump records for the failed CMIT was approximately 4.7 gpm @ 3000 psi. Subsequently an LDL located the leak at 7829' MD. The leak rate during this sequence was -3.1 gpm @ 3000 psi. This fluid loss was over a significantly longer time interval is considered to be more reliable. Riq up notes and requirements: - Rig up hard line through a choke skid to pump down both the Tbg and IA taking returns down the 11 -36 flow -line or to a contingency tank. Make sure there is a sample port in the choke skid to confirm return densities. Make sure there is a strap sheet for the contingency tank. 11 -36 is a long term SI Not Operable for a SC leak, but the flowline is still in service (per DSO 08/06/11). - Have a mud scale available for density measurements. - Include a tee before the choke skid to rig up the Seal -Tite tote as close to the wellhead as possible. (Note: There have been issues using the under balanced method to suck the sealant in though excessive hardline likely due to friction of the viscous pill. Try to have the tote rigged up as close to the wellhead as possible.) - If the underbalanced method is unsuccessful in sucking the sealant pill into the IA, an injection cylinder will be used in conjunction with a diaphragm pump. Be sure that this equipment is available and operational on the slope before beginning this work. - The sealant is freezable fluid. The special projects trailer will be needed for maintaining temperature and mixing the sealant pills. - Heaters for the well house and projects trailer. - Air compressor for the pumps. - Bleed trailer. - It is essential that the job only be pumped when it is certain slickline will be available and the forecast indicates a weather window adequate to complete the work. The Page 2 of 9 • • first time this job was executed the sealant sat for 5 days before a dummy could be set and the sealant activated. Volumes: Note — all volumes /depths below are corrected for RKB /BH elevation difference of 30'. As such all depths are denoted "MDBH" (Measured Depth to Bradenhead) Total IA volume - 9 5/8" x 4'/2" to Production Packer @ 10914' MDBH = 575.2 bbls To leak @ 7799' MDBH = 417.2 bbls To lowest gas lift mandrel @ 10701' MDBH = 571.9 bbls From leak to packer = 7799 - 10752' MDBH = 158.0 bbls Tubing 4 '/" 12.6 # /ft = .0152 bbl /ft x 10840' mdbh (to PXN plug) = 164.8 bbls Compression to Packer = 2 bbls / 1000 psi or 112' @ 3000 psi Compression above sealant = 1.46 bbls / 1000 psi or 82' @ 3000 psi Compression below sealant = .54 bbls /1000 psi or 30' @ 3000 psi Fluid requirements: - 800 bbls 9.8 ppg KCI with corrosion inhibitor - 10 bbls Diesel - 5 bbls of 8.95 ppq KCI to be mixed and loaded in the Seal -Tite mixing tote (STI Flo -Seal product will be shipped and supplied by STI. Storage is in U -11). Final density of the sealant/KCI mix will be 9.4 ppg. - 301 bbls 9.2 ppg KCI with corrosion inhibitor - 150 bbls Diesel and /or methanol blend for freeze protect Page 3 of 9 • • Procedure: Slickline: Change out GLVs 1. Hold PJSM. RU Fullbore and conduct a pre -job MIT on the IA to re- confirm the leak rate. 2. RU slickline. 3. Set circ valve in Sta #1. 4. Pump with triplex (or FB) to establish both TxIA and IAxT circulation. Fullbore and Projects: Circulate well out with brine and place Seal -Tite pill Note: Do not proceed until the weather forecast and slickline schedule indicate that the Steps 4-22 will be able to be done continuously. 5. Hold PJSM. RU FB pump to the choke skid. 6. Line up to pump down IA, taking returns up the tubing to nearby flowline of 11 -36. Leave -200 psi of back pressure on the tubing during circulation to make sure the system remains liquid packed. 7. Circulate a total of 800 bbls of 9.8 ppg brine down the tubing taking returns up the annulus. At 737 bbls (one round trip volume), the IA & Tbg should be fully displaced. Take density measurements of the returns with a mud scale to assure clean, consistent 9.8 ppg returns for the rest of the circulation. Maintain maximum pump rate as per PE manual. 8. Line up to pump down the tubing taking returns up the IA. Displace 10 bbls of diesel into tubing. This will set up -100 psi pressure differential from IA to tubing to enable easy injection of the sealant pill. 9. Blend 7 bbls of Flo -Seal to 9.4 ppg. Hook up sealant tank discharge to the hard line tee from the IA casing valve. 10.Open valves to the sealtite tank and bleed up to 10 bbls of diesel from the tubing to allowing the under balance to pull the 7 bbls of Flo -Seal into IA. • Take returns to the contingency tank to verify the volume bled off the tubing. If more than 12 bbls are bled, the well should equalize in pressure and this method will not work without pumping more diesel down the tubing. • If this method is unsuccessful in placing the sealant into the IA, a contingency rig up should be available as noted in the rig up notes above. 11. Line up pump down the IA taking returns up the tubing. Displace Flo -Seal with 301 bbls of 9.2 ppg inhibited KCI followed by 113 bbls of diesel and /or McOH blend for freeze protect. Bring pump rate up slowly at -0.25 bpm until -6 bbls of inhibited brine have entered the annulus. Increase pump rates to 1 bpm for the rest of the displacement. This should place the bottom of the sealant pill approximately 135' above the leak point. Freeze Protect Tree with 20 bbls of Diesel or McOH, which will move the bottom of sealant pill to 173' above the leak. 12.RDMO FB pump. Page 4 of 9 • • Slickline: Change out GLVs and MIT -T 13. RU SL. 14. Pull circ valve from Sta #1 and install a DGLV. • NOTE: At this point the IA is underbalanced to the tubing by -500 psi. Ensure that no pressure is bled from tubing or annulus until the gas lift dummy is confirmed to be installed and holding. 15. MIT -T to 3000 psi to ensure dummy is holding. Leave 3000 psi on tubing and monitor during remainder of program. 16. RDMO SL & FB pump. Projects with DHD assist: Activate Seal -Tite pill 17. RU triplex and pump diesel down IA to pressure up to 2000 psi. 18. Continue pushing sealant down at 2000 psi. It should take at approximately 5 bbls displacement in addition to any liquid compression to displace the sealant pill to the leak. Plan to monitor pressures every 15 min and repressure every 30 min until the leak rate begins to decrease. Once there are indications that the sealant has reached the leak, bleed the IA back to 1000 psi. • Note keep close track of the volume pumped to assure you do not overshoot the sealant pill. 19. Shut down pump and allow a seal to be obtained at 1000 psi. Let the sealant cure for a minimum of four hours. 20. Increase IA pressure to 1500 psi. Allow to cure for two hours. 21. Increase IA pressure to 2000 psi. Allow to cure for two hours. 22. Increase IA pressure to 3000 psi. 23. Shut in the IA and allow the sealant to cure for 5 days. Monitor pressure daily and bump back up if the pressure falls below 2000 psi. 24.After 5day curing period, MITIA to 3000psi. Bleed the IA to zero. Notify Well Integrity of test results and assure a safety note is recorded that the well has a sealant pill remaining in the IA. Slickline Pending: Pull TTP if the repair is successful 25. PJSM. RU SL. 26. Pull PXN TTP set @ 10870' MD on 5/1/11. 27. SBHPS as per attached sheet. 28.Assure well has been reclassified as Operable and notify Operations that well may be put BOL. 29. RDMO SL. Page 5 of 9 • • Riq Up Schematic Contingency P -Sub tank Choke skid Hard line to 11 -36 ... Swab flowline for returns Wing C <�� ► LRS inlet .•. SSV P9 Master .:. Inlet for STI tote IA CV BV Tee OA CV Page 6 of 9 • • TREE = McEVOY WELLHEAD = MCEVOY SAFETY NOTES: *"'4 -1/2" & 3 -1/2" CHROME LNR*"* ACTUATOR = AXELSON 4- 112" CHROME VERY ABRASIVE - SEE 04 /09/05 KB. E1.EV ,. ..._.._._58; AWGRS REPORT BF.ELEV= KOP = , ... - a ' 190 ' 0' " , I 23' H7" X 4 -1/2" XO, ID= 3.958" Max 'Angie-=` ... 56 @ 7400' Datum MD - ...... - 12162' ' ' L 2501' I— I4 -V2" HIES X11 D = 3.813" I Datum TVD = 8800' S S GAS LIFT MANDRELS 133/8" CSG, 72#, L -80, ID= 12.347" ' 2555' I ' ST RV ND DEV TYPE VLV LATCH PORT DATE 4 3434 3242 46 MMG DOME RK 16 08/17/05 C - ( II 3 7070 5589 53 MMG DOME RK 16 08/17/05 2 9582 7097 50 MMG DMY RK 0 03/26/05 L 7v y 7 `, 1 10731 7855 47 MMG SO RK 22 08/17/05 10759' H4 -1/2" HES X NP, D = 3.813" I Minimum ID = 2.75" @ 11901' ^ ∎-4 10780' — 4 -1/2" x 5 -112" XO, D = 3.958" I 3 -1/2" LNR LANDING COLLAR (MILLED) 10782' — 9 -5/8" X 5 -1/2" S -3 PKR, D= 4.75" 10786' 5 -1/2" X 4 -1/2" XO, D = 3.958" I I 10849' — 4 -1/2" HES X NP, D = 3.813" I4 -1/2" PXN (5/01/11) H 10870' I NM 10870 4 -1/2" HES XN NP, D = 3.725" I I4 -1/2" TBG, 12.6#, 13CR80, .0152 bpf, D = 3.958" H 10891' (•- -� I 10891' H4 -1/2" x 5-1/2" XO, ID = 3.958" I I 10896' HTOP OF 5-1/2" TBG STUB (3/26/05) I S 10902' — 9-5/8" X 5 -1/2" UNDUE OVERSHOT �-I 10944' — 9-5/8" X 5 -1/2" BAKER S -3 PKR I I-- 10978' H 5-112" HES X NIP, D = 4.562" I TOP OF 5-1/2" TBG 11001' 1 10998' H5 -1/7 UNIQUE OVERSHOT I 15 -1 /2" TBG, 17 #, L -80, .0232 bpf, D = 4.892" H 11006' 1.---"---. I'' 11015' H STNGER TIEBACK SLV 08/08/04 I Z K 11026' I- 1 9.5/8" X 5 -1/2" BAKER SB-3 PKR I 11034' HC-Z TIEBACK SLV, MLLED ID = 2.75" (04/14/05) ITOP OF 7" LNR H 11046' ( I. 1 5 -1/2" TBG -FC, 174, L -80, .0232 bpf, ID = 4.892" H 11048' I I . I 11048' 1"I5 -1/2" X 5" XO (BEHIND PIPE) I 11060' (-I3 -1 /2" OTIS X NIP, D= 2.813" 02/23/04 I I I 1 1094' H 5" OTIS X NIP, ID= 4.312" ( BEHIND PIPE) I 11114' H 5" BAKER SI-EAROUT SUB (BEHIND PIPE) I 15" TBG -PC, 154, L -80, .0232 bpf, D = 4.406" H 11115' I e 1111 5. H 5" WLEG (BEHIND PIPE) I i1'4� I1'1 19 -5 /8" CSG, 47 #, L -80, D = 8.681" H 11368' (---'• � ,j4 I41 Ilk 414 14 13 -1/2" LNR, 9.3#, 13 -CR, .0087 bpf, ID = 2.992" H 11935' r'1 .1 1 � 1 11901' HCMT SHEATH, MLLED ID = 2.75" (04/14/05) I NI 11 PERFORATION SUMMARY 44.4 � . 1 11998' CTM HBTM OF CMT SIfATH (04/16/05) I REF LOG: BHCS ON 01/10/87 ANGLEAT TOP PERF: 46 Q 11985' Note: Refer to Production DB for historical pert data I SIZE SPF INTERVAL Opn/Sqz DATE 2 -1/2: 6 11985- 11998 0 01/11/06 3 -3/8" 4 11998 - 12029 0 07/30/87 I 3-3/8" 4 12048 - 12062 0 09/03/89 .. ...... 1 12065' CTMD HTOPOFSAND(08 /04/05)I PBTD 12100' +1 ■ �. 7" LNR 29#, L -80, .0371 bpf, D = 6.184" H 12210' ' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/31/87 ORIGINAL COMPLETION 01/16/06 RLM/PAG ADD PERFS WELL: 11 -27 06/23/98 RWO 05/21/11 WRR/ PJC SET PXN (05/01111) PERMIT No: '1861480 03/27/05 WJH/TLH RWO API No: 50 -029- 21638 -00 05/03/05 WRR/PJC GLV d0 (04/01/05) SEC 28, T11 N, R15E, 4134.88' FEL & 3838.25' FM. 08/04/05 JNA/PJC MLLED SAND 08/17/05 KSB/TLH GLV 00 BP Exploration (Alaska) Page 7 of 9 • i • STATIC BOTTOM -HOLE PRESSURE SURVEY Ver14, Rev 08/122004(JDM) Well: 11 -27 API #: 50-029-21046-00 Date: 9/19/2012 Prod Engr Bernhard Stechauner Office Ph: 564 -4594 H2S Level: Cost Est: $10,000 Home Ph: 677 -0860 20ppm - -- 1/24/11 CC or AFE: APBNRWOS Cell /Pager: 360 -7485 WBL Entries Type Work Description Comments SP [Pull TTP, SBHPS Well SI on April 2011 for integrity /Ready after successful SealTite job Well Objectives, Loaning Notes. and Special Instructions: Following a successful SealTite job, the tubing tail plug needs to be pulled before putting the well on production. This is a great time to grab an opportunistic SBHPS The well has been SI since April 2011 and will be ready once the TTP has been pulled. Datum: 8800' SS I Well Data Procedure: Last Tag: 9688' MD Tag date: 11/8/2011 1. Make 10 min pressure stop in lubricator Max Deviation 30 Degs Depth: 8400' MD 2. Drop below the first pressure -stop requested. Pull -up to specified depth. 3. E /L: Measure pressure until it varies less than 1 psi in 20 min. Min. SI Time: 7 Days I Logging Data S /L: Hold guages at depth for time specified 4. E /L: Measure pressure until it varies less than 1 psi in 20 min. S /L: Hold guages at depth for time specified Requested Stops: MD SS Time 5. E /L: Measure pressure until it varies less than 1 psi in 20 min. First 9363' 8600' 15 min S /L: Hold guages at depth for time specified Second 9475' 8700' 15 min 6. E/L: Test tool in lubricator at 3000 psi with calibrated test gauge Third 9586' 8800' 15 min S /L: Hold guages in lubricator for 10 min stop. Compare to test guage 7. Leave well shut in, hand over to OPS to POP. Summary Dist Well: 11 -27 API #: 50- 029 - 21046 -00 PE Town: Date: Anch Prod Engr Service Co. New Tag: 'MD P.D. Center Upper Lower Date Time MD SS Gauge Gauge Temperature Test Gauge Pre -Job Lubricator Pressure 9363' 8600' 9475' 8700' 9586' 8800' 0 ' 0' Post -Job Lubricator Pressure Type of Pressure Tool SITP (Tubing): psig SICP (9- 5/8 "): Shut In Date: Comments: and Time: Total Shut In Time (hrs) ..... Page 8 of 9 I • • p " LEAK DETECTION - WLD _ - or XTU- HTU -<i- TEMP -MD _ «r • PebM NormN4 W00% dr 2T - May -24)11 " Company BP EXPLORATK)N (ALASKA), INC ` �ti - Ii i 11 - 27 r• _ Fmk) PRUDHOE BAY " � = ' 1 *. ---- -- — Gl,A,i IP ., Q Canty NORTH SLOPE slam ALASKA 71� F3�hc. Lomtmn 004:4 Swoon .sr k - ro y • ; �� g Q M1 67 FEL 6 22846N FEL ‘: , ___ R CD 4 2 - 5@C: 2! TNT` 11N NW 1W fk+,ir a8181181182 50 ' ' . a y � .. `c -+ an a ea FT Above O rn C m : 11 F tyli, a . AP , 5.8 Lori. 36.62&21636.04 6L 44144 .--.." 'v 4444 2 N1l. 2711 .+ a Nrrx'r Ots t , ..�_. 72 l a - PA T1C w 1$,181"1 b � 1 i POT7ls�1f WIT,�^� , WIN L���'^•a 4411'! 4y _ a � ,. TW- IY]1Mni te7F1Q 1 1VA la Ow 444.4o 64,4, No .... T I f44 : Ta _ t 4 L p 4 NNN - 1rnMhlNafr aa `!�' ANAL PRINT � fi � /{/a FAUCrM^S tAnM� '' Fl. MOO le S Rr bg IMiZ1 M lifii N47.4444 Ne s� ""f ApNwwA4 IN LWOW. Roan _„ �, Y 7 . .�__... �, ,. — ` Ron N.+rt Peet 1fl t 18. Ft FIah T9 s 4i? "ti r- '1 is e 1 1 'tt x.ks..saw "?36 Cpl IA. zYW_ ..'..°.44 -.°. I 7400 1 __ . Pm ra<.ti 4 <raa sa,±,r., n 3111` i � � an ? 43) ,.tea' tsOW ...it ' , 'ih 7500 . ti ... a 1 r 1 1 �1 1 1 ay - r -'• -Ali- . . •.. .. ' - -- „..44 '• A F .-' v 1 _ i :: - { Page 9 of 9 irlIttoC,i V = STATE OF ALASKA ALOCA OIL AND GAS CONSERVATION COMOSION SEP 0 6 7017 REPORT OF SUNDRY WELL OPERATIONS AOGGC 1. Operations Abandon L Repair Well U Plug Perforations U Perforate U Other L Seal -Tite Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development IN Exploratory ❑ - 186 -148 -0 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 a 50- 029 - 21638 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028322 ^ PBU 11 -27 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 12210 feet - Plugs measured 10870 feet true vertical 8892.25 feet Junk measured None feet Effective Depth measured 10870 feet Packer measured See Attachment feet true vertical 7949.85 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H-40 31 - 111 31 - 111 1490 470 Surface 2525 13 -3/8" 72# L -80 30 - 2555 30 - 2517.96 4930 2670 Intermediate None None None None None None Production 11340 9 -5/8" 47# L -80 28 - 11368 28 - 8298.32 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: %IwED LIAR 0 4 2013 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development Q ;. Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: „ Oil U Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -254 Contact Nita Summerhays Prepared by Nita Summerhays 564 -4035 Printed Name Nita Summerh- s Title petrotechnical Data Technician Sig natu , i r ' l O 1 f4 ,� Phone 564 -4035 Date 9/6/2012 RBD S SE: 01 e i lip o' if q /if/v Form 10-404 Revised 10/2010 • 4" i `., ! '; f 4 L 1 ti Submit riginal Only 3 60 , 1 Perforation Attachment ADL0028322 Perf Opera Meas Meas SW Operation tion Depth Depth TVD Depth TVD Depth Name Date Code Top Base Top Base 11 -27 5/1/11 BPS 10870 12065 7949.85 8788.97 11 -27 6/1/02 SPS 11624 11854 8422.18 8583.39 11 -27 6/13/02 SPR 11648 12100 8439.11 8755.67 11 -27 6/18/03 SPS 11878 11888 8600.16 8607.14 11 -27 12/24/03 SPR 11878 12065 8600.16 8730.97 11 -27 2/23/04 MIS 11901 11998 8616.23 8684.01 11 -27 1/11/06 APF 11984 11997 8674.23 8683.31 11 -27 7/30/87 PER 11998 12029 8684.01 8705.68 11 -27 5/7/01 FIL 12002 12062 8686.8 8728.86 11 -27 6/9/03 FIL 12015 12100 8695.88 8755.67 11 -27 9/3/89 APF 12048 12062 8719.02 8728.86 11 -27 12/24/02 BPS 12058 12062 8726.05 8728.86 11 -27 3/27/05 BPP 12058 12062 8726.05 8728.86 AB ABANDONED MIR REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET OH HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF 0 • Packers and SSV's Attachment ADL0028322 SW Name Type MD TVD Depscription 11 -27 PACKER 10782 7832.09 5 -1/2" Baker S -3 Packer 11 -27 PACKER 10944 7942.48 5 -1/2" Baker S -3 Packer 11 -27 PACKER 11026 7999.18 5 -1/2" Baker SB -3 Packer Casing / Tubing Attachment ADL0028322 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 31 - 111 31 - 111 1490 470 LINER 27 3 -1/2" 9.3# L -80 11015 - 11042 8049.54 - 8068.3 10160 10530 LINER 901 3 -1/2" 9.2# 13Cr80 11034 - 11935 8062.74 - 8698 10160 10530 LINER 1164 7" 29# L -80 11046 - 12210 8071.09 - 8892.25 8160 7020 PRODUCTION 11340 9 -5/8" 47# L -80 28 - 11368 28 - 8298.32 6870 4760 SURFACE 2525 13 -3/8" 72# L -80 30 - 2555 30 - 2517.96 4930 2670 • TUBING 6 7" 26# L -80 22 - 28 22 - 28 7240 5410 TUBING 10863 4 -1/2" 12.6# 13Cr80 28 - 10891 28 - 7964.17 8430 7500 TUBING 152 5 -1/2" 17# L -80 10896 - 11048 7967.59 - 8072.48 7740 6280 TUBING 67 5" 15# L -80 11048 - 11115 8072.48 - 8119.24 8290 7250 • • • Daily Report of Well Operations ADL0028322 ACTIVITYDATE 1 SUMMARY n -u " - - •- •'--7' ge reamen RIG UP - STAND BY FOR VALVE CREW 4/28/2012 * ** CONT ON 4 -29 -12 WSR * ** " "" CONT FROM 4 -28 -12 WSR * ** STAND BY FOR GREASE CREW SET 4 1/2" WHIDDON @ 10,862'SLM. IN HOLE W /KOT RUNNING TO STA #1 4/29/2012 * ** CONT ON 4 -30 -12 WSR * ** CONTI-ROM 4 -29 -12 WSR ,-** (gel treatment) PULLED RK -DGLV FROM STA #1 @ 10,731'MD SET RKP -FLOW SLEEVE /CIRC VALE IN STA #1 PULLED 4 1/2" WHIDDON CATCHER SUB @ 10862'SLM - EMPTY 4/30/2012 ***TURN WELL OVER TO PAD OP, LEFT WELL SHUT IN * ** 5/12/2012 Seal tite treatment Assist (Repair PC leak w/ Sealtite) Job Postponed. ** *WELL S/I ON ARR1VAL ** *(seal -tite repair) AWAIT LRS TO CIRCULATE IN FLO -SEAL SET 4 -1/2" WHIDDON C. SUB ON P -PRONG @ 10,861' SLM 5/13/2012 * * *CONT ON 05/14/12 WSR * ** T /I /0= 130/417/28 Temp =S /I Circ -out for pre Seal -Tite Treatment (Gel Treatment) Pumped 5 bbls methanol spear followed by 895 bbls 9.8 ppg brine down IA while taking returns up Tbg to well 11 -36 flowline for circ -out. Took sample from return line after 800 bbls pumped, took sample after 870 bbls pumped. Pumped 20 bbls diesel down tbg taking returns up IA to 11 -36 flowline. 5.8 bbls Seal tite pumped away. Pumped 285.7 bbls 9.2 ppg brine followed by 127 bbls diesel down IA, taking returns up Tbg to 11 -36 flowline. Pumped 15 bbls diesel down Tbg, taking returns up IA to 11- 36 flowline. Freeze protect hardline to open top with 1 bbls meth followed by 2 bbls diesel. Freeze 5/13/2012 protected 11 -36 flowline with 120 bbls 60/40 methanol. ** *WSR Continued ** ** *WSR Continued * ** MITT * *PASSED"" 3000 psi. Pumped 2.17 bbls of diesel to reach test pressure. 15 min T lost 70 psi. 30 min T lost 28 psi. Total loss of 98 psi in 30 mins. Leave 2926 psi on tbg. SSL to rig down. Pumped 2.6 bbls into IA to pressure up to 2000 psi and to spot Seal -tite pill at leak @ 7799' Monitor bleed off (see log for details) Total bbls pumped = 16.56 bbls diesel. SV, WV= C SSV, MV= 0 IA, OA= OTG FWHP's= 2612/1528/0 5/14/2012 ** *CON r FROM 05/13/12 WSR"**(seal -tite repair) PULLED RKP -FLOW SLEEVE FROM STA #1 @ 10,724' SLM (10,731' MD). SET RK -DGLV IN STA #1 @ 10,724' SLM (10,731' MD). PULLED EMPTY 4-1/2" WHIDDON C -SUB FROM 10,861' SLM LRS PERFORMED PASSING MIT -T TO 3000 psi. 5/14/2012 ** *WELL LEFT S /I, DSO NOTIFIED * ** T /I /O = 2331/230/9. Temp = SI. Assist Tite (Post Seal Tite Job). AL spool dropped. Hardline from tubing and IA to choke skid. T FL near surface. IA FL @ surface. Pressured up IA to 1000 psi 4 times and monitored for 1 hr between tests. Pumped a total of 147 gal diesel down IA. See log for details. Final WHPs = 2433/759/10 5/15/2012 SV, WV = C. SSV, MV = 0. IA, OA = OTG. NOVP. 19:35 T /I /O = 2305/247/11. Temp = 5I. Assist SeafTite (Post Seal Tite job). AL spool dropped. Hardline from TBG & IA to choke skid. T FL near surface. IA FL @ surface. TP decreased 142 psi, IAP decreased 558 psi, OAP unchanged overnight. Increased IAP to 1000 psi w/ diesel 2 times & monitored for 1 hr between tests. Pumped a total of 80 gal diesel. See log for details. Final WHPs = 2415/808/10. 5/16/2012 SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 14:30. • • T /I /O = 2287/301/11. Temp = Si. Assist Searrite(Post Seal Tite Treatment). AL spool dropped. Hard line from T & IA to choke skid, T FL near surface. IA FL @ surface. Pressured up IA to 1000 psi, 2000 psi and 2 times to 3000 psi. Monitoring 1 hr between tests. Pumped a total of 9.6 bbls diesel. See log for details. Final WHPs = 2581/1892/14. 5/17/2012 SV, WV = C. SSV, MV = 0. IA, OA = OTG. NOVP. 15:30. * ** WELL SHU f -IN ON ARRIVAL *** (SLB E -LINE / TECWELL LEAK DETEC f CIS) INITIALT /I /0 = 2300/0/0 PSI PRESSURE BLED ON TUBING FROM 2300 TO 300 PSI DB TEST FAILED - GREASE CREW CAME IN AND SERVICED TREE - DB PASSED AFTER THAT PDS INITIAL TOOLSTRING CHECK DID NOT PASS - TROUBLESHOOTING PERFORMED AND A BAD SPRING ON ONE OF THE WEIGHT BARS WAS FOUND PDS TOOLSTRING CHECK IS GOOD DECISION TO LAY IT DOWN FOR THE DAY AND CONTINUE OPERATIONS IN THE MORNING FINAL T /I /0 = 300/0/0 PSI 5/19/2012 ***WELL SHUT -IN UPON DEPARTURE * ** (JOB WILL CONTINUE ON 19 MAY 2012) * ** WELL SHU f -IN ON ARRIVAL*** (SLB E -LINE /1 ECWELL LEAK DETECT CIS) INITIAL T /I /0 = 200/0/0 PSI DB TEST DID NOT PASS GREASE CREW CAME AND SERVICE THE TREE - TROUBLESHOOTING ON LEAK - POSSIBLE FROM FLOWLINE OR LATERAL JOB CANCELLED 5/20/2012 ***WELL SHUT -IN UPON DEPARTURE * ** T /I /0 = 4/342/11. Temp = 51. Assist Sealtite (Sealtite treatment). AL disconnected. Integral installed on IA (no color). IA FL @ surface. Pumped 1447 gallons of diesel down IA for Sealtite treatment. 5/24/2012 ** *Work in progress, Continued on 05 -25 -12 WSR * ** ** *Work in progress, Continued from 05 -24 -12 WSR ** *Assist Sealtite (Sealtite treatment). AL disconnected. Integral installed on IA (no color). IA FL @ surface. Pumped 2312 gallons of diesel down IA for Sealtite treatment. Two day total of 3759 gallons of diesel down IA. ***Work in 5/25/2012 progress, Continued on 05 -26 -12 WSR * * *. * ** Work in progress, Continued from 05/25/12 WSR * * *. Assist Seal -tite. (Seal -tite treatment). AL disconnected. Integral flange installed on IA (no color). Pumped 1612 gallons (38.4 bbls) diesel down IA for Seal -tite Treatment. Bled IAP from 2805 to 490 psi in 30 min. Job complete. Final WHPs = 0/490/0. 5/26/2012 SV, WV = C. SSV, MV = 0. IA & OA = OTG. NOVP. 19:00 Hrs. — WELL SHU f -IN ON ARRIVAL * ** INITIAL T /I /0 = 0/300/0, SSV OPEN LRS PRESSURED UP ON IA TO 3000 PSI, INITIAL PRESSURE LOSS INDICATED A LEAK, STARTED LOGGING TECWELL LDL. LEAK STOPPED ABOUT 30 MINUTES AFTER LOGGING BEGAN. MIT -IA PASSED TO 3000 PSI. PE REQUESTED WE LOG ACROSS OLD LEAK POINT NEAR 7800' BEFORE POOH AND RIGGING DOWN. FOUND SMALL LEAK SIGNATURE AT 7816'. INFORMED PE, SAID TO POOH AND RD DUE TO TIME CONTRAINTS WITH 16HR RULE. PDS TOOLS CAME BACK TO SURFACE WITH RED FIBEROUS MATERIAL ON THE CENTRALIZERS. LRS BLEED IAP BACK DOWN AFTER MIT. FINAL T /I /0 = 700/220/0. LEFT WELL SHUT -IN AND SECURE, HAND OVER WITH DSO PRIOR TO DEPARTURE. 6/1/2012 ** *JOB COMPLETE * ** T /I /0= 0/280/0 Temp =S /I Assist E -line w/ LDL & MIT -IA to 3000 PSI PASSED 4th attempt (Repair PC leak w /sealtite) Pumped 5.8 bbls 50* crude down IA to initially reach PSI for log. Pumped an additional 0.67 bbls (Total 6.47) 50* crude for test. 1st 15 min IAP lost 23 psi, 2nd 15 min IAP lost 23 psi, 3rd 15 min IAP lost 19 psi for a total loss of 65 psi in 45 min. E -line logged from 8200 - 7500'. 6/1/2012 Bled back IAP, approx 6 bbls FWHP's = 927/500/2 SLB on well at departure • • T /I /O = 623/528/14. Temp = SI. MIT IA FAILED to 3000 psi. (Post Seal -tite repair). Extended Monitor. AL disconnected. Integral flange on IA. (No color stripe). IA FL @ surface. Pumped 6.75 bbls diesel down IA to bring pressure up to 3000 psi for 3 test. On 3rd attempt lost 23 psi in 1st 15 minutes, lost 23 psi in 2nd 15 minutes, and lost 23 psi in 3rd 15 minutes. Total loss of 69 psi in 45 minutes. Monitored for additional 2 hours and lost an additional 250 psi. Bleed IAP down to 2300 psi. Bled back 1 bbl of diesel. Job Complete. Final WHP's = 941/2317/18. 6/3/2012 SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 04:00 hrs. 171/0 = 900/1370/0 +. Temp = SI. Maintain 23U0 psi on IA (Load). AL disconnected. Integral installed on IA (no color). IA FL @ surface. Pumped 3 bbls diesel down IA to bring pressure to 2300 psi. Monitored for 30 min. IAP decreased 40 psi during monitor. IA Ops gauge reading 500 psi low. Job complete. Final WHPs = 900/2260/0 +. 6/3/2012 SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 17:30 hrs. T /I /O = 830/1410/20. Temp = SI. WHPs. (Seal-1 ite). AL Spool dropped. Integral installed on AL casing valve (no stripe). Tubing pressure decreased 140 psi, IAP decreased 750 psi & OAP increased —5 psi overnight. 6/4/2012 SV, WV = C. SSV, MV = O. IA & OA = OTG. NOVP. 16:45 Hrs. T /I /O = 850/1550/15. Temp = SI. Re pressure Seal -Tite to 2300 psi (PILL). Installed new 3000 # guage on IA. IA FL @ surface. Pumped 2.875 bbl's in 8 min to 2250 psi. Monitor for 30 min. IAP decreased 90 psi and IA FL unchanged. Job complete. Final WHPs = 970/2160/15. 6/4/2012 SV, WV = C. SSV, MV = O. IA, OA = OTG. 05:00. T /I /O = 840/1270/15. Temp = Si. WHPs (Seat - Tite). f■ FL © surface. Pumped 2.8 bbl's DSL in 10 minutes to 2200 psi. Monitored for 30 minutes, IAP decreased 120 psi and IA FL unchanged. Job complete. Final WHP = 970/2080/15. 6/4/2012 SV, WV = C. SSV, MV = O. IA, OA = OTG. 21:00 T /I /O = 1000/1210/30. Temp = SI. WHPs (Seal - Tite). AL spool dropped. TP increased 30 psi, IAP decreased 870 psi, OAP increased 15 psi since last night. IA FL @ surface. Pressured IA from . 1210 psi to 2300 psi in 15 min using 3 bbls diesel. Monitored for 30 minutes. During monitor IAP decreased 100 psi. Job complete. Final WHPs = 1000/2200/30. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 15:30 hrs. 6/5/2012 T /I /O = 830/1410/30. Temp = ST. WHPs (Seal - Tite). TP decreased 170 psi, IAP decreased 770 psi since 6/5/12. 6/6/2012 SV, WV = C. SSV, MV = O. IA, OA = OTG. 04:30. T /I /O = 800/1230/20. Temp = SI. WHPs (Seal- Tite). AL spool dropped. IA has integral installed (no color). Increased IAP w/2.7 bbls diesel to 2310 psi. Monitored while rigging down. IAP decreased 90 psi. Job complete. Final WHPs = 800/2220/20. 6/6/2012 SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 09:45. FLUIDS PUMPED BBLS 312.13 DIESEL 6 METH 895 9.8 PPG Brine 286 9.2 PPG Brine 6.47 CRUDE 5.8 Seal -Tite 120 60/40 METH 1631.4 TOTAL FLUIDS PUMPED GALS 1674 DIESEL i i I 1674ITOTAL I TREE = 6" CMN FLS • SAFETY NOTES: ""4 -112" & 3 -1/2 "CHROME LNR"° WELLHEAD = BAKERY ACTUATOR = BAKER C 1 2 7 4 -1/2" CHRDM E VERY ABRASIVE - SEE 04/09/05 AWGRS REPORT KB. ELEV = 58' BE ELEV = 23' 7" X 4 - 112 " XO, ID = 3.958" '1< 1900' Max Angle = 56° @ 7400' Datum NO = 12162' I 2601' I 14 - 1/2" HES X NIP, ID = 3.813" Datum TVD 8800' SS GAS LIFT MANDRELS 13 -3/8" CSG, 72 #, L -80, ID = 12.347" I� 2666' , STl BIM) TVD DEV TYPE VLV LATCH PORT DATE 4 3434 3242 "46 NOG DMY RK 0 08/17/05 3 7070 5589 ' 53 MMAG DMY RK 0 08/17/05 2 9582 7097 /1* 50 MMVIG DMY RK 0 03/26/05 1 10731 7855 47 WAG DMY RK 0 05/14/12 I 10759' -14 HES X NIP, ID = 3.813" I Minimum ID = 2.76" @ 11901' CA 10780' — 14 -1/2" x 5 -1/2" X0, ID = 3.958" 3 -1/2" LNR LANDING COLLAR (MILLED) ili I 10782' — 19 -5/8" x 5 -1/2' S -3 PKR, 10 =4.75" I I 10786' —15-1/2" X 4-1/2" XO, ID = 3.958" I 14 - 112" PXN PLUG (05/01/11) H 10870' I 10849' - 14 -1 /2" HES X NIP, ID = 3.813" I I 111 10870' -- I4 -1/2' HES XN NIP, ID = 3.725" I I4-1 /2" TBG, 12.6#, 13CR80, .0152 bpf, ID = 3.958" I--I 10891' I I 10891' H4-1/2" x 5-1/2" XO, ID = 3.958" I I 10896' --i TOP OF 5-1/2" TBG STUB (3/26/05) I 10902' — I9 -5/8" X 5 -1/2" UNIQUE OVERSHOT I ►.t ►7t 10944' i — { 9 -5 /8" X 5-1/2" BAKER S -3 PKR III 10978' H5 -1/2" HES X NIP, ID = 4.562' I I TOP OF 5-1/2" TBG H 11001' ' I 10998' H5-1/2" UNIQUE OVERSHOT I 15 -1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" I 11006' - 11016' H STINGER TIEBACK SLV 08/08/04 I ►�� ►�� I 11026' I- - 518" X 5-1/2" BAKER SB -3 PKR I I TOP OF 7" LNR I 11046' v, B 11034' C-Z TIEBACK SLV, MMLLED ID = 2.75" (04/14/05)1 5 -1/2" TBG -PC, 17 #, L -80, .0232 bpf, ID = 4.892" H 11048' I 1 11048' H5 -1/2" X 5" XO (BERM) PIPE) I I 11060' ]-13-1 /2" OTIS X NIP, ID = 2.813" 02/23/04 I I 11094' H5" OTIS X NIP, ID = 4.312" (REI #ND PIPE) I 11114' H5" BAKER SHEA ROUT SUB (MIND PIPE) I 5" TBG -PC, 15#, L -80, .0232 bpf, ID = 4.406" H 11115' 11 I 11116' I-15" WLEG ( 1 3 8 - 0 8 3 PIPE) I 74ro 1 1 9-5/8" CSG, 47 #, L -80, ID= 8.681" H 11368' ) • * 4 1 0 4 . 1 1 1 1. 1 , 4 I v 1 11901' --I CMT S H E A T H , MILLED ID = 2.75" (04/14/05) I I3 - 1/2' LNR, 9.3#, 13 -CR, -0087 bpf, ID = 2.992' H 11935' Ff■ ' I 44 14 PERFORATION SUMMARY ,414E ` I 11998' CTM I- I BTM OF GMT SHEATH (04/16/05) REF LOG BRCS ON 01/10/87 ANGLE AT TOP PERF: 46° ( 11985' Note: Refer to Production DB for historical pert data I SIZE SPF INTERVAL Opn /Sqz DATE 2 -1/2: 6 11985 - 11998 0 01/11/06 I 3-3/8" 4 11 998 - 12029 0 07/30/87 3-3/8" 4 12048 - 12062 0 09/03/89 1 12066' CTMD HTOPOF SAND (08 /04/05) I I PBTD I--I 12100' I r�.�.�.�.�.,... 17" LNR, 29 #, L - 80, .0371 bpf, ID = 6.184" H 12210' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY WIT 07/31187 ORIGINAL COMPLETION 04/05/12 DJF /JMD TREE C/O (04/04/12) WELL 11 -27 06/23198 RWO 04/22/12 BSE/ PJC SET PXN (05/01/11) PERMT No: '1861480 03127105 WJH/TLH RWO 04/30/12 LEC/JMD GLV C/O (04/30/12) API No: 50-029-21638-00 01/16'06' RLMIPAG ADD PERFS 05 /16/12 SWC/JMD GLV GO (05/14/12) SEC 28, T11 N, R15E, 4134.88' FEL & 3838.25' FNL 11/08111 RCT/ PJC GLV C/O (10/27/11) 06/11/12 RMVJMD TREE C/O (05/25/12) 01/29112 RCT/ PJC GLV C/0 (01/19/12) BP Exploration (Alaska) e 0 ro } C _ ' i . r , q , i % [I 7 SEAN PARNELL, GOVERNOR L ., 18 s [va ALASKA OIL AND GAS! 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Ross Huebel , (v j Petroleum Engineer BP Exploration (Alaska), Inc. MAF 0 2 L'UL2 P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 11 -27 Sundry Number: 312 -083 Dear Mr. Huebel: 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, / Cathy P. Foerster Chair DATED this 1 day of March, 2012. Encl. � STATE OF ALASKA � � ' . 6 `� ANOKAOILAND GAS CONSERVATION COMM ION RECEIVED 3' APPLICATION FOR SUNDRY APPRO ALS 20 AAC 25.280 FEB 9 8 ri2 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair ell ❑ Chan n s. Approved Gomm, Program ❑ Suspend ❑ Plug Perforations ❑ Perforate0 Pull Tu ing ( � r Time Extension ❑ V � Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate❑ Alter Ca ng LI !i Other: 2. Operator Name: 4. Current Well Class: - --5 ?- ermitln L?nll u mber _ 1 BP Exploration (Alaska), Inc. Development 0 _ Exploratory ❑ 186 -1480 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21638 -00 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ PBU 11-27 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO - 028322 ' PRUDHOE BAY Field / PRUDHOE 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): 12210 - 8892 12100 8814 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 31 111 31 111 1490 470 Surface 2525' 13 - 3/8 INCH 72 LB L -80 30 2555 30 2555 6870 4760 Intermediate 11340' 9 -5/8" 47# L -80 28 11368 28 11368 6870 4760 Production 27' 3 -1/2" 9.3# L -80 11015 11042 8050 8068 10160 10530 Liner 901' 3 -1/2" 9.2# 13CR80 11034 11935 8063 8698 10160 10530 Liner 1164' 7" 29# L -80 11046 I 12210 80711 8892 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 7" 26# L -80 22 28 - 4 -1/2" 12.6# 13Cr80 28 10891 - - 5 -1/2" 17# L -80 10896 11048 - - 5715# L -80 11048 11115 Packers and SSSV Tvoe: 5 -1/2" Baker S -3 Packer Packers and SSSV MD and TVD (ft): 10782 7890 5 -1/2" Baker S -3 Packer 10944 8000 5 -1/2" Baker SB -3 Packer 11026 8057 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/13/2012 Oil El- Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ross Huebel Printed Name Ross Huebel Title PE Signature �/ '-v ,1 n Phone Date ( K �/ 564 -5779 2/28/2012 Prepared by Nita Summerhays 564 -4035 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3/A „ d Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: q q ( b `i v- 1 :,...,4 4)&4„7 , /'_ APPROVED BY Approved by: / f T""� COMMISSIONER THE COMMISSION Date: 3 - -` -/ Z Form 1 000 0 -4 0 3 Rsed 1/2010 76- .?29%zO RIG 1 N A 2 in Duplicate 11 -27 186 -148 ` PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 11 -27 7/30/87 PER 11,998. 12,029. 8,742.01 8,763.68 11 -27 9/3/89 APF 12,048. 12,062. 8,777.02 8,786.86 11 -27 5/7/01 FIL 12,002. 12,062. 8,744.8 8,786.86 11 -27 6/1/02 SPS 11,624. 11,854. 8,480.18 8,641.39 11 -27 6/13/02 SPR 11,648. 12,100. 8,497.11 8,813.67 11 -27 12/24/02 BPS 12,058. 12,062. 8,784.05 8,786.86 11 -27 6/9/03 FIL 12,015. 12,100. 8,753.88 8,813.67 11 -27 6/18/03 SPS 11,878. 11,888. 8,658.16 8,665.14 11 -27 12/24/03 SPR 11,878. 12,065. 8,658.16 8,788.97 11 -27 2/23/04 MIS 11,901. 11,998. 8,674.23 8,742.01 • 11 -27 3/27/05 BPP 12,058. 12,062. 8,784.05 8,786.86 11 -27 1/11/06 APF 11,984. 11,997. 8,732.23 8,741.31 11 -27 5/1/11 BPS 10,870. 12,065. 7,949.85 8,788.97 11 -27 10/27/11 BPP 10,870. 12,065. 7,949.85 8,788.97 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • �,I • • • by Date: 02/28/11 To: Jerry Bixby /Rob Liddelow, AK, D &C Wireline Operations Team Lead Clark Olsen/Tyler Norene, AK, D &C Well Services Team Lead From: Tiffany Quy, Projects Well Integrity Engineer 253 - 576 -6153, Harm #6687 Ross Huebel, DS11 Pad Engineer, 907 - 564 -5779 office, 832 - 455 -0275 cell Neil Carry, STI Subject: 11 -27 Repair PC leak using Seal -Tite Est. Cost: $100,000 AFE: APBD11 WL27 IOR: 300 bopd Step Type Procedure 1 S Set circ sleeve in Sta #1. 2 F Circulate out the wellbore with KCL & displace sealant to leak site. 3 S Pull circ valve and DGLV #1 4 O/D Pump and activate sealant 5 D MIT -IA to 3000 psi 6 SP Pull TTP if repair is successful Objective: This program is to repair a production casing leak by circulating and squeezing a Seal- / Tite pill in the IA. A circulation valve will be used to circulate brine and sealant through the lowest mandrel. A MIT -IA will be performed to confirm operability of the well post repair. Well Stats: Well Status: SI and Not Operable for a PC leak Last well test: 4/26/11: 797 bopd, 590 bwpd, 30 mmscfd gas, 258 IOR Deviation: max 56° @ 7400' MD Min ID: 2.75" @ 11901' cement sheath Est BHP: 3264 psi @ 8800' TVD (2010 BHP map) SSSV: No Last H2S: 1/24/11: 20 ppm Well Events Summary: 11 -27 is a naturally flowing gas lifted producer last completed with 4.5" chrome tubing in 2005 RWO for TxIA communication. A TTP was set 05/01/11 and the well passed a MIT -T and failed a CMIT -TxIA with a LLR of 4.72 gpm at 3000 psi. A production casing leak was confirmed at 7829' with an LDL run 05/28/11. The well has no other known integrity issues. A PPPOT -T & PPPOT-IC both passed 7/21/11. Please call Ross Huebel (APE) at 564 -5779 or Neil Cary (Seal -Tite Engineer) at (985) 875 -1292 with any questions or concerns regarding this program. Cc: Well File AK, D &C Well Integrity Engineer • • Discussion: • Note: This is a retreatment of another job executed 1/15/12. That job failed to see any pressure increase indicating the sealant was trying to set. This job will have more of a density difference to help ensure the sealant pill stays in position as well as placing the pill higher in the annulus initially to make sure it is not accidentally placed below the leak site. • The IA was completed with 8.65 ppg inhibited seawater. The lower GLM #1 will be used to circulate and displace the tubing and IA. This will leave only 49' (2.6 bbls) of 8.65 completion fluid in the IA between the valve and the packer. This minimal volume should not negatively effect the Seal -Tite displacement. • The leak rate from pump records for the failed CMIT was approximately 4.7 gpm @ 3000 psi. Subsequently an LDL located the leak at 7829' MD. The leak rate during this sequence was —3.1 gpm @ 3000 psi. This fluid loss was over a significantly longer time interval is considered to be more reliable. Riq up notes and requirements: - Rig up hard line through a choke skid to pump down both the Tbg and IA taking returns down the 11 -36 flow -line or to a contingency tank. Make sure there is a sample port in the choke skid to confirm return densities. Make sure there is a strap sheet for the contingency tank. 11 -36 is a long term SI Not Operable for a SC leak, but the flowline is still in service (per DSO 08/06/11). - Have a mud scale available for density measurements.- - Include a tee before the choke skid to rig up the Seal -Tite tote as close to the wellhead as possible. (Note: There have been issues using the under balanced method to suck the sealant in though excessive hardline likely due to friction of the viscous pill. Try to have the tote rigged up as close to the wellhead as possible.) - If the underbalanced method is unsuccessful in sucking the sealant pill into the IA, an injection cylinder will be used in conjunction with a diaphragm , pump. Be sure that this equipment is available and operational on the slope before beginning this work. - The sealant is freezable fluid. The special projects trailer will be needed for maintaining temperature and mixing the sealant pills. - Heaters for the well house and projects trailer. - Air compressor for the pumps. - Bleed trailer. - It is essential that the job only be pumped when it is certain slickline will be available and the forecast indicates a weather window adequate to complete the work. The first time this job was executed the sealant sat for 5 days before a dummy could be set and the sealant activated. Volumes: Note — all volumes /depths below are corrected for RKB /BH elevation difference of 30'. As such all depths are denoted "MDBH" (Measured Depth to Bradenhead) Total IA volume - 9 5/8" x 4 to Production Packer @ 10914' MDBH = 575.2 bbls To leak © 7799' MDBH = 417.2 bbls To lowest gas lift mandrel @ 10701' MDBH = 571.9 bbls From leak to packer = 7799 - 10752' MDBH = 158.0 bbls Tubing 4 12.6 # /ft = .0152 bbl /ft x 10840' mdbh (to PXN plug) = 164.8 bbls Compression to Packer = 2 bbls / 1000 psi or 112' @ 3000 psi Compression above sealant = 1.46 bbls / 1000 psi or 82' @ 3000 psi • • Compression below sealant = .54 bbls /1000 psi or 30' @ 3000 psi Fluid requirements: - 800 bbls 9.8 ppg KCI with corrosion inhibitor - 10 bbls Diesel - 5 bbls 8.95 ppg KCI to be mixed and loaded in the Seal -Tite mixing tote (STI FIo- Seal product will be shipped and supplied by STI. Storage is in U -11). Final density of the sealant/KCI mix will be 9.4 ppg. - 301 bbls 9.2 ppg KCI with corrosion inhibitor - 150 bbls Diesel and /or methanol blend for freeze protect Procedure: Slickline: Change out GLVs 1. Hold PJSM. RU slickline. 2. Pull DGLVs from Sta# 1. Set circ valve in Sta #1. 3. Pump with triplex (or FB) to establish both TxIA and IAxT circulation. Fullbore and Projects: Circulate well out with brine and place Seal -Tite pill Note: Do not proceed until the weather forecast and slickline schedule look indicate that the Steps 4 -22 will be able to be done continuously. 4. Hold PJSM. RU FB pump to the choke skid. 5. Line up to pump down IA, taking returns up the tubing to nearby flowline of 11 -36. • Leave -200 psi of back pressure on the tubing during circulation to make sure the system remains liquid packed. 6. Circulate a total of 800 bbls of 9.8 ppg brine down the IA taking returns up the tubing. At 737 bbls (one round trip volume), the IA & Tbg should be fully • displaced. Take density measurements of the returns with a mud scale to assure clean, consistent 9.8 ppg returns for the rest of the circulation. Maintain maximum pump rate as per PE manual. 7. Line up to pump down the tubing taking returns up the IA. Displace 10 bbls of diesel into tubing. This will set up -100 psi pressure differential from IA to tubing to enable easy injection of the sealant pill. 8. Blend five bbls of Flo -Seal to 9.4 ppg. Hook up sealant tank discharge to the hard line tee from the IA casing valve. 9. Open valves to the sealtite tank and bleed up to 10 bbls of diesel from the tubing to allowing the under balance to pull the 5 bbls of Flo -Seal into IA. • Take returns to the contingency tank to verify the volume bled off the tubing. If more than 12 bbls are bled, the well should equalize in pressure and this method will not work without pumping more diesel down the tubing. • If this method is unsuccessful in placing the sealant into the IA, a contingency rig up should be available as noted in the rig up notes above. 10. Line up pump down the IA taking returns up the tubing. Displace Flo -Seal with 301 bbls of 9.2 ppg inhibited KCI followed by 105 bbls of diesel and /or McOH • • blend for freeze protect. Bring pump rate up slowly at -0.25 bpm until -6 bbls of inhibited brine have entered the annulus. Increase pump rates to 1 bpm for the rest of the displacement. This should place the bottom of the sealant pill approximately 135' above the leak point. Freeze Protect Tree with 1 -2 bbls of Diesel or McOH, which will move the bottom of sealant pill to 173' above the leak. 11. RDMO FB pump. Slickline: Change out GLVs and MIT -T 12. RU SL. 13. Pull circ valve from Sta #1 and install a DGLV. • NOTE: At this point the IA is underbalanced to the tubing by -500 psi. Ensure that no pressure is bled from tubing or annulus until the gas lift dummy is confirmed to be installed and holding. 14. MIT -T to 3000 psi to ensure dummy is holding. Leave 3000 psi on tubing and monitor during remainder of program. 15. RDMO SL & FB pump. Projects with DHD assist: Activate Seal -Tite pill 16. RU triplex and pump diesel down IA to pressure up to 2000 psi. 17. Continue pushing sealant down at 2000 psi. It should take at approximately 5 bbls displacement in addition to any liquid compression to displace the sealant pill to the leak. Plan to monitor pressures every 15 min and repressure every 30 min until the leak rate begins to decrease. Once there are indications that the sealant has reached the leak, bleed the IA back to 1000 psi. • Note keep close track of the volume pumped to assure you do not overshoot the sealant pill. 18. Shut down pump and allow a seal to be obtained at 1000 psi. Let the sealant cure for a minimum of four hours. 19. Increase IA pressure to 1500 psi. Allow to cure for two hours. 20. Increase IA pressure to 2000 psi. Allow to cure for two hours. 21. Increase IA pressure to 3000 psi. 22. Shut in the IA and allow the sealant to cure for 5 days. Monitor pressure daily and - bump back up if the pressure falls below 2000 psi. 23. After 5 day curing period, MITIA to 3000 psi. Bleed the IA to zero. Notify Well Integrity of test results and assure a safety note is recorded that the well has a sealant pill remaining in the IA. Slickline Pending: Pull TTP if the repair is successful 24. PJSM. RU SL. 25. Pull PXN TTP set @ 10870' MD on 5/1/11. • 26. Assure well has been reclassified as Operable and notify Operations that well may be put BOL. 27. RDMO SL. • • Rig Up Schematic ► Contingency P -Sub tank Choke skid Hard line to ... Swab 11 -36 flowline Wing (x) • LRS inlet 0 SSV Master . Inlet for —0 f STI tote IA CV BV Tee OA CV • • TREE= McEVOY WELLHEAD= MCEVOY i�' SAFETY NOTES: " " "4 -1/2" & 3 -1/2" CHROME LNR""" ACTUATOR = AXELSON 1 7 AWGRS REPORT ERY ABRASIVE - SEE 04109/05 KB. ELEV = 58' BF. ELEV = KOP= 1900' .\-, I 23' H7" X 4-1/2" X0, ID= 3.958" I Max Angle = 56 @ 7400' Datum MD= 12162' 11 I 2501 1-14 -1/2" HES X NIP, ID = 3.813" I Datum TVD = 8800' SS GAS LIFT MANDRELS 113 -3/8" CSG, 72 #, L -80, ID= 12.347" H 2555' 1 ' ' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3434 3242 46 MMG DOME RK 16 08/17/05 3 7070 5589 53 MMG DOME RK 16 08/17/05 2 9582 7097 50 MMG DMY RK 0 03/26/05 L C ? % Zal 1 10731 7855 47 MMG SO RK 22 08/17/05 `- ---- -I 10759' H4 -1/2" HES X NIP, ID = 3.813" I Minimum ID = 2.75" @ 11901' �� 10780' 4-1/2" x 5 -1/2" XO, ID= 3.958" 3 -1/2" LNR LANDING COLLAR (MILLED) 10782' 9 -5/8" x 5 -1/2" S -3 PKR, ID= 4.75" 10786' H5-1/2" X 4 -1/2" XO, D= 3,958" ' -'-- -1 10849' 4 -1/2" FMS X NIP, ID = 3.813" 1 14-1/2" PXN (5/01/11) H 10870' F - -11 10870' H4 -112" HES XN NIP, ID = 3.725" I I4 -1/2" TBG, 12.6 #, 13CR80, .0152 bpf, ID = 3.958" H 10891' 1. — I 10891' I— I4 -1/2" x 5 -1/2" XO, ID = 3.958" I I r I 10896' I — I TOP OF 5 -1/2" TBG STIR (3/26/05) 1 g 10902' J X 5 -1/2" UNIQUE OVERSHOT 1 g� 10944' H9-5/8" 9 -5/8" X 5 -1/2" BAKERS -3 PKR I 1 1 10978' H 5-1/2" FES X NIP, ID = 4.562" I 'TOP OF 5 -1/2" TBG H 11001' F--..4 -- �/) 10998' . 1 - 15 - 1/2" UNIQUE OVERSHOT I 5 -1/2" TBG, 174, L -80, .0232 bpf, ID = 4.892" H 11006' I 11015' I - I STINGER TIEBACK SLV 08/08/04 I 4 C. 11026' H9 -518" X 5 -1/2" BAKER SB -3 PKR 1 11034' HC -Z TIEBACK SLV, MILLED ID = 2.75" (04/14/05) ITOPOF 7" LNR H 11046' 1 5 -1/2" TBG -PC, 174, L -80, .0232 bpf, ID = 4,892" H 11048' I 11 048' H 5 -1/2" X 5" XO (BEHIND PIPE) li I 11060' H3 -1/2" OTISXNIP, D= 2.813" 02/23/04 I I 11094' H5" OTIS X NIP, ID= 4.312" (BEHIND PIPE) I 11114' H 5" BAKER SHEAROIJT SUB (BEHIND PIPE) I 15" TBG -PC, 15#, L -80, .0232 bpf, ID= 4.406" H 11115' 1 11115' 5" WLEG (BEHIND PIPE) 41' Fti 9 -5/8" CSG, 474, L -80, ID = 8.681" H 11368' ) I* I3 -1/2" LNR, 9.3 #, 13 -CR, .0087 bpf, ID = 2.992" I- ( 11935' `4' �'+ 11901' I SHEATH, MILLED ID = 2.75" (04/14/05) 1 ••■ 11 PERFORATION SUMMARY � ' y +, 1 11998' CTM HBTM OF CMT SHEATH (04/16/05) I REF LOG: BHCS ON 01/10/87 ANGLE AT TOP PERF: 46 @ 11985' Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn /Sqz DATE 2-1/2: 6 11985 - 11998 0 01/11/06 3 -3/8" 4 11998 - 12029 0 07/30/87 I 3 -3)8" 4 12048 - 12062 0 09/03/89 12065' CTMD H TOP OF SAND (08 /04105) 1 FBTD 12100' low ■ 1 7" LNR 294, L -80, .0371 bpf, ID = 6.184" H 12210' 4.01111* DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY (KNIT 07/31/87 ORIGINAL COM P L ET ION 01/16/06 RLM/PAG ADDPERFS WELL: 11 -27 06/23/98 RWO 05/21/11 WRR/ PJC SET PXN (05101/11) PERMIT No: '1861480 03/27/05 WJHITLH RWO AP1 No: 50- 029 - 21638 -00 05/03/05 WRR/PJC GLV C/0 (04/01/05) SEC28, T11N, R15E, 4134.88' FEL & 3838.25' FNL 08/04/05 JNA/PJC MILLED SAND 08/17/05 KSB/TLH GLV CIO BP Exploration (Alaska) • 0 " `� LC. C. 1 CT iii - ;LLi ~ x '14 a'• i ! it- . XIII- Hit:- CCL• TEMP -MILD '. r- I wyr�Y. +ilk•. Nohow hunt in, •. 2T - May 2011 '+• I I T ! Cvrnpary BP EXPLORATION (ALASKA), INC `f-... �y to i Wall 11 - 27 • q - + _ . = 3 ' y': Flo PRUDHOE BAY ~` —" �+ Cann NORTH SLOPE slate ALASKA 7100 *ti- ___ __ ....g 4 If: i L38,kUn - ..e•*' -a - w 'r 45I . 02 FEL 6 224.14• FEL ,-•. • 0. �• w - (k !:0 EG TV ItM CE t`-+= �`�'�"� - _ TT 1 :-` a y w'vr KB :8 FT ApOw Vlrrrk 0lLm CF a r. "i„ ;. V I b . /raan. 50.021654-00 Gt4Y5 _ - y r 77 w5 v3+0L.k+ t1,tU .. r 3 T 0 U t T ea'f r ■ wt. .tr., ,0 NAB 1„, n., ,,n„r,,,�„ Z7:6 1� FINAL PRINT Sin 11 I2312 • tl9lkM k+ ENfa• � - •� L -, -- .7001 Po Ev„NrWat WV Cr,lw ... 4'MWVKwra 1.17.1 r qn M•r0e1 bf F3n .. T. 3m I LY • R fie« • 1 1600 +1 • -., 14 00 ' mr a.. 4550' 4 $4,444. n.>sa - I: + . _..___. .. Ult. 2400 41 21 •. ,014 f _ I low .1112' 1y1 + +D15 11 • j y £ -�_ — 1.�r . i _ J t s .. L 1 - __ 7P( I C ■ - . - 1 _ +, 7900 _ L#* eon 4t11tr1 !•` ' .....-•-1 P.f i f ! r • - ' y 1 �_- r 1 - -_ I yy 6�y� i ' I - -7.J V 1 4 r I 1 Vic. ' , J 3 e . - .r' - - — I1 1 aicc tr « TREE' • MCEVOY • SAF OTES: ** *4 -1/2" & 3 -1/2" CHROME LNR*** , WELLHEAD = MCEVOY 1 4 )9 4-1/2" CHROME VERY ABRASIVE - SEE 04/09/05 - ACTUATOR = AXELSON AWGRS REPORT KB. ELEV = 58' BF. ELEV = KOP = 1900' I 23' Hr X 4-1/2" XO, ID = 3.958" Max Angle = 56 @ 7400' Datum MD = 12162' I 2501' 3 — I4 - 1/2" HES X NIP, ID = 3.813" I Datum TV D = 8800' SS GAS LIFT MANDRELS 1 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2555' ST I MD I TVD_DEV TYPE VLV LATCH PORT DATE 4 3434 3242 46 MMG DMY RK 0 08/17/05 MID 3 7070 5589 r 53 MMG DMY RK 0 08/17/05 1 9582 7097 r 50 MMG DMY RK 0 03/26/05 1 10731 7855_ 47 MMG DMY RK 0 _01/19/12 I 10759' — I4 -1/2" HES X NIP, ID = 3.813" I Minimum ID = 2.75" @ 11901' o r / 10780' — 14 -1/2" x 5 -1/2" XO, ID = 3.958" I 3 -1/2" LNR LANDING COLLAR (MILLED) ill 10782' — 19 -5/8" X 5 -1/2" S -3 PKR, ID= 4.75" I 10786' — I5 -1/2" X 4 -1/2" XO, ID = 3.958" I 10849' —14-1/2" HES X NIP, ID = 3.813" 3 10870' —14-1/2" HES XN NIP, ID = 3.725" I i4 -1/2" TBG, 12.6 #, 13CR80, .0152 bpf, ID = 3.958" 1-1 10891' I 1 ( 10896' —I TOP OF 5 -1/2" TBG STUB (3/26/05) I 10902' -19 -5/8" X 5 -1/2" UNIQUE OVERSHOT I k�, io .. 10944' —I9 -5/8" X 5 -1/2" BAKER S -3 PKR I 10978' —15-1/2" HES X NIP, ID = 4.562" I ITOP OF 5 -1/2" TBG I 11001' 10998' —15 -1/2" UNIQUE OVERSHOT I 1 5-1 /2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" I 11006' 11015' —I STINGER TIEBACK SLV 08/08/04 I • r4 11026' — I9 -5/8" X 5 -1/2" BAKER SB -3 PKR I ITOP OF 7" LNR I--{ 11046' • 11034' --I C-Z TIEBACK SLV, MILLED ID = 2.75" (04/14/05)1 1 5 -1/2" TBG -PC, 17 #, L -80, .0232 bpf, ID = 4.892" H 11048' I , I 11048' I- 15 -1/2" X 5" XO (BEHIND PIPE) I 11060' H 3 -1 /2" OTIS X NIP, ID = 2.813" 02/23/04 3 I 11094' H5" OTIS X NIP, ID = 4.312" (BEHIND PIPE) I 11114' 1-15" BAKER SHEAROUT SUB (BEHIND PIPE) I 15" TBG -PC, 15 #, L -80, .0232 bpf, ID = 4.406" 3-I 11115' I 11115' I-I5" WLEG (BEHIND PIPE) I w I►'�1 1 9-5/8" CSG, 47 #, L -80, ID = 8.681" H 11368' ��� �►��+ ICU 1 I V 11901' _I--I CMT SHEATH, MILLED ID= 2.75" (04/14/05) I I3 -1/2" LNR, 9.3 #, 13 -CR, .0087 bpf, ID = 2.992" 1—L 11935' 1 ,1 4 I 1.l ► 44 41 PERFORATION SUMMARY ' +v ,' 11998' CTM H BTM OF CMT SHEATH (04/16/05) 1 REF LOG: BHCS ON 01/10/87 ANGLE AT TOP PERF: 46° @ 11985' Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn /Sqz DATE 2 -1/2: 6 11985 - 11998 0 01/11/06 I 3 -3/8" 4 11998 - 12029 0 07/30/87 I 3 -3/8" 4 12048 - 12062 0 09/03/89 1 12065' CTMD 1--ITOPOF SAND (08 /04/05) I I PBTD I 12100' ,�.�. �. 1 7" LNR, 29 #, L - 80, .0371 bpf, ID = 6.184" I — I 12210' r�•A•. ;9 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/31/87 ORIGINAL COMPLETION 08/17/05 KSB/TLH GLV C/O WELL: 11 -27 06/23/98 RWO 01/16/06 RLM/PAG ADD PERFS PERMIT No: r 1861480 03/27/05 WJH/TLH RWO 11/08/11 RCT/ PJC GLV C/O (10/27/11) API No: 50- 029 - 21638 -00 04/14/05 BMcN/TLH MILL CMT & FCO 01/29/12 RCT/ PJC GLV C/O (01/19/12) SEC 28, T11 N, R15E, 4134.88' FEL & 3838.25' FNL 05/03/05 WRR/PJC GLV C/O (04/01/05) 08/04/05 JNA /PJC MILLED SAND BP Exploration (Alaska) STATE OF ALASKA ` ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other 0 Seal -Tite Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development (0 Exploratory ❑ . 186 -1480 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21638 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028322 PBU 11 -27 10. Field /Pool(s): R PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12210 feet Plugs (measured) None feet true vertical 8892.25 feet Junk (measured) None feet Effective Depth measured 12100 feet Packer (measured) 10782 10944 11026 feet true vertical 8814 feet (true vertical) 7890 8000 8057 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.5# H -40 31 - 111 31 - 111 1490 470 Surface 2525 13 -3/8" 72# L -80 30 - 2555 30 - 2555 5380 2670 Production 11340 9 -5/8" 47# L -80 28 - 11368 28 - 8298 6870 4760 Liner 27 3-1/2°9.3#I-80 11015 - 11042 8050 - 8068 10160 10530 Liner 901 3 -1/2" 9.2# 13Cr80 11034 - 11935 8063 - 8698 10160 10530 Liner 1164 7" 29# L -80 11046 - 12210 8071 - 8892 8160 7020 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ - - Tubing: (size, grade, measured and true vertical depth) 7" 26# L -80 22 - 28 22 - 28 {�y� 4 -1/2" 12.6# 13Cr80 28 - 10891 28 - 7964 S , \ v A , v R . FEB t 5-1/2" 17# L -80 10896 - 11048 7968 - 8072 5" 15# L -80 11048 - 11115 8072 - 8119 Packers and SSSV (type, measured and true vertical depth) 5 -1/2" Baker S -3 Packer 10782 7890 5 -1/2" Baker S -3 Pal 10944 8000 5 -1/2" BakerSB -3 Packer RECEIVE EF 8057 12. Stimulation or cement squeeze summary: I V Intervals treated (measured): ° FEB 201 Treatment descriptions including volumes used and final pressure: i Ahs . ^ ": .'7,7s _ Cons, Commission 13. Representative Daily.Average Product'. • e • : - — - .- Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 828 38,007 666 835 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development el i Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil r 61 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -254 Contact Nita Summerhays Printed Name Nita Summerha s Title Data Manager Si - -% // /1! ", -...- _` Phone 564 -4035 Date 2/7/2012 orm I =, 1 ' y y ''' /D 0 9 201 j 9,12_ (9 6Y u.mi •ngina •ny 11 -27 186 -148 PERF ATTACHMENT Date Perf Operation Code Meas Depth h To Meas Depth Base Tvd Depth Top Tvd De Sw Name Operation p p p p p p Depth Base p 11 -27 7/30/87 PER 11,998. 12,029. 8,742.01 8,763.68 11 -27 9/3/89 APF 12,048. 12,062. 8,777.02 8,786.86 11 -27 5/7/01 FIL 12,002. 12,062. 8,744.8 8,786.86 11 -27 6/1/02 SPS 11,624. 11,854. 8,480.18 8,641.39 11 -27 6/13/02 SPR 11,648. 12,100. 8,497.11 8,813.67 11 -27 12/24/02 BPS 12,058. 12,062. 8,784.05 8,786.86 11 -27 6/9/03 FIL 12,015. 12,100. 8,753.88 8,813.67 11 -27 6/18/03 SPS 11,878. 11,888. 8,658.16 8,665.14 11 -27 12/24/03 SPR 11,878. 12,065. 8,658.16 8,788.97 11 -27 2/23/04 MIS 11,901. 11,998. 8,674.23 8,742.01 11 -27 3/27/05 BPP 12,058. 12,062. 8,784.05 8,786.86 11 -27 1/11/06 APF 11,984. 11,997. 8,732.23 8,741.31 11 -27 5/1/11 BPS 10,870. 12,065. 7,949.85 8,788.97 11 -27 10/27/11 BPP 10,870. 12,065. 7,949.85 8,788.97 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 11 -27 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 1/7/2012T/I/O =SSV /650/20. Temp =SI. T & IA FLs (Pre sealtite). AL disconnected. 'Integral installed on IA. IA FL @ surface. Unable to get SSV open. SV, WV, SSV =C. MV =O. IA, OA =OTG. NOVP. 15:45 1/15/2012:T/I/0 560/620/60 Temp= SI Circ Well for Seal -Tite Treatment (Repair PC Leak) Pump down IA with 11 bbls 60/40 meth /water followed by 789 bbls 85 *G 9.8PPG brine taking returns up Tbg through hardline jumper to Flowline well #36. FP IA with 2 bbls 60/40, Tbg with 20 bbls diesel. SD and wait for Seal -Tite to be blended. Seat-Tite rigged up tote to IA and bled off TP. All Seal -Tite mixtured sucked into IA. After Seal -Tite, pumped 322 bbls 9.4 brine, 1 bbls 60/40 and 88 bbls diesel (411 bbls total) down IA taking returns up the Tbg and into Flowline of well #36 to spot Seal -Tite 25' above PC leak. Freeze protect Tbg with 5 bbls 60/40. Freeze protect flowline of well #36 with 15 bbls 60/40, pressure up Flowline to 1500 psi. FWHP 1300/1050/0. SV, WV, SSV = closed. MV =open. IA and OA open to gauges. All hardline valves closed. Well 36 WV, SV, SSV = closed. 1 /18/2012': * *"WELL S/I ON ARRIVAL * ** (Gel treatment) RIG UP SWCP 4516 TO CHANGE OUT CIRC VLV TO DGLV IN ST #1 (10,731' MD). ** *JOB IN PROGRESS, CONTINUED ON 1/19/12 WSR * ** 1/19/2012 ***CONTINUED FROM 1/18/12 WSR ** *(Gel treatment) :SET 4 -1/2" WHIDDON CATCHER SUB @ 10,870' MD. PULLED RKP -CIRC VLV FROM ST #1 & SET RK -DGLV AT ST #1 10.724' SLM / 10,731' MD. PULLED EMPTY 4 -1/2" WHIDDON C -SUB FROM 10,870' MD. PERFORMED SUCCESSFUL MIT -T TO 3000 PSI. ** *WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS * ** 1 1/20/2012,T/I/0= 2900/155/20 Assist with Sealtite job (Gel Treatment) Rigged up to IA ; pumping diesel. Pressure up to 2000 psi, allowing pressure to bleed off to 1500 psi twice. Repeated process pressuring up to 2k, bleeding off thru PC leak to Ot( ry, 1000 psi numerous times per procedure in a attempt to seal PC leak. Sealtite should have reached PC leak @ 7829' and at -7 bbl's diesel pumped, SAW NO 'INDICATION OF LEAK TRYING TO SEAL OFF. Pumped a total of 22.8 bbls 'diesel. TP and IAP left on well per procedure. (See log for details) FWHP= 3020 /1120 /60 * * *WV,SV,SSV= Closed MV =Open CV's= OTG * ** FLUIDS PUMPED BBLS 31 60/40 METH 789 9.8 BRINE 322 9.4 BRINE 141 DIESEL 5 9.2 NACL 1288 TOTAL GALS 34 FLO- SEAL -2 34 TOTAL TREE= McEVOY SAFETY NOTES: * * *4 -1/2" & 3 -1/2" CHROME LNR* ** WELLHEAD = MCEVOY 1 1 _2 7 AWGRS H REOM E VERY ABRASIVE - SEE 04/09/05 ACTUATOR= AXELSON KB. ELEV = 58' BF. ELEV = KOP = 1900' 1 1 1 23' I � 7" X 4-1/2" X0, ID = 3.958" Max Angle = 56 @ 7400' Datum MD = 12162' I 2501' 1 HES X NIP, ID = 3.813" 1 Datum TVD = 8800' SS GAS LIFT MANDRELS 113 -3/8" CSG, 72 #, L -80, ID= 12.347" H 2555' , ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3434 3242 ' 46 MMG DMY RK 0 08/17/05 M 3 7070 5589 53 MMG DMY RK 0 08/17/05 2 9582 7097 MMG DMY RK 0 03/26/05 1 10731 7855 ' 47 MMG CIRC RK - 08/17/05 1 10759' — 14 - 1/2" HES X NIP, ID = 3.813" Minimum ID = 2.75" @ 11901' k / 10780' —14 -1/2" x 5 -1/2" X0, ID = 3.958" 1 3 -1/2" LNR LANDING COLLAR (MILLED) 10782' —19-5/8° x 5 -112" S -3 PKR, ID= 4.75° 10786' —15-1/2" X 4-1/2" XO, ID = 3.958" 10849' —14-1/2" HES X NIP, ID = 3.813" I 10870' —14-1/2" HES XN NIP, ID = 3.725" 4 -1/2" TBG, 12.6 #, 13CR80, .0152 bpf, ID = 3.958" H 10891' I 10891' - 14 - 1/2" x 5 -1/2" XO, ID = 3.958" 10896' -fTOP OF 5 -1/2" TBG STUB (3/26/05) 1 1090T H 9 -5/8" X 5-1/2" UNIQUE OVERSHOT 1 ■ 10944' - 19 - 5/8" X 5 -1/2" BAKER S -3 PKR 1 10978' H5-1/2" HES X NIP, ID = 4.562" 1 'TOP OF 5 -1/2" TBG 1 11001' I 10998' — 5 - 1/2" UNIQUE OVERSHOT I 1 5-1 /2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" H 11006' NI 11015' -J STINGER TIEBACK SLV 08/08/04 I ∎�� 11026' —19 -5/8" X 5 -1/2" BAKER SB -3 PKR 1 ■ 11034' H C-Z TIEBACK SLV, MILLED ID = 2.75" (04/14/05)1 'TOP OF7 " LNR H 11046' 0 1 5 -1/2" TBG -PC, 17 #, L -80, .0232 bpf, ID = 4.892" H 11048' 1 ■ I 11048' H5 -1/2" X 5" XO (BEHIND PIPE) I I 11060' 1 OTIS X NIP, ID = 2.813" 02/23/04 I I 1 11094' 1-15" OTIS X NIP, ID = 4.312" (BEHIND PIPE) I 11114' H5" BAKER SHEAROUT SUB (BEHIND PIPE) 1 5" TBG -PC, 15 #, L -80, .0232 bpf, ID = 4.406" I 11115' d 11115' — 15" WLEG (BEHIND PIPE) 1 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 11368' 1.0 .4r '+� +, � , 0, 11901' _J CMT SHEATH, MILLED ID = 2.75" (04/14/05) 1 I3 -1/2" LNR, 9.3 #, 13 - CR, .0087 bpf, ID = 2.992" H 11935' WIC 1,x PERFORATION SUMMARY .4.4.. . 4.6. 11998' CTM H BTM OF CMT SHEATH (04/16/05) 1 REF LOG: BHCS ON 01/10/87 ANGLE AT TOP PERF: 46° @ 11985' Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn /Sqz DATE 2-1/2: 6 11985 - 11998 0 01/11/06 3 -3/8" 4 11998 - 12029 0 07/30/87 I 3 -3/8" 4 12048 - 12062 0 09/03/89 1 12065' CTM D IH TOP OF SAND (08/04/05) 1 1 PBTD 1 12100' moo ■ 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" p , H 12210' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/31/87 ORIGINAL COMPLETION 08/17/05 KSB/TLH GLV C/O WELL: 11 -27 06/23/98 RWO 01/16/06 RLM/PAG ADD PERFS PERMIT No: 5861480 03/27/05 WJHITLH RWO 11/08/11 RCT/ PJC GLV C/O (10/27/11) API No: 50- 029 - 21638 -00 04/14/05 BMcN/TLH MILL CMT & FCO SEC 28, T11 N, R15E, 4134.88' FEL & 3838.25' FNL 05/03/05 WRR/PJC GLV C/O (04/01/05) 08/04/05 JNA /PJC MILLED SAND BP Exploration (Alaska) • WELL LO TRANSMITTAL II. PrtoAciivE DiAgNOSric SERVICES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection[Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Nita Summerhays LR2 - 1 900 Benson Blvd. Anchorage, AK 99508 A)'ED S ) and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 - J ` 7)/ 1 Leak Detection - WLD 27- May -11 11 -27 BL/ CD 50- 029 - 21638 -00 2) Signed : 7L-C Date.: 3 ( A4 t ( f � Print Name: l .° kip) PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -8952 E - MAIL : PDSANCHORAGE( MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distribution \TransmittalSheets\BP Transmit.docx • • C7i SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Ross Huebel Petroleum Engineer d j �, BP Exploration (Alaska), Inc. S6 "{ P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 11 -27 Sundry Number: 311 -254 r Dear Mr. Huebel: � � . 9 2.011 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. Chair DATED this) 9 day of August, 2011. Encl. p r'I STATE OF ALASKA b It J�" ALASKA* AND GAS CONSERVATION COMMISSIO �I� ' 419-/.4 // APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate❑ Alter Casing ❑ Other:_SEAL TITE - 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development is _ Exploratory ❑ 186 -1480 - 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21638 -00 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: 11 -27 Spacing Exception Required? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field /Pool(s): ADLO - 028322 PRUDHOE BAY Field / PRUDHOE 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): 12210 8892.25 • 12100 8813.67 10870, 12065 NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H-40 31 111 31 111 1490 470 Surface 2525' 13 -3/8" 72# L -80 30 2555 30 2555 5380 2670 Intermediate 11340' 9 -5/8" 47# L -80 28 11368 28 11368 6870 4760 Production 27' 3 -1/2" 9.3# L -80 11015 11042 8050 8068 10160 10530 Liner 901' 3 -1/2" 9.2# 13CR80 11034 11935 8063 8698 10160 10530 Liner 1164' 7" 29# L -80 11046 12210 8071 8892 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 7" 26# L -80 22 28 - 4 -1/2" 12.6# 13Cr80 28 10891 - - 5 -1/2" 17# L -80 10896 11048 - - 5" 15# L -80 11048 11115 Packers and SSSV Tvoe: 5 -1/2" Baker S -3 Packer Packers and SSSV MD and TVD (ft): 10782 7890 5 -1/2" Baker S -3 Packer 10944 8000 5 -1/2" Baker SB -3 Packer 11026 8057 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 151 - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/29/2011 Oil 0 . Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ross Huebel Printed Name Ross Huebel Title PE Signature / Phone Date t- 564 -5779 8/11/2011 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ✓ 1 ` , r `,r r M. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ AUG 15 ZOii Other: Mika 01 & Gas C. 6�mn$$IOM Cm. Anttierege Subsequent Form Required: /d • yo y i � APPROVED BY �� � � Approved by: , COMMISSIONER THE COMMISSION Date: \ I 1 7 RAIN i d�l /t �' �� D vt .& uNiu1NAL ,,0r /rT�f Submit in Duplicate 11 -27 186 -148 . PERF ATTACHMENT Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 11 -27 7/30/87 PER 11,998. 12,029. 8,742.01 8,763.68 11 -27 9/3/89 APF 12,048. 12,062. 8,777.02 8,786.86 11 -27 5/7/01 FIL 12,002. 12,062. 8,744.8 8,786.86 11 -27 6/1/02 SPS 11,624. 11,854. 8,480.18 8,641.39 11 -27 6/13/02 SPR 11,648. 12,100. 8,497.11 8,813.67 11 -27 12/24/02 BPS 12,058. 12,062. 8,784.05 8,786.86 11 -27 6/9/03 FIL 12,015. 12,100. 8,753.88 8,813.67 11 -27 6/18/03 SPS 11,878. 11,888. 8,658.16 8,665.14 11 -27 12/24/03 SPR 11,878. 12,065. 8,658.16 8,788.97 11 -27 2/23/04 MIS 11,901. 11,998. 8,674.23 8,742.01 11 -27 3/27/05 BPP 12,058. 12,062. 8,784.05 8,786.86 11 -27 1/11/06 APF 11,984. 11,997. 8,732.23 8,741.31 • 11 -27 5/1/11 BPS 10,870. 12,065. 7,949.85 8,788.97 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • I op 0 Date: 07/06/11 To: Jerry Bixby /Rob Liddelow, AK, D &C Wireline Operations Team Lead Clark Olsen/Tyler Norene, AK, D &C Well Services Team Lead From: Tiffany Quy, Projects Well Integrity Engineer 253 - 576 -6153, Harm #6687 Ross Huebel, DS11 Pad Engineer, 907 - 564 -5779 office, 832 - 455 -0275 cell Neil Carry, STI Subject: 11 -27 Repair PC leak using Seal -Tite AFE: APBD11WL27 IOR: 300 bopd Step Type Procedure 1 S DGLV # 3 &4, set circ sleeve in Sta #1. 2 F Circulate out the wellbore with KCL & displace sealant to leak site. 3 S Pull circ valve and DGLV #1 4 O/D Pump and activate sealant 5 D MIT -IA to 3000 psi 6 SP Pull TTP if repair is successful Objective: This program is to repair a production casing leak by circulating and squeezing a Seal - Tite pill in the IA. A circulation valve will be used to circulate brine and sealant through the lowest mandrel. A MIT -IA will be performed to confirm operability of the well post repair. Well Stats: Well Status: SI and Not Operable for a PC leak Last well test: 4/26/11: 797 bopd, 590 bwpd, 30 mmscfd gas, 258 IOR Deviation: max 56° @ 7400' MD Min ID: 2.75" @ 11901' cement sheath Est BHP: 3264 psi @ 8800' TVD (2010 BHP map) SSSV: No Last H2S: 1/24/11: 20 ppm Well Events Summary: 11 -27 is a naturally flowing gas lifted producer last completed with 4.5" chrome tubing in 2005 RWO for TxIA communication. A TTP was set 05/01/11 and the well passed a MIT -T and failed a CMIT -TxIA with a LLR of 4.72 gpm at 3000 psi. A production casing leak was confirmed at 7829' with an LDL run 05/28/11. The well has no other known integrity issues. A PPPOT -T & PPPOT-IC both passed 7/21/11. Please call Ross Huebel (APE) at 564 -5779 or Neil Cary (Seal -Tite Engineer) at (985) 875 -1292 with any questions or concerns regarding this program. Cc: Well File • • AK, D &C Well Integrity Engineer Discussion: • The IA was completed with 8.65 ppg inhibited seawater. The lower GLM #1 will be used to circulate and displace the tubing and IA. This will leave only 49' (2.6 bbls) of 8.65 completion fluid in the IA between the valve and the packer. This minimal volume should not negatively effect the Seal -Tite displacement. • The leak rate from pump records for the failed CMIT was approximately 4.7 gpm @ 3000 psi. Subsequently an LDL located the leak at 7829' MD. The leak rate during this sequence was -3.1 gpm @ 3000 psi. This fluid loss was over a significantly longer time interval is considered to be more reliable. Rig up notes and requirements: - Rig up hard line through a choke skid to pump down both the Tbg and IA taking returns down the 11 -36 flow -line or to a contingency tank. Make sure there is a sample port in the choke skid to confirm return densities. Make sure there is a strap sheet for the contingency tank. 11 -36 is a long term SI Not Operable for a SC leak, but the flowline is still in service (per DSO 08/06/11). - Have a mud scale available for density measurements. - Include a tee before the choke skid to rig up the Seal -Tite tote as close to the wellhead as possible. (Note: There have been issues using the under balanced method to suck the sealant in though excessive hardline likely due to friction of the viscous pill. Try to have the tote rigged up as close to the wellhead as possible.) - If the underbalanced method is unsuccessful in sucking the sealant pill into the IA, an injection cylinder will be used in conjunction with a diaphragm pump. Be sure that this equipment is available and operational on the slope before beginning this work. - The sealant is freezable fluid. The special projects trailer will be needed for maintaining temperature and mixing the sealant pills. - Heaters for the well house and projects trailer. - Air compressor for the pumps. - Bleed trailer. Volumes: Note - all volumes /depths below are corrected for RKB /BH elevation difference of 30'. As such all depths are denoted "MDBH" (Measured Depth to Bradenhead) Total IA volume - 9 5/8" x 4 1 /2" to Production Packer © 10914' MDBH = 575.2 bbls To leak @ 7799' MDBH = 417.2 bbls To lowest gas lift mandrel @ 10701' MDBH = 571.9 bbls From leak to packer = 7799 - 10752' MDBH = 158.0 bbls Tubing 4 '/2" 12.6 # /ft = .0152 bbl /ft x 10840' mdbh (to PXN plug) = 164.8 bbls Compression to Packer = 2 bbls / 1000 psi or 112' @ 3000 psi Compression above sealant = 1.46 bbls / 1000 psi or 82' @ 3000 psi Compression below sealant = .54 bbls /1000 psi or 30' @ 3000 psi Fluid requirements: 800 bbls 9.8 lb /gal KCI 10 bbls Diesel 5 bbls Flo -Seal Sealant • 0 304 bbls 9.4 lb /gal KCI 150 bbls Diesel Procedure: Slickline: Change out GLVs 1. Hold PJSM. RU slickline. 2. Pull GLVs from Sta# 1, 3, & 4. Set DGLVs in Sta# 4 & 3. Set circ valve in Sta #1. ' 3. Pump with triplex (or FB) to establish both TxIA and IAxT circulation. Fullbore and Projects: Circulate well out with brine and place Seal -Tite pill 4. PJSM. RU FB pump to the choke skid. 5. Line up to pump down IA, taking returns up the tubing to nearby flowline of 11 -36. Leave -200 psi of back pressure on the tubing during circulation to make sure the - system remains liquid packed. 6. Circulate a total of 800 bbls of 9.8 ppg brine down the IA taking returns up the tubing. At 737 bbls (one round trip volume), the IA & Tbg should be fully displaced. Take density measurements of the returns with a mud scale to assure clean, consistent 9.8 ppg returns for the rest of the circulation. Maintain pump rate < 1 bpm to avoid flow cutting the bottom gas lift mandrel. 7. Line up to pump down the tubing taking returns up the IA. Displace 10 bbls of diesel into tubing. This will set up -100 psi pressure differential from IA to tubing to enable easy injection of the sealant pill. 8. Blend five bbls of Flo -Seal to 9.6 ppg. Hook up sealant tank discharge to the hard line tee from the IA casing valve. 9. Open valves to the sealtite tank and bleed up to 10 bbls of diesel from the tubing to allowing the under balance to pull the 5 bbls of Flo -Seal into IA. • Take returns to the contingency tank to verify the volume bled off the tubing. If more than 12 bbls are bled, the well should equalize in pressure and this method will not work without pumping more diesel down the tubing. • If this method is unsuccessful in placing the sealant into the IA, a contingency rig up should be available as noted in the rig up notes above. 10. Line up pump down the IA taking returns up the tubing. Displace Flo -Seal with 304 bbls of 9.4 ppg inhibited KCI followed by 107 bbls of diesel. Bring pump rate up slowly at -0.25 bpm until -6 bbls o in i • ite• brine have entered the annulus. Increase pump rates to 1 bpm for the rest of the displacement. This should place the bottom of the sealant pill approximately 25' above the leak point. 11. RDMO FB pump. Slickline: Change out GLVs and MIT -T 12. RU SL. 13. Pull circ valve from Sta #1 and install a DGLV. • • • • NOTE: At this point the IA is underbalanced to the tubing by -500 psi. Ensure that no pressure is bled from tubing or annulus until the gas lift dummy is confirmed to be installed and holding. 14. MIT -T to 3000 psi to ensure dummy is holding. Leave 3000 psi on tubing and monitor during remainder of program. 15. RDMO SL & FB pump. Projects with DHD assist: Activate Seal -Tite pill 16. RU triplex and pump diesel down IA to pressure up to 2000 psi. 17. Continue pushing sealant down at 2000 psi. It should take at least 1.3 bbls displacement in addition to any liquid compression to displace the sealant pill to ✓ the leak. Plan to monitor pressures every 15 min and repressure every 30 min until the leak rate begins to decrease. Once there are indications that the sealant has reached the leak, bleed the IA back to 1000 psi. • Note keep close track of the volume pumped to assure you do not overshoot the sealant pill. 18. Shut down pump and allow a seal to be obtained at 1000 psi. Let the sealant cure for a minimum of four hours. 19. Increase IA pressure to 1500 psi. Allow to cure for two hours. 20. Increase IA pressure to 2000 psi. Allow to cure for two hours. 21. Increase IA pressure to 3000 psi. 22. Shut in the IA and allow the sealant to cure for 5 days. Monitor pressure daily and bump back up if the pressure falls below 2000 psi. 23. After 5 day curing period, MITIA to 3000 psi. Bleed the IA to zero. Notify Well ✓ Integrity of test results and assure a safety note is recorded that the well has a sealant pill remaining in the IA. Slickline Pending: Pull TTP if the repair is successful 24. PJSM. RU SL. 25. Pull PXN TTP set @ 10870' MD on 5/1/11. 26. Assure well has been reclassified as Operable and notify Operations that well may be put BOL. 27. RDMO SL. • • Riq Up Schematic ► Contingency P -Sub tank Choke skid Hard line to .:. Swab 11 -36 flowline Wing ��� ► LRS inlet M SSV Master .:. Inlet for STI tote IA CV BV Tee OA CV .„ . • • TREE = McEVOY WELLHEAD = MCEVOY / / 1 '� SAFETY NOTES: ***4 -1/2" & 3 -1/2" CHROME LNR "* ACTUATOR = ' AXELSON 1 J 1 -2 7 A� RAM E �' ABRASIVE - SEE 04/09/05 . E KBLEV 5 $ ■ it ■ ■■ BF. 'ELEV = KOP= 1900' 23' H7" X 4 -1/2" XO, ID= 3.958" Msx Angle = 56'6 7400' Datum MD= „ ' ' 12162' I 2501' H4 -1/2" HES X NIP, ID = 3.813" I Datum ND = 8800' SS GAS LIFT MANDRELS 113 -3/8" CSG, 72 #, L -80, 0= 12.347" I—) 2555' I--41 ' ST1 MD ND 1 DEV 1TYPE VLV I LATCH) PORT DATE 4 3434 3242 46 MMG DOME RK 16 08/17/05 PC.. -'Z 3 7070 5589 53 MMG DOME RK 16 08/17/05 ll 2 9582 7097 50 MMG DMY RK 0 03/26/05 liri 111 1 10731 7855 47 MMG SO RK 22 08/17/05 . I 10759' H4 -1/2" HES X NIP, ID = 3.813" I Minimum ID = 2.75" @ 11901' 10780' 4- 1/2 "x5- 1 /2 "XO, D= 3.958" 3 -1/2" LNR LANDING COLLAR (MILLED) 10782' 9- 5/8 "X5- 12 "S -3PKR, ID= 4.75" 10786' — 5 -1/2" X 4 -1/2" XO, D = 3.958" 10849' — 4 -1/2" HES — 7 NIP, ID = 3.813" I4 -1/2" PXN (5/01/11) I-I 10870' I i I I 10870' H4 -1/2" HES XN NIP, ID = 3.725" I I4 -1/2" TBG, 12.6 #, 13CR80, .0152 bpf, ID = 3.958" H 10891' I — 10891' 1H4 - 1/2" x 5 -1/2" XO, ID = 3.958" I 10896' TOP OF 5 -1/2" TBG STUB (3/26/05) I Z 10902' -- I9 -5 /8" X 5 -1/2" UNIQUE OVERSHOT I I . r i 0944' 19 -5/8" X 5 -1/2" BAKER S -3 PKR I I 10978' 5-1/2" I-ES X MP, ID = 4.562" I ITOPOF 5- 1/2 "TBG H 11001' 'I 10998' I�5 - 1/2" UNIOl1EOVERSHOT 1 5-1 /2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" H 11006' I✓ . 11015' H STINGER TIEBACK SLV 08/08/04 I M I OM 11026' H 9-5/8" X 5 -1/2" BAKER SB-3 PKR ITOPOF 7" LNR H 11046' 11034' ( Z TIEBACK SLV, MILLED ID = 2.75" (04/14/05) 5 -112" TBG PC, 17 #, L -80, .0232 bpf, D = 4.892" H 11048' 11.9 X 5" XO (BEHIND PIPE) I I 11060' H3- 1 /2 " OTIS X NIP, ID= 2.813" 02/23/04 I I 11094' I--I5" OTIS X NP, 0= 4.312" (BEHIND PIPE) I 11114' H5" BAKER SHEAROUT SUB (BEHIND PIPE) I 15" TBG -PC, 15 #, L -80, .0232 bpf, ID = 4.406" H 11115' I I 1 1115' H5" WLEG (BEHIND PIPE) I 41) Ili 19 -518" CSG, 47 #, L -80, ID = 8.681" H 11368' I • + 1• i 1 ► 1 I3 - 1/2" LNR, 9.3 #, 13 -CR, .0087 bpf, ID = 2.992" I- 11935' r ' ` � I ►+1, 11901' H CMT SHEATH, MILLED ID =2.75" (04/14/05) I • + ►1 PERFORATION SUMMARY 1 4 1 . . 1 . , 1 11998' CTM HBTM OF CMTSHEATH (04/16/05) I REF LOG: BHCS ON 01/10/87 ANGLE AT TOP PERF: 46 @ 11985' Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn /Sqz DATE 2 -1/2: 6 11985 - 11998 0 01/11/06 3 -3/8" 4 11998 - 12029 0 07/30/87 I 3 -3/8" 4 12048 - 12062 0 09/03/89 1 12065' CTMD H TOP OF SAND (08 /04/05) I FBTD 12100' ;1.1.1.1— M 1 7" LNR 29#, L -80, .0371 bpf, ID = 6.184" H 12210' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/31/87 ORIGINAL COMPLETION 01/16/06 RLMIPAG ADD PERFS WELL: 11 -27 06/23/98 RWO 05/21/11 WRR/ PJC SET PXN (05/01/11) PERMIT No: '1861480 03/27/05 WJH/TLH RWO API No: 50 -029- 21638 -00 05/03/05 WRR/PJC GLV 00 (04/01/05) SEC 28, T11 N, R15E, 4134.88' FEL & 3838.25' FM. 08/04/05 JNA /PJC MILLED SAND 08/17/05 KSB/TLH GLV 00 BP Exploration (Alaska) 0 i - wrg LEAK DETECTION - WLU . 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Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 21, 2010 JA h 4 dim t Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ,,AN1 3 1 333 West 7 Avenue Anchorage, Alaska 99501 fu r -• CA 2 G ins C , sion Subject: Corrosion Inhibitor Treatments of GPB DS 11 Dear Mr. Maunder, 11 ' c Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 11 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -11 Date: 12/21/10 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement _ pumped cement date inhibitor sealant date ft bbls ft na gal 11 -01A 1921120 50029206440100 NA Sealed NA NA 6/25/2010 11 -02 1811280 50029206490000 NA Sealed NA NA 6/25/2010 11 -03A 1911520 50029206660100 NA Sealed NA NA 6/25/2010 11 -04A 1940230 50029204800100 NA Sealed NA NA 6/25/2010 11 -05A 1961570 50029206700100_ NA Sealed NA NA 6/25/2010 11 -06A 2042250 50029206740100 NA Sealed NA NA 6/25/2010 11 -07 1811770 50029206877000 NA Sealed NA NA 6/25/2010 11-08 1842290 50029212450000 NA Sealed NA NA 6/27/2010 11 -09A 1961280 50029214020100 NA 25 NA 42.50 6/29/2010 11 -10 1851590 50029213940000_ NA 5 NA 28.90 6/30/2010 11 -11 1851410 50029213820000 NA Sealed NA NA 6/27/2010 11 -12 1841950 50029212120000 NA Sealed NA NA 9/12/2010 11 -13A 1921 50029212290100 NA Sealed NA NA 9/12/2010 11 -16 1860780 50029215817000 NA Sealed NA NA 6/27/2010 11 -17A 2020320 50029215980100 NA _ Sealed NA NA 6/27/2010 11 -18 1861120 50029216070000 NA Sealed NA NA 6/27/2010 11 -22A 1950870 50029220356000 NA 1 NA 9.35 7/1/2010 11 -23A 1940810 50029216100100 NA Sealed NA NA 7/1/2010 11 -24A 1932040 50029216230100 NA Sealed NA NA 6/26/2010 11 -25A 1990820 50029204880200 NA Sealed NA NA 6/26/2010 11 -26 1861340 50029216280000 NA 1.9 NA 5.10 6/28/2010 11 -27 1861480 50029216380000 NA 3.5 NA 11.90 6/28/2010 11 -28A 2000950 50029219580100 NA Sealed NA NA 6/28/2010 11 -29 1940250 50029224660000 NA 0.2 NA 1.70 6/28/2010 11 -31A 1961830 50029225090100 NA 1.4 NA 6.80 6/28/2010 11 -32 1941310 50029225120000 NA 6.7 NA 59.50 6/30/2010 11 -33 1940900 50029224900000 NA 0.5 NA 2.55 6/30/2010 11 -34 1941380 50029225160000 NA 0.5 NA 3.40 11/27/2009 11 -35 1940650 50029224760000 _ NA 0.6 NA 5.10 6/30/2010 11 -37 1961740 50029227160000 NA 4 NA 42.50 7/1/2010 11 -38A 1982160 50029227230100 NA 2.1 NA 22.10 6/28/2010 SCblllfihBl'~P ~ska Data & Consulting Services >_5 Gambell Street, Suite 400 chorage,AK 99503-2838 7N: Beth Well Job # NO. 5385 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD 02-31A 17-09 12-30 17-09 B14B-00087 B3S0-00042 69RH-00003 AWJB-00047 SCMT - ~ -- TBG. CUT/FLOW DETECTION _ LDL MEM LDL 12/24/09 01/05/10 12/26/09 1 1 1 1 1 1 13-27A BALL-00009 USIT 01/03/10 1 1 JX-02A AWJW0065 MEM LDL 12/31/09 1 1 MPJ-19A L-103 W-217 AP3Q-00075 BALL-00010 AYKP-00056 - USIT _ RST/WFL - C CH EDIT PDC 12/29/09 12!29/09 01/06/10 1 1 1 1 1 1 12-05AL1 B2NJ-00025 USIT _ MCNL 11/27/09 1 V-224 D-14A 11-27 3-27/M-33 AYKP-00059 AWJI-00060 AP3Q-00068 88K5-00012 CH EDIT PDC USIT ... MCNL - C RST 'fS - ~ RST 09/29/09 12/14/09 11/15/09 11/06/09 11/18/09 1 1 1 1 1 1 1 1 1 ASE ACKNOWLEDGE REC EIPT BY SIGNIN G elun rtt=-n ipnuNr_ nruc rnov ewru T.,. :xploration (Alaska) Inc. ~technicai Data Center LR2-1 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~~' ~E~ ~ ~~~~ .--, ~~ U Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well F-48 G-19A NGI-13 MPE-30A F·11 B W-12A 11-27 02-22A 01-16 01-14 L5-05 D-21 14-15 D-18A 14-05A 1-23/0-15 S-03 1-09A1L-21 P2-19A OWDW-NW K-01 11-32 3-25B/L-27 Job# 11846815 11890315 11890313 11855817 11649954 11418301 11637127 11216214 11630486 11801086 11767129 11626119 11221550 11695074 11813055 11846802 11223120 11849930 11649963 11211370 11695073 11630498 11630490 5GANNED OCT :3 1 Z007 Lo!! Description USIT IV} 1- Oí ilL> USIT /9'1- to' 1 USIT I )""T.t'. t -=t-'.... -rA 1 USIT .;)0 I - 0 ( MCNL :Jcf-I-¡t '-1-# I;"),:) ""_"J MCNL J'ì"if-/7f~ "¡~Ç7'--1 RST j"Í({¡, -147í 11: 1";-5"~(.." MCNL :IN.... - ,... ~ö, "1t J ",.~ .r + RST 1~'7r-QD'ir ""t5S-j.-:8" RST ¡I"J-'-¡" _ {')"¡? ~ I K-~ of...., MCNL ¡-X- ~ j'L..c;. * , ,oç;ö 0 RST ¡ e;r;J - ():').;::) .. I ~x i RST 11r J - ó"ðLI ~ I ':'>.'> "X ~ I RST 0ó/- JÖ6 ~ 1":'\:"\ 75 RST ¡-Do¡::1 -(10 I .. 1~1f v, RST Ù"':"t.f'_ Lq'-li-I::J~ 11: 1<~155 RST I ~ 1 - /4,') 1!t t ';'Ç"'~(..( RST IO¡ '=} - (),9 q 11: I ~S- -+ ~ MCNL ~1()+- ()jd · 15'5?d RST l J,." -" '"\/1_ $i. /5,")'9-1 RST 1~3 - I;:) 1 'J>' /00% RST D¡Lf- /31 *"IJS~CJ RST .Qt"lQ ",:::¡ I ..., ~<"7 _ <;t' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Date Delivered: Date 10/12/07 09/30/07 09/30/07 10/01/07 03/22/07 09/10/06 06/05/07 10/02/06 06/28/07 07/07/07 06/17/07 09/12/07 03/07/06 08/28/07 06/11/07 08/11/07 06/13/06 08/04/07 04/22/07 02/28/06 08/27/07 09/03/07 07/26/07 ,,·.c"·' NO. 4459 Company: State of Alaska Alaska Oil & Gas Cons Gomm Attn: Christine Mahnkeln 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Endicott, Aurora, Milne Pt.,LisburnE BL CD Color 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ~;~:m::K ""~"iL Received by: C1 "" 1 0/23/07 . . 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: _ STATE OF ALASKA _ ALA" OIL AND GAS CONSERVATION COMrvW>ION REPORT OF SUNDRY WELL OPERATIONS o o o RECEIVED FEe 2 1 2006 P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development R1 Stratigraphic 0 Stimulate 0 e OS. WaiverD Time Extension DAnchorage Re-enter Suspended Well 0 5. Permit to Drill Number: 186-1480 o 6. API Number: 50-029-21638-00-00 9. Well Name and Number: 3. Address: Exploratory Service 58 KB 11-27 ADL-028322 11. Present Well Condition Summary: 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool 8. Property Designation: Total Depth measured 12210 true vertical 8892.25 feet feet Plugs (measured) Junk (measured) None None Effective Depth measured 12065 true vertical 8788.97 feet feet r Casing Conductor Surface Production Liner Length 80 2525 11340 27 Size 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 3-1/2" 9.3# L-80 MD 31 - 111 30 - 2555 28 - 11368 11015 - 11042 TVD 31 - 111 30 - 2555 28 - 8298.32 8049.54 - 8068.30 Burst 1490 5380 6870 10160 Collapse 470 2670 4760 10530 Liner 901 3-1/2" 9.2# 13Cr80 11034 - 11935 8062.74 - 8698 10160 10530 Liner 1164 7" 29# L-80 11046 - 12210 8071.09 - 8892.25 8160 7020 Perforation depth: Measured depth: 11985 - 11998 11998 - 12029 12048 - 12062 True Vertical depth: 8732.93 - 8742.01 8742.01 - 8763.68 8777.02 - 8786.86 Tubing: (size, grade, and measured depth) 7" 26# L-80 22 - 28 4-1/2" 12.6# 13Cr80 28 - 10891 5-1/2" 17# L-80 10896 -11048 5"15# L-80 11048 - 11115 Packers and SSSV (type and measured depth) 5-1/2" Baker S-3 Packer 10782 5-1/2" Baker S-3 Packer 10944 5-1/2" Baker SB-3 Packer 11026 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft FEB 2 2 lO06 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 306 4260 2043 213 Subsequent to operation: 278 3691 2179 212 14. Attachments: 15. Well Class after Droposed work: Copies of Logs and Surveys Run Exploratory Development M Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil M Gas 0 WAG GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal Printed Name Sharmaine Vestal / Title Data Mgmt Engr . ,~...1 Signatu~5~1..~ '. ~' Phone 564-4424 Date 2/16/2006 . . Form 10-404 Revised 04/2004 ORIGINAL Submit Onglnal Only .. e e 11-27 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 1/3/2006 ***WELL FLOWING ON ARRIVAL*** (ADPERF) RAN 2.25" BAILER, RECOVERED FRAC & FORMATION SANDS @ 11,966' SLM. TROUBLE SPOTS @ 10,867' & 10,979' SLM. *** JOB CONT ON 1-04-06*** 1/4/2006 *** JOB CONT FROM 1-03-06*** (ADPERF) LOCATED X-NIPPLE @ 11,024' SLM=36' CORR. TAG @ 11,966' SLM, 12,002' MD. NEEDED 11,998' MD. ***WELL POP*** 1/11/2006 WELL FLOWING ON ARRIVAL. CALLED DSO FOR PERMISSION TO SHUT IN. *** NO THREE WAY VALVE ON SSV *** TAGGED TD AT 11998 FT PERFORATE 13' FROM 11984.2' - 11997.2' CCL TO TOP SHOT = 10.2' CCL STOP DEPTH = 11974' API DATA: PEN = 25.2" EH = 0.32" EXPL. LOAD = 10.5 GM FLUIDS PUMPED BBLS 1 I Diesel TOTAL 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS D D D 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 58 KB 8. Property Designation: ADL-028322 11. Present Well Condition Summary: Total Depth measured 12210 true vertical 8892.25 Effective Depth measured 12065 true vertical 8788.97 Casing Conductor Liner Surface Length 80 901 2525 Size 20" 91.5# H-40 3-1/2" 9.2# 13Cr80 13-3/8" 72# L-80 Perforation depth: Measured depth: 11998 - 12029 True Vertical depth: 8742.01 - 8763.68 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 11998' - 12062' Treatment descriptions including volumes used and final pressure: see attached fluid summary; TIO 246/1000/150 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 276 284 x SfP 1 ~~~ 20 Of)' Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development [l;?]i Stratigraphic Stimulate 0 f,~J~~r ß~D" Waiver D Time ExtensiõM:3' Re-enter Suspended Wél'I:'[j':I)r::J; '": 5. Permit to Drill Number: Exploratory Service 186-1480 6. API Number: 50-029-21638-00-00 9. Well Name and Number: 11-27 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool feet feet Plugs (measured) Junk (measured) None None feet feet MD 31 - 111 11034 - 11935 30 - 2555 TVD 31 - 111 8062.74 - 8698 30 - 2555 Burst 1490 10160 Collapse 470 10530 12048 - 12062 8777.02 - 8786.86 :','-' ¡("" ,d\ (¡\. ï ~ ~ iC trj 11...... E p ;)~fnö'ïlð'\1t¡,,;;.f.\...; ,J ,] ~~; 0 2005 4-1/2" 12.6# 7" 26# 13Cr80 L-80 28 - 10891 22 - 28 5-1/2" Baker S-3 Packer 5-1/2" Baker S-3 Packer 5-1/2" Baker SB-3 Packer 10782 10944 11 026 RBDMS 8FL SEP 1 6 2005 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 3712 1577 180 3~8 1~9 1~ Tubing pressure 246 246 15. Well Class after Droposed work: Exploratoryr Development R 16. Well Status after proposed work: Oil R" Gasr WAG r Service r GINJ r WDSPL r WINJI 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr Signatu~"'j; <.. Form 10-404 Revised 04/2004 2Ld ORIGINAL Phone 564-4424 Date 9/13/2005 Submit Original Only ""' 11-27 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 8/4/2005 CTU #4, 1.75" Coil, Acid Wash. MU 2.5 JSN with BKR indexing tool for rotation with 1 deg bent sub. RIH down to PBTD at 12065' ctmd. With well flowing, pumped Diesel/Xylene and 12 HCI DAD acid from 11997 to 12065'. Jetted across obstruction at 11986' ctmd with last 10 bbls of acid in attempt to clear obstruction. RIH back down to PBTD clean rat hole then POOH. On way out, RBIH to ascertain whether obstruction was still present; set down at same spot, 11986. Obstruction ist present.. ASRC to proceed with flowback after unit is off location. *** Job Complete *** FLUIDS PUMPED BBLS 68 1 % KCL 24 80/20 diesel/xylene 49 90:10 DAD acid (120/0 KCL) 141 TOTAL , STATE OF ALASKA '\ ALASKJ.. )IL AND GAS CONSERVATION CGI1,.MISSION REPORT OF SUNDRY WELL OPERATIONS RI=~EIVED APR 2 2 DMher o Waiver 0 Time Extension o Re-ErI'Ws9j~~e§~~pns. Commission 5. per~l'Fo B~ffA!lumber: 186-148 6. API Number: 50-029-21638-00-00 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 028322 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Tieback Liner Length 110' 2525' 11342' Perforation Depth MD (ft): Perforation Depth TVD (ft): IBI Repair Well 0 Plug Perforations o Pull Tubing 0 Perforate New Pool o Operation Shutdown 0 Perforate 58' 12210 8892 12006 8748 1164' 920 o Stimulate 4. Current Well Class: IBI Development 0 Exploratory o Stratigraphic 0 Service 99519-6612 9. Well Name and Number: PBU 11-27 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool feet feet Plugs (measured) 12006 feet Junk (measured) None feet Size MD TVD Bu rst 20" 110' 110' 1490 13-3/8" 2555' 2518' 4930 9-5/8" 113681 8298' 6870 7" 11046' -12210' 8071' - 8892' 8160 3-1/2" 11015' - 11935' 8050' - 8698' 10160 Collapse 470 2670 4760 7020 10530 11998' - 12062' 8742' - 8787' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 4-1/2",12.6# 13Cr80 10902' 5-1/2",17# x 5",15# L-80 108961 - 11006 9-5/8" x 5-1/2" Baker ISB-3' pkr; 9-5/8" x 5-1/2" Baker 'S-31 11026' & 10944' & pkr; 9-5/8" x 4-1/2" Baker IS-3' pkr; 4-1/2" 'X' Nipple 10782'; 2501' Treatment description including volumes used and final pressure: ~r'A',' I.\.bNE~) l~ pn 9, ~5 2005 ~...~~ ~'~I .~,,~ ~..\~ 8'1\ (.....J Go. 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl CasinQ Pressure Tubinq Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run IBI Daily Report of Well Operations IBI Well Schematic Diagram 15. Well Class after proposed work: o Exploratory IBI Development 0 Service 16. Well Status after proposed work: IBI Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Paul Bartel, 564-5402 N/A Printed Name Terrie Hubble s¡gnature-iill!li.o. ~ Form 10-404 Revised 04/2004 Title Technical Assistant Phone Date ~/?-J, los Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only 564-4628 RB 0'Y\5 tf/~ ) ) Well: Field: API: Permit: 11-27 Rig Workover Prudhoe Bay Unit 50-029-21638-00-00 186-148 Accept: Spud: Release: Rig: 03/20/05 N/A 03/27/05 Doyon #14 PRE-RIG WORK 02115/05 DRIFTED WI 4.5" CENT & S. BAILER TO 10,960' SLM. S. BAILER EMPTY. 02/26/05 PERFORMED STRING SHOT (10903' - 10917'). TBG PUNCH (10818' - 10819'). CHEM CUT TBG AT 10911' (CENTER OF FIRST FULL JOINT ABOVE PKR). JOB COMPLETE. RECEIVED APR 2 2 Z005 Alaska Oii & Gas Cons. Commission Anchorage ') ) . .. .... . . . . . . . .. . . L~P7X~LÖ~ATI?~ ,RECErVED QPérati~!\~Surn'l'ar~¡ReÞ~'fJR2 2'2005 .......¡ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-27 11-27 REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Alaska Oil & Gas Cons. Commission Anl!h ß-pud Date: 12/27/1986 Start: 3/19/2005' ora~nd: 3/27/2005 Rig Release: 3/27/2005 Rig Number: Date 'Ftont- 'To Hoürs Task Code' NPT Phasé " '[)escri þti;Q n ()fQp~rat¡ohs 3/19/2005 09:00 - 15:00 6.00 MOB P PRE Raise/Secure Cellar Doors. Move Rig off PM1-05, position in pad to remove BOPE and to Lower and tie-down Derrick for Rig move. Clean area around Tree and Pad. When the Rig was backed off the well, liquid was seen on top of the Herculite 5' from the wellhead on the Off-Driller side. SRT was notified; then the area was cleaned. About a gallon of slushy material was collected. None leaked through to the pad. SRT Spill Tech said that this was NOT a Recordable Event. 15:00 - 16:00 1.00 MOB P PRE Lower Derrick and chain down for Travel to DS 11. 16:00 - 19:00 3.00 MOB P PRE Install Booster Wheels. Wait on security. 19:00 - 00:00 5.00 MOB P PRE Move rig from P105 to DS11. 3/20/2005 00:00 - 04:30 4.50 MOB P PRE Move rig from P105 to DS11. 04:30 - 06:00 1.50 MOB P PRE PJSM. Remove booster wheels from sub. 06:00 - 18:00 12.00 MOB P PRE Raise Derrick, drive in Derrick Pins, string Bridle Lines, set up BOP Stack, install HCR Valves on BOP Stack. Lay-out Herculite. 18:00 - 21 :00 3.00 RIGU P DECOMP Accept rig at 1800 hours. Position slop tank to take returns from pit conveyor. Take on 120 deg F 8.5ppg sea water. R/U lines to manifold to displace diesel and kill well. Blow down lines to assure no plugs. 21 :00 - 22:00 1.00 KILL P DECOMP R/U lubricator, pull BPV. Well on vacuum, tubing and casing pressure = 0 psi. 22:00 - 22:30 0.50 KILL P DECOMP Held PJSM. Test surface lines to 3500 psi. Held Ok. 22:30 - 00:00 1.50 KILL P DECOMP Align valves, circulate long way at 3 BPM -initial pressure 150 psi, incrreased to 520 psi after 800 strokes, gradually increasing as diesel removed out of hole. 3/21 /2005 00:00 - 03:30 3.50 KILL P DECOMP Circulate out diesel, displace hole with 120 deg F 8.5 ppg at 3 bpm 580 psi, end 620 psi. Returns 8.2 (+/-) ppg diesel-seawater. Total volume pumped 854 bbl, 16 bbl remaining surface volume. No additional trucks availalbe. S/I pump and monitor well pressures; no flow, well dead. Loaded and Tallied DP in pipe shed. 03:30 - 04:00 0.50 WHSUB P DECOMP PJSM Bled down lines and tree. Close annulus valve. Install TWC valve per instructions of Cameron Wellhead technician. Tested same to 1000psi, held Ok. 04:00 - 05:00 1.00 WHSUB P DECOMP Bled control lines, had diesel flowback. Close in control lines, adaptor flange. Suspect diesel strung out in well. Ordered out DSM amd more 120 deg F 8.5ppg seawater to continue circlulating.. 05:00 - 08:30 3.50 WHSUB P DECOMP RU lubricator and pull TWC valve. Take on seawater. Circ out diesel @ 8 BPM, 55 Bbls. Realign valves and Rev Circ @ 7-8 BPM, 35 Bbls. 08:30 - 09:00 0.50 WHSUB P DECOMP Bleed down, monitor well. Dead. Install TWC. 09:00 - 12:00 3.00 WHSUB P DECOMP Test TWC to 1000 psi, good. Bleed down control lines, R/U to suck out stack. Bleed down Kill Line, N/D and remove Tree. 12:00 - 14:30 2.50 BOPSUP P DECOMP N/U BOPE and get ready to test per AOGCC and BP requirements. Chuck Scheve, AOGCC, waived AOGCC's presence. 14:30 - 20:30 6.00 BOPSUP P DECOMP Test BOPE per AOGCC and BP requirements, 250 psi low and 3,500 psi high. Witnessed by BP company representatives. 20:30 - 21 :00 0.50 BOPSUP P DECOMP Blow down lines and choke manifold. 21 :00 - 23:30 2.50 RIGU P DECOMP Held PJSM. Slip & cut 486' drill line. 23:30 - 00:00 0.50 RIGU P DECOMP R/U lubricator and lines. Pull TWC valve. Printed: 3/28/2005 8:04:34 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . ....... .~~EXPLORATION.. . RIECEIVED Pagë20f5 . ...... ()peré1ti()n~SLÎmrnary·R~p(:)rt ·APR22. ·..2005 Alaska Oil & Gas Cons. Commission Ars~.Øate: 12/27/1986 Start: 3/19/2005 End: 3/27/2005 Rig Release: 3/27/2005 Rig Number: 11-27 11-27 REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Pe$cripfiÖr1· of Operations· 3/22/2005 Date . From - To Hours Task COde 00:00 - 00:30 00:30 - 01 :00 01 :00 - 02:00 02:00 - 03:00 03:00 - 07:00 07:00 - 12:00 12:00 - 12:30 12:30 - 17:30 17:30 - 18:00 18:00 - 20:00 20:00 - 20:30 20:30 - 21 :00 21 :00 - 23:00 3/23/2005 23:00 - 00:00 00:00 - 07:00 07:00 - 08:00 08:00 - 09:00 09:00 - 09:30 09:30 - 10:00 10:00 - 13:00 13:00 - 14:00 14:00 - 16:00 16:00 - 17:00 17:00 - 17:30 17:30 - 18:30 0.50 PULL P 0.50 RIGU P DECOMP Pull TWC. R/D lubricator and extension. DECOMP R/U equipment to pull completion. Spotted and chain down control line spooler M/U x-overs to drill pipe, RIH slowly, screwed into hanger. BOLD's in tubing spool. DECOMP Pull up on tubing hanger slowly, 210K Ibs up, 11 Ok Ibs down. Pulled up, then set back down in tubing bowl, due to restriction. Had to remove rotary bushings and drip pan sleeve. Broke out one joint and pulled hanger through rotary. Reinstalled drip pan sleeve. DECOMP Disconnected SSSV control lines, B/O and UD tubing hanger. Inspected hanger, no visible damage or wear observed. DECOMP POOH and UD 5-1/2" 17# LTC tubing, spooled up control line. Numbering tubing joints laid down. B/O SSSV assy. Recovered 49 of 54 SS Bands used for banding the Control Lines to the Tubing string. R/D control line spooling equipment. DECOMP POOH and L/D 5-1/2" 17# LTC tubing. Numbering tubing joints laid down. DECOMP Serviced rig. DECOMP POOH & UD5-1/2" 17# LTC tubing jts. Recovered 257 jts plus cut jt, 5 GLM assemblies, one sssv assembly. Measured cut jt. 21.31',5-1/2" OD. Cut was clean. DECOMP R/D Floor equipment. DECOMP Set Test Plug. RILD's. Tested Lower Pipe Rams, 250 psi Low/ 3500 psi High. Held Ok. Witnessed by BP Company Representative B. Tate. Pulled Test Plug. DECOMP Set Wear Bushing, 9" ID. DECOMP R/U for M/U BHA#1. DECOMP M/U Dress Off BHA#1 :8-1/2"OD Metal Muncher Shoe, 2 X 8-1/8" W.P. Extensions, 8-1/8" W/O Boot Basket- dressed internally w/6-1/4" OD mill, x/o, 9-5/8" casing scraper, 6-5/8" OD JB, x/o, bumper jar, oil jars. M/U 12, 4-3/4"OD spiral drill collars.Torqued connections per Baker Fishing Tool Representative recommendations. BHA#1, total length 419.45' DECOMP RIH on 4" DP from pipe Shed, Rabbited all DP run in hole. DECOMP RIH w/ Dress Off BHA on 4" DP. P / U DP 1 x 1 from Pipe Shed. Rabbitted All DP Run in Hole. DECOMP Held PJSM. M / U HES 9-5/8" RTTS Packer w/ Storm Valve. DECOMP RIH w/ 9-5/8" RTTS Packer - Storm Valve on 1 Stand of 4" DP. String Weight Up 145,000#, String Weight Down 115,000#. Set RTTS Packer 60' Below Wellhead. Stacked 10,000# on Packer to Ensure Packer was Set. Released from Packer. DECOMP POOH, Stood Back DP. Closed Blind Rams, Tested RTTS to 1,000 psi from Above, OK. Bled Off Pressure, Opened Rams. DECOMP Held PJSM. B / D Lines, R / U Bleed Trailer to OA. Drained Stack. Bled Down 25 psi from OA. Pulled Wear Bushing. DECOMP N / D Flowline and Riser. N / D BOP Stack, N / D Tubing Spool. BOLDS. DECOMP M / U Packoff Retrieving Tool onto 4" DP. Latched and Pulled Old Packoff. M / U, Ran and Installed New Packoff. RILDS. DECOMP N / U New 13-5/8" 5,000# Tubing Spool. N / U BOP Stack. DECOMP Injected Plastic Packing to Energize Packoff Seals. DECOMP Tested Packoff to 5,000 psi, OK. DECOMP N / U Riser and Flowline. 1.00 PULL P 1.00 PULL P 4.00 PULL P 5.00 PULL 0.50 PULL P 5.00 PULL P 0.50 PULL P 2.00 BOPSUP P 0.50 CLEAN P 0.50 CLEAN P 2.00 CLEAN P 1.00 CLEAN P 7.00 CLEAN P 1.00 CLEAN P 1.00 CLEAN P 0.50 CLEAN P 0.50 WHSUR P 3.00 WHSUR P 1.00 WHSUR P 2.00 WHSUR P 1.00 WHSUR P 0.50 WHSUR P 1.00 BOPSUR P Printed: 3/28/2005 8:04:34 AM ) R....·..··.cC.., :.E..·.:··.·.··..I.V. ED.::·::· ~J?E«P4QRJ,\TION. page 3915 . ··APR22'Z005 . Qpè~a~iøljs$ul'l1rnarYRèp()rt .'.... .,.., ,.:...:....., .:......:.:.. .:.... . Alask:p Oil&G8$ Cnns~Ct1mrnis$iQo Anchorage Spud Date: 12/27/1986 End: 3/27/2005 ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-27 11-27 REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 bäte · Start: 3/19/2005 Rig Release: 3/27/2005 Rig Number: 3/23/2005 4.50 BOPSUP P =rofT};.ToHÖurs Task Code NPT Ø~scripti()nof Öþeråti~ns 18:30 - 23:00 3/24/2005 23:00 - 00:00 00:00 - 07:00 1.00 BOPSUP N 7.00 BOPSUP N 07:00 - 08:00 1.00 BOPSUF P 08:00 - 09:30 1.50 PULL P DECOMP Seated test plug. Attempted full body BOP test 250 psi lowl 3500 psi high. Test failure. Checked valves for leak, no leaks. Pulled test plug, inspected rubber seal, ok. Reran and seated test plug. RILDS. Filled Riser with water. Retested BOPE body, observed flow. Increased Annular preventor sealing pressure from 900 to 1400 psi. Flow still observed. Annular preventor packer element leaking. RREP DECOMP Blow down lines. RD test equipment. RREP DECOMP PJSM. B/O Annular Preventor Cap Screws, Removed Cap. Bolted up Lifting Flange to Annular Top and Screwed Out of Annular Body. Removed Worn Packer Element. Cleaned Out Cavity and Greased Inside. Installed New Packer Element and Greased Same. Installed Annular Top and Screwed into Annular Body. Caulked Seal, Bolted Up Annular Cap. DECOMP Held PJSM. R I U Test Equipment, Tested Annular and BOP Stack Body 250 psi f/5 Minutes I 3,500 psi fl 5 Minutes. All Tests Held wI No Leaks or Pressure Loss. Test Witnessed by BP Drilling Supervisor. Blew Down All Lines, RID Test Equipment. DECOMP Held PJSM. M I U RTTS Retrieving Tool onto 4" DP. RIH Attempted to Sting into RTTS without Success. Suspect Annular Rubber on Top of Tool. Engaged Pump, 10 bpm, 1,000 psi, Washed Down to Top of Tool, Shut Down Pump, Stung into RTTS. Released RTTS Packer, Allowed Packer Element to Relax. Monitored Well, Static. POOH, B I 0 and LID RTTS Packer wI Storm Valve. Found 4" Piece of Rubber in Tool. Circulated Bottoms Up as Precaution to Plugged Pipe and Possible Gas in Wellbore. 5 bpm, 450 psi. No Gas on Bottoms Up. RIH wI Dress Off BHA on 4" DP to 10,840'. PI U DP 1 x 1 from Pipe Shed. Rabbitted All DP Run in Hole. M I U Top Drive, Established Parameters: Pump Rate 5 bpm, 650 psi, String Weight Up 205,000#, String Weight Down 135,000#, Rotating Weight 165,000#, 60 rpm, Torque 8,000 ft I Ibs. Washed Down to 10,896', Tagged Up on Tubing Stub at 10,896' DPM. DECOMP Washed and Milled Over Tubing Stub 10,896' to 10,904'. ICR 5 bpm, 620 psi, FCR 8 bpm, 1,600 psi, rpm 80, Torque Off Bottom 10,000 ft I Ibs, Torque On Bottom 12,000 ft / Ibs. Washed Down to 10,904', Dressed Off Top of Tubing Stub 10,904' - 10,904.6'. Circulated 2 x Bottoms Up, Pump Rate 10 bpm, 2,350 psi. Pulled 2 jts. BID top drive, install air slips. POOH, UD DP. POOH, LID 4" DP. POOH, B I 0 and LID Dressoff BHA. Cleared and Cleaned Rig Floor. Pulled Wear Bushing. Held PJSM. Changed Out Bails, R I U Power Tongs, Elevators, Compensator and Torque Turn Equipment. M I U 4-1/2" 12.6# 13Cr80 Vam TOP Tail Pipe Assembly: Unique Overshot Assy - XN Nipple Assy wI RHC-M Sleeve - Lwr X Nipple Assy - 1 Joint 4-1/2" 12.6# 13Cr80 Vam TOP Tbg 09:30 - 10:00 0.50 PULL P DECOMP 10:00 - 12:00 2.00 PULL P DECOMP 12:00 - 15:30 3.50 CLEAN P DECOMP 15:30 - 16:30 1.00 CLEAN P DECOMP 16:30 - 17:30 1.00 CLEAN P 17:30 - 19:30 2.00 CLEAN P DECOMP 19:30 - 20:00 0.50 CLEAN P DECOMP 20:00 - 00:00 4.00 CLEAN P DECOMP 3/25/2005 00:00 - 06:00 6.00 CLEAN P DECOMP 06:00 - 08:30 2.50 CLEAN P DECOMP 08:30 - 09:30 1.00 CLEAN P DECOMP 09:30 - 11 :00 1.50 RUNCOrvP RUNCMP 11 :00 - 12:30 1.50 RUNCOrvP RUNCMP Printed: 3/28/2005 8:04:34 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-27 11-27 REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 ) ... ..... ............ ..... .... .' .... . RE¡Ut::IVt::Ù BPEXPLORATION ..... .......................... .... .. ....... . .... . . ..' :P····R '0'2> ')005 . .:.............: ......... ........... ............ .....:..<. '. .......:. .... '.' ". .... ..... ...:.. .'. . ...........:. ..~.. .......f,J.l.....: ¡....... .... .' . ·0......····. ".p. .. ...e.. .......ra. ..1.. 1.0..··.... ".... ..·..s... ...... Su......m..... .'. m.é1.. r.".'. Re. .' ....p..... ...0...·...... r.... t." ......... ....... .... ........ ...... ... ... ..... '. . ... ..... · ...... · . .. c·' .... .... .. ....... ·S. '···.0·· n ...¡.... .., ...... .... :..'.. .'. .... .... '. ..... .'. ....z . . ... ...I\'lsk,riif&GasCôns. omm,s' .... Anchorage Spud Date: 12/27/1986 End: 3/27/2005 ) Start: 3/19/2005 Rig Release: 3/27/2005 Rig Number: [)a.tê . From -To Code NþT" '" '. ... " Description' of OperatioÒs ..::' 3/25/2005 11 :00 - 12:30 1.50 RUNCOMP RUNCMP - 9-5/8" x 5-1/2" Baker S-3 Packer Assy - Upper X Nipple Assy. Sakerlocked All Connections Below Packer. PI U All Assy's and Joints wI Compensator, Torque Turned All Connections. M I U Torque fl 1 TC-II Connection 2,750 ft I Ibs, M I U Torque fl Vam TOP Connections 4,450 ft I Ibs. Doped Connections wI Shell Malleus TC. RIH wI 4-1/2" 12.6# 13Cr80 Vam TOP Tubing. PI U Joints wI Compensator, Torque Turned All Connections. M I U Torque 4,450 ft I Ibs. Doped Connections wI Shell Malleus TC. RIH wI 257 Joints 4-1/2" 12.6# 13Cr80 Vam TOP Tubing. PI U Joints wI Compensator, Torque Turned All Connections. M I U Torque 4,450 ft I Ibs. Doped Connections wI Shell Malleus TC. RID Compensator, M I U Circulating Head to Jt #258. M I U Jt #258 to Tubing String. Established Parameters: String Weight Up 155,000#, String Weight Down 110,000#, IPR 1 bpm,40 psi, FPR 3 bpm, 120 psi. Washed Down, Stacked Out on Top of Tubing Stub wI 10,000#, 5' in on Jt #258, Observed Shear Pins Shear, Continued in and Stacked Out 15,000# on 5-1/2" Tubing Stub wI 14' in on Jt #258, Observed Pump Pressure Increase to 280 psi. PI U, Shut Down Pumps, RIH and Stacked Out on 5-1/2" Tubing Stub wI 15,000# x 2 To Ensure Proper Depth. 12:30 - 00:00 11.50 RUNCOMP RUNCMP 3/26/2005 00:00 - 02:30 2.50 RUNCOMP RUNCMP 02:30 - 04:00 1.50 RUNCOMP RUNCMP 04:00 - 06:00 2.00 RUNCOMP RUNCMP RID Circulating Head and Lines. LID Jt #258, #257 and #256. M I U Space Out Pup Joints, M I U Jt #256. M I U Tubing Hanger and Landing Jt. Landed Hanger in Tubing Head. Tubing Spaced Out wI Unique Overshot at 10,902' TMD. 6.0' Over 5-1/2" Tubing Stub at 10,896' TMD. Completion Equipment Set At The Following Depths: Item Length Depth Unique Overshot Assy 20.99' 10,902.00' XN Nipple wI RHC Sleeve Assy 20.92' 10,860.09' Lwr X Nipple Assy 20.87' 10,839.22' 1 Jt 4.5" 12.6# 13Cr80 Vam TOP Tbg 41.48' 10,797.73' 9-5/8" x 5-1/2" S-3 Packer Assy 27.76' 10,779.97' Upper X Nipple Assy 20.88' 10,749.09' #4 GLM Assy 28.34' 10,720.75' 27 Jts 4.5" 12.6# 13Cr80 Vam TOP Tbg 1,119.90' 9,600.85' #3 GLM Assy 28.34' 9,572.51' 60 Jts 4.5" 12.6# 13Cr80 Vam TOP Tbg 2,484.27' 7,088.24' #2 GLM Assy 28.36' 7,059.88' 87 Jts 4.5" 12.6# 13Cr80 Vam TOP Tbg 3,607.37' 3,452.51' #1 GLM Assy wI DCR Shr Valve 28.39' 3,424.12' 22 Jts 4.5" 12.6# 13Cr80 Vam TOP Tbg 912.42' 2,511.69' Printed: 3/28/2005 8:04:34 AM ) ) . . ..... ........ R.:..E.··.·,.:.C..···.·..·.iE...·..···..I..V. E.....·,D.··: Sf> EXPLORATION 0'" . .. ·t·· .... S" ······n·· ... ·t· iAPR222U05 p,~rªl()nsijl'TlrnarylT1øPQr¡ ...... ......... . Alaak,O¡I& r;asCons.: Commission' : Anchorage Spud Date: 12/27/1986 End: 3/27/2005 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ¡:Pate·· 11-27 11-27 REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 3/19/2005 Rig Release: 3/27/2005 Rig Number: . . .,' Hours Téisk Code: NPT . .... .. .. . pescriþtioh· ofOþëra.tions 03:30 - 06:00 2.50 RUNCOfvP RUNCMP X Nipple Assy 20.85' 2,490.86' 58 Jts 4.5" 12.6# 13Cr80 Vam TOP Tbg 2,403.54' 87.30' 2 - 4.5" 12.6# 13Cr80 Vam TOP Pup Jts 17.62' 69.68' 1 Jt 4.5" 12.6# 13Cr80 Vam TOP Tbg 41.47' 28.21' Tubing Hanger 6.20' 21.97' RUNCMP Held PJSM wI Rig Crew, Vac Truck Drivers, Tool Pusher and Drilling Supervisor. RID 4-1/2" Tubing Handling Equipment, Cleared and Cleaned Rig Floor. R I U Circulating Lines to Landing Joint and 9-5/8" x 4-1/2" Annulus. Pressure Tested Lines to 3,500 psi. RUNCMP Pumped 200 bbls 140 deg Clean Seawater, Followed by 575 bbls 140 deg Seawater wI Corrision Inhibitor. Pumped Down 9-5/8" x 4-1/2" Annulus Took Returns Up Tubing to Slop Tank. Pump Rate 3 bpm, 40 psi. RUNCMP PJSM wI Rig Crew, Baker Rep, Tool Pusher and Drilling Supervisor on Setting Packer and Testing Tubing. Broke Out Head Pin, Dropped Ball I Rod Assy. Allowed Ball / Rod Assy to Fall On Seat. M I U Head Pin, Pressured Up on Tubing to 2,500 psi to Set Packer, Increased Pressure to 3,500 psi, Tested Tubing f/30 minutes. Bled Tubing Pressure to 2,000 psi. Tested 9-5/8" X 4-1/2" Annulus to 3,500 psi fl 30 minutes. RUNCMP Bled Tubing Pressure Down and Sheared DCR Valve, Valve Sheared at 3,000 psi Differential. Bled Down All Pressures. Pumped Down Tubing and Took Returns off of Annulus, Pump Rate 3 bpm, 600 psi. DCR Valve Fully Sheared. Blew Down and RID Lines, B I 0 and LID Landing Joint and XO's. Set TWC and Tested From Below to 1,000 psi. Held PJSM. N I D BOPE. Set back BOP Stack on Pedistal and Secure Same. Held PJSM. N I U Adaptor Flange & Production Tree. Cameron Rep Tested Neck Seal and Void t/ 5,000 psi f/30 min. Tested Tree wI Diesel to 5,000 psi, Held f/5 min. Ok. RID Test Line, Pumped Out Tree. R I U DSM Lubricator, Pulled TWC, RID Lubricator. Held PJSM. R I U Little Red to 9-5/8" x 4-1/2" Annulus.Tested lines to 2,500 psi. Pumped 160bbls Diesel Down IA to Freeze Protect, Pump Rate 3 bpm, 1,000 psi. Aligned Valves on Circulating Manifold, Allowed Tubing and IA to U - Tube. RID Little Red. RUNCMP Installed BPV and Tested from Below to 1,000 psi. Installed Tubing, lA, OA Pressure guages. RID Lines, N I D Secondary Annulus Valve. Secured Well. Released Rig at 0600 hrs 3 I 27 I 2005. 3/26/2005 04:00 - 06:00 2.00 RUNCOMP 06:00 - 07:00 1.00 RUNCOMP 07:00 - 12:00 5.00 RUNCOMP 12:00 - 14:00 2.00 RUNCOMP 14:00 - 14:30 0.50 RUNCOMP 14:30 - 15:00 0.50 RUNCOMP RUNCMP 15:00 - 17:30 2.50 BOPSUR P RUNCMP 17:30 - 22:30 5.00 RUNCOMP RUNCMP 22:30 - 00:00 1.50 RUNCOrvP RUNCMP 3/27/2005 00:00 - 03:30 3.50 RUNCOWP RUNCMP Printed: 3/28/2005 8:04:34 AM ) RECEIVED ) Well: 11-27 Rig W orkover APR 2 2 Z005 Accept: 03/20/05 Field: Prudhoe Bay Unit Alaska Oil & Gas Cons. Commission Spud: N/A API: 50-029-21638-00-00 Release: 03/27/05 Permit: 186-148 Anchorage Rig: Doyon #14 POST RIG WORK 03/31/05 PULL BALL & ROD FROM 10,841' SLM. PULL DUMMY VALVE FROM STA#3 AT 7055' SLM. ATTEMPTTO PULL SHEAR VALVE FROM STA#3 WI NO SUCCESS. STA# 3 EMPTY. RHC PLUG BODY STILL IN HOLE, LDFN. 04/01/05 PULL SHEAR VALVE FROM STA#4 AT 3419' SLM. SET GENERIC GAS LIFT DESIGN IN STA'S # 3 & 4. PULL RHC PLUG BODY FROM 10,844' SLM. DRIFT WI 2.70" CENT. & SAMPLE BAILER TO 10,903' SLM. SAMPLE OF GOOEY SOLIDS. 04/04/05 RAN 3.70" JUNK BASKET TO 10974' SLM. 04/05/05 JUNK BASKET RAN FROM 10974' SLM, EMPTY. SEVERAL RUNS WI GRABS 3.40" & 2.60", COULD NOT WORK THRU GLM #3 AT 7053' TO 7105' SLM. RAN 3.65" CENT & 3.0" LIB TO 10,869' SLM. RAN 3.65 CENT ABOVE 2' STEM & 3.40 GRAB TO TOP OF CUT TBG AT 10877' SLM. RAN KNUCKLE ABOVE 3.65 CENT & 3.40 GRAB, MADE IT INTO TOP OF 5-1/2" CUT TBG. STOPPED DUE TO HEAVY FLUIDS, ONLY ABLE TO GET TO 10905' SLM. 100 PSI ON WELL FROM TESTING O-RINGS WI GAS. TREE CAP TESTED WI LIFT GAS TO 1200 PSI. 04/07/05 RIH WITH 3 1/8 VENTURI. WORK VENTURI TO 10960, SET DOWN. POH RUBBER, CEMENT, STEEL BAND AND SHEAR PINS IN VENTURI BASKET. RE-RUN VENTURI, WASH DOWN TO 11,024', SOME DRAG OFF BOTTOM. POH. 04/08/05 POH WI 2ND 3-1/8" VENTURI BASKET RUN. PIECE OF STEEL BAND AND METAL SHAVINGS. 3RD RUN WITH 3-1/8 VENTURI SET DOWN SOLID AT 11024. SOME DRAG POH AT 10,500 - 10,400. 4-5K OVER NORMAL WEIGHT. SMALL AMOUNT OF METAL SHAVINGS IN VENTURI. CLEAN TO 11024. PU 23/16 VENTURI. RIH, SET DOWN AT 10985. PU, SET DOWN AT 10975. UNABLE TO GO DEEPER. POH 3 SMALL PIECES RUBBER. MU ORIENTER TOOL TO MS BHA. RIH. SET DOWN AT 10995 AND 11039. WASH DOWN TO 11050. POH, DRAG WIOUT PUMPIMG AT 9500 TO 9450. RECOVERED SEVERAL PIECES OF CEMENT, SMALL RUBBER CHUNKS, AND SAND. RE-RUN 2-3/16 VENTURI WI ORIENTATOR TOOL. 04/09/05 GIH 2ND RUN WI WEATHERFORD 2-3/16 VENTURI JB WITH OREINTATOR. CLEAN WASHIDOWN TO 11075, DID NOT TAG. RECOVERED SMALL AMOUNT OF SAND AND PIECES OF RUBBER. CT SHOWS AREA OF CONCERN AT 6630 - 6650. 3RD RUN IN CHROME PIPE SINCE LAST CUT. CUT 125' CT, RIH WITH 1.75 JSN SLICK, SET DOWN AT10990. PUMP DOWN TO 11010. POH CHECKING WEAR AREA'S ON COIL. WORST WEAR IS 53, THIS IS BELOW MIN OF .116 PIPE. FP WELL. 04/13/05 RIH SLICK WI 1.75" JSN. TAG FILL AT 11060'. FCO TO 11243' WI XS KCL & FLOPRO SWEEPS. PROBLEMS WITH CTU TRACTOR. CALL OUT FOR & HOOK UP SPARE TRACTOR. CONTINUE FCO TO 11872', HARD TAG. GETTING A LOT OF SAND IN RETURNS. PUMP 15 BBL FLOPRO SWEEP OFF BTM, POOH AT 80%. FP WELL TO 1000'. 11-27 Rig Workover, March 20L, ) Page 2 ) RECEIVED APR 2 2 2005 Alaska Oil & Gas Cons. Commission 04/14/05 Anchorage MUIRIH WI JARS, MTR, 2.75" 5-BLADED CONCAVE MILL. TAG TIEBACK SLEEVE AT 11019', ROLL THROUGH. MILL THROUGH BULLNOSE ON BTM OF TIEBACK SLEEVE AT 11035'. LOCATE FILL AT 11790'. HARD TAG AT 11904', FLOAT COLLAR. MILL AHEAD WIXS KCL & FLOPRO. MILL THROUGH LINER GUIDE SHOE AT 11936'. CONTINUE MILLING DOWN TO 11960', APPEAR TO BE IN SAND. POOH, FP WELL TO 800'. 04/16/05 RIH WI 2" JSN. SET DOWN AT 10921', WORK THROUGH. TAG FILL AT 11831', BEGIN FCO. HARD CRUSTS AT 11990',12000'. BREAK THROUGH FINAL CRUST AT 12006' & WELL STARTS DRINKING ALL FLUID, LOSING SURFACE RETURNS, CAN'T LOCK UP WITH FLOPRO. STRANGELY ENOUGH, WHP LOCKS UP WHEN PUMPING DOWN BACKSIDE, BUT CAN PUMP DOWN COIL EASILY. RIH AS DEEP AS 12020' ONE TIME, TAG - 12006' ON SUBSEQUENT TRIPS. OVER PULLS WHILE POOH UNTIL INTO 5-1/2" TBG, THEN NORMAL WT. RUBBER DEBRIS FORMING DOWNHOLE PACKOFF AT 3-1/2" LINER TOP? POOH, FP WI METH. RD, WILL LEAVE LOCATION IN A.M. gTkr.±= McEVOY WELLHEAD = MCEVOY • SAFETY NOTES: 3 CHROME LNR ACTUATOR = AXELSON B. BF. ELE = 58' From Drilling - DRAFT 1 7 I 2,501' H4 -1/2" X NIPPLE ID= 3.813" KOP = 1900' Max Angle = 56 @ 7400' GAS LIFT MANDRELS Datum MD = 12162' ST MD TV D DEV TYPE VLV LATCH PORT DATE Datum TV D = 8800' SS I 4 3433 3220 45 MMG DCR RKP 3 7069 5575 52 MMG DMY RK 2 9582 7100 50 MMG DMY RK 1 10730 8540 45 MMG DMY RK 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2555' 1 - 41 , 14-1/2" 12.6# L -80 Vam TOP Tbg H 10,902' 10,758' 4 -1/2" X NIPPPLE ID= 3.813" I 6 10,782' 9 - 5/8" X 5 -1/2" BAKER S -3 PKR 1 1111111 10,848' 4-1/2" X NIPPPLE ID= 3.813" 15-1/2" Unique Overshot I 10,90 Yi 10,869' 4 -1/2" XN NIPPLE ID= 3.725" Minimum ID = 2.813" @ 11060' -.1. ��� 10,896' I-I TBG CUT (02/26/05) I 3-1/2" OTIS X NIPPLE . 10944' H9-5/8" X 5 -1/2" BAKER S -3 PKR I (TOP OF 5-1/2" TBG I 11001' A 10978' (—i 5 -112" HES X NIP, ID = 4.562" I _ 10998' H5-1/2" UNIQUE OVERSHOT I 5 -1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" I-1 11006' I-- 11015' I-1 STINGER TIEBACK SLV 08/08/04 I 2 ri 11026' 1-19 -518" X 5 -1/2" BAKER SB -3 PKR I TOP OF 7" LNR Hi 11046' I _ • 5 -1/2" TBG -PC, 17 #, L -80, .0232 bpf, ID = 4.892" I-1 11048' l 11034' H C-Z TIEBACK SLV, ID = 4.00" 02/23/04 I 11048' - 15- 1 /2 " X5 "XOI TOP OF 5" TBG PC H 11048' I 11060' —13-1/2" OTIS X NIP, ID = 2.813" 02/23/04 I 11094' — 15" OTIS X NIP, ID = 4.312" I 11114' H 5" BAKER SHEAROUT SUB I 5" TBG -PC, 15 #, L -80, .0232 bpf, ID = 4.406" H 11115' I 7 L 11115' — 15" TUBING TAIL I •$ O. 11107' H ELMD TT LOGGED 02/04/89 I a v 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 11368' .. TA 0. 3 -1/2" LNR, 9.3 #, 13 -CR, .0087 bpf, ID = 2.992" I--I 11935' :7 44 11878' —) TOP OF SAND PERFORATION SUMMARY REF LOG: BHCS ON 01/10/87 A NGLE AT TOP PERF: 46 @ 11998' = _ Note: Refer to Production DB for historical pert data — I 12006' I Ead WY' QUIZ SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 4 11998 - 12029 0 07/30/87 1 APR 2 2 2005 3 -3/8" 4 12048 - 12062 0 09/03/89 Alaska Oil & Gas Cons. Commission Anchorage PBTD I 12100' A . A . A . A . A . A . A .. � 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" I—I 12210' ♦.0.0.0 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/31/87 ORIGINAL COMPLETION 12/28/03 JLJ /PAG GLV C/O WELL: 11 -27 06/23/98 LAST WORKOVER 03/01/04 JGM/TLP TIEBACK SLV, XNIP, PBTD, LNR PERMIT No: 1861480 01/04/02 RN/TP CORRECTIONS 08/08/04 SRB /TLP TIEBACK SLV API No: 50- 029 - 21638 -00 06/01 /02 DBM/KK SAND DUMP 03/09/05 JRA /TLH TBG CUT (02/26/05) SEC 28, T11N, R15E, 4134.88' FEL & 3838.25' FNL 06/13/02 ATD /TP UR CMT /SAND FCO,NEW PBTD 12/06/03 DAV/TLP SAND TOP CORRECTION BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATION!èCT 0 [} 7004 Stimulate D Alaska Dtitli?r~s (. " . . --- ...,óiìlm¡SSlon WaiverD Time ExtensioAlliJhûrage Re-enter Suspended Well 0 5. Permit to Drill Number: 186-1480 6. API Number 50-029-21638-00-00 '" 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 Repair WellŒ) PluQ PerforationsD Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 58.00 8. Property Designation: ADL-0028322 11. Present Well Condition Summary: Total Depth 4. Current Well Class: Development Œ1 Stratigraphic D 9. Well Name and Number: 11-27 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool Exploratory 0 Service 0 measured 12210 feet None Effective Depth true vertical 8892.3 feet None measured 11901 feet Plugs (measured) Junk (measured) true vertical 8674.2 feet Casing Conductor Liner Liner Liner Production Surface Length 80 27 901 1164 11315 2495 Perforation depth: Size 20" 91.5# H-40 3-1/2" 9.3# L-80 3-1/2" 9.2# 13Cr80 7" 29# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 MD TVD Burst Collapse 31 - 111 31.0 - 111.0 1490 470 11015 - 11042 8049.5 - 8068.3 10160 10530 11034 - 11935 8062.7 - 8698.0 10160 10530 11046 - 12210 8071.1 - 8892.3 8160 7020 26 - 11341 26.0 - 8279.0 6870 4760 30 - 2525 30.0 - 2490.8 4930 2670 Measured depth: All Perforations Below Cement Plug True vertical depth: All Perforations Below Cement Plug Tubing ( size, grade, and measured depth): 7" 26# L-80 5-1/2" 17# L-80 5" 15# L-80 @ 25 @ 29 @ 11045 29 11048 11112 Packers & SSSV (type & measured depth): 5-1/2" Baker S-3 Packer 5-1/2" Baker SB-3 Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casing Pressure 36.3 1770 350 Well Shut-In 430 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron .J/~ t-~ 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run - Daily Report of Well Operations, ! Signature @ 10940 @ 11023 Oil-Bbl 1072 Tubing Pressure 1186 246 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oil Œ] GasD DevelopmentŒ] ServiceD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: NIA Title Production Technical Assistant n F') I Phorie 564-4657 Form 10-404 Revised 4/6eANNED OCT 0 9 2004" :\ , GIN A L BFL Date.. 1 OCt 0 II 111M 0/1/04 11-27 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/08/04 CTU #5, SCAB LINER; MIRU DS CTU #5. RU 5-1/1611 BOP STACK. PERFORM BOP TEST. MU & RIH W/ BAKER STINGER SEAL ASS1Y W/ ALUMINUM BULL NOSE. STAB STINGER SEAL ASSY INTO TIEBACK RECEPTACLE AT 110221 CTMD. PRESSURE UP AND RELEASE. POOH W / BAKER SETTING TOOL. CONT' ON WSR 8/09/04 ... 08/09/04 CTU #5, SCAB LINER; CONT' FROM WSR 8/08/04... POOH WITH BAKER SETTING TOOL. FP WELL FROM 2500' TO SURFACE WITH 50/50 METHANOL. RD DS CTU #5. . NOTE: EST. TOP OF STINGER TIEBACK RECEPTACLE IS 110151 MDBKB.. . *** JOB COMPLETE *** FLUIDS PUMPED BBLS 102 43 145 50/50 Methonal 1 % KCL TOTAL Page 1 SCANNED OCT 0 9 2004 TREE = WR.LHEAD = ACTlJA. TOR;;' , , - KB. ELEV = . R_~'_""<" --,~~----~ - BF. ELEV = KOP= Max Ànge = DàtumMÒ =' 'DatÙ m NO"'= MeBl OY tvCBI OY AXELSON 58' 1900' 56 @ 7400' , "'.1 iï 62ï "'8800' SS I 7" TBG, L-80 H ITOPOF 5-1/2" TBG H 113-3/8" CSG, 72#, L-80, ID = 12.347" H 33' 33' Minimum ID = 2.813" @ 11060' 3-112" OTIS X NIPPLE I TOP OF 5-1/2" TBG H 11001' I 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 1-1 11006' TOP OF T' LNR H 11046' 11-27 ) SAÆTYNOTES: 3-1/2" CHROME LNR 33' HT'X 5-1/2" XO - 2177' H5-1/2 CAM BAL-O SSSV f\lP,ID =4.562" 1 GA S L FT fv\A. f\DRELS DBI TYÆ VLV LATCH FORT' DATE 48 LB DOM: T-2 16 12/23103 50 LB DMY T-2 0 06112/02 I-DLE QEANOUT I-DLE 12/23103 LB DMY T-2 0 LB DMY T-2 0 LB DMY T-2 0 ~ ST MD TVD 1 3586 3345 2 6388 5151 H 7846 6028 3 8067 6157 55 4 8932 6682 51 5 10878 7955 47 L :8: I 10944' H9-5/8" x 5-1/2" BAKERS-3 PKR ~ N~ I l J- :8: . :8'- I 1 m I 10978' H5-1/2" HES x NIP, ID = 4.562" 1 10998' H5-1/2" UNIQLE OVERSI-DT 1 11015' HSTINGERTIEBACKSLV 08/08/04 I 11026' H9-5/8" X5-1/2" BAKERSB-3 A<R 1 J I 11034' Hc-Z l1EBACK SLV ,ID = 4.00" 02/23/04 15-1/2"TBG-FC, 17#, L-80, .0232 bpf, ID =4.892" H 11 048' ~ 'ì ITOP OF 5" TBG-FC H ~ I 11048' H5-1/2" X5" XO 11048' t I 11060' H3-1/2"011SXNP,ID=2.813" 02/23/04 1 I 11094' H5" 011S x NP, ID = 4.312"1 11114' H5" BAKER SHEAROUT SUB 1 15" TBG-PC, 15#, L-80, .0232 bpf, ID = 4.406" H 11115' 1 1 r I 11115' H5"TLBING TAIL! 11342' r-JI.u." 11107' H ELMD TT LOGGED 02/04/89 I I 9-518" CSG, 47#, L-80, () = 8.681" H I 11901' HPBTD 02/231041 13-1/2" LNR, 9.3#, 13-CR .0087 bpf, ID=2.992" H 11935' I. 11878' j-fTOPOF SAND I PERFORATION SUMMA RY REF LOG: BHCS ON 01/10/87 ANGLEATTOP ÆRF: 46@ 11998' I\bte: Refer to A'oduetion DB for historieal perf data SIZE SPF INTER\! AL OpnlSqz DA TE 3-3/8" 4 11998-12029 0 07ßO/87 3-3/8" 4 12048 - 12062 0 09103/89 I PBTD H 12100' 17"LNR, 29#,L-80, .0371 bpf,ID=6.184" H 12210' DATE 07/31/87 06123/98 01/04102 06101102 06113102 06115102 COMMENTS ORIGINAL COM PLETION LAST WORKOVER RN/lP CORREC110NS DBM/KK SAND DUtvP A TDITP UR CMf/SAND FCO,NEW PBTD RL/lP ADD GL VLV INFO DATE 12/06/03 12/28/03 03/01/04 08/08/04 REV BY SCANNED OCT 0 9 2004 II 1'1 ~ REV BY COMM:NTS DA V ffLP SAND TOP CORRECTION JLJ/PA G GL V C/O JGMffLP TEBACK SLV, XNIp, PBTD, LNR SRBffLP TEBACK SLV PRLDI-DE BAY U\JIT WELL: 11-27 PERMT I\b: 1861480 APII\b: 50-029-21638-00 SEC 28, T11 N, R15E, 4134.88' FEL & 3838.25' FNL BP Exploration (Alaska) ~ I'" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D Repair WellŒ Pull TubingO Operation ShutdownO PluQ Perforations 0 Perforate New Pool D Perforate D Stimulate 0 OtherD WaiverD Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Number: 186-1480 6. API Number 50-029-21638-00-00 2. Operator Name: 3. Address: 4. Current Well Class: Development Œ] Stratigraphic D 9. Well Name and Number: 11-27 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): ExploratoryD ServiceD 58.00 8. Property Designation: ADL-0028322 11. Present Well Condition Summary: Total Depth measured 12210 feet 8892.3 feet None true vertical Plugs (measured) Junk (measured) 11901 feet 8674.2 feet measured None Effective Depth true vertical Length 80 27 901 1164 11315 2495 Size 20" 91.5# H-40 3-112" 9.3# L-80 3-1/2" 9.2# 13Cr80 7" 29# L-80 9-5/8" 47# L-80 13-318" 72# L-80 Casing Conductor Liner Liner Liner Production Surface Perforation depth: Measured depth: All Perforations Below Cement from Scab Liner MD TVD 31 111 31.0 111.0 11015 - 11042 8049.5 - 8068.3 11034 - 11935 8062.7 - 8698.0 11046 - 12210 8071.1 - 8892.3 26 - 11341 26.0 - 8279.0 30 - 2525 30.0 - 2490.8 Burst Collapse 470 10530 10530 7020 4760 2670 1490 10160 10160 8160 6870 4930 True vertical depth: All Perforations Below Cement from Scab Liner RECEIVED SEP 1 5 2004 Tubing ( size, grade, and measured depth): 7" 26# L-80 5-1/2" 17# L-80 5" 15# L-80 @ 25 @ 29 @ 11045 @ 10940 @ 11023 29 11048 11112 Alaska Oil & Gas Cons. Commission Anchorage Packers & SSSV (type & measured depth): 5-112" Baker S-3 Packer 5-112" Baker SB-3 Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Averaae Production or Iniection Data Gas-Me! I Water-Bbl Casing Pressure 36.3 1770 2400 Well Shut-In 450 13 Oil-Bbl 1072 Tubing Pressure 1186 450 Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Exploratory 0 16. Well Status after proposed work: OilŒJ GasD Development ŒI ServiceD Copies of Logs and Surveys run - Daily Report of Well Operations. WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or NIA if C.O. Exempt: NIA ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron ß~ Ln~ Title Production Technical Assistant . . Signature Phone 564-4657 ORIGINAL Date 9t.13/04 SEP 1 5 20Ult RBDMS 6FL Form 1 0-404 Revised 4/2004 ~ ~ 11-27 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 01/22/04 T/1/0=1200/2400/250 LOAD LA. TO SECURE WELL. PUMPED 10 BBLS METH, 705 BBLS WATER, 93 BBLS CRUDE TO HOLD BACK SIDE FOR SAND BRIDGE PLUG. RIGGED UP TO TUBING TO FREEZE PROTECT FLOW LINE. PUMPED 5 BBLS METH, 140 BBLS CRUDE, 5 BBLS METH. FINAL T10=1200/1150/220 01/23/04 TIO= VAC/800/200. WELL SI. TBG FL @ 78' (2 BBLS). IA FL @ 2657' (117 BBLS). (POST SAND DUMP). 01/24/04 T/I/O= VAC/950/200. TEMP= COLD. MONITORED WHP'S. (POST SAND DUMP). lAP INCREASED 150 PSI OVERNIGHT. 01/25/04 T/I/O= VAC/950/200. TEMP= COLD. MONITORED WHP'S. (POST SAND DUMP). WHP'S REMAINED UNCHANGED OVERNIGHT. 02/04/04 ***WELL SHUT IN ON ARRIVAL***. TAG TOP OF SAND @ 11153 SLM WI 3-1/2" CENT I SB.. SET SLIP STOP CATCHER @ 3618' SLM.. CONTINUE ON 2-05-04 WSR 02/04/04 PRESSURE TEST FOR KLONDIKE 1. 02/05/04 Station 1 02/05104 ***CONTINUED FROM 2-04-04 WSR***. PULL STA # 1 GLV @ 3575 SLM. SET DGLV STA # 1 @ 3575 SLM, T-2. PULL CS. *** LEFT WELL SHUT-IN *** 02/15/04 T/I/0=750/750/50 (LUBRICATE IN) LOAD IA WITH 512 BBLS CRUDE TAKING RETURNS FROM TBG TO TANKS, FWP=1200/850/150 02/16104 T/I/O= 1250/750/150 PUMPED 266 BBLS CRUDE DOWN lA, TAKING RETURNS UP TUBING INTO TIGER TANK. FWP= 500/350/200 02117/04 CTU #9: SCAB LINER. MIRU MATE UP TO WWP. PERFORM BOP TEST. TEMP -40 DEG F. GO TO WEATHER STANDBY. 02/20104 CTU #9: SCAB LlNERIEXTENDED TUBING PATCH. CONTINUED FROM 2/17/04 WSR AFTER WEATHER STANDBY. RIH WITH 2.25" JSN. CLEAN OUT TO 11965' CTM. PUMP BU AND PUH TO 8000' AT 65%. RBIH TO TAG SAND TOP. TAG AT 11930' CTM, WAIT AND RE-TAG AT 11917' CTM. «< CONTINUED ON WSR 21-FEB-04 »> 02/21/04 CTU #9: SCAB LlNERIEXTENDED TUBING PATCH. «< CONTINUED FROM WSR 21-FEB- 04 »> RBIH AND CLEANOUT TO 11965' CTM, CHASE OUT TO 9,700' WHILE CIRCULATING BU AT MAX RATE. RBIH AND RE-TAG AT 11952' CTM. POOH. MU 2-3/8" CONNECTOR AND DART CATCHER, PUMP DART TO VERIFY COIL VOLUME. RIH WIPDS MEMORY GR/CCL, LOG FROM 11,926' TO 7,000' CTM. FLAG PIPE AT 10,000, RBIH POOH LAYING IN FLO PRO, PERFORM NO FLO TEST, FREEZE PROTECTED WELL WHILE POOH. LAY DOWN LOGGING TOOLS AND GO TO WEATHER STANDBY. TIE IN COIL LOG W/BHC 11-JAN-1987. ADDED 24.5' TO TIE-IN. CORRECTED SAND TOP 11,947' ELMD. WIND 25-45 MPH, TEMP -27 DEG F. CHILL -60. «< WEATHER STANDBY »> 02/22/04 CTU #9: SCAB LINER AND EXTENDED PATCH. CONTINUED FROM 2/21/04 WSR AFTER WEATHER STANDBY. MU AND DEPLOY 3-112" SCAB LINER. MU TO COIL AND RIH. RIH HAD HAVE TROUBLE WORKING WAY TO BOTTOM. WORKED 3-1~" LINER TO 11,935' ELMD AND LANDED. TOL @ 11,034' (TIE BACK SLEEVE C-2 4.5" OD, 4.0" ID). DROPPED BALL AND RELEASED FROM TOP OF LINER. VERIFIED WEIGHT, SET BACK DOWN AND CIRCULATED BOTTOMS UP. «< CONTINUED ON WSR 23-FEB-04 »> 02/23/04 Top of Cement @ 11901'-12058' Page 1 ~ ~ 11-27 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/23/04 CTU #9: SCAB LINER AND EXTENDED PATCH. «< CONTINUED FROM WSR 22-FEB-04 »> CIRCULATED BOTTOMS UP AND CEMENTED LINER IN PLACE WI 19.9 BBLS CLASS G CEMENT. TOL @ 11,034' ELMD. FLOAT HELD, PRESSURED UP ON COIL AND POOH FROM LINER. COIL PULLED HEAVY AND HAD TO BE WORKED OUT OF HOLE UP TO -9600 FT. AND THEN PULLED NORMAL WEIGHT OOH. LAY DOWN TOOLS. RIH WITH 3.5" JSN TO 11025' CTM (TAG) AND JET OUT TIE BACK SLEEVE WITH 40 BBLS BIO. GOT SOME SAND BACK IN RETURNS. POOH AT 80%. FP COIL AND WELL, PREP FOR CMIT AND PATCH WHILE WOC. AT 20 HOURS WOC, CMIT TXIA TO 2000 PSI, PASS. «< CONTINUED ON WSR 24-FEB-04 »> 02/24/04 CTU #9: SCAB LINER AND EXTENDED PATCH. «< CONTINUED FROM WSR 23-FEB-04 »> PU 4.2" OD BAKER 8040 GBH 22 LOCATOR TUBING SEAL ASSEMBLY, 13CR, W/1 BONDED SEAL UNIT LOCATOR SUB. LOCATOR 4.2" OD W/3-1/2" STL BOX X FULL MULE SHOE AND START RIH WITH 3-1/2" 13CR TUBING PATCH. FINISH RUNNING 118 FULL JNTS 3-1/2" 13CR PATCH + PUPS, MU BAKER 5-1/2" X 4.0" SLPR LINER HANGER PACKER W/3-1/2" STL PIN. HANG OFF IN BOP'S. RAIST MAST AND PU INJECTOR «< JOB CONTINUED WSR 25-FEB-04 »> 02/24/04 CTU #9: SCAB LINER AND EXTENDED PATCH. «< CONTINUED FROM WSR 23-FEB-04 »> PU 4.2" OD BAKER 8040 GBH 22 LOCATOR TUBING SEAL ASSEMBLY, 13CR, W/1 BONDED SEAL UNIT LOCATOR SUB. LOCATOR 4.2" OD W/3-1/2" STL BOX X FULL MULE SHOE AND START RIH WITH 3-1/2" 13CR TUBING PATCH. FINISH RUNNING 118 FULL JNTS 3-1/2" 13CR PATCH + PUPS, MU BAKER 5-1/2" X 4.0" SLPR LINER HANGER PACKER W/3-1/2" STL PIN. HANG OFF IN BOP'S. RAIST MAST AND PU INJECTOR «< JOB CONTINUED WSR 25-FEB-04 »> 02/24/04 CTU #9: SCAB LINER AND EXTENDED PATCH. «< CONTINUED FROM WSR 23-FEB-04 »> PU 4.2" OD BAKER 8040 GBH 22 LOCATOR TUBING SEAL ASSEMBLY, 13CR, W/1 BONDED SEAL UNIT LOCATOR SUB. LOCATOR 4.2" OD W/3-1/2" STL BOX X FULL MULE SHOE AND START RIH WITH 3-1/2" 13CR TUBING PATCH. FINISH RUNNING 118 FULL JNTS 3-1/2" 13CR PATCH + PUPS, MU BAKER 5-1/2" X 4.0" SLPR LINER HANGER PACKER W/3-1/2" STL PIN. HANG OFF IN BOP'S. RAIST MAST AND PU INJECTOR «< JOB CONTINUED WSR 25-FEB-04 »> 02/25/04 CTU #9: SCAB LINER AND EXTENDED PATCH. «< CONTINUED FROM WSR 24-FEB-04 »> RIH WISLPR LINER PACKER HANGER AND 3-1/2" 13CR LINER WISEAL ASSEMBLY. TAG C-2 SLEEVE AT 11027' CTM. ATTEMPT TO RIH AND GET IN SLEEVE. MAKE VARIOUS ATTEMPTS AND CAN'T GET MULE SHOE IN SLEEVE. POOH TO TURN PIPE. TURN PIPE 180? RIH WITH 3.5" PATCH ASSY. TAG AT 11027 (DOWN)., UNABLE TO ENTER DEPLOYMENT SLEEVE. POH WITH PATCH. JOB IN PROGRESS. 02/26/04 CONTINUED FROM WSR OF 2/25/04. SPOT EQUIPMENT AND PULL TUBING PATCH OUT OF HOLE. NO DAMAGE TO SEAL ASSY, SCARS ON MULE SHOE INDICATING SETTING ON TOP OF TIE IN SLEEVE. RD TBG RUNNING TOOLS.SECURE WELL. FP SURFACE LINES. PERFORM WEEKLY BOP TEST. JOB IN PROGRESS. 02/27/04 ASSIST CTU WITH PRESSURE TESTING. PREHEAT 25 BBLS DIESEL TO 90* AND PUMP TO WARM UP LINES. 02/27/04 CONTINUED FROM WSR OF 2126104. COMPLETE BOP TEST. AS PER BP I AOGCC LOW 200 PSI - HI 4000 PSI. CUT 98' COIL,. MU I MHA PT 22K,PT 200/4000PSI. MIU - RIH W/2 JOINTS 1-114" CS HYDRIL 11.75" JSN. JOB IN PROGRESS. CONTINUED ON 2/28/04 WSR. Page 2 ~ ~ 11-27 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/28/04 ***RIG UP ON COIL TUBING UNIT***. TAG TOP OF TIE-BACK SLEEVE @ 11,025' SLM WITH 4.50" CENT, DE-CENT., 4.50" LIB. LIB SHOWS TOP OF TIE-BACK SLEEVE NOT CENTERED IN TBG.. RIH WI 4.50 CENT 5.5 X-LINE 4.48 LIB SD @ 11025' SLM POOH ( UNABLE TO LOC X NIPPLE). LIB SHOWS SAME.. RDMO. GIVE WELL BACK TO CTD 02/28/04 CONTINUED FROM 2/27/04 WSR. RIH WI 1.75" NOZZLE W/2 JTS 1-114" CS HYDRIL. TAG HARD @ 11012' CTM. UNABLE TO JET THRU I INTO LINER TOP. POOH @ 80%. FREEZE PROTECT TO 2000' MD WI 60/40 METH. FP SURFACE LINES. MONITOR WELL FOR FLOW, WELL DEAD. SET BACK INJECTOR AND RU SLlCKLINE. RIH WITH 4.5" LIB. POH , LIB HAD IMPRESSION OF TIE BACK SLEEVE.OFFSET ON BLOCK INDICATION TBG OUT OF ALIGNMENT. RIH WITH 4.5" LlBAND XLiNE RUNNING TOOL FOR DEPTH CORRELATION. RIG UP TO PERFORM BOP TEST ON 5 1/8" BOP'S. JOB IN PROGRESS. 02/29/04 CONTINUED FROM WSR OF 2/28104. COMPLETE BOP TEST. RIH WITH 1.75" NOZZLE. CHANGE WELL FLUID TO CLEAN WATER FOR UPCOMING CAMERA DIAGNOSTIC RUN. FP TO 2500'. RDMO TO E-05 **** NOTIFY DSO WELL LEFT SHUT IN **** 03/11/04 **** WELL SHUT IN UPON ARRIVAL**** (SCAB LINER TUBING PATCH). UNABLE TO GET PAST TUBING HANGER WI 4.5" SWAGE.. RAN DHV SIL MEMORY CAMERA. PICTURE OF BPV. VECO PULLED BPV.. DRIFT WI 4.5" SWAGE TO TIEBACK SLEEVE @ 11009' SLM.. RUN DHV SIL MEMORY CAMERA. TAKE PICTURES FROM 11000' SLM TO 11009' SLM.. UNABLE TO SEE WI CAMERA BIC OF BLACK FLUID.. ****CONT ON 3- 12-04 WSR*** 03/12/04 ***CONT FROM 3-11-04 WSR***. UNABLE TO READ DATA FROM DHV MEMORY CAMERA BIC OF DARK FLUID.. DOWNHOLE WELL TEMP WAS 158 DEG @ 11009' SLM. RDMO.. ***WELL LEFT SHUT IN FOR FURTHER EVALUATION OF TIEBACK SLEEVE***(NO PERFS) 03/12/04 ***CONT FROM 3-11-04 WSR***. UNABLE TO READ DATA FROM DHV MEMORY CAMERA BIC OF DARK FLUID.. DOWNHOLE WELL TEMP WAS 158 DEG @ 11009' SLM. RDMO.. ***WELL LEFT SHUT IN FOR FURTHER EVALUATION OF TIEBACK SLEEVE***(NO PERFS) 03/18/04 ***WELL SII ON ARRIVAL** (SCAB LINER). MADE TWO ATTEMPTS W/4.5 LIB, SET DOWN @ 6366' (SLM).. UNABLE TO WORK PAST MANDREL, MARKS AROUND EDGE OF LIB.. CONTINUE TO 03/19/04.. 03/19/04 CONTINUE FROM 03/18/03 (DRIFT INTO LINER TOP). RIH W/OM-1 KOT, LIB, GOT PICTURE OF LATCH @ 6363' (SLM).. TAG TIE BACK SLEEVE @ 11,005 (SLM) W/4.5 LIB.. DRIFT WI 24.54' SCAB LINER WI NO GO WI BRASS TATTLETALE AND BLANK SEAL MANDREL, DRIFT TO 11010' SLM. NO-GO TATTLE TAILS SHOWS ENTRY INTO TOL. (PICTURES IN PROD ENG FOLDER ON S DRIVE). *** RESEARCH INDICATES TOP OF SCAB LINER 2-4' BELOW ORIGINAL PRODUCTION PACKER IN MOE ***. ***WELL LEFT SII. PLAN TO RU SERVICE COIL AND PLACE NEW PACKER WITH GUIDE PIPE INTO TOP OF SCAB LlNER*** 05/15/04 ***WELL SHUT IN ON ARRIVAL*** (MEMORY CCL-GAMMA COLLAR LOG). MADE 2 ATTEMPTS TO RUN MEMORY LOG. UNABLE TO GET THROUGH TIE BACK SLEEVE.. LIB @ OFFICE FROM PREVIOUS AWGRS SHOWS 1-1/2" LIP ON LOW SIDE.. DRIFT WI 2.75" TAPERED SWAGE, SAMPLE BAILER.. ABLE TO WORK THROUGH TOL. SAT DOWN @ 11356' SLM.. SET UP NEW MEMORY LOG TOOL W/3 ARM CENT.. ***CONT ON 5-16-04 WSR*** Page 3 ~ ~ 11-27 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/15/04 ***WELL SHUT IN ON ARRIVAL*** (MEMORY CCL-GAMMA COLLAR LOG). MADE 2 ATTEMPTS TO RUN MEMORY LOG. UNABLE TO GET THROUGH TIE BACK SLEEVE. . LIB @ OFFICE FROM PREVIOUS AWGRS SHOWS 1-1/2" LIP ON LOW SID 05116/04 ***CONT FROM 5-15-04 WSR*** (PRE SCAB LNR JEWELRY LOG). PERFORM PDS MEMORY JEWELRY LOG FROM 11370' SLM TO 10800' SLM.. GOOD DATA. RDMO.. ***WELL LEFT SHUT IN*** 08/08/04 CTU #5, SCAB LINER; MIRU DS CTU #5. RU 5-1/16" BOP STACK. PERFORM BOP TEST. MU & RIH WI BAKER STINGER SEAL ASS'Y WI ALUMINUM BULL NOSE. STAB STINGER SEAL ASSY INTO TIEBACK RECEPTACLE AT 11022' CTMD. PRESSURE UP AND RELEASE. POOH WI BAKER SETTING TOOL. CONT' ON WSR 8/09/04... 08/09/04 CTU #5, SCAB LINER; CONT' FROM WSR 8/08/04... POOH WITH BAKER SETTING TOOL. FP WELL FROM 2500' TO SURFACE WITH 50/50 METHANOL. RD DS CTU #5. . NOTE: EST. TOP OF STINGER TIEBACK RECEPTACLE IS 11015' MDBKB.. . *** JOB COMPLETE *** 08/20104 T/I/0=VAC/310/160. TBG AND IA FL'S. (D&D HOLE FINDER). TBG FL NEAR SURFACE. IA FL @ SURFACE. 08/20104 T/I/0=VAC/310/160. TBG AND IA FL'S. (D&D HOLE FINDER). TBG FL NEAR SURFACE. IA FL @ SURFACE. 08/23/04 CONTINUED TO 8-24-04 JOB IN PROGRESS. 08/24/04 CONTINUED FROM 8-23-04 **D&D HOLEFINDER WI SLlCKLlNE** CMIT TXIA TO 1000 PSI. FAIL. MITT TO 1000 PSI. FAIL. LOADED TUBING WITH 20BBLS CRUDE. SLlCKLINE SET TOOL AT VARIOUS POINTS IN TBG. ALL TESTS FAILED. RIGGED DOWN WITH SLlCKLINE STILL ON WELL. FLUIDS PUMPED BBLS 20 Methonal 1415 Water 1780 Crude 1796 1 % KCL 17 Neat Methonal 45 Diesel 1686 Xtra Slick KCL 46 FloPro 1021.5 60/40 Methonal/Water 202 KCL 19.9 15.8 ppg Class G Cement 62 Biozan 102 50/50 Methonal 8212.4 TOTAL Page 4 ST tv[) TVD 1 3586 3345 2 6388 5151 H 7846 6028 3 8067 6157 55 4 8932 6682 51 5 10878 7955 47 5" TLBIt-G TAIL I 11107' HELMDTTLOGGED02/O4/89 I 11901' 11878' ~ TREE = McEVOY WB.LHEAD = WCEVOY ACrtJATOR = AXELSON KB. ELEV = 58' BF. ELEV = KOP= 1900' Max Angle = 56 @ 7400' Datum MD - 12162' DatumTVD = 8800' SS 11-27 33' 2177' 13-3/8" CSG, 72#, L-80, ID = 12.347" Minimum ID =2.813" @ 11060' 3-112" OTIS X NIPPLE 10944' TOP OF 5-1/2" TBG 5-1 (2." lBG, 17#, L-80, .0232 bpf, ID = 4.892" TOP OF 7' L~ 11034' 5-1/2"TBG-FC, 17#, L-80, .0232 bpf,lD =4.892" 11048' 11060' TOP OF 5" TBG-FC 5" lBG-PC, 15#, L-80, .0232 bpf, ID = 4.406" 11115' 9-518" CSG, 47#, L-80, D = 8.681" 3-1/2" L~, 9.3#, 13-CR. .0087 bpf, ID = 2.992" 11935' PffiFORA TION SUMMA RY REF LOG: BHCS ON 01/10/87 At-GLEA TTOP ÆRF: 46 @ 11998' IIbte: Refer to Roduction DB for hisDrical perf data SIZE SPF INTERV AL OpnlSqz DUE 3-3/8" 4 11998-12029 0 07130/87 3-3/8" 4 12048 - 12062 0 09A>3/89 12100' 12210' ()II.TE RBI BY COMMENlS DATE REV BY COMMENTS 07/31/87 ORIGINAL COM PLErION 12/06103 ()II. V /fLP SAND TOP CORRECTION 06123198 LAST WORKOVER 12/28/03 J...J/PAG GL V C/O 01/04¡Q2 RNITP CORRECllONS 03/01/04 JGM/fLP TEBACK SLV, XNIP, PBTD, L~ 06101,\)2 DBMIKK SAND DUMP 08/08/04 SRB/fLP TEBACKSLV 06l13¡Q2 A TD/lP URCMT/SANDFCO,NEW PBTD 06l15¡Q2 RLITP ADD GL VLV INFO ~ SAFETY NOTES: 3-1/2" CHROME LNR 7"X 5-1(2." XO 5-1/2CAM BAL-O SSSV NP,ID =4.562" GAS LFT Mð.NDRELS DEV TYÆ VLV LATCH 48 LB DOME T-2 50 LB DMY T-2 HOLE CLEANOUT LB DMY T-2 LB DMY T-2 LB DMY T-2 FORT DA TE 16 12/23103 0 06112/02 HOLE 12/23103 0 0 0 9-5/8" X 5-1/2" BA KER S-3 PKR 5-1/2" He; X NIP, ID = 4.562" 5-112" UNOLE OVERSHOT 9-5/8" X 5-1/2" BAKERSB-3 A<R C-Z llEBACK SLY ,ID = 4.00" 02/23/04 5-112" X 5" XO PRUDHOE BAY ~rr WELL: 11-27 PERMIT lib: 1861480 API lib: 50-029-21638-00 SEC28, T11 N, R15E, 4134.88' FEL & 383825' FNL BP Exploration (Alas ka) lds C!\] I.. WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7"'Street Suite # 700 Anchorage, Alaska 99501 RE: Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 WELL DATE LOG TYPE DIGITAL OR CO-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR COLOR Open Hole 1 Res. Eva!. CH 1 1 1 ) 8to - It{g 11-27 5/15/04 ) ~ fA ì Mech. CH 1 Caliper Survey Print Name: I'~)/ ~ "I I / . J'4-0 .~ '\! t\ v' r\ {)jl~ cJ k L~Y\.l{ Date: ;( J- Jf'/"Vl ~ (tt.v{ Signed: PI(oAniv[ Dil\GNosrk SERvins, INC, PO Box I ~b9 Srl\lfORd TX 77477 Phone:(281) 565-9085 Fa~:(281) 565-1369 E-mail: pds.V.mcmorylog.com Wcbsitc: w\\w.memorylog.com j 8!.ç -/Lf~ ~s". WEU LOG TRANSM,"AL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7"'Street Suite # 700 Anchorage. Alaska 99501 RE: Distribution - Final Print[s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. AK 99508 WELL DATE lOG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S] REPORT OR CoLOR Open Hole 1 Res. Eva!. CH 1 1 1 OS 11-27 2-21-04 Mech. CH ) t) L¡~i Caliper Survey Signed: -.-~C \- ~ ~ \. C ~ ~ ~ Date: RECEIVED Print Name: ~1~.R 2 2 2004 Alaska Oil & GasCons. Commiaion AncIøage PROACTivE DÎAGNOSTic SERvicES, INC" PO Box I }b9 STAffoRd IX 77477 Phone:(28l) 565-9085 Fax:(28l) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com '" 'R~ ~ f\\ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abanonr'] SuspendE~] Operation ShutdownE~ Perforate[~] Vadancer'] Annuar Disposalr-~ After Casin.a[--I Repair WellD Plug Perforationsr"] Stimulate[-'l Time ExtensionD Other, Change Approved Program['"~ Pull Tubing[-~ Perforate New Pool[~ Re-enter Suspended Well[--] SAND PLUG 2. Operator 4. Current Well Class: 5. Permit to Ddll Number: Name: BP Exploration (Alaska), Inc. Development · Exploratory["'~ 186-148 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic[--~ Service~] 50-029-21638-00-00 7. KB Elevation (ft): 9. Well Name and Number: 58.00 11-27 8. Property Designation: 10. Field/Pool(s): ADL 028322 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 12210 feet true vertical 8891 feet Plugs (measured) Sand Plug Top @ 11878' (06/22/2003). Effective Depth measured 11878 feet Junk (measured) true vertical 8658 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 141' 141' 40K 520 Surface 2494' 13-3/8" 2525' 2491' 80K 2670 Intermediate 11311' 9-5/8" 11342' 8280' 80K 4760 Liner 1164' 7" 11046'-12210' 8071'-8892' 80K 7020 Perforation depth: Measured depth: Open Perfs 11998'-12029', 12048'-12062'~' JUl_ True vertical depth: Open Parrs 8742'-8764', 8777'-8787'. ,,'~ , , , ,. ,..., Tubing: ( size, grade, and measured depth) 7" 26# L-80 TBG @ 33'. 7" x 5-1/2" XO @ 33'. ,~.,'.i,~.=i,;.~..i,.~ 5-1/2" 17# L-80 Tubing @ 11048'. 5-1/2" x5" XO @ 11048'. 5" 15# L-80 Tubing @ 11115'. Packers & SSSV (type & measured depth) 9-5/8"x5-1/2" BKR S-3 PKR @ 10944'. 9-5/8"x5-1/2" BKR SB-3 PKR @ 11026' 5-1/2" Camco BAL-O SSSV Landing Nipple @ 2177'. 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casin~ Pressure Tubin~l Pressure Prior to well operation: SHUT-IN Subsequent to operation: SHUT-IN 14. Attachments: 15. Well Class after proposed work: Exploratoryr-I Development~ Servicer'l Copies of Logs and Surveys run _ 16. Well Status after proposed work: o,· ~asl-I WA~I--I ~NJI--! W~NJI--IWDSP'I--I Daily Report of Well Operations ~X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A if C.C. Exempt: Contact DeWayne R. S~ffn-'Gl~' " I N/A ,t,e Signature ~"~,~'~¢,~,'~,-,' Phone 907/564-5174 Date June 23, 2003 " D Form 10-404 Revis~~~,-~''' JUL 0 9 2003 ORIGINAL 06/09/2003 06/11/2003 06/16/2003 06/16/2003 06/17/2003 06/17/2003 06/18/2003 06/21/2003 06/22/2003 06/09/03 06/11/03 06/16/O3 06/16/03 06/17/03 06/17/03 06/18/03 11-27 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PATCH TUBING PATCH TUBING PATCH TUBING PATCH TUBING PATCH TUBING PATCH TUBING PATCH TUBING PATCH TUBING PATCH TUBING / LINER: / LINER: / LINER: / LINER: / LINER: / LINER: / LINER: / LINER: / LINER: TUBING TAIL PLUG AC-FLUID LEVEL SAND PLUG LOAD WELL TO SECURE SAND PLUG PATCH TUBING / CASING SAND PLUG DRIFT/TAG DRIFT/TAG EVENT SUMMARY WELL SHUT-IN ON ARRIVAL. PULLED PRONG FROM PLUG BODY @ 10,936' SLM. PULLED PX PLUG BODY FROM X-NIP @ 10,939' SLM. RAN HES GAUGES, T.T. @ 11072' SLM, +35' CORRECTION TO 11107' ELM. TAGGED BOTTOM @ 11980' SLM + 35'= 12015' CORR DEPTH. PERFS 11998-12062 (17' OPEN PERFS/47' OF FILL). STOP @ T.D FOR 45 MIN W/10 MIN STOP IN LUBRICATOR BEFORE & AFTER. WELL LEFT SHUT-IN. TIO=2400/2150/100. WELL IS SHUT-IN. TUBING, IA FL's. (PRE SAND DUMP FOR COIL). TUBING FL @ 7898' OR 183 BBLS. IA FL @ 5264' OR 230 BBLS. MIRU UNIT #9. KILL WELL WITH KCL. BLEED IA AND LOAD WITH CRUDE. MIX AND PUMP 7 BBLS RIVER SAND. ESTIMATE TOS @ 11935'. WAIT ON SAND TO SETTLE. TAG SAND @ 11979'. DROP BALL AND JET CSG/TUBING FROM 11950' TO 11000'. RBIH &TAG @ 12018'. SAND PLUG GONE. POH TO RECOVER BALL. REKILL TUBING AND RIH. TAG @ 12028' (UP). (ALL DEPTHS FROM THIS POINT ON REFERENCE CTMD). LOAD TUBING WITH 70 BBLS CRUDE. BEGIN LAYING IN SAND PLUG #2. JOB IN PROGRESS. LOAD AND KILL IA/THEN HOLD PRESSURE DURING COIL SAND PLUG OPERATION. LAY IN SAND PLUG FROM 12025 CTMD (12018 ELMD). WAIT TO LET SAND SETTLE. LAY IN SAND FROM 11980 CTM. WAIT ON SAND TO SETTLE. RIH TAG @ 11904' CTM. PUH WAIT ON SAND TO SETTLE, SQUEEZE AND TAG SAND AT 11891' CTM PUSH DOWN TO 11893' CTM. FINAL TAG ON PLUG IS 11890'. REVERSE OUT SAND TOP TO 11930' CTM. JOB IN PROGRESS. PUMPED FOR COIL TUBING SAND PLUG. PUMPED 115 BBLS CRUDE FOR TESTING SAND PLUG. PUMP FLO-PRO SWEEP TO CLEAR COIL. CIRCULATE IN KCL TO REPLACE CRUDE. RETAG SAND TOP @ 11897' (UP). SWAP TO REVERSE OUT TO 11930' CTMD (DOWN). AS REVERSE FILL UP COIL LOOSE WHP. Page 1 11-27 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 06/18/O3 (CONTINUED) SWAP AND PUMP TO CLEAR COIL. PUMP AT 2 BPM FOR 38 BBLS. 50% RETURNS. RETAG TD @ 11925' CTMD. POH. ESTIMATED OVERBALANCE TO FORMATION WITH FLUIDS LEFT IN WELL IS 200 PSI. NOTIFY DSO THAT WELL REMAINS SI. 06/21/03 <<< WELL SHUT-IN ON ARRIVAL >>> (POST CT SAND PLUG - PRE SCAB LINER). RIGGED UP SLICKLINE. RUNNING IN HOLE W/3.625 CENT, TEL & SB. O6/22/O3 (POST CT SAND PLUG - PRE SCAB LNR). DRIFTED TO TOP OF SAND W/ 3.625" CENT, TEL & SB (LOC TT @ 11068' SLM + 39'= 11107' CORR TO ELM -- TAG TOP OF SAND @ 11839' SLM + 39'= 11878' CORR TD (120' OF SAND COVERING TOP PERF @ 11998'). (BAILER FULL OF SAND). <<< LEFT WELL SHUT IN >>> FLUIDS PUMPED BBLS 10 METHANOL 63 50/50 METHANOL WATER 718 CRUDE 1078 1% KCL WATER 109 FRESH WATER 42 GEL/SAND MIXED @ 8 PPG 5 FLO-PRO 2025 TOTAL Page 2 TREE = Mc EVOY I WELLHEAD = rvlCEVOYI SAFETY NOTES: 11-27 KB. ELEV = 58' BF. ELEV = ~o.= ~oo, 2X ~ ~ ~. l-t~"x~,,~'×oI 'u~ A~ = 56 ~ 7400' // ' ' 12162' Datum MD = Dat. mrVD= ~00'SS~? ~ ~, 2177 ~5-1~2CAU~AL-OSSSVN~',~D=4.5~"I IT°~°Fs'I~2''Tm I--[ aa'[ ~ASL~'~mm_S I13-3/8"CSG, 72#, L-80,1D =12.347' H 2525' · ST IvD TVD DEV TYFE VLV LATCH PORT DATE ! 1 3586 3345 48 LB oorvE T-2 16 06/12/02 2 6388 5151 50 LB S/O T-2 20 06/12/02 3 8067 6157 55 LB T-2 Minimum ID = 4.313" @ 11094' 4 8932 6682 51 LB T-2 5-1/2" OTIS X NPPLE ; 5 10878 7955 47 LB T-2 [::x:: X I 10944' HS-5/8"XE-1/Z'BAKERS-3PKR] I ; I I~o,o,~-~,~'~.~1--[ ,00~' ]--.._]: ,~ ' 10998' 1--15-1/2"UN'QUEOVERSHOTI [ 5'I/2"TBG, 17#, L-80,0.0232bpf, ID=4. O9Z' H 11006' X E::x: [ 11026' Ho-5/8,,x5-1/Z' BAKER SB-3 PKR I I.o~ o~ ~,.~. I-I ~o.~'; I~.~,,..~-.c, ~#,.-~o,o.o~,~,.o:~.oo~' I-I .o.~' I ' ~o~s' I-I~-~"x~"xol I -' ~ 1100~' I--~5"OT~XN~,~D=4.312"I I I~''*~-~,~#,'-~°,°'°~*,'~--4'~°~'' H ~' I ~I~FOR~TION S~hi~lA RY U REF LOG: BHGS ON 01110187 ANGLEATTOP PERF: 46 @ 11998' Note: Refer to R'oductJon DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11998-12029 O 07/30/87 3-3/8" 4 12048-12062 O 09/03/89 17"LNa, 29#, L-80, 0.0371~p*, ID = 6.184" ~ 12~10' I I DATE REV BY COMIVENTS DATE REV BY I COMMENTS PRUDHOEBAY UNIT 07/31/87 ORIGINAL COMPLETION 06/01/02 DBIVVKK SANDDUMP WELL: 1t-27 06/23/98 LAST WORKOVER 06/13/02 ATD/TP UR CMT/SAND FCO, NEW FBTD PI~MIT No: 1861480 01/15/01 SIS-MH CONVERTEDTOCANVAS 06115102 RLfTP ADD GL V LV INFO ARNo: 50-029-21638-00 01/22/01 SIS-MD FINAL SEC 28, T11N, R15E 4134.88 FEL 3838.25 FNL 01/04/02 RN/TI3 CORRECTIONS BP Exploration (Alaska) SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11998-12029 O 07/30/87 3-3/8" 4 12048-12062 O 09/03/89 DATE REV BY COMMENTS DATE REV BY COMMENTS 07/31/87 ORIGINAL COMPLETION 06/01/02 DBM/KK SANDDUMP 06/23/98 LAST WORKOVER 06/13/02 ATD/TP UR CMT/SAND FCO, NL:W FBTD 01/15/01 SIS-MH CONVERTEDTOCANVAS 06/15/02 RLfl-P ADDGLVLV INFO 01/22/01 SIS-MD FINAL 01/04/02 RN/'rP CORRECTIONS STATE OF ALASKA ALASK,, OIL AND GAS CONSERVATION C~.,v~MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Pull Tubing []Alter Casing 2. Name of Operator ARCO Alaska Inc. 5. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 451' NSL, 229' WEL, SEC. 28, T11 N, R15E, UM At top of productive interval 928' NSL, 1355' EWL, SEC. 21, T11N, R15E, UM At effective depth 1412' NSL, 1140' EWL, SEC. 21, TllN, R15E, UM At total depth 1441' NSL, 1129' EWL, SEC. 21, T11N, R15E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural 12210 feet 8891 feet 12166 feet 8859 feet Length Size E~ Plugging [] Perforate [] Repair Well [] Other Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 9. 10. 1. i~ EL, E ! V Plugs (measured) Junk (measured) 6. Datum Elevation (DF or KB) 58' RKB 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 11-27 Permit Number / Approval No. 86-148 APl Number 50-029-21638 Field and Pool Prudhoe Bay Field / Prudhoe Bay EL) 1998 Alaska 0il & Gas Cons. Commission Anchorage Cemented MD TVD Conductor 110' 20" Surface 2525' 13-3/8" Intermediate Production 11342' 9-5/8" Liner 1164' 7" 200 cu ft Poleset 2500 sx CS Ill, 400 sx CS II 500 sx Class 'G', 300 sx AS I 350 sx Class 'G' 110' 110' 2555' 2518' 11368' 8297' 11046'-12210' 8070'-8859' Perforation depth: measured 11998' - 12029', 12048' - 12062' true vertical 8742'- 8764', 8777'- 8787' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 to 11006', 5-1/2", 17#, L-80 11006' - 11048', 5", 15#, L-80 11048'- 11115' Packers and SSSV (type and measured depth) Camco BaI-O SSSV at 2177; Baker S-3 packer at 10944'; Baker SB-3 packer at 11026' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 5. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed e~-------'~_ ~,~ Dan Ston Title Engineering Supervisor Prepared By Name/Number: I16. Status of well classifications as: [] Oil [] Gas [] Suspended Service Date Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicat,6 Facility Date/Time 17 Jun 98 18 Jun 98 19 Jun 98 20 Jun 98 21 Jun 98 22 Jun 98 Progress Report PB DS 11 Well 11-27 Page 1 Rig Doyon 14 Date 21 July 98 11:00-18:30 18:30-06:00 06:00-15:00 15:00-21:00 21:00-22:30 22:30-23:30 23:30-00:00 00:00-00:30 00:30-01:00 01:00-03:45 03:45-04:30 04:30-06:00 06:00-06:15 06:15-08:45 08:45-10:00 10:00-11:00 11:00-11:15 11:15-11:30 11:30-11:45 11:45-12:00 12:00-13:00 13:00-14:15 14:15-15:30 15:30-16:15 16:15-20:00 20:00-20:45 20:45-02:00 02:00-03:00 03:00-04:00 04:00-04:15 04:15-06:00 06:00-13:30 13:30-15:00 15:00-18:00 18:00-18:30 18:30-19:00 19:00-19:15 19:15-04:30 04:30-05:00 05:00-06:00 06:00-07:00 07:00-10:00 10:00-11:00 11:00-14:00 14:00-14:30 14:30-15:15 15:15-15:30 15:30-06:00 06:00-07:30 07:30-11:00 11:00-12:00 12:00-13:30 13:30-14:00 14:00-15:30 Duration 7-1/2 hr 11-1/2 hr 9hr 6hr 1-1/2 hr lhr 1/2 hr 1/2 hr 1/2 hr 2-3/4 hr 3/4 hr 1-1/2 hr 1/4 hr 2-1/2 hr 1-1/4 hr lhr 1/4 hr 1/4 hr 1/4 hr 1/4 hr lhr 1-1/4 hr 1-1/4 hr 3/4 hr 3-3/4 hr 3/4 hr 5-1/4 hr lhr lhr 1/4 hr 1-3/4 hr 7-1/2 hr 1-1/2 hr 3hr 1/2 hr 1/2 hr 1/4 hr 9-1/4 hr 1/2 hr lhr lhr 3hr lhr 3hr 1/2 hr 3/4 hr 1/4 hr 14-1/2 hr 1-1/2 hr 3-1/2 hr lhr 1-1/2 hr 1/2 hr 1-1/2 hr Activity Rigged down Drillfloor / Derrick Rig moved 60.00 % Rig moved 100.00 % (cont...) Rigged up Drillfloor / Derrick Installed Circulating head Retrieved Hanger plug Held safety meeting Circulated at 11000.0 ft Tested Xmas tree Circulated at 11000.0 ft Installed Hanger plug Removed Xmas tree Removed Xmas tree (cont...) Installed BOP stack Retrieved Hanger plug Monitor wellbore pressures Made up BHA no. 1 R.I.H. to 32.0 ft Fished at 32.0 ft Pulled out of hole to 0.0 ft Laid down 200.0 ft of Tubing Installed Retrievable packer Removed BOP stack Removed Tubing head spool Installed Tubing head spool Installed BOP stack Tested BOP stack Retrieved Retrievable packer Rigged up Completion string handling equipment Held safety meeting Laid down Tubing of 2000.0 ft Laid down 11000.0 ft of Tubing (cont...) Rigged up Slickline unit Conducted slickline operations on Slickline equipment - Tool run Rigged down Slickline unit Rigged up Drillstring handling equipment Rigged up sub-surface equipment - Retrievable packer Singled in drill pipe to 10987.0 ft Set packer at 10987.0 ft with 3000.0 psi Tested Casing Serviced Block line Pulled out of hole to 6500.0 ft Repaired Handling equipment Laid down 6500.0 ft of 5in OD drill pipe Rigged down sub-surface equipment - Retrievable packer Rigged up Completion string handling equipment Held safety meeting Ran Tubing to 11004.0 ft (5-1/2in OD) Rigged up Tubing hanger Circulated at 10990.0 ft Installed Tubing hanger Rigged up Slickline unit Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Tool run Facility Date/Time 23 Jun 98 Progress Report PB DS 11 Well 11-27 Page 2 Rig Doyon 14 Date 21 July 98 15:30-17:30 17:30-18:00 18:00-19:00 19:00-19:15 19:15-20:00 20:00-20:30 20:30-21:00 21:00-22:00 22:00-22:15 22:15-23:00 23:00-01:15 01:15-01:30 01:30-03:30 03:30-05:00 05:00-06:00 06:00-06:30 06:30-07:30 07:30-08:00 Duration 2hr 1/2 hr lhr 1/4hr 3/4 hr 1/2 hr 1/2 hr lhr 1/4 hr 3/4 hr 2-1/4 hr 1/4hr 2hr 1-1/2 hr lhr 1/2 hr lhr 1/2 hr Activity Conducted slickline operations on Slickline equipment - Setting run Conducted slickline operations on Slickline equipment - Setting run Rigged up Slickline unit Set Production packer at 10944.0 ft with 1500.0 psi Tested Tubing Tested Casing Rigged down High pressure lines Installed Hanger plug Held safety meeting Removed BOP stack Installed Xmas tree Tested Xmas tree Retrieved Hanger plug Freeze protect well - 150.000 bbl of Diesel Circulated at 2200.0 ft Circulated at 2200.0 ft (cont...) Installed Hanger plug Functioned Xmas tree GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9670 Company: 8/25/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Log Description Date BL RF Sepia DIR MWD Disk -j D.S. 4-19-'~ 95291 USIT 950817 I 1 D.S. 4-19.~ // 95291 CBT 950818 I 1 D.S. 11-27// 95265 CNTG 950730 I SIGNED' AUG 2 5 1995 ~,i~.J:)ii & ,G_a! C{~ns., .... Commission ~11~44Ul dy~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 8/24/95 NO. 9660 GeoQuest 500 w. International Airport Road ~, Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99518-1199 ~. ~ Attn: Larry Grant AI-rN: Sherrie , (~ l~fl~ \ 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 15-33 95250 DUAL BURSTTDT-P 950623 1 D.S. 5-36 q I ? ~' PROD PROFILE 950731 1 1 D.S. 6-08 '-7 ~ .Z-'Z-- LEAK DETECTION 950729 1 1 D.S. 7-33 ~C~ ~-~ ~' DUAL BURST TDT-P 950729 I 1 O.S. 11-27 ~'~' {~ I~'~'~' CNTG 950730 I 1 D.S. 11-32 ~L~ ',~'Z2~ PERF RECORD 950730 1 1 D.S. 12-01~7C( ~-'_~~ _. PRODLOG 950728 1 1 D.S. 12-12 ~{ ~ ~_~ GAS LIFTSURVEY 950727 1 1 D,S. 12-28 ~ ~ .O .~ I PROD PROFILE 950725 I 1 D.S. 12-29 ~,~ O ,'~ ""Z.- PROD PROFILE 950725 I 1 D.S. 13-3'7~ ~(~ "Z.- PROD PROFILE 95 0731 I .. 1 D.S. 15-1 ~:f'~"~-~ ()O/~ DUAL BURST TDT-P 950726 I 1 D.S 15-13 T~ I I~-.,?'~, DUAL BURST TDT-P 950727 1 1 D.S, 15-25" ~ ¢3 ~ DUAL BURST TDT-P 950725 1 1 D.S. 17-20 ~7..-- II ~ PERFRECORD 950730 I 1 D.S. 18-02A /3' c"'" ~., '") f,~ PERFRECORD 950726 I 1 D.S. 18-02A -! _3 LJ~'~-" PROD FLUID SAMPLER 950722 I I , r, ,,. ... - . 41a~ka Oil &.Sa~ Cons. SIGNED DATE: Anchorage ¢°rnr~isSion Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie RECEIVED APR I 2 1995 Alaska 011 & Gas Cons. Commission Anchorags NO. 9391 Company: 4/1 1/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 6-9 ~ 95055 CNTD 01 2395 1 D.S. 4-35 ~ 95085 DUAL BURST-TDT-P 022895 1 D.S. 14-3 ""J 94187 REDO CNTD 0328941 1 D.S. 2-16A'"-J 95147 REDO MWDGR 102394, 1 D.S. 1-06 "'-J 94399 REDO DUAL BURSTTDT-P 061394 1 ,. D.S. 4-19 "J 95106 DUAL BURST TDT-P 031795 1 D.S. 9-36 BL'''''-J 95025 MWDGR 101294 1 D.S. 1-06A'"-J CBT 032495 I 1 D.S. 1-06A"'-J CNTG 032495 I 1 ,., D.S. 1-22A "',J PERF RECORD 033095 I 1 D.S. 4-12"'"'-'x CBT 032695 I 1 D.S. 4-12 ~ TUBG PUNCHER RECORD 032395 1 1 D.S. 6-8 ~ PERFRECORD 032595 I 1 D.S. 7-24 '--,3 PERFRECORD 032695 1 1 D.S. 11-27 "--,3 BASE LINE SURVEY 032395 1 1 D.S. 9-36 BL'''J MWD GR (MD) 102194 I 1 D.S. 9-36 BL "'J MWD GR (TVD) 1 021 94 I 1 D.S. 9-36 BL ""--J MWD GTF (MD) 1 021 94 I I 7~-51 -/8- I~ PLEASE NOTE: D.S. 14-3 REDO - ORIGINAL WAS MISSING FILE #4 D.S. 2-16A REDO - MERGED TWO PREVIOUS RUNS TOGETHER (JOB # 93560 & 93561) w,o, DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9366 Company: 3/23/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk 4~VDW 2-1 STATIC TEMP-INJ PROF 031 795 I 1 O.S. 02-13 POGLM SETTING RECORD 031 095 I 1 D.S. 03-09 PERFRECORD 031095 1 1 D.S. 3-29 PERFRECORD 031 895 I 1 D.S. 4-12 TUBG PUNCHER RECORD 030395 I 1 D.S. 4-38 TUBG CUTTER RECORD 031 695 I 1 D.S. 7-18 PROD PROFILE 030495 I 1 D.S. 11-27 BASELINE TEMP 031795 I 1 D.S. 12-14 ST1 PERFRECORD ' 030495 I 1 D.S. 12-34 ROPE PERF REC/FLD DET 030795 I 1 D.S. 16-13 PROD PROFILE 030695 I 1 D.S. 16-27 PERF RECORD 031 895 I 1 D.S. 1-22A 95049 DUAL BURSTTDT-P 020395 1 D.S. 4-37 95037 CNTD 01 2095 I SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED DATE: 1 1995 . _ Alaska Oil & Gas Cons. C0mmissj.0n Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 8-10-93 REFERENCE: ~z~~2- 21 -36 -36 -36 7-17-93 Eh_~al Burst TDTP Rnn 1, o . oc 7-25-93 Perf Record R~_m 1, 5'd°z~q- 5" I~°~l~lc 7-15-93 USIT ~lor Rnn 1, cn 7-20-93 Pe~ Record Rnn 1 5" , h 7-24-93 Perf Record I z~4~4;~o R~_m 1, 5" Sch 7~i~_~ 4-12 7-18-93 CNL ~l~-~zs Rnn 1, 5" Sch t~ * 4-16 7-19-93 ~ml Brat ~P ~~~ 1, 5" Sch q~~4-40 7-22-93 ~ ~tect z~-f%~ Rnn 1, 2"&5" Sch ~~~-1 7-23-93 Pe~ Record ~5-~ Rnn 1, 5" Sch ~~-29 7-22-93 ~od ~offie ~-1o5~5 Rnn 1, 5" ~ Sch ~~-32 7-22-93 ~od ~offie 101~-,!,~ Rnn ], 5" '~' '":"'"" ch ~~~ 1-27 7-18-93 ~ml B~t ~ R~m l, 5" ~~ch -~~~ 4-4 7-24-93 ~~~ 5-3 7-14-93 ~m! Brat T~ R.n 1, ~ _ ._ ocn ~~~5-4 7-24-93 ~ B~t ~ Rnn 1, ~,,~lo~o~ . ~~15-13 7-24-93 C~ Rnn 1, ~V~5-14 7-25-93 C~ Ivq%-x~ Rnn 1, 5" ~h ~~6-9A 7-26-93 ~uc~on ~ga~l~~~ 1, 2"&5" Sch ~~17-3 7-20-93 ~uc~on ~g Ron 1, 2"&5" Sch Plebe s~ ~d ret~ ~e at~ched copy RECEIVED BY - ~.~.~ ..~ . ATO- 1529 ~s~ 93~2 '::',¥~,:., . ,,/ # CENTRAL FILES # CHEVRON D&M # CLINT CHAPMAN # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILF~ R&D # BPX # STATE OF ALASKA TEXACO The correct bottom logged Interval for 4-16 is 11,507 feet. ARCO Alaska, Inc. Post Office F'~--100360 Anchorage, ,a 99510-0360 Telephone 907 276 1215 August 10, 1993 Ms. Joan Miller Alaska Off and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Outstanding Application Approvals Dear Ms. Miller: Per your 7/30/93 letter to Mr. James Cawvey, regarding the listed outstanding 10-404's (Report of Sundry Well Operations), the following summary is provided: 7a-a 1) Well 1-16' Approval # 8-988, Approved 12-28-88. Report Sundry attached covering Reperforating work. Well 3-16i: Approval # 9-740, Approved 8-23-89. Report Sundry attached covering Acid Stimulation, Squeeze, & Reperforating work. Well 3-16i: Approval # 91-234, Approved 8-6-91. Report Sundry covering Perforatiing work was completed & sent to AOGCC 11/91. A copy of Lhis Report is attached. Cement previously Well 5-18' Approval # 9-993, Approved 11-15-89. Report Sundry attached covering Initial Perforating work. Well 5-26:.~Approval # 90-060, Approved 2-1-90. The approved Stimulation work for 2/90 was never-performed. Please ;cancel:'this approval. 6) Well 7-06:' Approval # 90-666, Approved 8-27-90. The approved Gas Shutoff work for 9/90 was never performed. Please-cancel this approval. Well 11-2: Approval # 90-066, Approved 2-6-90. Report Sundry attached covering Tubing'Washes Reperforating work. R E C E IV ~ D ARCO Alaska, Inc. Is a Subsidiary of Allantlc Richfield Company AU 6 1 9 t99; Alaska 0ii & Gas Cons. Commissio~ Anchorage Ms. Joan Mi August 10, Page 2 %'b-''\~ 9) Well 11-27: Approval # 9-750, Approved 8-24-89. Report Sundry covering Perforatiing work was completed & sent to AOGCC 9/89. A copy of this Report is attached. previously Well 12-25: Approval # 92-019,' Approved 2-4-92. The approved Pull Tubing work for 2/93 was never performed. Please cancel this approval. Well 15-8: Approval # 90-526, Approved 7-12-90. The approved Stimulation work for 8/90 was performed 3/91. The Report Sundry is attached. Well 15-10A: Approval # 90-463, Approved 6-19-90. The approved Pull Tubing work for 8/90 was never.-performed. Please cancel this approval. 12) Well LGI-4: Approval # 90-852, Approved 12-3-90. Re: the approved Stimulation/Reper£orating work for 11/90: Since this is a Lisburne Well, reconciliation of this approval will be handled by the Lisburne Operations Group. I will notify the person responsible, in the Lisburne group to handle this outstanding Report Sundry. WGI-3: Approval # 8-76, Approved 2-10-88. Report Sundry attached covering Stimulation Treatment work. Sincerely, Engineering Aide JWP/OIO Attachments cc..~]J. L. Cawvey - (ARCO) - ATO- 1520 ' M. Sloan - (BPX) - Drilling Dept. RECEIVED A U G I 9 .t 95 Alaska Oil & Gas Cons. Commission Anchorag. STATE OF ALASKA ¢J ~ ( / / 'c,z ' /..J //..J! '" ,D -. A' - 'A OIL AND GAS CONSF~VATION COMI~' ION REPOF.' OF SUNDRY WELL OPEI,,.,;"IONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging_ -Pull tubing __ Alter Casing __ Repair well 2. Name of Operator ARCO Alaska, Inc. Perforate __ Other .... Datum elevation (DF or ~K~,')'/'~/-~ ? / 58' RKB 3. Address P.O. Box 100360 Anchorage, AK 99510 Type of Well: Development x Exploratory Stratigraphic Service Location of well at surface 451' FSL, 229' FEL, Sec. 28, T11N, R15E, UM At top of productive interval 928' FSL, 1355' FWL, Sec. 21, T11N, R15E, UM At effective depth 1412' FSL, 1140' FWL, Sec. 21, T11N, R15E, UM At total depth 1441' FSL, 1129' FWL, Sec. 21, T11N, R15E, UM 12. Present well condition summary: 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 11-27 9. Approval number 9- 7 5 0 <~(,cr 0. APl number 5 0-0 2 9-216.38 Field/Pool i rhl F Bay Poo ~.,LI ¥ Total depth: measured I 2 21 0 feet Plugs (measured) true vertical 889 1 feet Effective depth: measured I 2 1 6 6 feet Junk (measured) true vertical 8859 feet Casing Length Size Cemented Conductor I 10' 20" 200 cuft Poleaet Surface 2525' 13-3/8" 2500 ax CS III 400 ax CS II Production 11342' 9-5/8" 500 ax Claus G 300 ax AS I Liner 1164' 7" 350 ax Class G AU G 1 9 t993 Alaska 0il & Gas Cons. U~'~ss~l' Anchorage Measured depth True vertical depth 110' 110' 2555' 2518' 11368' 8297' 11046'-12210' 8070'-8859' Perforation depth: measured 11998'- 12029', 12048"- 1 2062' true vertical 8742'-8764', 8777'-8787' Tubing (size, grade, and measured depth): 5-1/2", 17#, L-80, 5", 15#, L-80, PC, Packers and SSSV (type and measured depth): - PC, 0'-11048' MD 11048'-11115' MD Camco BaI-O SSSV @ 2225' MD Baker SB-3 Packer @ 11026' MD 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Averaqe Production orlniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 2583 5473 0 N/A 3705 9109 0 N/A Tubing Pressure 1251 840 15. Attachments 116. Status of well classification as: I Copies of Logs and surveys run __ Daily Report of Well Operations x Oil x Gas __ Suspended Service 17. I hereby/cprtify that t_he foregoing is true and correct to the best of my knowledge. Signed Form 10-404 Rev 10/01/88 / / SUB-MIT IN DUISLICATE SUMMARY OF WELL OP~,~ATIONS ARCO Alaska, Inc. p~,rforated DS 11-27 at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit on 9/3/89 (12048'-12062' MD, Ref Log: BHCS 1/11/87). This well was perforated approximately 500 psi underbalanced and flowed to clean-up. The wellbore fluid at the time of perforating was the produced fluids; oil, water, and gas. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. The SSSV was installed at the conclusion of the perforating and clean-up operation. A short summary of the work is given below. - Began perforating operation on 9/3/89. - RU perforating unit and pressure tested equipment to 3500 psig. - RIH w/ gun #1, tied-in, and shot 12048'-12062° MD @ 4 SPF. - SI well. - POOH. All shots fired. - Secured well. RD. RE.¢EIVED AU O 1 9 t99 5 Alaska Oil & Gas Cons. commiSSion Anchorage ~LASKA OIL AND GAS CONSEI~V~kTION CO~I~IIS$1ON .j WALTER J. HICKEL, GOVERNOR ~. 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-14,33 TELECOPY: (907) 276-7542 July 30, 1993 Mr. James L. Cawvey Engineering Supervisor ARCO Alaska lnc P.O. Box 100360 Anchorage, AK 99510-0360 Re: Prudhoe Bay Unit, AOGCC Forms 10-403 and 10-404 Dear Mr. Cawvey, In making a review of well files we have found some files which contain approved Application of Sundry Approval forms (form 10-403) that have no subsequent Reports of Sundry Well Operations (form 10-404). Enclosed a list of the wells in question. To be in compliance with AS 20 AAC 25.280(d) of the Regulations, the form 10-404 is required to be filed with 30 days following completion of work. We would also appreciate notification of any canceled work So that the corresponding Application on file can be marked accordingly. Your help in directing the enclosed list to the appropriate responsible parties will be appreciated. Sincerely, Joan Miller Statistical Technician PRUDHO~ BAY - ARCO Well No. DSl-16 D$3-16 DS5-18 DS5-26 D$7-6 DSll-2 DSll-27 DS12-25 DS15-8 DSlS-10A LGI-4 WGI-3 Permit No. 78-8 79-93 89-76 89-113 78-14 81-128 83-1~6 84-155 88-85 88-13 79-49 Approval Date & No. 12-28-88, 8-988 8-23-89, 9-740 8-6-91, 91-234 11-15-89, 9-993 2-1-90, 90-060 8-27-90, 90-666 2-6-90, 90-066 8-24-89, 9-750 2-4-92, 92-019 7-12-90, 90=526 6-19-90, 90-463 12-3-90, 90-852 2-10-88, 8-76 Description Perforate 12-88 Perforate 8-89 Perforate 3 Q '91 Perforate 11-15-89 Stimulate 2-90 Gas shutoff treatment 9-90 Perf., stimulate, perform CTU cement squeeze 2-90 Perforate 3 Q '89 Pull tubing 2-93 ~ Stimulate 8-90 Pull tubing 8-90 Stimulate, perforate 11-90 Stimulate 2-88 I ARCO ALA,?K A P ~ O. BOX ANCHORAGE: ALA.?K A DA-E ' ,3-t 8-9(f: HA(;.NETIC TAF::E.($) W..i;'f'H Ll£-f"ii'-id(,?) HLS fl_AS i i... A ,':-; D I S T iR I B U T ]: 0 N CENTRAL FILES C H F:~ V' F-.: ;" N D & M ]"r'ii'i HA S BROWN EXXON MAF;:.A TH;ON HOB ii L ( C 14 ) ( 0 H /~3 C T ) RECEIVED OCT '/9 Alaska 011 & (~as Cons. Commission Anchorage ARCO ALASKA, INC~ F',.O. BOX J00360 ANCHORAGE, ALASKA _ DATE ' 9-28~9~ 995 i ~ REFERENCE' ARCO CASED HOLE F:[NALS RECEIVED '""- 1990 ' · i Alaska Oil ,2 Gas Cons. Commission Anchorage i-i (~ 9-i 2-90 F'ERF RECORD RLJN i , [::"" i -i 4, o'-i. ,_?-90.F'ERF RECO!;.'.D i;..'[JN i .,, _:-":' ... i 3 --?.~-c,,.:,, CNL-qR l:~'.i · ~ ~ · ,_- _ ... , .~ ._;' i i-4 9-i 7-9,'3 F'ERF RECOF:.D F,..'LJN i., i i - i i o---,r.--,-c.,,..--, CNL.-GR F;'~ IF..~ i ':'.'" : ,,4.. -..- ,- ~ ..... i i -i ,5 9-'2;.":,-9¢.) F'ERF RECORD F;.'l. Jr-.! i., 5." i i -- 2'7 9- 20- 9,:-]' C N L- G R F;.: U N i , 5:" i S-2 9-i 8-90 COLLAR/F'EF.:F i";:.UNi., .5" F'I EASE SIGN AND RETURN THE ATTACHED COF'Y A,~.: F'. .... ,..,[:.ZF'T OF: i,'ATA,. RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER ATO-i527 A F' F' F;.: 0 VI~ D 'i'RAN,S.':~ 9;¢'~.°.7 - DISTRIBUTION CENTRAL FILES CHEVRON EXTENSION EXPLORATION EXXON MARATHON MOBIL '"" P H ;[ L L 'r I:, -:.:' F'B WEi_L F'];LES R & D' BP¥ . · ..-~ · /, ..... '" ~ [Iq ! b OF; ALA~-'I<A T E X A C 0 ARCO ALASKA, INC. P.O. BOX iOnS60 ANCHORAGE, ALASKA 995 i ~ DATE' i-s-go REFERENCE' ARCO CASED HOLE FINALS 2-9 ii-ii--89 F'ERF RECORD 4-5 ii ..._, 89 F'ERF 17ECORD 4-22 it-i2-89 PERF RECORD 5-4 i0-i-89 F'ERF RECORD i i -27 9-,3-89 F'ERF F.:ECORI) t2-ii ii-i6-89 F'ERF RECORD i3-i,3 ii-8-89 F'EF.:F RECORD t 3-27 t i-8-89 F'EF,'F RECORD i`3-29 ii-9-89 PERF RECORD i `3-`3(-~ i i -9--89 PFF<F RECORD i4-2S 9-i5-8:2 F'ERF RECORD i 5-i 4 i ;3-27-89 DZFF" '¥EMF' i7-;5 ii-t-89 PERF RECORD PLEASE SIGN AND RETURN THE ATTACHED COF'Y AS RECEIPT OF RECEIVED BY __~,~----~ Y'RECEIVED SALLY HOFFECKER ATO-i 529 JAN 10 1990 APPROVED, ~. ~~..~.__ TRANS-~ 9 r-}g eS CENTRAL FILES CHEVRON D&M EXTENSION EXPLORATION EXXON~- MARATHON, MOBIb · ._ PHILLIPS PB WELL FI:LES R'& D BF'X STATE OF ALASKA TEXACO RtJN i, 5" I:;:tJN i , 5' RUN i , 5' RUN i , 5' RUN i, ..,-~'~' 1-71.JN i .,5' RUN i , 5:" RUN i, 5' RUN 1 , '5' I;,'UNt, 5' RUNS i -3, F.,'UN t, S' RUN i , ~" DATA I-il_£' F-ILS HL£' HL£ 14LS HI_S Ft L.':...' HLS I-ILS i-iI_Z HLS HLS FILS OIL AND GAS CON~RVATION A 'ATION FOR SUNDRY ROVALS 1. Type of Request: Abandon Suspend Operation shutdown Alter casing Repair well Plugging Change approved program ~ Pull tubing 2. Name of Operator 5. Type of Well: ARCO Alaska, Inc. x 3. Address , 12. Re-enter suspended well P.O. Box 100360 Anchorage, AK 99510 Development Exploratory Stratigraphic Service Location of well at surface 451' FSL, 229' FEL, Sec. 28, T11N, R15E, UM At top of productive interval 928' FSL, 1355' FWL, Sec. 21, T11N, R15E, UM At effective depth 1412' FSL, 1140' FWL, Sec. 21, T11N, R15E, UM At total depth 1441' FSL, 1129' FWL, Sec. 21, T11N, R15E, UM Present well condition summary: Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 2 0 ' Surface 25 25' I 2 2 1 0 feet 889 1 feet 1 2 1 6 6 feet 8859 feet Plugs (measured) Junk (measured) Size Cemented 20" 200 cuft Poleaet 13-3/8" 2500 sx CS III 400 sx CS II Time extension Stimulate Variance Perforate x Other 6. Datum elevation (DF or KB) 58' RKB feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS11-27 9. Permit number 86-148 10. APl number. 11. Field/Pool I Prudhoe Bay Oil Pool tCtlVtU AI 2 1989 ;:,taska 0il & 6as Cons, Measured depth True vertical depth 110' 110' 2555' 2518' Production 11342' 9-5/8" 500 sx Claas G 11368' 8297' 300 sx AS I Liner 1164' 7" 350 sx Class G 11046'-12210' 8070'-8859' Perforation depth: measured I 1 9 9 8'- 1 2 0 2 9' ~ '"~; ,.. ~.~. true vertical 8742'-8764' ~.'~/-,~, f ,, , , · , .; ~.., Tubing (size, grade, and measured depth): 5-1/2 , 17#, L-80, PC, 0-11048 MD- Packers and SSSV (type and measured depth)' al S Baker SB-3 Packer @ 11026' MD 13. Attachments: Description summary of proposal x Detailed operations program BOP sketch 14. 16. Estimated date for commencing operation 3Q '89 If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas ~ Suspended Service 17. I hereby.,~ertify that the foregoing is true and correct to the best of my knowledge. Signed .~""~¢~&~ Title~.~~ ~, l~~e ~"/~'/~:~ FOR COMMISSION USE ONLY / / CONDITIONS OF APPROVAL: Notify Commission so representative may witness Plug integrity BOP Test Location.~clearance Mechanical Integrity Test Subsequent ~ferm required 10. q: '~ Approved by order of the Commissioner ./"~-,~ .....~ ,/t_.,,,~ ,_.~. Commissioner Form 10-403 Rev 06/15/88 ( [Approval No. Date .? ?h'/?' SUBMIT IN TRIPLICATE STATE OF ALASKA AL ~, OILAND GAS CONSERVATION COMM' 'ON RE. POIIT OF SUNDRY WELL OP£R/. IONS '1. Operations performed: Operation shutdown__ Stimulate__ Plugging Pull tubing Alter Casing __ Repair well __ Perforate x Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service , Location of well at surface 451' FSL, 229' FEL, Sec. 28, T11N, R15E, UM At top of productive interval 928' FSL, 1355' FWL, Sec. 21, T11N, R15E, UM At effective depth 1412' FSL, 1140' FWL, Sec. 21, T11N, R15E, UM At total depth 1441' FSL, 1129' FWL, Sec. 21, T11N, R15E, UM 6. Datum elevation (DF or KB) 58' RKB feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 11-27 9. Approval number 9-750 0. APl number 50-029-21581-00 1. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary: Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor I I 0' Surface 2 5 2 5' I 2 2 1 0 feet Plugs (measured) 8 8 9 1 feet I 2 1 6 6 feet Junk (measured) 8 8 5 9 feet Size 20" 13-3/8" Production I 1342' 9- 5/8" Liner I I 64' 7" Cemented Measured depth True vertical depth 200 cuft Poleset 110' 110' 2500 sx CS III 2555' 2518' 400 sx CS II 500 sx Class 6; 11368' 8297' 300 sx AS I 350 sx Class G 11046'-12210' 8070'-8859' Perforation depth: measured 11998'-12029', 12048'-12062' true vertical 8742'-8764', 8777'-8787' Tubing (size, grade, and measured depth)' Packers and SSSV (type and measured depth): 5-1/2", 17#, L-80, PC, 0'-11048' MD 5", 15#, L-80, PC, 11048'-11115' MD Camco BaI-O SSSV @ 2225' MD Baker SB-3 Packer @ 11026' MD 13. Stimulation or cement squeeze summary N/A · ' Intervals treated (measured) . Treatment description including volumes used and final pressure 14. Representative Daily Avera,qe Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pre~Sure Prior to well operation 2 5 8 3 5 4 7 3 0 N / A I 2 5 1 Subsequent to operation 3 7 0 5 9 1 0 9 0 N / A 8 4 0 15. Attachments 116. Status of well classification as: I Copies of Logs and surveys run Daily Report of Well Operations x Oil x Gas __ Suspended __ Service 17. I hereby/c'prtify that ~e foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 10/01/88 ! / SUBMIT IN DUISLICATE ~SUMMARY OF WELL OPERATIONS ARCO Alaska, Inc. perforated DS 11-27 at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit on 9/3/89 (12048'-12062' MD, Ref Log: BHCS 1/11/87). This well was perforated approximately 500 psi underbalanced and flowed to clean-up. The wellbore fluid at the time of perforating was the produced fluids; oil, water, and gas. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. The SSSV was installed at the conclusion of the perforating and clean-up operation. A short summary of the work is given below. - Began perforating operation on 9/3/89. - RU pedorating unit and pressure tested equipment to 3500 psig. - RIH w/ gun #1, tied-in, and shot 12048'-12062' MD @ 4 SPF. - SI well. - POOH. All shots fired. - Secured well. RD. ARCO ALASKA, INC. F'.O. BOX J t:~L:6¢~ ANCHORAGE, ALASKA 995i O DATE' 8-22-89 REFERENCE' ARCO CASED HOLE FINALS 1-t A 8-i "'2-89 CET-THICKNESS' RUN t, "i-tA 8..-'t2-89 CORR. F'ROTECTION EVAL. RUN i, t-t 9 8-t :5-89 COLLAR/PERF RUN t , 4-6 8-t 0-89 C ]I_LAR RUN 4-6 8-t,3-89 BRIDGE PLUG RUN I , 5-tt 8-14-89 DIF'F . TEMP RUN 5-t t 8-t 4-'89 CNI._-C;AMMA RUN t , ..5-i 8 8-1 ¢-89 CE]' RUN 'i , 9-t~ 8-2-89 INJECTION PROFILE RUN i , 9-i8 8-S-89 INJECTION PROFILE RUN t, 9-t9 8-4-89 INJECTION PROFILE RUN t , 9-25 8.-4--89 INJECTION PROFILE RUN .-tl-27 7-2-89 DUAL SPACED NEUTRON RUN i, t6-t 8-7-89 INJECTION PROFILE RUN t, t 7-5 8-9-89 COLLAR/PERF RUN t, i 8-t ~-5 8-5-89 I'EMP/WHUT SURYEY RUN PLEASE SIGN AND RETURN THE ATTACHED COPY A~' RECEIF'T OF' DATA. · 5' 5" 5' 5" 5' 5' 5" 5' 5" y. 5" 5' 5' 5" ~CH ~CH ATLAS A TI_A,S' ATLA,S' ATLAS ATLAS .',:,' C H CAMCO CAMCO CAMCO CAMCO HI.S CAMCO ATLAS CAMCO RECEIVED BY ,SALLY HOfrFECKER .._~f~'~.¢~ i .~.-~''¢'' PROVED ATO-t 529 ~ ~~gz~=~ '~-AN3'~ 89356 Alaska & Ccns DZZTRZBOTZO~ CENTRAL FILES ~ PHIl_LIPS CHEVRON PB WELL FILES D & M R & D EXTENSION EXPLORATION ~ BPX EXXON ~ S-FATE OF ALASKA MARATHON ~ TEXACO MOBIL THE CORRECTED AF'I~ FOR 5-ti IS 50-e29-20252.,. THE CORRECTED AF'I$ FOR 9-i9 IS 5o-e29-2026e,. ARCO ALASKA, INC, P.O. BOX t00360 ANCHORAGE, ALASKA ~?SJO DATE: 8-'t 8-89 REFERENCE: ARCO MAGNETIC TAf:'E'."(S) WITH LISTING(S) t t-27 7-2-89 DUAL 3'PACED NEUTRON JOB.~t~63(~t PLEASE SIGN AND RETURN THF ATTACHED COPY AS RECEIF'T OF DATA. HL~' RECEIVED BY HAVE A NICE DAY! SAt. LY HOFFECKER ~ AFFROVEI) ~ :~G: I'RAN~ 89355 ATO- ~ 52~ DI$'TRIBUTION CENTRAL FILES (CH) ~ PHILLIPS CHEVRON F'B WELL FILES D & M R & D TAHMA$ BROWN (OH) ~ BPX EXXON ~ ~ STATE OF ALASKA MARATHON TEXACO MOBIL STATE OF ALASKA ,~ ~KA OIL AND GAS CONSERVATION COM~'' 'SION APPLICATION FOR SUNDRY APrROVALS 1. Type of Request: Abandon__ Suspend Operation shutdown Alter casing Repair well Plugging Change approved program __ Pull tubing .__ Re-enter suspended well Time extension Stimulate Variance Perforate × Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510 . 5. Type of Well: Development Exploratory Stratigraphic Service 12. Location of well at surface 451' FSL, 229' FEL, Sec. 28, T11N, R15E, UM At top of productive interval 928' FSL, 1355' FWL, Sec. 21, T11N, R15E, UM At effective depth 1412' FSL, 1140' FWL, Sec. 21, T11N, R15E, UM At total depth 1441' FSL, 1129' FWL, Sec. 21, T11N, R15E, UM Present well condition summary: Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 2 0 ' Surface 25 25' I 221 0 feet Plugs (measured) 889 1 feet I 21 66 feet Junk (measured) 8 85 9 feet Size Cemented 20" 200 cuft Poleset 13-3/8" 2500 sx CS III 400 sx CS II 6. Datum elevation (DF or KB) 58' RKB feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number DSll-27 9. Permit number 86-148 10. APl number 50-029-21581-00 11. Field/Pool In poo, i Et, EI V EIJ AUG2 I Anch0 e Measured depth True vertical depth 110' 110' 2555' 2518' Production 11342' 9-5/8" 500 sx Class G 300 sx AS I Liner 1164' 7" 350 sx Class G 11368' 11046'-12210' 8297' 8070'-8859' Perforation depth: measured I 1 9 9 8' - 1 2 0 2 9' true vertical 8742'-8764' Tubing (size, grade, and measured depth): Packers and SSSV (type and measured depth): 5-1/2", 17#, L-80, PC, 0'-11048' 5", 15#, L-80, PC, 11048'-11115' Camco BaI-O SSSV @ 2225' MD Baker SB-3 Packer @ 11026' MD MD MD 13. Attachments: Description summary of proposal x Detailed operations program BOP sketch 14. Estimated date for commencing operation 3Q '89 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas__ Suspended__ Service 17. I hereby,A:ertify that th.~ foregoing is true and correct to the best of my knowledge. Signed FOR COMMISSION USE ONLY CONDITIONS OF APPROVAL: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- /~W- ORIGINAL SIGNED BY Approved by order of the Commissioner [0NNIE C. SM!TH Commissioner Form 10-403 Rev 06/15/88 I A P _P r_°~v_.a.l~ ~N °~ ~., ~ljlj, vv ~,~ Returned SUBMIT IN TRIPLICATE SUMMARY OF PROPOSAL ARCO Alaska, Inc. proposes to perforate DS 11-27 at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit. This well will be perforated approximately 500 psi underbalanced and flowed to clean-up (the expected static bottom hole pressure is 3650 psia). The wellbore fluid at the time of perforating will be the produced fluids; oil, water, and gas (currently 2500 STBO, 2000 SCF/STB, and 0% Water) All wireline work will be done through a 5000 psi WP BOP/Lubricator (see attached schematic) tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed perforation interval(s): 12048'-12062' MD Ref Log' BHCS 1/11/87 :. ,laska Oil & Co s. Anchorage 1. '~000PSI 7" WELLHEAD CONNECTOR FLANGE 2. 50CI,0PSI WlR£LIN£ RAMS (VARIABLE SIZE) 3. ~000 PS1 4 l/a" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-orr 2 RECEIVED ~,iaska Oil & Gas Cons. L;ommissio,, Ancl~orag~ _H 1 RE.L_ 1 .NE. .BOP. EOUIPI~NT ARCO ALASKA, INC. P.O. BOX t00360 ANCHORAGE, ALASKA DATE' 9-25-88 REFERENCE~ ARCO PRESSURE DATA ~ - t 5 9-J-88 ~ -4 5 9-?-88 ~-24 8-28-88 f-25 8-5-88 ~-~'~'7 8- ~ 7-88 7-4 ~-~ ~-88 BHP--$TATIC GRADIENT BHP--~TATIC GRADIENT BHP--~'¥ATIC GRADIENT BHP--F'BU BHF'--F'BU BHF'--$TA'¥1C GRADIENT CAMCO CAMCO CAMCO OTIS OTIS CAHCO F'LEAS'E 3IGN AND RETURN THE A'I-TACHE'D COF'Y AZ RECEIPT OF DATA. HAVE A NICE DAY! SALLY HOFFECKER ATO-~ 529 TRAN$ $8858(~ APPROVED DI$'¥RIBUTION CENTRAL FILES' CHEVRON D & M EX'TENSION EXPLORA'TION ~'- EXXON MARATHON ~~ MOBIL F'H ILL I F':';' F'B WELL r'ILES' R & D SAF'C STATE OF ALAS'KA TEXACO Aias',.a Oil & Gas Cons." ....... ,~- A~?C. 13 Al AX'IfA. /NC... Y'. FI . RI']¥ 't Ai'.JF.'HFII.~'Ar;I:..-., Al A.'.;'KA 9~7%..¢ DATF' A-I Z-RF: RFFER'F'NCF' AR'CPI r:AYEP FINI F FTNAI 4.-.-'2. 6-9-?,R ENI ¢ 7:~3/8' ) F;.'l!i'.J 4 .~" X'F:I-.I 4-% Z-,- c2-- R R CHI_/F,F~ F.'l.J N 4-R .6- R. -,o,,o, X F' ]; N i'J ~ R' / T E;i'd F' F R' A 'f'l IR F F;.'I.I N 4 -,-z, ¢ A-R-RP, .... C/'.Jl./CF: F,'I .IN ~-'l~.., ~. ..... 6-4-RR CHI.. (.-4,~/o.,.., ) r4,'llN. %-'i6 6-4-R,o CH! (ur Z/o,) R'IIN 4 .. . i., .. .~ . ,. ~ . . . ,, ,",-- 1 4 A-S-,°, R C. NI (.-z;'-z / R ·) RI.IN ........ ! ...... ...!. _ .!., ..~ .. . 'i t -2,'7- 5-~'-.RF't, CHI.. F;I IN t , ~ · ~C..H t .~,-t 6-.~-P,,q C. NI.. (' Z .'~/R · ) I:;.'I.IN -z "'-" ,~'CH ................ · ..~ .~ ../ F'I F'A,~E ¢.TF, N AND RETIIRN THE ATTACHED COPY ¢,~ RECFZF'T DF' DATA .. ,.t- .......... ,"- . .. RECEIVED BY_ HAVF A NICE DAY! ' F'..F. GGY BENNFTT ATR- ~ TN'AN,? -,-'"'CENTRAl ...... F T I...E.,:: ~ CHEVF:ON · v :.l~ .. PI... ~ E_,, T E ~--.,,_'., I O N F':4 RF:AT_T. ONr - ¢' EXXON HARATtqON · ~" MOB'[ t... ARCO ALASKA, INC. P~O. BOX t005&8 ANCHORAGE, ALASKA DATE: t-t2-88 REFERENCE: ARCO CASED HOLE FINAl._ i-22 t 2-t S-87 F'I.iMF'-IN TEMF'E'.RATIJRE SIlRVEY RUN 5-14 t2-i6-87 LEAK DETECTION RUN 6-8 t.,=n- t i -87 PRODUCTION F'ROFII...E El.IN .6-t 5 t 2-t 2-87 PRODI..ICTION PROFILE RIJN 6-t8 t..'2..-t t-87 PRODUCTION PROFT. LE RI. IN 9-2 ~2-t9-8'7 PRODUCTION FR.]F.[I_E RUN 9-3 $ 2-24-87 PRODUCTION F'ROF.TI..E ELIN 9-.5 t 8-,"58-87 PFC LOG I:~'.tJN .9-3 i 8-50-87 VERTILOG Iq'l..I N 9-.5 i-5-88 F'RODUCTT. ON LOg RUN 9-t4 t2-t9-87 STEP RATE INJECTION PROFILE RUN i-iT t2-t7/i8 PITS R. UN 2-i 4-87 FLO~METER RUN iS-.. i2-2,'5/24 F'R. ODUCTION F'ROFILE RUN 3-i4 10-i8-87 F'RISM RUN ~i5-29 i2-25-87 F'RODUCT.T. ON F'ROFIi_E RUN 5-35 t.,_?-i ,_,-z-87 PRODUCTION F'RDFILE kUN ~i4-6 i2-20-87 PRODUCTION PROFILE RUN 4-ii i-.'-"'~.~8-87 Fi_OWMETER SURVEY. RUN t.5-9 i2-27-87 PRODUCTY..ON-F'RnF'r~ =. RI.IN ~-22 ti-2-8'7 VERTIL06 RUN %i 6-'7 i 2-26-8'7 F'RODUCTION F'ROF.II...E RUN 7-t.,...° i O-t i -8-", DIFF/TEMF'ERATi.IRF-_/GR Rt.' IN -"-t, ''~ i O-i i -87 PRISM R!JN PLEASE SIGN AND RE TURN T~H~F.._~_.TaTT~~ COPY AA' RECE.IF'T OF DATA HA~'E A NICE DAY! PEGGY BENNETT ~TO-i 529 TRAMS ~88026 APPROVED DISTRIBUTION 5' 5' 5· 5' 5· 5' ..5' 5' 5' 5' 5' 5" 5' 5' 5" 5' 5" 5' .5' 5' CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO WAI WAI ~CH CAMCO CAMCO CAMCO CAMCO ATLAS CAMCO CAMCO CAM~O CAMCO CAMCO WA:[ CAMCO WAI ATI..A~ CENTRAl_ FILES ~ F'HZL. i..IF'S CHEVRON F'B WEL. L I) & M R & D EXTEN~I ON EXPLORATION ~ ~AF'C EXXON ~ STATE OF MARATHON ~' TEXACO MOBIl... ALASKA o~eXe.L sd!'t'l Jqd '1.~ qoH ,.. uoq~. uox x-4 uo ~ 4. e.¢uldX~l uo ~ ~ue4. x':.l uo.t^aq3T Se'l.~.-I 'le-t~ua3 . p~^o~dd~ ,aq.I. ud.n),.a.~, pue 06 ! s ,uSeald una (6o-I uo!.l, eJoJ.~,ed) -~ellOL} LO-/..I,-fi una (6o"'1 uO!.l.e~uj..xa,::l) -te'l'lOg /..8-f,,'-6 .01,-£t, un~j (6o'1 uo!4. e-~oJ..tad) -tellOSI LS-~£-fi l-£1, Un~l (6o'1 uo! u'n~ (6o'1 UOl.l.e~eJ.~,a,::l) -~e'l'lOg 2. fi-~-6 Un~l (6o'1 UOlSe.~u~.~ed) .~ellOSI L~-I£-L LL~-~I un,y (60'1 uo!.l.e.(uJ..,t,a,::l) .tel 'log LS-~.-L ?'~-~ un;?j .~e'l IoLI LEI- ~,~-B tz£-6 un,y (6o"1 uu!1. e.luj..~ed) -tel log L8-gl,-Ol, ~-6 un~j (6o-'1 uo!4. e.toJ,.~ed) .~e'l'lOLI /.B-OI,-L I,t,-L un~j (60"I uo! ( 6o"1 uu ! .I.e.toj.-te.::l) -~el 1 un~ (6o'1 uo! .I.e~u.4.~e,.J) u'n,y (6o'"1 uo ! ~ e.~o.~ -~e,_-I ) un,~j (6o"1 uo! ~e.~o.~.t~,:l) .tel Io3 LS-I ~-/_ e~-I ~n~j (609 uoll. e-~o.~-~d) -~e'11o~ LO--~I-L ~l-I, un~j (6o"1 UOll. e-~o.~-I~,J) -~UllO~ /_fi-Il-/_ lI-I ~'n~ {6o-'1 uot l.e.~o~-~s,.-l) -~e'l lO3 Le-~,~,-fi Z-I un~ (6Ol uo!le-~o}-Iecl) -~ellO0 Lfi-S-6 £-1 'leUl~ ~'lOH : 33N3~3'~3,~ LB-6-~ eq,s'e 1 ~ 'a6e~oq~u¥ (.)9£00 !, x o~I · 0" d "uuI ' e,'l:S'el V ULI,~JV .... STATE Of ALASKA ALASl~A OIL AND GAS CONSERVATION uOMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .. 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-148 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21638 4. Location of well at surface 9. Unit or Lease Name 451' FSL, 229' FEL, Sec.28, T11N, R15E, UN Prudhoe Bay Unit Classification of Service Well At Top Producing Interval 928' FSL, 1355' FWL, $ec.21, T11N, R15E, IJH At Total Depth 1441' FSL, 1129' FWL, Sec.21, T11N, ELSE, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 58 ' 6. Lease Designation and Serial No. ADL 28322 ALK 2326 10. Well Number 11-27 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool 12. Date Spudded 12/27/86 17. Total Depth (MD+TVD) 12210'HD, 8891'TVD 13. Date T.D. Reached 01/11/87 18. Plug Back Depth (MD+TVD) 12166'MD, 8859'TVD 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 7/31/87' N/A feet MSL 1 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost YES~] NO [] 2225' feet MD I 1900' (approx) 22. Type Electric or Other Logs Run D IL/Sonic/GE/SP, CDL/CN/GR/Cal, CBT/GR/CCL, GCT 23. CASING, LINER AND CEMENTING RECORD . .. CASING SIZE ZU" A/T. PER FT. 91.5# GRADE H-40 HOLE SIZE SETTING DEPTH MD TOP BOTTOM Surf 110' Surf 2555 ' Surf 11368' 11046' 12210' 30" CEMENTING RECORD 200 ft3 Poleset (approx 2500 sx CS III & 400 sx AMOUNT PULLED 13-3/8" 72.0# L-80 17-1/2" CS II 9-5/8" 47.0# L-80 12-1/4" 500 sx Class G & 300 sx AS I 7" 29.0# L-80 8-1/2" 350 sx Class G 25. TUBING RECORD 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 11996'-12027'ND 8739'-8761'TVD Perforated w/4 spf, 120° phasing SIZE DEPTH SET (MD) PACKER SET (MD) 5-1/2" 11115' 11026' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production 9/14/87 Date of Test Hours Tested 9/14/87 10.5 hfs Flow Tubing Casing Pressure Press. 651 500 psi 28. I Method of Operation (Flowing, gas lift, etc.) F1 owing TEST PERIOD ~ 1000 714 CALCULATED , OIL-BBL GAS-MCF 24-HOUR RATE I~ 2286 1632 WATER-BBL 23 WATER-BBL 52 CORE DATA CHOKE SIZE GAS-OIL RATIO 380 I 714 OIL GRAVITY-APl (corr) 29.3° Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None *Note: Drilled RR 1/15/87. Tubing run 6/24/87. Perforated well 7/31/87. wcs///:BANI CONTINUED ON REVERSE SIDE Form 10-407 Rev. 7-1-80 Gas Ct,r,,'-', <;r,~;mh;?.-n ,/:\0(;h0: h'.:¥ Submit in duplicate 29. 30. GEOLOGIC MARKERS MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadl erochit 11420' 8334 ' N/A G0C 11838'-11891 8629'-8666' Base Sad] erochi t 12061 ' 8784 ' 'i 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .~O,/)'Ij~d,_,~'~/.~/,._; Title Ass°ciate Encj 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- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10~,07 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION GOMMISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-148 _ - 3. Address 8. APl Number P. 0o Box 100360, Anchorage, AK 99510 -' 50- 029-21638 9. Unit or Lease Name ' Prudhoe Bay Unit 4. Location of well at surface 451' FSL, 229' FEL, 5ec.28, T11N, ELSE, UM At Top Producing Interval 928' FSL, 1355' FWL, Sec.21, TllN, R15E, UM At Total Depth 1441' FSL, 1129' FWL, Sec.21, T11N, ELSE, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 58' I ADL 28322 ALK 2326 12. Date Spudded 113. Date T.D. Reached 14. Date Comp., Susp. or Aband. 12/27/86 I 01/11/87 7/31/87, 17. Total Depth (MD+TVD)Ii18'Plug Back Depth (MD+I'VD) 19. Directional Survey I 12210'MD, 8891 'TVD I 12166'ND, 8859'TVD YES [] NO [] I 22. Type Electric or Other Logs Run DIL/Sonic/GR/SP, CDL/CN/CR/Ca], CBT/CR/CCL, GCT 10. Well Number 11-27 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool 15. Water Depth, if offshore 16. No. of Completions N/A feet MSL 1 20. Depth where SSSV set I 21. Thickness of Permafrost 2225' feet MD [ 1900 ' (approx) 23. CASING, LINER AND CEMENTING RECORD CASING SIZE 20" WT. PER FT. 91.5# 13-3/8" 72.0# 9-5/8" 47.0# 7" 29.0# GRADE H-40 L-80 l'80 SETTING DEPTH MD TOP BOTTOM Surf 110' Surf 2555' Surf 11368' 11046' 12210' HOLE SIZE 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 11998'-12029'MD 8740'-8762'TVD 30" 17-1/2" 1 2-1/4" CEMENTING RECORD 200 ft3 Poleset (approxI 2500 sx CS III & 400 sx 500 sx Class G & 300 sx L-80 8-1/2" 350 sx Class G 25. TUBING RECORD Perforated w/4 spf, 120° phasing Ref: BHCS 1/11/87 ~,MOUNT PULLED CS II AS I SIZE DEPTH SET (MD) PACKER SET (MD) 5-1/2" 11115 ' 11026 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT& KIND OF MATERIAL USED I N/A 27.N/A PRODUCTION TEST Date First Production Flowed to white elephant. Date of Test Hours Tested Casing Pressure Flow Tubing Press. Method of Operation (Flowing, gas lift, etc.) Not Jhooked up to manifold building. PRODUCTION FOR TEST PERIOD I~ IcALcuLATED 124-HOUR RATE OIL-BBL OIL-BBL GAS-MCF GAS-MCF WATER-BBL WATER-BBL CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-AP (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None .,-,;.~. '~.,~ ~ ~ . .,t~ C v' ', '..2 . .% .~" *Note: Drilled RR 1/15/87. Form 10-407 Rev. 7-1-80 Tubing run 6/24/87, Perforated well 7/~1/R7.. WC3/63:DANI CONTINUED ON REVERSE SIDE Submit in duplicate NAME Include interval tested, pressure data; all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sad1 eroch~t: 11'~20' 833b, ' N/A GOC 11838'-11891 , 8629,-8666, ._ : , Base Sadlerochil: 12061 ~ 8784' : . .... ~ . _ . .. !'~ .. . 9,-.....~ .... : .. · :31, LIST OF ATTACHMENTS Addendum (dar, ecl 7/21/87) . . 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ ~ _~Jl/~_., TitleAss°clare Engi neet 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". Form 10-407 ADDENDUM ~ELL: 3/30/87 5/30/87 6/07/87 6/27/87 11-27 Arctic Pak w/300 sx CS I & 119 bbls Arctic Pak. Tst failed. Re-Arctic Pak well w/300 sx AS I & 110 bbls Arctic Pak; tst failed. Will re-tst. Press tst Arctic Pak; tst failed. Perform long term tbg tst. Release well to Wireline Group. Drilling Supervisor Date Teleco Oilfield ,c :es of Alaska Inc. I TELEEO ] 6~ ~6 Nielsen W '~ Anchorage,99502 AK (907) 562-2646 January 16, 1987 JOB #555 ARCO ALASKA WELL: DS-Ii #27 PRUDHOE BAY RIG: PARKER 141 Please find attached a copy of the computer calculated MWD directional surveys for the above mentioned well. We at Teleco appreciate this opportunity to provide service to ARCO. Teleco is committed to providing the highest quality of service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Pat Havard, Field Service Supervisor PH/el Enclosures A ~1~1~'!' COMPANY Date 01/12/87 TELECO OILFIELD SERVICES JOB #555 SURVEY CALCULATIONS Page Company: ARCO ALASKA Well: DS-ii #27 Location: P.B.U. Rig: PARKER 141 TELECO Job # 555-TAK Grid Correction: Magnetic Declination: Total Correction: Proposed Direction: 0.00 degrees 31.00 degrees 31.00 degrees 328.70 degrees RADIUS OF CURVATURE CALCULATION MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' ASSUME VERTICAL TO 1500 1500.00 0.0 316.1 N 43 54 W 1500.00 0.00 0.00N 0.00E 0.00 N 90.000E 0.000 TELECO MWD SURVEYS 1813.00 7.9 331.2 N 28 48 W 1812.11 19.96 16.52N 11.26W 19.99 N 34.283W 2.997 1908.00 10.5 332.3 N 27 42 W 1905.88 35.13 29.90N 18.45W 35.13 N 31.679W 2.743 2001.00 12.0 326.0 N 34 00 W 1997.09 53.26 45.46N 27.75W 53.26 N 31.397W 2.083 1719.00 5.1 328.4 N 31 36 W 1718.72 9.33 7.32N 5.91W 9.41 N 38.898W 2.525 1597.00 2.1 316.1 N 43 54 W 1596.97 1.73 1.28N 1.23W 1.77 N 43.843W 2.165 TELECO Job # 555-TAK 01/12/87 Page 2 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/lO0' **************************************************************************************************** 2096.00 15.3 323.1 N 36 54 W 2089.39 75.62 63.72N 40.75W 75.64 N 32.597W 3.547 2189.00 19.6 326.0 N 34 00 W 2178.09 103.42 86.43N 56.91W 103.49 N 33.365W 4.716 2284.00 20.7 325.6 N 34 24 W 2267.27 136.11 113.50N 75.31W 136.21 N 33.566W 1.167 2378.00 23.3 322.8 N 37 12 W 2354.42 171.20 142.05N 95.90W 171.40 N 34.025W 2.982 2500.00 24.4 322.1 N 37 54 W 2466.00 220.24 181.16N 125.97W 220.65 N 34.812W 0.931 2681.00 25.8 322.4 N 37 36 W 2629.91 296.53 241.87N 172.97W 297.36 N 35.570W 0.777 2870.00 30.1 326.0 N 34 00 W 2796.82 384.81 313.69N 224.77W 385.91 N 35.623W 2.443 3025.00 33.4 326.0 N 34 00 W 2928.61 466.27 381.32N 270.34W 467.43 N 35.335W 2.129 3119.00 36.0 326.7 N 33 18 W 3005.88 519.73 425.86N 299.99W 520.91 N 35.162W 2.798 3214.00 40.8 327.7 N 32 18 W 3080.31 578.70 475.45N 331.94W 579.86 N 34.922W 5.095 3305.00 43.0 326.0 N 34 00 W 3148.04 639.44 526.32N 365.17W 640.60 N 34.754W 2.720 3401.00 46.1 324.2 N 35 48 W 3216.44 706.64 581.55N 403.70W 707.94 N 34.768W 3.487 3495.00 47.4 327.0 N 33 00 W 3280.85 775.00 638.04N 442.37W 776.39 N 34.735W 2.573 3677.00 49.1 327.0 N 33 00 W 3402.04 910.72 751.94N 516.28W 912.12 N 34.473W 0.934 3866.00 50.0 326.7 N 33 18 W 3524.66 1054.47 872.36N 594.92W 1055.91 N 34.293W 0.491 4178.00 49.8 327.4 N 32 36 W 3725.62 1293.03 1072.63N 724.73W 1294.51 N 34.045W 0.183 4491.00 48.5 329.1 N 30 54 W 3930.34 1529.77 1273.95N 849.31W 15.31.10 N 33.690W 0.584 TELECO Job # 555-TAK 01/12/87 Page 3 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/lO0' **************************************************************************************************** 4807.00 47.7 330.5 N 29 30 W 4141.38 1764.92 1477.22N 967.61W 1765.91 N 33.226W 0.416 4896.00 47.7 329.1 N 30 54 W 4201.28 1830.73 1534.11N 1000.72W 1831.65 N 33.117W 1.163 5146.00 50.9 323.1 N 36 54 W 4364.28 2019.96 1691.33N 1106.37W 2021.06 N 33.191W 2.224 5270.00 50.4 323.1 N 36 54 W 4442.90 2115.39 1768.04N 1163.91W 2116.76 N 33.357W 0.405 5395.00 50.5 323.5 N 36 30 W 4522.49 2211.34 1845.31N 1221.50W 2212.97 N 33.503W 0.261 5489.00 51.2 323.9 N 36 06 W 4581.83 2283.96 1904.06N 1264.66W 2285.79 N 33.592W 0.815 5616.00 51.7 323.9 N 36 06 W 4660.98 2382.93 1984.34N 1323.14W 2385.02 N 33.695W 0.395 5754.00 51.6 321.7 N 38 18 W 4746.60 2490.57 2070.53N 1388.57W 2493.04 N 33.847W 1.252 6061.00 50.7 322.1 N 37 54 W 4939.18 2727.98 2258.68N 1536.09W 2731.52 N 34.219W 0.310 6279.00 50.4 323.9 N 36 06 W 5077.69 2895.47 2393.11N 1637.39W 2899.66 N 34.380W 0.652 6373.00 50.1 323.9 N 36 06 W 5137.80 2967.49 2451.52N 1679.95W 2971.90 N 34.422W 0.323 6687.00 48.8 324.9 N 35 06 W 5341.93 3205.40 2645.51N 1818.83W 3210.44 N 34.509W 0.479 7009.00 51.6 324.6 N 35 24 W 5548.03 3452.18 2847.52N 1961.60W 3457.78 N 34.562W 0.873 7151.00 54.3 325.3 N 34 42 W 5633.58 3565.26 2940.29N 2026.68W 3571.10 N 34.578W 1.942 7310.00 55.9 326.0 N 34 00 W 5724.54 3695.47 3047.95N 2100.26W 3701.50 N 34.570W 1.069 7476.00 56.1 325.6 N 34 24 W 5817.37 3832.92 3161.77N 2177.62W 3839.12 N 34.556W 0.234 7633.00 55.4 325.3 N 34 42 W 5905.73 3962.48 3268.66N 2251.21W 3968.89 N 34.556W 0.473 FELECO Job # 555-TAK 01/12/87 Page 4 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' 7788.00 55.6 326.0 N 34 00 W 5993.52 4090.05 3374.12N 2323.29W 4096.63 N 34.550W 0.394 8103.00 53.9 326.0 N 34 00 W 6175.32 4346.99 3587.44N 2467.02W 4353.85 N 34.516W 0.540 8320.00 53.1 324.9 N 35 06 W 6304.39 4521.14 3731.11N 2565.95W 4528.28 N 34.517W 0.550 8622.00 52.4 325.3 N 34 42 W 6487.19 4761.05 3928.26N 2703.48W 4768.66 N 34.536W 0.255 8937.00 51.5 324.9 N 35 06 W 6681.34 5008.61 4131.70N 2845.40W 5016.70 N 34.554W 0.303 9093.00 50.4 324.6 N 35 24 W 6779.62 5129.47 4230.63N 2915.32W 5137.84 N 34.571W 0.721 9256.00 50.3 325.3 N 34 42 W 6883.63 5254.71 4333.38N 2987.40W 5263.34 N 34.582W 0.336 9411.00 50.3 324.6 N 35 24 W 6982.64 5373.71 4431.01N 3055.89W 5382.59 N 34.593W 0.348 9617.00 50.4 332.3 N 27 42 W 7114.09 5532.21 4566.08N 3138.82W 5540.88 N 34.506W 2.878 9774.00 49.9 333.3 N 26 42 W 7214.69 5652.43 4673.28N 3193.92W 5660.45 N 34.350W 0.583 9999.00 48.2 333.7 N 26 18 W 7362.15 5821.76 4825.36N 3269.74W 5828.83 N 34.122W 0.767 .0311.00 48.5 333.7 N 26 18 W 7569.50 6054.01 5034.41N 3372.94W 6059.87 N 33.821W 0.097 ~0622.00 48.0 334.4 N 25 36 W 7776.59 6285.02 5243.04N 3474.47W 6289.79 N 33.532W 0.232 .0995.00 46.1 335.8 N 24 12 W 8030.72 6556.31 5490.66N 3589.41W 6559.82 N 33.174W 0.579 .1323.00 44.6 336.9 N 23 06 W 8261.23 6787.57 5704.40N 3683.01W 6790.05 N 32.848W 0.516 ~ zLE£O 0 i i-F i ~ i d S~rv i c~s PLA~i ViEW WEST ..... .u__..... ~---t .... ;---i .-4 .......... 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Well Name ...DRILLSITE 'I]-27(45]' FSL, 229' FEL,SEC 28,TllN,R15E,UM) J i ! · i FleldlLocation.PRUDH, o,E BA,¥, NORTH SLOPE, ALASKA I I ii I i Job, Reference No. _ 72183 Logaed By: MCBRIDE Date 20-JAN-87 Computed STEVENS .: GCT DIRECTIONAL SURVEY CUSTOMFR LISTING FOR ARCO ALASKA, INC. DS 11-27 PRUOHOE BAY NORTH SLCPE, ALASKA SURVEY DATE: ZO-JAN-87 ENGINEER: MCBRIDE METHODS CF CGMPUTATZON TOOL LCCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 31 DEG 15 MIN WEST 0000000000 000000000 000000000 O0000CDO00 000000000 0 0000000000 000000000 0 0000000000 0 0000000000 0 0000000000 ZZZZZ~ZZZ Z Z ~T'_ Z ZZZ ~Z 2~ ZZZ2;ZZZZZ Z' · · · · · · · · · · t.o Uj r,,0 r,o r-,j i-, i ZZZZZZ2'ZZ · · · · · · · · · · ZZZZZZZZZZ ZZZ2TZ'~- ~2~ZZ~_ lX~ I I I I I I I I t111 0000000000 ooolo~liol · · · · · · · · · · · oooooooooo G~JH H--.t ITt H 0 nl m 7OC --tEl i~ I'n-< ):::,, ,,il Z 1> C') UiCD ;:g · C. ar,-- COMPUTATION DATE: 5-F~B-87 ARCO ALASKA, DS 11-27 PRUDHOE BAY NORTH SLOPE, INC. ALASKA KELLY DATE OF SURVEY: BUSHING ~LEVATION: ENGINEER: INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE MEASURED VERTICAL DEPTH DEPTH SUB-SEA COURSE VERTICAL DEVIATION AZIMUTH DEPTH' OEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR SECTION SEVERITY NORTH/S~UTH FEET DEG/IO0 FEET PAGE 2 20-JAN-_87 58.00 FT MC6RiD2 4000.00 3612.79 4100.00 3677.04 4200.00 3742.09 4300.00 3807.56 4400.00 3874.04 4500.00 3940.28 4600.00 4006.65 4700.00 4073,24 4800.00 4140.58 4900.00 4208.13 3554.79 50 10 N 32 19 W 3619.04 49 31 N 31 56 W 3684.09 49 44 N 32 15 W 3749.56 48 28 N 30 48 W 3816.04 48 14 N 29 57 W 3882,28 48 33 N 29 52 W 3948.65 48 27 N 29 34 W 4015.24 47 48 N 29 6 W 4082.58 47 40 N 28 48 W 4150.13 47 41 N 29 12 W 1140.59 0.43 936.42 N 121?.21 ~ 3.27 1001.15 N 1293.14 0.37 1065.63 N 1368.73 1.30 1129.94 N 1443.41 0.16 1194.46 N 1518.30 0.69 1259.40 N i593.07 0.30 1324.35 N 1667.64 0.98 1389.34 N 1741.51 0.32 1454.07 N 1815.17 2.15 1518.71 N 655.47 W 1143.03 N 34 59 W 696.4~ W 1219.58 N 34 49 W 736.59 W 1295.43 N 34 39 W 776.30 W 1370.92 N 34 29 W 813.94 W 1445.42 N 34 16 851.30 W 1520.13 N 34 :, 888.38 W 1594.72 N 33 51 ~ 925.02 W 1659.11 N 33 39 W 96.0,73 W 1742,79 N 33 27 W 996.2i W 1816.29 N 33 15 W 5000.00 4274.30 5100.00 4337.07 5200.00 4400.33 5300.00 4464.30 5400.00 4528.29 5500.00 4591.63 5600.00 4654.62 5700.,00 4716.63 5800.00 4778.97 5900.00 4841.05 4216.30 49 48 N 34 11 W 4279.07 51 43 N 35 46 W 4342.33 50 6 N 34 54 W 4405.30 50 26 N 35 33 W 4470.29 50 26 N 35 58 W 4333.63 50 22 N 35 41 W 4596.62 51 31 N 36 23 W 4658.63 51 52 N 36 46 W 4720.97 51 33 N 36 41 W 4783.05 51 16 N 36 46 N 1890.10 4.87 1562.63 1967.72 1.90 1646.03 2044.94 1.01 1709.08 2121.64 1.03 1772.00 2198.26 1.13 1834.49 2275.35 3.57 1896.96 2352.76 1.02 1959.93 2430.85 0.69 2022.80 2508.68 1.75 2085.47 2586.72 .0.54 2148.34 N 1035.31 W 1891.i9 N 33 11 W N 1060.45 W 1968.96 N 33 16 W N 1125.41 W 2046.34 N 33 21 N N 1169.55 W 2123.17 N 33 25 W N 1214.26 W 2199.95 N 33 30 W N 1259.92 W 2277.25 N 33 55 W N 1305.37 W 2354.85 N 33 39 W N 1352.29 N 2433.19 N 33 45 W N 1399.06 ~ 2511.26 N 33 51 N N 1445.88 W 2589.58 N 33 56 W 6000.00 4903.69 6100.00 4966.58 6200.00 5030.45 6300.00 5094.04 6400.00 5158.01 6500.00 5222.36 6600.00 5287.23 6700.00 5352.~0 6800.00 5418.54 6900.00 5462.90 4845.69 51 6 N 37 9 W ~908.58 50 54 N 37 0 N 4972.45 50 12 N 35 59 W 5036.04 50 19 N 36 10 N 5100.01 50 7 N 35 56 W 5164.56 49 48 N 34 55 W 5229.23 49 15 N 34 57 W 5294.60 48 48 N 35 10 W 5360.54 49 16 N 35 1 W 5424.90 50 25 N 34 55 W 2664.29 0.25 2210.61 2741.62 1.01 2272.54 2818.25 4.92 2334.54 2895.12 0.56 2396.67 2971.70 0.61 2458.76 3048.04 0.49 2521.15 3123.99 0.46 2583.5S 3199.49 1.60 2645.50 3274.51 1.72 2707.01 3350.88 0.80 276~.73 N 1492.77 ~ 2667.43 N 34 1 W N 1539.7~ W 2745.06 N 34 7 W N 1585.33 W 2821.94 N 3~ 10 W N 1631.12 w 2399.0~ N 34 14 W N 1676.42 W 2975.8~ N 34 17 W N 1720.75 N 3052.41 N 34 18 N 1764.2d W 312B.51 N 34 19 N 1807.77 W 32C4.17 N 34 20 i~ N 1851.01 W 327'9.35 N 34 21 W N 1894.86 ~ 5355.~7 N 34 22 W ?000.00 5546.18 7100.00 5606.82 7200.00 5665.20 7300.00 5721.79 7400.00 5777.34 7500.00 5832.93 7600.00 5889.28 7700.00 5945.95 7800.00 ~002.37 7900.00 6059.44 5488.18 51 22 N 34 49 W 5548.82 53 44 N 34 30 W 5607.20 54 55 N 34 10 W 5663.79 55 53 N 33 33 W 5719.34 56 25 N 33 45 W 5774.93 55 59 N 33 53 W 5831.28 55 37 N 33 55 W 5887.95 55 37 N 33 46 W 5944.37 55 28 N 33 3~ W 6001.44 54 54 N 33 50 W 3428.15 2.39 2833.20 3507.51 1.43 2898.61 3588.57 1.66 2965.58 3670.92 0.63 3033.95 3754.00 0.63 3103.04 3837.04 0.49 3172.10 3919.56 0.26 3240.65 4001.86 0.79 3309.07 4084.35 0.28 3377.76 4166.38 0.14 5446.03 N 1939.21 W 5*33.30 N 34 23 W N 1984.41 W 3512.50 N 34 23 W. N 2030.30 W 3593.99 N 34 23 W N 2075.31 w 3~76.43 N 34 23 W N 2122,65 W 375'9.5~ N 34 22 W N 2168.91 W 3842.71 N 3~ 21 W N 2215.01 N 3925.31 N 34 21 W N 2260.91 ~ 4007.70 N 34 20 ~ N 230~.72 k ~090.Z6 N 3* 19 N N 2352.34 N ~172.37 N 34 19 W COORDINATES HORIZ. DEPARTURE EAST/WEST gIST. AZIMUTH FEET FEET DEG MIN COMPUTATION DATE: 5-FEB-B7 ARCO ALASKA, DS 11-27 PRUDHOE BAY NORTH SLOPE, INC. ALASKA DATE KELLY BUSHING DF SURVEY: ELEV~1TION: 5NGIN-ER: INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED OEPTH TRUE SUB-SEA COURSE MEASUREO VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL SECTION FEET PAGE 3 20-JAN-8? 58.00 FT MCBRiCE 8000.00 6117.09 6059.09 54 31 N 33 57 W 8100.00 6175.51 6117.51 53 54 N 34 2 W 8200.00 6235.01 6177.01 53 7 N 34 16 W 8300.00 6295.06 6237.06 53 8 N 34 33 W 8400.00 6355.28 6297.28 52 54 N 34 32 W 8500.00 6415.60 6357.60 52,42 N 34 33 W 8600.00 6476.23 6418.23 52 35 N 34 37 W 8700.00 6537.29 6479.29 51'56 N 34 42 W 8800.00 6599.23 6541.23 51 31 N 34 52 W 8900.00 6561.50 6603.50 51 31 N 34 53 W 4248.01 4329.08 4409.34 4489.18 4568.88 4646.51 4727.90 4~06,.95 4885.30 4963.40 0.43 3513.88 N 2397.8~ W 4254.08 N 34 1~ W 0.64 3561.17 N 2443.26 W 4335.23 N 34 18 W 0.26 3647.64 N 24~8.43 W 4415.61 N 34 18 W 0.28 3713.61 N 2533.61 W 4455°56 N 34 18 W 0.63 3779.36 N 2578.90 k 4575.40 N 34 18 0.17 3845.05 N 2624.14 W ~655.16 N 34 18 0.32 3910.51 N 2669.29 W 4734.68 N 34 19 , 0.79 3975.65 N 2714.32 W ~813.87 N 34 19 N 0.77 4040.13 N 2759.10 W 4892.37 N 34 19 W 0.44 4104.31 N 2803.88 W 4970.03 N 34 20 ~ 9000.00 6723.88 6665.88 51 11 N 35 5 W 9100.00 6787.01 6729.01 50 27 N 35 1i W 9200.00 6851.23 6793.23 49 47 N 35 14 W 9300.00 6915.75 6857.75 49 56 N 35 14 W 9400.00 6980.07 6922.07 49 58 N 35 15 W 9500.00 7044.02 6986.02 50 29 N 34 25 W 9600.00 7107.49 7049.49 50 26 N 28 56 W 9700.00 7171.38 7113.38 50 10 N 27 9 W 9800.00 7235.91 7177.91 49 14 N 26 49 W 9900.00 7302.01 7244.01 48 13 N 26 39 ~ 5041.40 5118.77 5195.24 5271.47 5347.84 5424.54 5501.76 5578.55 5654.73 5729.53 0.78 4168.38 N 2848.67 W 5048.7'9 N 34 20 W 1.13 4231.77 N 2893.32 W 5126.32 N 34 21 W 0.41 4294.38 N 2937.54 W 5202.97 N 34 22 W 0.95 4356.84 N 2981.56 W 5279.37 N 34 23 W 0.45 4419.32 N 3025.81 W 5355.93 N 34 23 W 2.88 4482.19 N 3070.06 W 5432.79 N 34 24 W 3.96 4547.83 N 3110.7~ W 5f09.94 N 34 22 W 0.76 4615.97 N 3146.47 W 5586.36 N 34 16 W 1.22 4684.07 N 3181.07 W 5662.14 N 34 10 N 0.49 4751.09 N 3214.82 W 5736.54 N 34 5 ~ 10000.00 7368.61 7310.61 48 15 N 26 39 W 10100.00 7435.20 7377.20 48 16 N 26 51 W 10200.00 7501.72 7443.72 48 23 N 26 54 W 10300.00 7568.05 7510.05 48 24 N 26 41 W 10400.00 7634.18 7576.18 48 44 N 26 27 W 10500.00 7700.09 7642.09 48 44 N 26 20 W 10600.00 7766.16 7708.16 48 18 N 2~ 7 W 10700.00 7833.57 7775.57 47 28 N 25 36 W 10800.00 7901.07 7843.07 47 21 N 25 34 W 10900.00 7968.97 7910.97 46 5~ N 25 12 W 5803.87 5878.25 27.30 6102.06 6177.02 6251.78 6325.30 6398.74 6471.78 0.42 4817.75 N 3248.27 W 5510.51 N 33 59 W 0.40 4884.39 N 3281.82 W 5584.55 N 33 53 W 0.54 4950.95 N 3315.66 W 595~.65 N 33 48 W 0.71 5017.75 N 3349.38 W 6032.92 N 33 43 W 0.53 5084.82 N 3382.90 W 6107.36 N 33 38 W 0.27 5152.17 N 3416.45 ~ 6181.99 N 33 32 1.68 5219.49 N 3449.65 W 0256.44 N 33 27 2.58 528~.07 N 3461.64 ~ 6329.6~ N 33 22 ~ 0.74 5352.52 N 3513.68 W 6402.77 N 33 16 W 1.25 5418.86 N 3545.15 W 5475.50 N 33 11 W 11000.00 8037.72 7979.72 46 7 N 24 50 W 11100.00 8107.37 8049.37 45 39 N 24 14 W 11200.00 8i?T.44 8ii9.44 45 24 N 23 56 ~ 11300.00 8248.12 8190.12 44 19 N 22 54 W 11400.00 8319.53 8261.53 4* 24 N 23 19 W 11500.00 8390.76 8332.76 44 46 N 23 52 W 11600.00 8461.57 8403.57 43 3 N 24 26 W 11700.00 8532.12 8474.12 45 18 N 24 41 W 11800.00 8602.01 8544.01 45 50 N 24 42 W 11900.00 8671.81 8613.61 45 38 N 24 13 W 6543.96 6615.22 668~.00 6756.14 6825.43 6895.00 6965.09 7035.48 7106.53 7177.65 0.92 5484.65 N 3575.87 W 0547.38 N 33 6 W 0.74 5549.90 N 3605.71 W 6618.35 N 33 0 W 0.43 5615.03 N 3634.81 ~ 6655.~3 N 32 54 W 6.15 5679.81 N 3663.26 W 6758.63 N 32 49 W 0.53 5744.12 N 3690.87 W 0827.70 I'i 32 43 W 0.50 5808.47 N 3718.91 w 6897.00 N 32 37 W 0.52 5872.89 N 3747.d5 ~ 6~66.87 N 32 32 W 0.54 5937.32 Iq 3777.37 W 7037.07 N 32 27 W 0.26 6002.28 N 3807.26 W 7!07.9J N 32 23 W 0.66 6067.43 N 3837.01 W 7178.68 N 32 18 W . . DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH BEG/lO0 FEET FE~T FE~T DEG MiN COMPUTATION DATE: 5-FEB-87 PAGE 4 ARCO ALASKA, INC. OS 11-27 PRUDHOE 8AY NORTH SLOPE, ALASKA DATE UF SURVEY: ZO-JAN-57 KELLY ~bSHING ELEVATION: 58.00 -PT ENGINEER: HCBRIOE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEViA'TION AZIMUTH DEPTH DEPTH DEPTH OEO MIN DEG MIN VERTICAL COGLEG RECTANGULAR COOROINATES HORIZ. DEPARTURE ,SECTION SEVERITY NORTH/SOUTH EAST/WEST Di'ST. AZZMUTH FEET DEG/IO0 FEET FEET FEET OEO MIN 12000.00 8741.75 8683.75 145 43 12100.00 8811.96 8753.96 45 0 12200.00 8883.58 8825.58', 43 55 12210.00 8890.79 8832.79 43 55 N 23 50 W 7248.55 N 22 37 W 7319.10 N 20 35 W 7387.81 N Z0 35 W 7394.62 0.29 1.76 0.00 O.O0 e132.75 N 3,866.02 W 7249.61 N 32 13 W 6198.05 N 3694.41 W 731'3.99 N 32 6 W 6263.10 N 3919.66 ~ 7388.51 N 32 2 W 6269.59 N 3922.10 W '7395.31 N 32 1 W COMPUTATION DATE: 5-FEB-87 PAGE 5 ARCO ALASKA, INC. OS 11-27 PRUOHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: ZO-JAN-B7 KELLY BUSHING ELEVATION: 55,00 -FT INTERPGLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-S~A' COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVE'RITY NORIH/SOUTH EAST/WEST GIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG HZN 0.00 0.00 -58.00 0 0 1000.00 999.89 941.89 0 52 2000.00 1996.30 1938.30 11 46 3000.00 2909.23 2851.23 33 2 4000.00 3612.79 3554.79~ 50 10 5000.00 4274.30 4.216.30 49 48 6000.00 4903.69 4845.69 511 6 7000.00 5546,18 5488.18 51 22 8000.00 6117.09 6059.09 54 31 9000.00 6723.88 6665.88 51 1! N 0 0 E 0.00 S 42 27 W -1.39 N 33 48 W 41.93 N 33 35 W 436.58 N 32 19 W 1140.59 N 34 11 W 1890.10 N 37 9 W 2664.29 N 34 49 W 3428.15 N 33 57 W 4248.01 N 35 5 ~ 5041.40 0.00 0.47 3.37 2.16 0.43 4.87 0.25 2.39 0.43 0.78 0,00 N 0,00 E 0,00 N 0 0 ~,08 S 10,63 W 13,35 S 52 46 25.90 N 38.14 W 46.10 N 55 49 344.83 N 273.30 W 440.00 N 38 23 W '936.42 N 655.47 W 1i43.03 N 1582.63 N 1035.31 W 1891.19 N 33 1.~ 2210.61 N 1492.77 W ;)667.43 N 34 1 2835.20 N 1939.21 ~ 3433.30 N 34 23 3513.88 N 2397.88 w 4254.08 N 34 1~ W 4168.38 N 2848.67 ~ 5048.79 N 34 20 10000.00 7368.61 7310.61 48 15 11000.00 8037.72 7979.72 46 7 12000.00 8741.75 8683.75 45 43 12210.00 8890.79 8832.79 43 55 N 26 39 W 5803,67 N 24 50 W 6543,96 N 23 50 W 7248,55 N 20 35 ~ 7394.62 0.42 .0,92 0,29 0.00 4817.75 N 3248.27 ~ 5810.51 N 33 59 W 5484.65 N 3575.~7 W 6547.38 N 33 6 W 6132.75 N 3866.02 W 7249.61 N 32 13 W 6269.59 N 3922.10 W 7395.31 N 32 1 W 0000000c'DC~o 4" I--'~) CD U, I--~ ~0 C'-' (~' · · · · · · · · · · ~ c) o cD cD oc~c~cD ~ oc)oooooooo o o oc~c.~ ooooo o o cD O00CL30000 0 0 0000000000 0000000000 0000000000 0000000000 · · · · · · · · a, · 0000000000 0000000000 00000000 oooooooooo ~~~o~o ~~)~'~ZZ oo~o~~-~o Iill oooCooc~ooo ;,;,,L,S;-,; .¢ o ~o~o~o OlIJIlIIII (~ (/) (~ (/3 03 (~) (~ (~ Z Z l'~J C) I~ UJ 0'- 60 I-'z' rj: t_,,J 0 ITi H (-1 --I K__'J ZI'-- rr~ -n ~ H r Z · IO Z---I i~~, r- -3i ~ oZ m I ARCO ALASKA, DS ii-Z7 PRUDHOE BAY NORTH SLOPE, T MEASURED VER DEPTH D 4526.72 39 4677.25 40 4825.87 41 4974.93 42 5133.68 43 5290.13 44 5446.81 45 5605.43 46 5766.48 47 5927.07 48 6086.3'7 49 6243.56 50 6399.99 51 6555.11 52 6708.15 53 6861.03 54 7019.00 55 7187.50 56 7364.99 57 754~.63 58 7721.39 59 7897.49 60 8070.21 61 8238.28 62 8404.50 63 $569.97 64 8733.50 65 8894.38 66 9054.22 67 9210.43 68 9365.71 69 9521.99 70 9679.10 71 9833.70 72 9984.04 73 10134.26 74 10284.89 75 10436.15 76 10587.66 77 10736.28 78 INC. ALASKA COMPUTATION DATE: RUE TIDAL EPTH 58.00 58.00 58.00 58.00 58.00 58.00 58.00 58.00 58.00 58.00 58.00 58.00 58.00 58.00 58.00 58.00 58.00 58.00 38.00 58.00 58.00 58.00 58.00 58.00 58.00 58.00 58.00 58.00 58.00 58.00 58.00 58.00 58.00 58.00 58.00 58.00 58.30 58.00 58.00 38.00 INTERPCLATED VALUES FOR EVEN 100 SUB-SEA CgURSE VERTICAL DEVIATION AZIMUTH DEPTH OEG MIN DEG MIN 3900.00 48 26 N 29 48 W 4000,00 48 1 N 29 16 W 4100,00 47, 32 N 28 44 W 4200.00 49 7 N 32 50 W 4300.00 51 5 N 35 42 W 4400.00 50 22 N 35 27 W 4500,00 50 40 N 36 11 W 4600,00 51 31 N 36 26 W 4700.00 51 14 N 36 43 W 4800.00 51 15 N 36 53 ~ 4900,00 50 57 N 37 6 W 5000.00 50 31 N 36 26 W 5100.00 50 7 N 35 36 W 5200.00 49 30 N 34 52 W 5300.00 48 45 N 35 10 W 5400.00 50 ~ N 34 56 W 5500.00 51 35 N 34 44 W 5600.00 54 44 N 34 15 W 5700.00 56 23 N 33 47 W 5800.00 53 39 N 33 55 W 5900.00 55 44 N 33 45 ~ 6000.00 54 55 N 33 50 W 6100.00 54 6 N 34 0 W 6200.00 53 4 N 34 21 W 6300.00 52 55 N 34 32 W 6400.00 52 39 N 34 37 W 6500,00 51 45 N 34 45 W 6600.00 51 33 N 3~ 54 W 5700.00 50 4~ N 35 9 W 6800.00 49 45 N 33 13 W 6900.00 49 55 N 35 19 W 7000.00 50 34 N 33 24 W 7100.G0 50 15 N 27 19 W 7200.00 48 47 N 26 44 W 7300,00 48 16 N 26 39 W 7400.00 46 18 N 20 56 W 7500.00 48 19 N 26 42 W 7600.00 48 47 N 20 27 W 7700.00 48 26 N 26 10 W 7800.00 47 34 N 25 46 W 5-FE8-87 DATE GF SURVEY: KELLY BUSHING ELiVATIDN: ENGINEER: VERTICAL SECTION FEET 1338.29 1650.76 1760.61 1871.08 1994.03 2114.05 2234.30 2356.99 2482.66 2607.74 2731.09 2851.85 2971.69 3090.00 3205.59 3320.97 3442.99 3578.38 3724,84 3873.91 4019.52 4164.34 4305.00 4439.90 4572.46 4704.08 4833.24 ~959.01 3083.43 5203.22 5321.67 5441.49 5562.53 5680.08 5791.99 5903.75 6016.05 6129.17 6242,58 6352.01 FEET OF SUB-SEA DEPTH DOGLEG RECTANGULAR COORDINATES H SEVERITY NORTH/SOUTH EAST/WEST DI BEG/lO0 FEET FEET FE 0.44 1276.73 N 861.25 W 1540 1.13 1374.60 N 916.77 ~; 1652 0.84 1470.63 N 969.94 W 1761 5.50 156b.77 N 1024.77 W 1372 3.06 1667.44 N 1095.88 W 1'995 1.05 17~5.81 N 1165.13 W 2115 0.46 1863.70 N 1235.60 W 2236 0.94 1963.34 N 1307.90 ~ 2359 1.60 2064.51 N 1383.42 W 2435 0.38 2165.24 N 1458.53 W 2610 0.5'7 2264.10 N 1533.38 W 2734 1.23 2361.66 N 1603.39 W Z633 0,61 2458.75 N 1676,42 W 2975 0.86 2555.66 N' 174~.77 W 3094 1.26 2650.50 N 1811.29 ~ 3210 1.10 2745.15 N 1877.70 N 3325 2.98 2845.42 N 1947.70 W 3448 1.67 2957.14 N 2024.56 W 3583 0.59 3078.77 N 2106.43 W 3750 1.10 3202.74 N 2189.50 W 3879 0.60 3323.76 N 2270.74 W 4023 0.17 3444.33 N 2351.20 ~ ~170 0.75 3561.19 N 2429.77 W 4311 0.38 3672.93 N 2505.67 W 4446 0.69 3782.31 N 25~0.94 W 457~ 0.20 3890.88 N 2655.73 W 4710 0.36 3997.30 N 2729.32 0.42 4100.71 N 2801.35 W 4966 0.59 4202.82 N 2372.91 W 50~0 0.34 4300.92 N 2942.16 W 5210 0.10 4397.91 N 3010.65 W 5329 4.15 4496.26 N 3079.54 W 5449 0.65 4601.68 N 3139.12 N 5570 1.42 ~706.78 N 3192.53 W 5687 0.41 4807.10 N 3242.92 k 5795 0.16 4907,20 N 3293.40 W 5909 0,31 5007.66 N 3344,31 W 6021 0.14 5109.17 lq 3395.09 ~ 6134 1.07 5211.19 N 3445.5'7 W 6247 0.69 . 5310.20 N 3493.34 W 6356 PAG~ 7 ZO-JA N-..87 38.00 PT MCBRIDE GRIZ. DEPARTURE ST. AZIMUTH ET DEG MIN · 07 N 34 0 W .27 N 33 42 W .86 N 33 24 W .15 N 33 11 W · 32 N 33 18' .57 N 33 25 .09 N 33 32 ,, · 09 N 33 40 W .17 N 33 49 N · 57 N 33 57 W .49 N 34 6 W .65 N 34 12 W .87 N 34 17 W · 45 N 34 19 W · 2~ N 34 20 W ,90 N 34 2_2 W .18 N 34 23 w .'TS N 34 23 W .40 N 34 22 W · 62 N 34 21 W · 37 N 34 gO w · 32 N 34 19 w ,13 N 34 18 W · gl N 34 18 W · 99 N 34 18 W . ~2 N 34 18 · .gO N 34 19 · 2Z N 34 20 N · 90 N 34 21 N . '97 h 34 22 W .o9 N 34 23 W · 76 N 34 24 W .42 N 34 16 w · 35 N 34 8 W .69 N 34 0 W .91 N 33 ~2 w .72 N 33 ~4 N .35 N 33 36 w .27 N 33 25 W .2.3 N 33 2_0 W ARCO ALASKA, INC. DS Il-Z7 PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATIDN DATE: 5-FEB-87 P~GE 8 DATE ~F SURVEY: ZO-J~N-~7 , KELLY ~USHING ELEVATION: 58.00 ET ENGINEER: MCORICE INTERPOLATED VALUES FOR EVEN 100 FEET OF SU6-SEA DEPTH TRU2 SUB-SEA' COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG 'MIN 10883.91 7958.00 7900.00, 47 3 11029.20 8058.00 8000.00 45 58 11172.28 8158.00 8100.00 .45 27 11313.69 8258.00 8200.00 44 16 11453.92 8358.00 8300.00 44 34 11594.96 8458.00 8400.00 45 3 11736,92 8558,00 8500,00 45 36 11880.25 8658,00 8600,00. 45 42 12023.28 8758.00 8700.00 45 40 12164.48 8858.00 8800.00 43 55 12210.00 8890.79 8832.79 43 55 DEG MIN FEET DEG/iO0 FEET FEET FEET OEO MIN N 25 16 W 6460.06 N 24 43 W 6564,83 N 23 59 W 6666,40 N 22 51W 6765,50 N 23 33 W 6862.87 N 24 25 W 6961,54 N 24 43 W 7061.62 N 24 21W 7163,63 N 2.3 48 W 7265,09 N 20 35 W 7363.59 N 20 35 W 739~.62 1',05 0,35 0,16 5,72 0,65 0,45 0,84 0,55 0,60 0,00 0.00 5408.21 N 35~0.13 W 6~63.84 N 33 12 W 5503.73 N 3584.67 W 6565.17 N 33 4 W 5596.98 N 3626.78 ~ 6669.31 N 32 56 N 56~8.59 N 3666.83 W 6767,99 N 32 48 W 5778.80 N 3705.88 ~ 6~64.99 N 32 40 ~1 5869.64 N 3746.38 ~ 096,3.33 N 32 32 5961.22 N 3788.37 ~ 7063.14 N 32 26 ~, 6054.56 N 3831.19 W 7164.89 N 32 19 W 6148.00 N 3872.70 W 7266.10 N 32 12 N 6240.03 N 3910.99 W 736~.36 N 32 4 W 6269,59 N 3922.10 N 7395,31 N 3Z 1 W ARCO ALASKA~ INC. DS 11-27 PRUDHOE BAY NORTH SLOPE, ALASKA MARKER TOP SHUBLIK TOP SADLEROCHIT ZONE 3 ZONE 2 G/O CONTACT G/O CONTACT ZONE 18 SASE SADLEROCHIT PBTD DRILLER TD COMPUTATION DATE: INTERPOLATED VALUES MEASORED DEPTH BELOW KB 11381.00 11420.00 11586.00 11673.00 11838.00 11891.00 11919.00 12061.00 12166.00 12210.00 5-FEB-8? FOR CHOSEN HORIZONS ORIGIN: TVD FROM ,K~ SU~-SEA 8305.95 8247.95 8333.80 8275.80 8451.67 8393.67 8513.10 8455.10 8628.50 8570.50 8665.52 8607.52 8685.11 8627.11 8784.40 8726.40 8859.09 8~01.09 8890.79 8832.79 DATE KELLY BUSHING SUR FSL~229' FEL,S RECTAN NISRTH OF SURVEY: ELEVATION: ENGINEER: FACE LOCATION AT EC 28,TllN R15E,~N GULAR COORDINATE /SOUTH EAST/WEST 20-JAN-.B7 55.00 FT MCBRIDE 5751.93 N 3685.61 5756.99 N 3696.41 5863.~7 N 3743.77 5919.90 N 3769.36 6027.04 N 3818.66 6061.56 N 3834.36 6079.~2 N 3842.56 6172.66 N 3883.60 6241.02 N 3911.36 6269.59 N 3922.10 ARCO ALASKA~ INC. DS 11-27 PRUDHOE BAY NORTH SLOPEr ALASKA MARKER TOP SHUSLIK TOP SADLEROCHIT ZONE 3 ZONE 2 G/O CONTACT G/O CONTACT ZONE lB BASE SADLEROCHZT PETD DRILLER TD COMPUTATION DATE: ,,MEASDRED DEPTH BELOW KB ,. 11381.00 11420.00 11586.00 11673.00 11838.00 11891.00 11919.00 12061.00 12166.00 12210.00 5-FEB-87 DATE OF SURVEY: KELLY BUSHING ELEVATION: ENGINEER: FROM .K~ 8305.95 8333.80 8451.67 8513.10 8628.50 8665.52 8685.11 8784.40 8859.09 8890.79 PAGE 10 2.0-JAN-~7 58. O0 ~T MCBRIDE SURFACE LOCATION AT ORIGIN: 451' FSL,229' FEL,SEC 28,TllN,R15E,UM TVD RECTANGULAR COORDINATES SUB-SEA N~RTH/SOUTH EAST/WEST 8247.95 5731.93 N 3685.61 W 8275.80 5756.99 N 3696.41 W 8393.67 5~63.~7 N 3743.77 W 8455.10 5919.90 N 3769.36 W 8570.50 6027.04 N 3818.66 W 8607.52 6061.56 N 3834.36 W 8527.11 6079.82 N 3842.56 W 8726.40 6172.66 N 3883.60 W 8801.09 6241.02 N 3~11.36 W 8832.79 6269.59 N 3922.10 W FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH CEPTH 12210.00 8890.79 8832.79 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 7395.31 N 32 1 ~B[~£ 33N3W3~3W /.8 - NWP - O~ 030009 3/W0 ~ o Nnw 093IB £~-II SO 993M · 3NI 'W>~SW-]W ODWW ANUdN03 A3AUr]s qlUNO 1133W I O U30W38NQ3HOS ISU~ 153H 0008 0009 000~ 0002 0 0002- 000~- 0009- 0008- I::-:: :i i.:.;";"!i · !,-'..I-:,'-~ !';" :-- ';., ........ ~--,--.¥-, ~-I ~--;--': ...... !..-;-;.-:.--~-t-~---::-,.~---~ ;--;-.-~-d---~---,-.;-.-;---~---~---.~---:'.-.:---t--,--~ ...... :--.~--;.~*-~--d ooo~-.&nos .. ;. =77¥'7.'¥-:; C~.~--~' ':..~ ~..L;...~.. ;... ~... ~...~..~ , ~ ~ · , . ~ ~ ;.......¢..~...,...~..., .... ~...~. i-.~ ~: -~ ;--;--:..: .... :..~ :. :..~.: ~...~...:... :.;..~...~...~.. 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'J . .. ;;;;;.;. .. .;;; ..;;.;~ ; :.;;;;..;; .;.?.' ================================;;;;~..L;;;¥';:.;.'; E;' '; - 7' ?' :': ~": 'r" 7"t' ;'"'F';" -t .... ' ' - ~ : : ' ~ ; ~ ; ; t ' * - ' · ' ; ; ~ : : ;'="!'"7'7 ....... 7"J"'?"~'"7"'."'~ NOI123~O~d ]VINOZI~OH (Hfi '35L~ 'NLti 'SZ '~S ']3~ ,6ZZ.'qS~ ,L~) ZZ-L'L 3IIS]]I~O ']]3M II - '88£ 3N~'id '1U31183^ NO NOi.LJBPO~8 '8ZE 00081 NOIi33fO~d ]VDIi~]A .Z2-.[I ~'ilSqlI~ 'qqqM Xl( N ddV ARCO Ala_~ka, Inc. P,O, Box I00S50 Anchorage, Alaska 995~0 DATE: August tt, t987 REFERENCE: ARCO t--t6 7-25-87 Static Gradient 1-25 8-2-87 HF' Pressure Survey Log t t--26 8--2-87 HP F'res~ure ~'urvey Log t-27 8-2-8'7 HP F're$$ure Survey Log 2-26 7-25-87 ~'t"a~ic Gradient Run l Run t Run t Otis $ch ~ch $ch Otis PI. ease sign mad return the mtfmched copy a.s receipt of data, Received By HAVE A NICE DAY! Ro~anne Peek ATO-I 529 I'RAN~ ~874tS ~ Approved~ ................ DISTRIBUTION Central I:.'i Le.s Chevron · "',- I) & M Extension Exp[or'ation ~rz EX XOll Marathon ~ Mob i I. · ,,-" F'hi [Lips; F'B 14~11 ~- R & I) ~ Soh i o ~ ,S"l:.afe of Alaska .- Texaco - STATE OF ALASKA AL, ~A OIL AND GAS CONSERVATION CO. ~ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed. Operation shutdown .~ Stimulate Alter Casing ~ Other ~ Comp'lete 2. Name of Operator ARCO Alaska, Inc. 3. Address P.0. Box 100360 AnchOrage, AK 99510-0360 4. Location of well at surface 451' FSL, 229' FEL, 5ec.28, TllN, R15E, UN At top of productive interval 928' FSL, 1355' FWL, Sec.21, TllN, R15E, UM t effective depth A1412' FSL, 1140' FWL, Sec.21, TllN, R15E, UM A~4t~t§l ~lCLP,th1129' FWL, Sec.21, T11N, R15E, UN Plugging r~ Perforate I~ Pull tubing 5. Datum elevation (DF or KB) RKB 58' 6. Unit or Property name Prudhoe Bay Unit 7. Well number 11-27 8. Approval number 7-121 9. APl number 50-- 029-216:38 10. Pool Prudhoe Bay 0il Pool Feet/ 11. Present well condition summary 12210'MD Total depth: measured true vertical 8891 'TVD Effective depth: measured 12166'MD true vertical 8859'TVD Casing Length Size Conductor 80' 20" Surface 2525' 13-3/8" Production 11342' 9-5/8" Liner 1164' 7" Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) 5-1/2", L-80, tbg w/tail (~ 11115' Packers and SSSV (type and measured depth) 3B-3 pkr (~ 11026' & BAL-O SSSV @ 2225' feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth 200 fta Poleset (approx) 110'MD 2500 sx'CS II1 & 2555'MD 400 sx CS II 500 sx Class G & 11368'MD 300 sx AS I 350 sx Class G 11046'-12210'MD True Vertical depth 110'TVD 2518 ' TVD 8297'TVD 8070 '-8859 'TVD 12. StimUlation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well Hist.o. ry w/Addendums, dated 3/20/87 & 6/8/87) Daily Report of Well Operations ~ ' Copies of Logs and Surveys Run ~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Title Associ ate Engineer Date (Dani) SW02/47 Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District State Alaska North Slope Borough Alaska Well no. 11-27 County or Parish Field Lease or Unit Prudhoe Bay ADL #28322 Auth. or W.O. no. T t e AS1037 Completion WWS #1 A_PI 50-029-21638 Operator A.R.Co. W.I. ARCO Alaska, Inc. 21.66% Spudded or W.O. begun Date Complete 6/22/87 Date and depth as of 8:00 a.m. 6/22/87 thru 6/23/87 6/24/87 Complete record for each day reported Iotal number of wells (active or inactive) on this I Dst center prior to plugging and I bandonment of this well I our 1 Prior status if a W.O. I 0830 Hrs. / il~' - 7" @42,210' 12,166' PBTD, RIH w/5½" CA 9.3 ppg Brine Accept rig @ 0830 hrs, 6/22/87. ND tree, NU & tst BOPE to 5000 psi. RU DA, make 2 rns w/GR/JB, RD DA. RU & rn 266 its, 5½", 17#, L-80 AB Mod 8RD tbg w/SSSV @ 2225', SB-2 perm pkr @ 11,026', TT @ 11,115'. 7" @L12,210' 12,166' PBTD, RR Diesel Rn 266 its, 5½" & 1 jt 5" tbg & lnd w/TT @ 11,115', SB-3 pkr @ 11,026', SOS @ 11,114', X nipple @ 11,094'. Displ w/diesel. Set pkr. Tst tbg to 3000 psi. Set BPV. ND BOPE, NU & tst tree to 5000 psi. RR @ 0500 hrs, 6/24/87. Move rig to DS 13-14. Old TD New TD PB Depth 12,116' Released rig Date Kind of rig 0500 Hrs. 6/24/87 Rotary Classifications (oil. gas, etc.) Type completion (single. dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Sadlerochit 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 The abov,~.~ correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date Title 7/21/87 Drilling Supervisor ADDENDUM WELL: 3/30/87 11-27 Arctic Pak w/300 sx CS I & 119 bbls Arctic Pak. Tst failed. 5/30/87 Re-Arctic Pak well w/300 sx AS I & 110 bbls Arctic Pak; tst failed. Will re-tst. Drilling Supervisor Date ADDENDUM WELL: 1/21/87 11-27 RU Schl, rn CBT/GR/CCL f/10,947'-12,170' @ 0 psi. Rn GCT gyro f/12,150'-surf. Secure well. Drilling Supervisor Date STATE OF ALASKA ALASK,-, OIL AND GAS CONSERVATION COMM..,,.41ON APPLICATION FOR SUNDRY APPROVALS 1, Type of Request: Abandon ~, Suspend ,D Operation Shutdown ~ Re-enter suspended well '~ Alter casing '% Time extension [] Change approved program ~_ Plugging ~ Stimulate '_% Pull tubing .'.-' Amend order ~ Perforate - Other _- 2. NaAn~f Ooerator ATaska, Inc 3. Address P. O. Box 100360 Anchorage, AK 9951 0-0360 4. Location of well at surface 451 ' FSL, 229' FEL, 5ec.28, At top of productive interval 1320' FSL, 1320' FWL, Sec.21, At effective depth 1468' FSL, 1126' FWL, Sec.21, At total depth 1439' T11N, R15E, UM T11N, R15E, UM (approx.) T11N, R15E, UM FSL, 1138' FWL, Sec.21, T11N, R15E~ UM (approx. ) (approx.) 5. Datum elevation (DF or KB) RKB 58 ' 6. Unit or Property name Prudhoe Bay Unit 7. Well number 11-27 8. Permit number 86-148 9. APl number 50--n79- 71RZR 10. Pool Prudhoe Bay Oil Pool feet 11. Present well condition summary Total depth: measured true vertical 1 2,21 0 ' M D feet 8881 ' TVD feet Plugs (measured) None Effective depth: measured 1 2,1 66 ' MD feet true vertical 8850 ' TVD feet Casing Length Size Conductor 80 ' 20" Surface 2525' 13-3/8" Production 11 ,342' 9-5/8" Liner 1164' 7" Junk (measured) None Measured depth llO'MD Cemented Conductor report not available 2500 sx CS II I & 2555 'MD 400 sx CS II 500 sx Class G 11,368'MD 350 sx Class G 11,046'-12,210'MD True Vertical depth 110'TVD 2516'TVD 8291'TVD 8065'-8881' Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None Packers and SSSV(type and measured depth) None 12.Attachments WELL HISTORY Description summary of proposal Detailed operations program _ BOP sketch _ 13. Estimated date for commencing operation June, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed d~//~/y~(.~J ~_f~.~L~p(,,~L..,_ Title Associate Engineer (DANI) SA/217 -' Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. I Date Approved by Plug integrity Commissioner Form 10-403 Rev 12-1-85 BOP Test ..- Location clearance by order of the oommis io. D t. Submit in triplicate 'G~scom~.~nY:': <}-- Well History- Initial Report-Dally ~--'~i th.e ',~,~';L~itlel Report" on the fi~:st Wednesday after a well is spudded o .... kover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District : ~:'~ ICounty. parish or b .... gh Alaska ' I North Slope Boroush Field ILease or Unit Prudhoe Bay liT'tie ADL #28322 Auth. or W.O. no. ' AS 1037 I Dr ill State Alaska Well no. 11-27 Parker #141 API 50-029-21638 Operator ARCO Alaska, Inc. Spudded or W.O. begun IDate Spud I 12/27/86 Date and depth Complete record for each day reported as of 8:00 a.m. I ARCO w.I. IHour Prior status if a W,O, 1300 Hrs. 12/28/86 thru 12/29/86 12/30/86 12/31/86 1/01/87 thru 1/02/87 1/03/87 thru 1/05/87 21.66% 20" @ 110' 2094' (1984'), Dyna drilling Wt. 9.2, PV 20, YP 38, PH 8.5, WL 16.9, Sol 0 Accept rig @ 0100 hrs, 12/27/86. NU diverter sys. S~ud well @ 1300 hrs, 12/27/86. Drl & surv to 2094'. 1645', 3.0°, N32.3W, 1644.95TVD, 3.66VS, 3.64N, 1.05W 1855', 8.8~, N29.SW, 1853.84TVD, 25.25VS, 22.15N, 12.13W 20" @ 110' 2575', (481'), Rn'g 13-3/8" csg Wt. 9.2, PV 21, YP 44, PH 9.0, WL 16.4, Sol 7 POOH for new bit. TIH, wsh & rm f/2233' - 2292'. DD & surv to 2575', C&C, POOH to run csg. RU & run 13-3/8" csg. 2064', 15.3°, N36.gw, 2058.27TVD, 68.68VS, 58.51N, 35.92W 2500', 24.6°, N37.9W, 2466.96TVD, 218.98VS, 180.67N, 124.16W 13-3/8" @ 2555' 2575', (0'), Test BOPE Wt. 8.5, PV 4, YP 3, PH 8.0, WL --, Sot.2 Fim rn'g 63 its, 13-3/8", 72#, L-80 BTC csg w/FC @ 2472', FS @ 2555'. Cmt w/2500 sx CS III & 400 sx CS II. Displ using rig pmps, bump plug to 2000 psi - OK. Install McEvoy Gen III csg head & tbg spool. NU & tst BOPE. 13-3/8" @ 2555' 5490', (2915'), Drlg Wt. 9.2, PV 2, YP 2, PH 8.0, WL --, Sol 7 TIH w/BHA, tst csg to 2000 psi. DO cmt & flt equip + 10' new hole. Perform leakoff test to 14.3 ppg EMW. Drl f/2584'-2616'. Lost pump press. TOH, chg bit. Jet & drl to 3556', DD to 5490'. 13-3/8" @ 2555' 9075' (3585'), Drlg Wt. 9.6, PV 8, YP 4, PH 10, WL 8.2, Sol 9 Drl & surv 12¼" hole to 9075'. 5489', 51.2°, N36.1W, 4576 TVD, 2293 VS, 1913N, 1269W 6061', 50.7°, N37.9W, 4934 TVD, 2738 VS, 2271N, 1535W 6687', 48.8°, N35.1W, 5336 TVD, 3215 VS, 2657N, 1819W 7009', 51.6°, N35.4W, 5543 TVD, 3462 VS, 2860N, 1962W 7633', 55.4°, N34.7W, 5903 TVD, 3970 VS, 3279N, 2250W 8320', 53.1°, N35.0W, 6303 TVD, 4528 VS, 3741N, 2565W 8937', ~51.5°, N35.1W, 6680 TVD, 5016 VS, 4142N, 2844W The~ is correct For form prep~,t~n and distrib~+i~~, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IOs~e 2/0b/87 I Title Oril£lng Supervisor ARCO Oil and Gas Company ~ Daily Well History--Interim nstructione: 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 official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District County or Parish [State Alaska North Slope Borough I Alaska Field Lease or Un t Prudhoe Bay ADL #28322 Date and deptt~ Complete record for each day while drilling or workover in progress as of 8:00 a.m. Well no. 11-27 1/06/87 1/07/87 1/08/87 1/09/87 1/10/87 thru 1/12/87 1/13/87 13-3/8" @ 2555' 9612' (537'), DD Wt. 9.7, PV 10, YP 5, PH 10, WL 7.0, Sol 10 Drl & surv 12¼" hole to 9612'. 9256', 50.3°, N34.7W, 6881.39 TVD, 5262.57VS, 4344.62N, 2985W 13-3/8" @ 2555' 10,395', (783'), Drlg Wt. 9.8, PV 10, YP 8, PH 9.5, W-L 6.8, Sol 10 Drl & surv 12¼" hole to 10,395'. 9,617', 50.5°, N27.7W, 7111.50 TVD, 5540.72 VS, 4582.54N, 3129.44W 10,311', 48.5°, N26.3W, 7567.65 TVD, 6062.15 VS, 4995.94N, 3364.32W 13-3/8" @ 2555' 11,167', (772'), Drlg Wt. 10.0, PV 19, YP 10, PH 9.5, WL 5.6, ~ol 12 Drl & surv 12¼" hole to 11,167'. 10,622', 48°, N25.6W, 7774.94 TVD, 6293.04 VS, 5204.49N, 3465.59W 10,995', 46.1°, N24.2W, 8028.84 TVD, 6564.62 VS, 5452.33N, 3580.63W 13-3/8" @ 2555' 11,385', (218'), Rn'g 9-5/8" csg Wt. 10.1, PV 21, YP 10, PH 9.5, WL 5.5, Sol 12 Drl & surv to 11,385', short trip, C&C, POOH. RU to rn csg. 10,311', 48.5°, N26.3W, 7567.65 TVD, 6062.15 VS, 5047.56N, 3364.32W 10,622', 48.0°, N25.6W, 7774.94 TVD, 6293.04 VS, 5256.12N, 3465.59W 10,995', 46.1°, N24.2W, 8028.84 TVD, 6564.63 VS, 5503.96N, 3580.63W 11,323', 44.6°, N23.1W, 8259.14 TVD, 6796.12 VS, 5717.97N, 3674.13W 9-5/8" @ 11,368' 12,210', (825'), CBU Wt. 7.3, PV 16, YP 12, PH 11.0, WL 5.6, Sol 7 Fin rn'g 9-5/8" csg w/FC @ 11,286', FS @ 11,368'. Cmt w/500 sx C1 "G" w/.75% D-31 & .20% R-5. Drl & surv to 12,210', POH f/logs. RU DA, rn DIL/Sonic/GR/SP f/12,210'-11,368', CDL/CNL/GR/CAL f/12,210'-11,368'. Cont w/GR to 13-3/8" shoe, RD DA. Make wiper trip, CBU. 12,210', 44.8°, N16W (SS) 7" f/11,046'-12,210' 12,210', (0'), POOH Wt. 9.3, PV 13, YP 9, PH 9.5, WL 5.8, Sol 7 C&C, POOH. RU & rn 26 + 1 mkr jr, 7", 29#, L-80 BTC lnr f/11,046'-12,210' & cmt w/350 sx C1 "G" w/3% KCl, 1.1%, FL-28, .2% A-2, .3% CD-31 & 1 gal/lO0 sx FPSL. Displ using rig pmps, bump plug. POOH. The a~c.~is correct Drilling, Pages 86 and 87 2/06/87 Drilling Supervisor i/-~i[.and Gas Company ~ Daily Well History-Final R Instructions: Prepare and submit the "Fine! Report" .o.n the first Wed.ne.sd. ay after ,al!.o .w. able has been. .ass. igned or well is,, Plugg. ed. Aban. do . o,r ,So. Id. "Final Rel3ort" shOuld be submitted also when o. perations .a~e su.spe, no.e~ for .a.n in. oenmt~ .or. a_p.Preci_ame. ~_ength.of.time. ,Jn .worKove. rs, when an. onic~al test is not required upon completion report completion anD representative test Data in DlOCRS proviDeD. /ne "l-inel Plepor~" ]orm may De used i'or reporting the entire operation if space is available. District Alaska Field Prudhoe Bay Auth. or W.O. no. AS1037 County or Parish Lease or Unit Title North Slope Borough ADL #28322 Drill IAccounting cost center code State Alaska Well no, 11-27 Parker #141 Operator ARCO Alaska, Inc. API 50-029-21638 A.R.Co. W.I. 21.66Z Spudded or W.O. begun Date Spud 12/27/86 Date and depth Complete record for each day reported as of 8:00 a.m. 1/14/87 1/15/87 I otal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our Prior status if a W.O. 1300 Hrs. 7" f/11,046'-12,210' 12,210', (0'), Drlg LC Wt. 9.3, PV 12, YP 8, PH 12.0, WL 6.8, Sol 7 Fin POOH. MU bit & csg scrpr, TIH to 12,040', tst csg to 3000 psi. Drl cmt f/12,040'-12,079'. 7" f/11,046'-12,210' 12,166' PBTD, (0'), RR 4.5 ppg Brine Drl cmt to FC @ 12,166' PBTD. Displ well to 9.3 ppg NaCl, press tag csg to 3000 psi; OK. LD DP, spot 400' diesel cap. ND BOPE, NU & tst tree. RR @ 0400 hrs, 1/15/87. Skidding rig to DS 11-26. Old TO Released rig 0400 Hrs. Classifications (oil, gas, etc.) Oil Producing method FlOwing New TD Date 12,210' 1/15/87 PB Depth Kind of rig IType completion (single, dual, etc.) Single Official reservoir name(s) Sadlerochit 12,166' Rotary Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Produclion Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective dale corrected The above is correct For form prep~mt.~n and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. I Date ITitle ~[e, 2~06~87 Drilling Supervisor ;:-:-:: I' :-.- (:) 'f: ,::I a '1: ,::i :. ... .. :.....: :'~ !.2 ...-.,. ., ~ i.:..! ' h... ..i .... ~.-..~ ~:..... ~ ..... > ~ 'i'.' ~2 L~'"~ U 3:. :-.:'~ Cf! '::i.~ :':: <C 0 .... ":'" · .:. ........ :l::" ,i-'": :i.':'- .::ii i ...... !: :.! .... :2.:.. · ...... ....... ~"_:~ ....... i!i!: ....... ?-' :'~.~ ...... · :.:ii~ .:l :'i~::.:: ..~:2 i::!.'i~ iD ..~.,' .:'i~ (178-0L Aa~)~ LO0-~O pIaI~ z[~q aoqpn~ /E-II S(I flgct OD'~V ~ s a,T, clOE :_l. O3rBns ~Hs~lV jo : glOl:l--I :Nil H_L :Ol STATE OF ALASKA ~ALASKA OIL ~.O.P.E. Inspection Eeport Represenca::tve Reserve ~4 ' ,Mud Svst~s Visual Audio Trip Tank Gas Detec:ors . BOPE Stack Annular Preventer Pipe R~-~ Blind P.~- ~ Choke Line Valves N.C.P,. Valve YdH Line Taives Check V~=e Test Pressure Full Ch~-rge Pressure ~~.~ psi~ Pressure After Closure /~~ psig Pump incr. c!os. pres. 200 psiE Full Charge Pressure Attained: ~ =in ~3sec. :i~ ~ sec. Con:roil: ~suer ; Remoue~~ Blinds s~i:ch Ke!iv and Floor Safety Valves Upper Kelly / Test Pressure Lower Ke~y / Test Pressure Ball T)Te / Test Pressure Inside BOP / Test Pressure No. V~!ves ~ No. flanges ~ ~ Adjuszabie Chokes / Hvdrauica!lv ooerated choke / Test Resu!us: Failures ~ Tes: Time Repair or Rep!acemen~ of faiie~ equipment to be =a6e ~:hin o Co~issicra ~' -~' Remarks: -' h~s. 6ay~ and Inspec:o:/ Dis:_-ibu:ton orig. - AO&GCC cc - Opezauor cc - Supervisor July 28, 1986 Mr. T. P. Oostermeyer Regional Drilling Engineer ARCO Alaska, Inc. Po O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Prudhoe Bay Unit DS 11-27 ARCO Alaska, Inc. Permit No. 86-!48 Sur. Loc. 451'.FSL, 229'FEL, Sec. 28, TllN, R15E, Btm_hole Loc. !470;FSL, 1229'~, Sec. 21, T!IN, R15E, U~. Dear Mr. Oostermeyer: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to co~encing 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. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Co_v~nission may witness testing before drilling below the shoe of the conductor pipe. Ve~) tr~uly~o~rs~ ~ [ I J/( ?I~../~-~,: Chai~an o~ Alaska Oil and Gas Conservation Co~ission BY ORDER OF ~!E CO}*~4ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation ~g/o enc!. ~. Doug L. Lowery STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION CUMMISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill ~ Redrill ~.1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry ~ Deepen~1 Service ~ Developement Gas I~ Single Zone [~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 58', PAD 27'GL feet ~rudhoe Bay Fieid 3. Address 6. Property Designation ~rudhoe Bay Oil Pool P.O. Box 100360 Anchorage~ AK 99510 ADL 28322 ALK 2326 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 451'FSL,229'FEL,Sec.28,T11N,R15E,UM(approx) Prudhoe Bay Unit ~tatewide At top of productive interval ~ Target 8. Well nu,mber Number 1320'FSL, 1320'FWL, Sec.21, T11N, R15E, UM 11-27 ~8088-26-27 At total depth 9. Approximate spud date Amount 1470'FSL, 1229'FWL, Sec.21, T11N, R15E, UM 08/01/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line ~0' from 11-1~, 12104'MD 1229' ~ TD feet ~ 2500'TVD feet 2560 (8835'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 1500 feet Maximum hole angle49~° Maximum surface 2966 psig At total depth (TVD) 3850 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) Rf~'~ ;~n,, :~1 r~ Pl-b.n Wc. ld 8! ' ~R, 28' !09' !09' 200 ft3 Po!eset 17-1/2" 3-~/8" ~.0# K--~-~ RTC 53' 27' 77' .~O., ~O' ?~On 72,0# L-80 BTC 245'$' ~O' ~O' 2535 2500' 400 sx CS il 12-1/4")-5/8" ~7.0# L-80 NS-CC 5565' 25' 25' 5590 4500' 500 sx Class G )-5/8"~7.0# L-80 BTC 5685' 5590' 4500 11275 ' 8298' 8-1/2" 7"- 29..0# L-80 BTC 1129' 10975' 8103' 12104' 8835' 300 sx Class G Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ConductorRECEIVED Surface Intermediate JUL 2 Production Liner Alaska 0il & Gas Cons. C0mmissi0r~ Perforation depth: measured Anchorage true vertical .. 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ,,~ DiverterSketch ~ Drilling program Drilling fluid program ~ Time vs depth plot ~ Refraction analysis C Seabed report ~ 20 AAC 25.050 requirements 21. I hereby certify t_hat th~foregoing is true and correct to the best of my knowledge Signed /' Title Regional Dri 11 ing Engineer Date Commission Use Only ( GSW ) PD/PD302 , Permit Number ~;~. I APl number ,~' I A p p r~)v¢ I/~a~e/ I See cover letter '"/~' 50-- ¢ ~.'~ ~ ~-- ( r'.~. ¢, 8 6 for other requirements Conditions of approval Samples required L~ Yes ¢ No Mud Icg required ~ Yes ~No Hydrogen sulfide measures ~ Yes [q No Directional survey required ~ Yes .~ No Other: Required ~._.~~~J~~ 5M' ?i 10M; r-, 15M working essure or ~2 · ~ 3M; ,,~ , by order of Approved by Commissioner the commission Dat , ,. in triplicate DS 11-27 DRILLING PROGRAM 1. Set 20" conductor and cement. A 20", 2000 psi annular diverter might not be used for the well. A waiver of the surface hole diverter system for Drill Site 11 has been received from the AOGCC. 2. MIRU Nabors Rig 22E. 3. Drill 17-1/2" hole to 1500'MD(1500'TVD) . Kick off and build 2.5°/100' N31°15'W to 49°34'. Hold and continue drilling to 2535'MD(2500'TVD). 4. Set 13-3/8" casing and cement to surface. 5. Install 13-5/8", 5000 psi, RSRRA BOP stack. Test BOP stack to 5000 psi. Test BOP stack weekly. Perform leakoff test. 6. Finish build and drill 12-1/4" hole to 11,275'MD(8298'TVD). 7. Set 9-5/8" casing and cement. Test casing to 3000 psi . Perform leakoff test. 8. Drill 8-1/2" hole to 12,104'MD (8835'TVD). 9. Run open hole 1 ogs. 10. Set 7" liner from 10,975' - 12,104'MD (8103'-8835'TVD). Clean out liner. Displace hole wi th 9.4 ppg brine. Test liner to 3000 psi . 11. Secure well and release rig. 12. Run cased hole logs. 13. HIRU completion rig. 14. Run 5-1/2" tubing string with packer, gas lift mandrels and provisions for subsurface' safety equipment. Set packer above Sadlerochit. 15. NU tree and test to 5000 psi. 16. Secure well and release completion rig. 17. Perforate well and stimulate. NOTES: a. Reserve pit fluids will be disposed of down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The annulus will be seal ed wi th 300 sx of cement followed by Arctic Pack upon the completion of the fluid disposal process. b. The drilling fluid program and fluid surface system will conform to the regulations set forth in 20 AAC 25.033. c. Maximum surface pressure is based upon recent BHP surveys and a full column of gas to TD (0.10 psi/ft). d. Existing wells within 200' of the proposed well are: DS 11-13 80' at 2500'TVD; DS 11-14 118' at 700'TVD; DS 11-8 145' ~ 2661 'TVD; DS 11-11 168' at 2935'TVD. PD/PD302a:tw 07/21/86 AlaSka Oit & Gas Cons. comm'~ssio° AnChoYage Depth (TVD) Plas Density Vi sc. #/gal (CP) Surf 8.8 Funnel to to 100- 13-3/8" 9.2 250 Csg Poi nt DS 11-27 MUD PROGRAM Yield Point Initial 1OM FL % % pH and #/100 ft2 Gel Gel CC/30M Oil Solids T~/pe of Mud Ce1 -Benex 40-60 30+ 50+ 25 0 8 Spud Mud 13-3/8" Csg Shoe 8.8 to to K-10 9.4 M i ni mum Possible 2 2 5 25 3.5 Low Solids to to to to 0 to Non-dispersed 4 4 10 10 6.5 K-lO 9.2 10 to to to 9-5/8"Csg. Pt. 9.8 20 6 4 8 8 2 4 pH 9-10 to to to to to to Low Sol ids/ 10 8 12 4 5 8 Non-dispersed 9-5/8" Csg. Shoe 8.8 10 to to to TD 9.2 20 6 4 8 10 2 4 Low Solids/ to to to to to to Non-Dispersed 10 8 12 4 5 8 EQUIPMENT - DRILLING FLUID SYSTEM 1. Degasser 2. Shakers Pit level indicator (with both visual and audio warning devices) 4. Drilling fluid flow sensors (with readout convenient to the driller's console) 5. Trip tank 6. Agitators 7. Mud cleaners and centrifuges PD/PD302b:tw 07/21/86 DRILL SITE 1 1 TYPICAL HUD PIT $CHEI~ATIC (DRAWING IS NOT TO SCALE) CUTTINGS CONVEYOR I · SHAKERS ! ICENTRIFUGE I SAND TRAP TRIP TANK AGITATORS 1 AGITATOR CUTTINGS AUGER HUD CLEANER I '1 AGITATOR I AGITATOR AGITATOR tlUD CLEANER WATER TANK RECE PILL PIT AGITATOR :I\/FF~ ! ¥ I.· ~ J U L 2 5 1986 Alaska Oil & Gas Cons. Commission Anchorage JO 5/16/86 1.6. ,~cum,~acor C~cic¥ Test ~. ~k ~ ~ill K~ator ~se~oir co level ~th ~lic fl~. ~. ~s~ ~c ~~ator p~s~e is lO00 ~SO0 ps~ ~c~ oE c~ relator. ~e C~, C~n clo~ all '~Cs s~~ly all ~ts ~ clos~ wi~ ~r~ ~ cEE. is ~5 s~ clcs~ t~ ~ IZO0 pst Z. ~ck ~t all ~ld ~ s~s a~ ~I1~ ~. ~ test pl~ ~ ~1 pi~ ~ seat ~. ~o~ ~~ p~~r ~ ~$t~m valves. ~. ~i~l~ test · ~. -In e~ of ~ ~11~ tes~, [ir~ ~ld a Z~O psi 1~ ~s~ test ~r a ~ o~ ~ ~es, test at ~ ~ ~s~. 5. ~m ~s~ to ~0 psi ~ ~ld for of )~es. Sl~~~ to ze~. 7. ~m ~~ ~~er ~ cl~ t~ set ~. [~m ~$~ to ~000 psi ~ ~Id ~r at lent 3 ~. Bl~~s~ to :e~. 9. ~n top ~t of pi~ ~ t~ clcH ~t~ set pi~ ru.~ ~~ ~s~ to ~000 psi uce$. with SOOO psi ~c~ oi v~ ~ ~em press~e ~. ~o~ ~ jo~c ~~1 ~ c~1e. Close bl~ ~ ~ cesc co SO00 ps~ ~oc ac ~euc ~ces. ~1~ ~ss~ o~ all ~~. ~ bl~ r~. ~z~ ~ ~ a~l v~ves a~e sec ~ ~s~c~. Test sc~~ valves ~o ~000 ps~. ~y ~. ~ cesc ~o~c~on ~ bl~ p~vencer RECE:IVED J U L 2 5 1986 Ala~k~ Oil & Gat, Cons. RevisecL 2121184 O811-27 0 0 lO00 2000 3000 4000 5OOO 60CC 7000 8O0O 9000 10000 tO00 2000 3000 4000 5000 6000 7000 8000 9000 ...... ' ' ' ~b'-' ~;AW~ h~b' '-'~zb ................................... ' ................... o KOP TVD = 1500 ARC ::) AL,,a SKA, INC. i,[ 1~.5 ~CALI= I IN = 1000 Fl. 2000 i 2._ (ASING TVD = 2,500 MD = 2535 DEF = 230 SEC. 28, F11N, RI§E, U 2.5 THL: 1320' :SL, 1320' FVTL, 37.5 · -4-2.5 ~FC_ 21, '1'11N~ RI.RF~ I11~1 3000 ~-7.5 ECC TVD = 324.5 MD - 34B3 DEP "' 8()6 4000 '~~', N 31 E EG 15 MIN W 5000 7192 FT(TO TARGET AVERAGE ANGLE 49 DE{ 34 MIN 6000 ~, 7000 K-10 TVD = 7178 MD '-9548 DEP [] 5422 K-5 TVD = 7733 MD ~- 1040 I. DEP = 60;'4 ~ 8000 9-5/8' CASING T¥D ---- 8298 MD = 11275 DEP = 6737 LCU T~'D ---- 8307 NID ---- 11289 E~EP ---- 6748 TOP SAD .EROCHIT T~'D = 8308 !~40 = 11290 )EP = 6749 - ,'/O CONTA(:T TVD = 8{~33 MD = 11;'92 DEP = 7 30 - TAR(lIE7 TVD = 8 $88 MD = 1i873 DEP = 7192 -" BAS!-: SADLEROCH!T TVD =, .¢[73_~ MD -. 11954 DEP -- 7253 ' 9000 TD TVD = B835 MD = 12104 DEP [] 7367 LISBURNE TVD == 8913 MD = 12223 DEP = 7459 , ................................................................................. 10000 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 VERTICRL SECTION J U L [ 1986 Alaska 0il & G~s ~;ons, commission A.-,~-,. ;',, E - I,,,I COORDINFIT,.J o -6000 -5000 -4000 -3000 -2000 -1000 0 1000 SEC. 28 T11N, R15E, THL: 1321)' FSL, 1320' SEC. 21, T11N, R15E, I. OS1 1-~',7 TARGET 8 ,~85 TVD -- 86 TM D ---- 11 i73' DEP = 71~ N 6149 W 3731 I I I I I I I I I ~ [ I I I I I 0 o (33 0 o o (Jo 0 0 o 0 ~-~. I I -6000 -5000 -4000 -3000 -2000 - ! 000 0 - H O00ROINBTF. S 1000 E - 14 COORDINRTES o -6000 -5000 -4000 -3000 -2000 - 1000 0 1000 0 CD O O CD CF) o 0 '7 ; I I I I I Il' ' i i i ~ t i i i ii i [ I I ' ' i Ii i i ! i ! t ! I, t ! m i i i : i~ i i t , ~ ! ~t m , i ~ m t i i x t - 67 8760 ~677E 0', 11-8 96 359 ~q3F S ~56 ~ ~7 ~5 558; ~069 91~ ~882 ~67 3 / I 0S 11- 13 -6000 -5000 -4000 -3000 -2000 - 1000 0 E - N OOOROINBTES 88 1000 S~WNIOWO03 M - ~ i t 00~ 00~ 00~ 0 00[- 00~- 00£- 00~- OOg- SSIIWNIOWOO3 M - CHECK LIST FOR NEW W~JJ. PERMITS ITEM APPROVE DATE (1) Fee ~/~u_ ?- ~s~-~C 1. / (2) Loc ~/~, ~ - ~s~-8 ~ . (2' thru 8) ~: (8 (3) Achd_n /~?~ ~-%'-~/~ 9. '(9 thru 13). 10. '-/~-'* %,it~71f,% 11. ,,.~r., ~ .~," (10 and 13) <' 12. 13. (4) Casg ~~,~, 7-~'-MA (14 thru 22) 14. 15. 16. 17. 18. 19. 20. 21. 22. (6> OTHER (29 thru 31) (6> Add: Ceo logy .:, Rng'.zneering WVA rev: 07/18/86 6.011 Company YES Is the permit fee attached .......................................... Is well to be located in a defined pool ............................. Is well located proper distm]ce from property line .................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ................ Is operator the only affected party ................................. Can peri, it be approved before fifteen-¢~y wait ...................... Lease & Well No. NO Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ...................................... Does the well have a unique name and number ......................... 23. 24. 25. 26. 27. 28. For 29. 30. 31. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will c~nent cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandommnt procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schen~qtic mid list of equipment adequate Are necessary ¢liagrmns and descriptions of ~~ BOPE attached. Does BOPE have sufficient pressure rating - Test to ~-'OOO psig .. Does the choke mm]ifold comply w/AP1 RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphicwells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented ~] shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented-- 32. Additional requirements ............................................. POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE Additional Remarks: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically organize this category of information. LIBRARY TAPE CURVE SPECIFICATIONS Company ARCO Alaska, Inc. Wel! D.S. 11-27 Field Prudhoe Bay County, State North Slope, Alaska Date 1/11787 Curve Name (Abbrev.) Standard Curve Name Scale RFOC RILD RILD GR AC SP GR1 CAL CN ZCOR ZDEN PORD PE Resistivity Focussed ResistivitY Medium Ind. Resistivity Deep Gamma Ray Acoustic Log Self Potential Gamma Ray Caliper Compensated Neutron Correction. Bulk Density Denisty Porosity PHOto-El.ectic DIFL -Ii AC D1FL CN/CDL .2 - 2,000 II 0-t,00, 100-200 15o - 5O i -100 - 100 ~- , ! 0-t00, 100-200 j O- 16 6o - o '{ ' -'.25 - .25 2 - 3 J "60 - o 2-12 EEL N~4ME : ~T~ : ...... RI&,I'N :~' FS¥S ERV'ICE N'AME: BITLIS EEL CONTINUATION NUMBER: 01 · R..E~ V i,.O U...S · .R E E.L ..N AM E .: .... A,,~m,,'~a · ~, ~ · :' ~ ' " ' : ' ' · ' u,-,~',E',~T'S~ uRESSER ATLAS 'LiS CUSTC~;iER ENGTM.;. "' 132 BYTES T~PE ---"CRE'~TE:c: 'BY"'S'DS'"'pR'OGR~M : ~' 2.u U I ILE N4.;4E..~.; 1.41.7.5 "'"" · .~ '.. ',. ., , . . · .I..~U.' t.'. ', ' :~ViC~: NA'NE': i. LE..T.y..~E.:,LO.:..' .. ..... ~.E V i.G.US. E.i.L E. NAM E: W N .FN U, IJ U I~ ST~T LCC E NT R Y EL ~ ~ES girt DEPTHS DECREASE FRAME SF~CiNG FRAME SPACING UNITS TER~4INATGR ~EVEL SP~CING 4TU:-~ S~CIFIC*~'I""~ - ,-, ~,, 8LOCKS u~V[ ~E"R- ' CuRvr. AME CODE ·SIZE SAMPLE LNiTS N~ME CODE SiZE SAMPLE UNITS 68 I MV I, US/F I 0HMM I AP1 '*' 'FORM/~T ** · ~ .' · ~0,.0 .I-~A.~.i:: · ~F,.A'Ci:N6 .. .' .' .' 9 ..... *ii"'N ...... F~f4:E S¢'~C/NG uNlfS ii 16 FAXiMUM FR~iME$/RECO~D .,.. ... '0 f ER~ZNATOR -0.,500, LEVEL SPACZNG ,, ,,, · ,,,,,, ATU. M' SFr-CZmiCATiON.:. 8LOCKS CURVE · REPR · . S'Z'~ '= 68 68 68'' 68 '.. 68 68 . . PO~D '6:8 ' 4 ' .... 4,, · '1 · 4 ····i 4.. .1 4 ' "' "1' 4. ..... 4 '1 U iN i T S MV · US'/F OH MM BAR N % 39.'324 0.,000 O.OOO EPTH i2200.,300 FT 3718.568C ..'4. iLD :292.'~01 SP -2.43,,6 GR 118. 4L . O.O00 ZDEN 0.000 ZCOR 0.000 PE 0 .GOO EPTd i2i00.000 FT 3688.087C M iLD 244.887 SP -0.978 FOC 4.959 RiLM 4.375 ~C O,CO0 ZutN 3,C00 N O,CO0 PORD O,OOO GR RiLD ZCOR iii .2~5 AC 4..084 GR1 O .OeO P: 84.377 0.000 0.000 EPTH 12000.C:C0 FT 5657.607C M IIIIIIIIlIIIlllIIIIIIlIlIIlII iLD 6.127 SP -40.263 =OC i,~9.274 RiLM 119.475 AL &.~OZ ZDEN 2.188 N 22.8C2 POR3 30.529 GR RiLD ZCOR 36.338 ~C Ic:.~u~ GRI 0.026 PE z,,-,n 119"0 C''~' FT 5627.17"C M IIiIilI i ii! i I ii ! ! ii! imIiIIiI l ILO 16.765 SP 29.~56 DOC 693.481 ~iL~ i76.752 AL 8 · 904 ZDEN 2Il. 477 GR RiLD ZCOR 25. O'"C;; ~C =9 646 ,,.,, 8PTH 11800.0 i LD 4. PO ~ 282 A.L O0 FT 3,59,6.6470 M 656 SP -42.403 634 RILM 92.809 88? .... ZDEN. · · 2.2.85. ~76 FORD' 24.'8'52' ' GR RILD ..Z'COR.. 26.590' AC 214.799 GR1 · .0.03'2 · P,E'. .... 94.503 29.066 .3...230 ... .. CO' F'T' "3'566. 167'6"M ILO 2.666" SP' :.:FO.:6.~ ......B..47'.61.7....Ri. LM.' · .... . · . N 14 647 FOR.~ . ... ,, . .... ,, . ... . .. . ,n..., ,, ,.,.,,.,. ~ .... ,.,, u O ..F., ~52'5...68.70 M · . . .. ~- ..... --., :, ..... :~ _ ~ ,,=- _ ..... · .. · :.....: .... ~A.~'..' , · .~/. "~: · ~.,~. . ... . ..' .~.. ,.~.~.., .~.:. ,~'~.:.~ .../..'.,':(.'.~,,; .:...,..~,~:4...~ ~,..,.... :'....:,'.., ...~'.,'...,~,~,'.; AL · . ..,3, 9~¢'..o ZBE.N . 2.377 .ZCOB. . '. O' 0~t.. ' · .....PS.,',. ",. ..,t.7.52 .' .' .. , . . . . . , ..,.?.....'....,. ~ ''" ' "'O~ ."~M ¢~'*~ ..... ~ D "'' ' '" "'1~"~'"~" ' .......... ' ...... ' ' ' · .,..., ,,.,._._.,, ...... . .... , ....... ..... .......: .., ...:, ,., , '.,.,':~ ...... FOC .. · I' 13..862 RiLM ,~L ~. ~uu Z:DEN ~5_ "_ ___7 ¢'9"" '.._ ' _I '"'"""u~ · ,'""~ '"' "7~ ' .... ' .... 51.336. RILD ·. """" 6u.'.u.,. ..... ' 4..0,0.'$.6 I,~..l~ ! . ~,.~ i .... , . . . . .'.. · . . .... ,, . . , . ... ";""""' '"" :" .... ' ...... ,3 :~ ':':'''' ...... "~ ~? 2, ,+ ~ .,-, ZCOR '-0._ 27 ~: ... ~ _ _ ............ 12..3.41 . · · · E,.~TH i.1..400..uu'""'O...,-'T 347...4... ,'27'0 M ..... · · · . ..... ,.. ..... ~-_~_'_~_L='_~,.~:~;~ ...... ._ '" ' ' · ' ' " .... ,' 'x~.::::,.{:,,, .' ."/,i:,::;...', ',.,' '"'.' ',.'" '.' ,'"" · .' ';." .. '. · · ..'.' ..... ~?;i:.: ~ ~ ~ii~ .... ~,~.,. ;,;i?i!i!: . . . ,::'o.u",~ ~ · ;;4i:,},ii .... -..,.4.,,.~,. 8,~,4 .. ....... GR .... . · :2.' ;,.*.:~,: ,..' .... .. ~0..8:~2. .. . ~,.~..~ .;' .. . · 1 i.. 2.4 ;. ;:;!!; ili ~i:: i~:~!:!:;~!~:~:~. ...: ..., ~ .. 41. ~.. · .~m~ ,',, ~.;,.:: .,..!¥,; '...::..,'.,.... ~.~.¢1; ~',:~,,,:. c::.;,~::. ~,,-.-T~ . ,,,,,.,,.,,.,-,,.,,,., , , 3444.2470 ~ " :..., .......................................................................................................................................................................................................................... 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E: 1 024 BYTES MN:M (.,UN ~. ,.~N 1~ AP!N :Du-u29-2NO$8 C.N ; ARCC. ALASKA :uN ....... : ~,',' s'-'i :i - ~ 7 {,UuN : N,$LOP~ · 5.7 A 7 ......:.. AL A'S. KA. .' ......' · .". LCC ' .....1 5'0", O0 .... ' .... '" ....... '"?' ":' :" Y''' '":'" i'.;...' .. ....... ..' ....', ..... ........,: ,,],,,: ,,,,,~:,,,",, ~ ~,~ ~ ,_ _~' . . , . .. . '. . . · . ... ..... .. . .. · ENT. R.Y .BLOC. KS . ii 31 M 0 · .i: · ' ',-o..-5oo L ATOll' SPECiFiC · ENTRY D=$~'RI PTIv,~ · · ...... ...... .... .' .. . . .. · i - D:P?~S ~.ECREAS~ ....... ' 60.~' ~'RA~E S~AC~NG .:i.im FRAM¢ SPA.C'~'NG UN~T.S · .' '.. ' .... ' '" . . . ~ -', -- - ~ · · *-' ~'~::S'::.'.' "~ · ~ ~ · ~ ~ I .~, ~ ~. ~ ~ ~' · · ' ', ' ' ' , -:c~..::':;:'.,' ;~.>.~:." ' , ' ' '' · ' ' Ex~.[N~~¢~7-FZ.~:.%. : ........... :...,7...~ ' ..' 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"RILM' ''3.'~,,~ .... ~"lC"D''. . - . 0o.15 4 !LD 244 464 SP O 239 GR 1' ~ ' 9 C 84.247 FOC. 4,957 RI.LN .. 4.371 · ~IL.D.. .4.0,9t ........ · .... . . . . . . ...... : · · .... . . ... .. · . . . ..' , ... . . . . I.L.D. 6 a3.9 SP. 44.85.7 GR ~e 520 .aC .i. Gi ~.2..4 ~ . . . . , . . , .,~: .. I . . ' ' . .'. '. .' ' .'. : . I. FOC 165.915 RiLM 1'6 " ~"" ~'~ ~ .731 ~I' ~ ,~ ~u 9"C ~ 3-4:8 84.4.10 EPTH 11600.C00 FT 3535.6870 M IitiIllIiiIIililIItIlIlIIl~iI iLD I.'~ ?~ 3 ~ Or 6 I~'~ FOC 750.369 RiL~'~ uo.url ,.,,,""' -'~.'= 916 AC 77.613 ~iLO 715.517 EPTH 11580CCO. ;T, 3505 .28~u M iLD 11.7~2 SP -57.9~ FOC ~5.301 RILM 58.'9' GR 36.232 ~C 101.259 EP'"~,,, 114nn,.,~,.CcC FT 34~'',.,.7;7C'' M ILD 31.245 SP FOC 52.571 RILM -53.513 25.752 GR 195.483 AC 88.~77 ""~ ~2.00~ ILO O.O00 Sr FOC' O.O00 RILM O.CCO ¢'~ C.OCO AC O.OOO, RILD C,.OOO ILD 48.357 SP -94.053 GR FOC 0.488 RILM IOGO0.O00 RILD TARTING DEPT~ :12237,000 FT 37~9,8450 M m.D.iNG DEPTH :ii2~.3.500. FT 344~,2660 'N 114,268 ~C 41,418 20,679 · . NAME: .]~i75. ,00.2 ',. ER¥iCE NAME: :k.k.SiON..#': 1 ...... '" .".'' .. ~XiMUM LENGTH; 1024 .. . IFFY: LU FiLE NA~': · . ... iLE 'NAM6: ]4i75 ,003 ' ERS.iON'. #. : .1 :ATE: 8S/i1/2 A.X.. RECORD Lc. iL E T'YFE: LO N.GTH: i024 6YTES. REViOUS F.iLE NAME: . . · iNFORMATiON RECORDS ** ... ... 'iq N E M" APi'N .CN : WN : FN : COUN : STAT : bCC : YPE ENTRY DESCRiPTiON i i 0 I DEPTHS DECREASE 60.0 'FRAME S=~CING .lin FRAME SPACING UNITS i27 'M~XiMUM FRANES/RECORD ?ERNiNATOR -O.$OS L:VEL SD~CiNG ~TUM ~PECiFiC~TiON BLOCKS &ME CODE SiZE SAMPLE UNITS R 68 4 1 API FORMAT ** ENTRY BLOCKS 'Y P E E N T R Y 1 $ 60.0 9 .lIN 1.1.. I Z7 · -0.500 .. · .. .. . D E $C RIPTION DEPTHS. DECREASE ~- R AM E SPACING FRAME SPACING UNITS NAXiMU. M. FRA'ME S./RECORD T E R't-'.., I "" '"~ L E..V.6L SF,,~C ATUM. .S~ECIFICA.TIGN GLOCKS .. URVE. '. A'M E C 0 D E .. SiZE SAMPLE R '68 4 1 APl' . " 3,~ 4 R" ' i 3'I . 523 E'PTH 1'1'2 E~,H 11.1 EPTH 110 :F~r~ lU.~Uu.uuu FT 329i.8470 M 110.543 EPTH 10"'""",'uu.C~'C,~ FT 3261.3670 t'~ = .... I~'n~ CO~ :T 72~'~ '~6C M R 69.671 EPTH I:d¢OO.CCO ~T ]159.9270 R ..... 56.164 EPTH 10300. COO _.. R ~ 6 . 368 FT 3139.446C H EPTH 10_~00.C00 FT '3108,9660 M . . . 63.642 EPTH ]O000.uuu ,-~ ~u48'.006C, ~ ~guu. CO0 FT 3,.0i 7. 5260 H i~ i~l,I I I.i I. IiI. I I i.i I ! ~i i I I ~i I, i ! I ii.,~m ~ I 55.528 " . . . ... 'R 80. i 2 i ' R, EPTH 9 """" :,: :~ f,;,,..; :.:; f .:,..'.. ~, ~ ~ ~ ~_ . ~;,'F.;'i.~.,~_ ,~.~.~: ,:,_.::';..:,;!' ??,'...i,?'.:.'..'"".~ ..... ":.':,'?.."~:'...::::;~;,'.:'~:' .... .~":L~'::;.'?:_...'::.::~'..':, -~..~;~`:.:?~:..:`-:`~..;;~`~-.;`~.~`f?~?:.`..~`~;`(:~`~.~.~:i:~.:~¢~`.:::?:~L~`~`~``. ' 0. 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Cuu FT 'Io4;.923C ~ }EPTH 5300.600 FT 1615.44~3C M 'R 49.26'3 ~,=.~,.,..~ :_--~,.,..n ¢00 FT' I ... .. ~K ),,E':PTH · 510,~,000 FT i~54.4830 H ~9.49"0' )~PTH '5"'"'0 ,u,uu r' ~ I ¢. · 0 " · . . iR' " .... Z, 3","Z 8'4 ' .. 1280.1630 'PTH 41~n ~ uu.uu,¢ FT 1249.6830 rrT,~ 4COO.COO rT 1219.2020 iq ...........Z, 9 . C01 =nTH 3~n ,,,0 CCh :T 11~8.7~-2u R 47.906 EPTH 3800.000 FT 1158.2420 M R 3'8.743 3700.000 FT 1127,7620 40.915 )~PTH,. ~600.C00 FT 10~7.28**. ~u ;R' ' ~8-07'8 )E'PTH .......... 3:SO0;"O0:O FT i066,8020 M i 9.7 58 ,R ~'9,1'52 ..!I Ii"i !.t.! iIII I Ii.i I Iii i.iilll.ll.l' .. .. 'FT ' """5' " -.~,- ,3621 ........ ! ! ! ~ !, ! ! .. ? ::~n 3 .Ouu T 914.4,019 M '~ .~ I~' ~ $7.2 EP'TH 2700.~'00 FT 822.9,617 M ~8.23~ EPTH 2$OO.CCO FT 76~.0015 IIlIIlIlIllllllIIlIlIlllllIIi ~6.3~0 5PTH 2485.5C0 FT 758.4963 ~ 26.;42 T4RTiNG DE2TH =1143Z.CGO FT NDiNG DEPTH ~ 24.88.500 FT 758.4963 M * FiLE TR&ILER ** iLE NAME: 14175 .003 ERViCE NANE. ERSiON N : 1 ATE: ~5ili/ ILE TYPE: LC :XT FIL~ NAME: * T/!PE TR.41LER ** _, ~P.E. N~ME. ERV"~CE NEME; 14175 · ' '" ATE: ....... ·. . ~J.,..,z~'~ O~ O.~'TA: FS'YS ' .AR- C.ONTiNU4TiON # .; OMME. NTS'. ......... , ~,~ REEL T~c~ ~ " EEL N~ME; · .. , ,.. ... .. .. . ERViCE NAME: 5ITLIS ATE. : .... EEL CONTiNUaTiON ~,~ , REEL N'"'"' ~ ...... ............ ATLAS EEL HE~BER ~ q LIS .CUST.GMER TAPE .=--.C. REAT.ED .2¥..SGS, PROGR. AM....R...2...O . HEADER - · 1 ,NFORM~T ION 3 ~kTA 322 ~.c DUMP - 3 .ZL.E TRAILER - A~E TR~ZLER - EEL TR.~iLER - OTAL RECOROS: ALASKA COMPUTING CENTER * ....... SCHLUFIBERGER COMPANY NAME : ARCO ALASKA INC. WELL NAM~ : DS 11-27 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-21638-00 REFERENCE NO : 97506 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/11/12 ORIGIN : FLIC REEL NAME : 97506 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 11-27, API# 50-029-21638-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/11/12 ORIGIN : FLIC TAPE NAME : 97506 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 11-27, API# 50-029-21638-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 11-27 API NUMBER: 500292163800 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 12-NOV-97 JOB NUMBER: 97506 LOGGING ENGINEER: SADDLER OPERATOR WITNESS: MIKE MOONEY SURFACE LOCATION SECTION: 28 TOWNSHIP: 1 iN RANGE: 15E FNL: FSL: 451 FEL: 229 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 58. O0 DERRICK FLOOR: 57. O0 GROUND LEVEL.. 28. O0 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9.625 11342.0 47.00 7.000 12210.0 29.00 5.500 11048.0 17.00 5.000 11115.0 15.00 CURVE SHIFT DATA - ALL PASSES TO STANDARD (~SURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NU~BER: PASS NUMBER: DATE LOGGED: il-JAN-87 LOGGING COMPANY: ATLAS WIRELINE BASELINE DEPTH 88888 0 12021 5 12018 5 12015 5 12008 0 12003 5 11999 5 11988.5 11981.5 11981.0 11970.5 11959.0 11958.0 11954.0 11941.0 11940.5 11936.5 11934.5 11934.0 11930.5 11922.5 11921.5 11921.0 11908.0 11896.5 11894.0 11871.0 11870.0 11865.5 11861.0 11850.0 11849.0 11843.0 11839.5 11834.5 11833.0 11828.0 11825.0 11818.5 11815.5 11815.0 11804.0 11803.0 11796.5 11795.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH ClFTG 88887.0 88890.0 12023.5 12019.5 12014.5 12007.0 12004.5 11999.5 11988.5 11981.0 11970.0 11958.5 11954.0 11940.0 11936.0 11932.0 11920.5 11907.5 11895.0 11868.0 11847.0 11840.5 11830.5 11826.0 11813.5 11802.5 11794.5 11981.0 11958.5 11940.0 11932.5 11929.5 11921.5 11918.0 11892.5 11868.0 11861.0 11858.0 11846.5 11836.5 11831.0 11823.5 11816.5 11813.5 11803.0 11795.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 11788. 11770. 11767. 11757. 11756. 11753. 11749. 11740. 11730. 11728. 11718. 11717. 11709. 11705. 11678. 11675. 11674. 11667. 11662. 11649. 11643. 11637. 11633. 11633. 11625 11624 11616 11615 11600 11594 100 $ REMARKS: 11787.0 11769.5 11767.0 11756.0 11755.5 11752.5 11749.5 11741.0 11728.0 11727.5 11717.0 11716.5 11710.0 11705.0 11705.0 11678.5 11674.5 11673.5 11667.0 11662.0 11648.0 11642.5 11636.5 11634.5 11634.0 11626.5 11624.5 11616.5 11616.0 11600.5 11593.5 99.5 100.0 CONTAINED HEREIN IS THE CASED HOLE CNTG LDWG FORMATTED DATA ACQUIRED ON ARCO ALASKA'S D.S. 11-27 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #1 AND GR.BCS, AND NPHI PASS #1 AND GR. BCS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE ' FLIC VERSION : O01CO1 DATE : 97/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: EDITED CURVES LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 PAGE: Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~fARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12023.0 11593.0 CNTG 12033.0 11593.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUM~ER: BASELINE DEPTH $ REMARKS: .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG THIS FILE CONTAINS THE EDITTED DATA FOR CNTG PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 15 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) O0 000 O0 0 1 1 1 4 68 0000000000 DEPT FT 1125469 NPHI CNTG PU-S 1125469 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 1125469 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTG PU-S 1125469 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTG 1125469 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 1125469 O0 000 O0 0 1 1 1 4 68 0000000000 ENRA CNTG 1125469 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTG CPS 1125469 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTG CPS 1125469 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 1125469 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 1125469 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 1125469 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNTG CPS 1125469 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTG GAPI 1125469 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTG LB 1125469 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTG V 1125469 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1125469 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 12150.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG -999.250 CCL.CNTG GR.BCS 117.304 DEPT. 11500.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG -999.250 CCL.CNTG GR.BCS 35.709 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE ' FLIC VERSION · O01CO1 DATE : 97/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12043.0 11595.0 CNTG 12053.0 11595.0 $ CURVE SHIFT DATA - PASS TO PASS (FiEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 12032.0 12025.0 12021.5 12018.5 12010.0 12007.5 12004.0 11999.5 11996.0 11990.5 11989.0 11983.5 11981.5 11981.0 11971.0 11959.0 11958.0 11956.0 11955.0 11952.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG .............. 88885.5 88889.5 12019.0 12007.0 12004.0 12000.0 11995.5 11992.0 11988.5 11983.0 11981.0 11970.5 11958.5 11951.0 12033.5 12026.0 12023.5 12019.5 12010.5 11981.0 11958.5 11956.0 11955.0 11953.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 PAGE: 11951.0 11942.5 11941.0 11936.5 11934 5 11931 0 11930 5 11924 5 11922 5 11921 5 11921 0 11896.5 11893.5 11891.0 11879.5 11872.0 11870.0 11865.5 11861.5 11850.0 11849.5 11839.5 11838.0 11834.5 11826.5 11825.0 11818.5 11815.5 11804.0 11803.5 11796.5 11795 5 11788 5 11770 0 11767 5 11757 5 11753 5 11749 5 11730 0 11718 0 11716.5 11708 5 11705 5 11694 0 11677 5 11675 5 11670 0 11667 0 11662 5 11658 5 11643 0 11637 0 11635 5 11633 0 11626.5 11935.5 11928.5 11923.0 11920.0 11895.0 11890.0 11878.0 11868.0 11847.0 11835.5 11825.5 11802.5 11795.0 11769.5 11750.0 11716.0 11710.0 11705.5 11693.5 11677.5 11667.0 11660.0 11636.5 11627.0 11949.5 11941.5 11940.0 11932.5 11929.5 11921.5 11918.0 11891.5 11868.0 11861.0 11858.0 11847.0 11836.5 11831.0 11823.5 11816.5 11813.5 11803.0 11795.5 11787.0 11767.0 11756.5 11752.5 11728.0 11717.5 11705.5 11674.5 11669.5 11662.0 11642.5 11636.5 11634.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 PAGE: 11624 11619 11617 11616 11600 100 $ 0 5 11620.5 0 11617.5 0 5 0 100.5 1i 624.5 11616.5 11600.5 100.0 REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1, AND NPHI PASS #2 AND NPHI PASS #1 CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1125469 O0 000 O0 0 2 i 1 4 68 0000000000 NPHI CNTG PU-S 1125469 O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNTG PU-S 1125469 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNTG PU-S 1125469 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTG 1125469 O0 000 O0 0 2 i 1 4 68 0000000000 CRAT CNTG 1125469 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 PAGE NAME SERV UNIT SERVICE API API API API FILE ~ NU~iB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~I CODE (HEX) ENRA CNTG 1125469 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTG CPS 1125469 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTG CPS 1125469 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTG CPS 1125469 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 1125469 O0 000 O0 0 2 1 1 4 68 0000000000 CNEC CNTG CPS 1125469 O0 000 O0 0 2 1 1 4 68 0000000000 CFEC CNTG CPS 1125469 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTG GAPI 1125469 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTG LB 1125469 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTG V 1125469 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 12054.500 NPHI.CNTG 23.871 ENPH. CNTG 23.309 CPHI. CNTG NRAT. CNTG 2.734 CRAT. CNTG 2.712 ENRA.CNTG 3.935 NCNT. CNTG FCNT. CNTG 878.588 CNTC. CNTG 2223.247 CFTC. CNTG 870.233 CNEC. CNTG CFEC. CNTG 724.491 GRCH. CNTG -999.250 TENS. CNTG 3085.000 CCL. CNTG DEPT. 11595.000 NPHI.CNTG 8.156 ENPH. CNTG 10.619 CPHI. CNTG NRAT. CNTG 1.621 CRAT. CNTG 1.596 ENR~.CNTG 2.344 NCNT. CNTG FCNT. CNTG 2641.147 CNTC. CNTG 3957.351 CFTC. CNTG 2560.565 CNEC. CNTG CFEC. CNTG 1700.043 GRCH. CNTG -999.250 TENS. CNTG 3635.000 CCL. CNTG 19. 730 2403. 644 2851.168 O. 000 6.606 4341.839 3985.229 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 97/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 PAGE: 10 FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SUF~L~RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12046.0 11594.0 CNTG 12056.0 11594.0 $ CURVE SHIFT DATA - PASS TO PASS (M~AStrRED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNTG 88888.0 88884.5 88889.0 12032.5 12033.5 12027.5 12030.0 12025.5 12026.0 12021.5 12023.5 12019.5 12019.5 12018.5 12015.0 12010.0 12010.5 12008.0 12007.0 12004.0 12004.5 12003.0 12004.0 11999.5 12000.0 11996.0 11995.5 11983.5 11984.0 11981.0 11980.5 11981.0 11975.5 11975.5 11959.0 11958.5 11958.5 11959.0 11956.0 11956.0 11955.0 11955.0 11952.0 11953.0 11951.0 11949.5 11942.5 11942.0 11941.5 11941.0 11940.0 11936.5 11936.0 11934.5 11932.5 11933.0 11931.5 11930.5 11930.0 11922.5 11921.5 11921.5 11920.0 11919.0 11918.0 11917.0 11916.5 11915.0 11914.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 PAGE: 11 11908.5 11893.5 11887.5 11879.0 11876.5 11873.0 11870.5 11869.5 11865.0 11861.5 11849.5 11848.5 11839.5 11834.5 11825.0 11822.0 11818.5 11815.0 11803.5 11802.0 11796.5 11795.5 11787 5 11769 0 11767 5 11757 5 11753 5 11749 0 11740 0 11729 0 11726 5 11718 0 11715 5 11705 5 11704.5 11682.5 11680.0 11675.5 11673.0 11670.0 11667.5 11666.5 11643.0 11637.0 11635.0 11633.0 11624.0 11616.0 11610.0 11600.5 100.0 $ REMARKS: 11887.0 11878.0 11868.0 11846.5 11820.5 11802.0 11795.5 11769.5 11749.5 11727.0 11715.5 11705.5 11680.0 11673.5 11667.5 11636.5 11611.0 101.0 11906.5 11891.5 11875.0 11870.0 11868.0 11861.0 11858.0 11847.0 11836.5 11831.0 11823.5 11816.5 11813.5 11803.0 11795.5 11787.0 11767.5 11756.5 11752.5 11739.5 11728.0 11717.5 11705.5 11682.0 11674.5 11670.5 11667.5 11642.5 11636.5 11634.0 11624.5 11617.0 11600.5 100.0 THIS FILE CONTAINS CASED HOLE CNTG PASS #3. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 PAGE: 12 GRCH PASS #3 AND GRCH PASS #1, AND NPHI PASS #3 AND NPHI PASS #1 CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT i1 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUFiB NI3M~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1125469 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU-S 1125469 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU-S 1125469 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNTG PU-S 1125469 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTG 1125469 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTG 1125469 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNTG 1125469 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTG CPS 1125469 O0 000 O0 0 3 I 1 4 68 0000000000 FCNT CNTG CPS 1125469 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS 1125469 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 1125469 O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNTG CPS 1125469 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNTG CPS 1125469 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTG GAPI 1125469 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTG LB 1125469 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTG V 1125469 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 PAGE: 13 * * DA TA * * DEPT. 12057.000 NPHI.CNTG 23.833 ENPH. CNTG 22.673 CPHI. CNTG NRAT. CNTG 2.679 CRAT. CNTG 2.710 ENRA.CNTG 3.862 NCNT. CNTG FCNT. CNTG 864.759 CNTC. CNTG 2313.210 CFTC. CNTG 873.450 CNEC. CNTG CFEC. CNTG 795.723 GRCH. CNTG -999.250 TENS. CNTG 3260.000 CCL. CNTG DEPT. 11594.000 NPHI.CNTG 7.250 ENPH. CNTG 9.575 CPHI.CNTG NRAT. CNTG 1.517 CRAT. CNTG 1.515 ENR~.CNTG 2.200 NCNT. CNTG FCNT. CNTG 2763.993 CNTC.CNTG 4265.132 CFTC. CNTG 2850.931 CNEC. CNTG CFEC. CNTG 1911.204 GRCH. CNTG -999.250 TENS. CNTG 3785.000 CCL. CNTG 21.050 2439.210 3073.456 0.000 6.013 4578.907 4204.930 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS CNTG 1, 2, 3, $ REMARKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF CASED HOLE CNTG PASS 1,2, & 3. ALL DATA HAS BEEN CLIPPED LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 PAGE: 14 AND DEPTH CORRECTED PRIOR TO AVERAGING THE DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB * * .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 56 4 66 1 S 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE AU3YrlBNUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1125469 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 1125469 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1125469 O0 000 O0 0 4 1 1 4 68 0000000000 CPHI CNAV PU-S 1125469 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 1125469 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNAV PU-S 1125469 O0 000 O0 0 4 1 1 4 68 0000000000 ENRA CNAV 1125469 O0 000 O0 0 4 1 1 4 68 0000000000 NCNTCNAV CPS 1125469 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNAV CPS 1125469 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 1125469 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 1125469 O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNAV CPS 1125469 O0 000 O0 0 4 1 1 4 68 0000000000 CFEC CNAV CPS 1125469 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTG GAPI 1125469 O0 000 O0 0 4 1 1 4 68 0000000000 ................................. 7 ..................................................... LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 PAGE: 15 ** DATA ** DEPT. 12035.000 NPHI.CNAV 23.398 NRAT. CNAV CRAT. CNAV 2.686 ENPH. CNAV 20.900 ENRA.CNAV FCNT. CNAV 889.577 CNTC. CNAV 2349.007 CFTC. CNAV CFEC. CNAV 918.007 GRCH. CNTG -999.250 DEPT. 11592.500 NPHI.CNAV -999.250 NRAT. CNAV CRAT. CNAV -999.250 ENPH. CNAV -999.250 ENRA.CNAV FCNT. CNAV -999.250 CNTC. CNAV -999.250 CFTC. CNAV CFEC. CNAV -999.250 GRCH. CNTG 22.078 2.784 CPHI.CNAV 3.655 NCNT. CNAV 884.916 CNEC. CNAV -999.250 CPHI.CNAV -999.250 NCNT. CNAV -999.250 CNEC. CNAV 21.143 2419.833 3355.743 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE · 97/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH CNTG 12050.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: STOP DEPTH .......... 11600.0 03-SEP-97 CP44.2 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 PAGE: 16 TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 1434 03-SEP-97 12037.0 11593.0 12056.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CNTG COMPENSATED NEUTRON GR GAM2~A RAY $ TOOL NUFIBER CNC-GB-063 SGC-SA-479 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 11342.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : · PRODUCED NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): E P I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 8000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): 1.0 REMARKS: TIED INTO ATLAS BHC ACOUSTICLOG DATE JAN-II-1987. PUMPED 300 BARRELS OF CRUDE BEFORE LOGGING. PUMPED IN 56 BARRELS OF CRUDE WHILE LOGGING AT 1 BARREL A MINUTE. PUMPED IN 6 BARRELS OF DIESEL AFTER LOGGING. THIS FILE CONTAINS THE RAW DATA FOR CASED HOLE LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 PAGE: 17 CNTG PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUF~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1125469 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 1125469 O0 000 O0 0 5 1 1 4 68 0000000000 ENPH PS1 PU 1125469 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH PS1 PU 1125469 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA PS1 1125469 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS1 1125469 O0 000 O0 0 5 1 1 4 68 0000000000 ENRA PSl 1125469 O0 000 O0 0 5 1 1 4 68 0000000000 CFEC PS1 CPS 1125469 O0 000 O0 0 5 1 1 4 68 0000000000 CNEC PSi CPS 1125469 O0 000 O0 0 5 1 1 4 68 0000000000 RCEF PS1 CPS 1125469 O0 000 O0 0 5 1 1 4 68 0000000000 RCEN PSi CPS 1125469 O0 000 O0 0 5 1 1 4 68 0000000000 RCNT PS1 CPS 1125469 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 1125469 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PS1 CPS 1125469 O0 000 O0 0 5 1 i 4 68 0000000000 CFTC PS1 CPS 1125469 O0 000 O0 0 5 1 1 4 68 0000000000 NPOR PS1 PU 1125469 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1125469 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1125469 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 PAGE: 18 NAME SERV UNIT SERVICE API API API API FILE NUM~ NURiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFI~ SAMP ELEM CODE (HEX) CCL PS1 V 1125469 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 12048.000 NPHI.PS1 25.959 ENPH. PS1 21.563 TNPH. PS1 TNRA.PS1 2.827 RTArR.PSl 2.848 ENRA.PS1 3.734 CFEC. PS1 CNEC. PS1 3401.717 RCEF.PS1 907.138 RCEN. PS1 3221.232 RCNT. PS1 RCFT. PS1 804.163 CNTC.PS1 2229.384 CFTC. PSI 804.298 NPOR.PS1 GR.PS1 52.688 TENS.PSI 2555.000 CCL.PS1 0.000 DEPT. 11591.500 NPHI.PS1 8.652 ENPH. PS1 10.635 TNPH. PS1 TNRA.PS1 1.639 RT1FR.PS1 1.629 EArRA.PS1 2.346 CFEC. PS1 CNEC. PS1 3925.730 RCEF.PS1 1703.749 RCEN. PS1 3760.725 RCNT. PS1 RCFT. PS1 2387.051 CNTC.PS1 3842.693 CFTC. PSi 2421.791 NPOR.PS1 GR.PS1 18.563 TENS.PSi 3665.000 CCL.PS1 0.000 22.819 911.107 2329.313 22.819 7.105 1673.134 3942.499 7.453 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE ' 97/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE ' FLIC VERSION · O01CO1 DATE : 97/11/12 MA3fREC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NU~BER: 2 DEPTH INCREMENT: 0.5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 PAGE: 19 FILE SU~94ARY VENDOR TOOL CODE START DEPTH CNTG 12050.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 11600.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CNTG COMPENSATED NEUTRON GR GAF~fA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 8000 03 -SEP-97 CP44.2 1434 03 -SEP-97 12037.0 11593.0 12056.0 1800.0 NO TOOL NUMBER ........... CNC-GB-063 SGC-SA-479 11342.0 PRODUCED E P I THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 PAGE .. 20 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): 1.0 REMARKS: TIED INTO ATLAS BHC ACOUSTICLOG DATE JAN-ii-1987. PUMPED 300 BARRELS OF CRUDE BEFORE LOGGING. PUMPED IN 56 BARRELS OF CRUDE WHILE LOGGING AT 1 BARREL A MINUTE. PUMPED IN 6 BARRELS OF DIESEL AFTER LOGGING. THIS FILE CONTAINS THE RAW DATA FOR CASED HOLE CNTG PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1125469 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 1125469 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH PS2 PU 1125469 O0 000 O0 0 6 1 1 4 68 0000000000 TNPH PS2 PU 1125469 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 1125469 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 1125469 O0 000 O0 0 6 1 1 4 68 0000000000 ENRA PS2 1125469 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC PS2 CPS 1125469 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 PAGE: 21 NAME SERVUNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELEM CODE (HEX) CNEC PS2 CPS 1125469 O0 000 O0 0 6 1 1 4 68 0000000000 RCEF PS2 CPS 1125469 O0 000 O0 0 6 1 1 4 68 0000000000 RCEN PS2 CPS 1125469 O0 000 O0 0 6 1 1 4 68 0000000000 RCNTPS2 CPS 1125469 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 1125469 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 1125469 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 1125469 O0 000 O0 0 6 1 1 4 68 0000000000 NPOR PS2 PU 1125469 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1125469 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1125469 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1125469 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 12060.000 NPHI.PS2 23.005 ENPH.PS2 22.813 TNPHoPS2 TArRA.PS2 2.665 RTNR.PS2 2.685 F2V-RA.PS2 3.879 CFECoPS2 CNEC. PS2 2883.199 RCEF. PS2 740.125 RCEN. PS2 2730.225 RCNT. PS2 RCFT. PS2 863.263 CNTC. PS2 2254.998 CFTC. PS2 863.408 NPOR.PS2 GR.PS2 40.938 TENS.PS2 2165.000 CCL.PS2 0.000 DEPT. 11593.500 NPHI.PS2 8.119 ENPH. PS2 10.195 TNPH. PS2 TNRA.PS2 1.593 RTNR.PS2 1.574 ENRA.PS2 2.286 CFEC. PS2 CNEC. PS2 3963.002 RCEF. PS2 1662.550 RCEN. PS2 3771.964 RCNT. PS2 RCFT. PS2 2521.743 CNTC. PS2 3980.617 CFTC. PS2 2608.642 NPOR.PS2 GR.PS2 17.594 TENS.PS2 3610.000 CCL.PS2 0.000 20.532 743.363 2356.074 20.532 6.371 1733.712 4084.102 6.707 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 PAGE: 22 **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH CNTG 12050.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 11600.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... CNTG COMPENSATED NEUTRON GR GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 03-SEP-97 CP44.2 1434 03-SEP-97 12037.0 11593.0 12056.0 1800.0 NO TOOL NUMBER ........... CNC-GB-063 SGC-SA-479 11342.0 PRODUCED LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 PAGE: 23 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERk4AL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (?T) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 8000 ArEAR COUNT RATE LOW SCALE (CPS) '. 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): 1.0 REMARKS: TIED INTO ATLAS BHC ACOUSTICLOG DATE JAN-ii-1987. PUMPED 300 BARRELS OF CRUDE BEFORE LOGGING. PUMPED IN 56 BARRELS OF CRUDE WHILE LOGGING AT 1 BARREL A MINUTE. PUMPED IN 6 BARRELS OF DIESEL AFTER LOGGING. THIS FILE CONTAINS THE RAW DATA FOR CASED HOLE CNTG PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 PAGE: 24 TYPE REPR CODE VALUE 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1125469 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 1125469 O0 000 O0 0 7 1 1 4 68 0000000000 ENPH PS3 PU 1125469 O0 000 O0 0 7 1 1 4 68 0000000000 TNPH PS3 PU 1125469 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 1125469 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 1125469 O0 000 O0 0 7 1 1 4 68 0000000000 ENRA PS3 1125469 O0 000 O0 0 7 1 1 4 68 0000000000 CFEC PS3 CPS 1125469 O0 000 O0 0 7 1 1 4 68 0000000000 CNEC PS3 CPS 1125469 O0 000 O0 0 7 1 1 4 68 0000000000 RCEF PS3 CPS 1125469 O0 000 O0 0 7 1 1 4 68 0000000000 RCEN PS3 CPS 1125469 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PS3 CPS 1125469 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 1125469 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 1125469 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 1125469 O0 000 O0 0 7 1 1 4 68 0000000000 NPOR PS3 PU 1125469 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1125469 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1125469 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1125469 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 12064.000 NPHI.PS3 19.386 ENPH. PS3 22.451 TNPH. PS3 TNRA.PS3 2.443 RTNR.PS3 2.462 ENRA.PS3 3.837 CFEC. PS3 CNEC. PS3 3130.621 RCEF. PS3 812.381 RCEN. PS3 2964.520 RCNT. PS3 RCFT. PS3 925.406 CNTC. PS3 2213.477 CFTC. PS3 925.562 NPOR.PS3 GR.PS3 38.375 TENS.PS3 2460.000 CCL.PS3 0.000 DEPT. 11592.500 NPHI.PS3 7.448 ENPH. PS3 9.712 TNPH. PS3 TNRA.PS3 1.533 RTNR.PS3 1.549 ENRA.PS3 2.219 CFEC. PS3 CNEC. PS3 4067.903 RCEF. PS3 1866.444 RCEN. PS3 3719.147 RCNT. PS3 RCFT. PS3 2784.179 CNTC. PS3 4198.117 CFTC.PS3 2834.441 NPOR.PS3 GR.PS3 23.578 TENS.PS3 3840.000 CCL.PS3 0.000 17. 472 815. 935 2312. 692 17. 472 5.834 1833.065 4398.448 5.785 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1997 10:49 PAGE: 25 **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/11/12 ORIGIN : FLIC TAPE NAME : 97506 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 11-27, API# 50-029-21638-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/11/12 ORIGIN : FLIC REEL NAME : 97506 CONTINUATION # : PREVIOUS REEL : COf4~ENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 11-27, API# 50-029-21638-00 * ALASKA COMPUTING CENTER * .- ........................... ~ .......SCHLUMBERGER .......* COMPANY NAME : ARCO ALASKA INC. WELL NAME : DS 11-27 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292163800 REFERENCE NO : 95265 0 0 0 0 I~~ ~Z 000 ~ ~O~U~** ~ Z ~N U~ Z O~ 0 ~ w 00o0 0oo~ 0000 ~ ~0~ W ~000 ~ ~000 ~ ~0~ ~ Z W CO ~ ,--~0 CO ~D 0 0 O0 C~J Od 04 CO ~ ~ ~ o LL 0 u ~J ~- 0 I-- ~J ,m,. .~J i_uu z ~o Z-~ rU =:-,-- 0 0-r- (L)~-,-- q) 0 ~ 0 ~ ~-r-- (L) 0)~ 0 ZZZ~J~O~O~O~Z LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-AUG-1995 16:53 PAGE: 5 TUNI VALU DEFI APD FT 58. Above Permanent Datum EKB FT 58. EDF FT 57. ECL FT 28. TDD FT 12052. TDL FT 12050. BLI FT 12044. TLI FT 11650. DFT PUMP-IN SEAWATER/CRUDE TLAB 1245 30-JUL-95 Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Total Depth - Logger Bottom Log Interval Top Log Interval Drilling Fluid Type Time Logger at Bottom TABLE TYPE : CURV DEFI DEPT Depth NPHI Compensated Neutron Porosity, SS Matrix, cali& dead time corr. ENPH Epithermal Neutron Porosity CPHI Compensated Neutron Poro., SS matrix, tool & Environ. Corr. 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Top Log Interval DFT PUMP-IN SEAWATER/CRUDE Drilling Fluid Type TLAB 1245 30-JUL-95 Time Logger at Bottom TABLE TYPE : CURV DEFI DEPT Depth NPHI Compensated Neutron Porosity, SS Matrix, cali & dead time corr. ENPH Epithermal Neutron Porosity CPHI Compensated Neutron Poro., SS matrix, tool & Environ. Corr. NRAT Neutron Ration Non-Dead time Corrected (N/F) CRAT Neutron Ratio, Dead Time Corrected (RN/RF) ENRA Epithermal Neutron Ratio Calibrated NCNT Raw Near Detector Count Rate, Dead Time Corrected FCNT Raw Far Detector Count rate, Dead Time Corrected CNTC Corrected Near Detector Count Rate CFTC Corrected Far Detector Count Rate CNEC Corrected Near Epithermal Counts CFEC Corrected Far Epithermal Counts GRCH Gamma Ray in Casing TENS Surface Tension CCL CCL Amplitude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 i .o ~J 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 ZZZZZZZZZZZZZZZ UUUUUUUUUUUUUUU ~Z~UZU~Z~UUUU~U ZZZZ ZZZZ UUUU UUUU ~Z~U ~UZU UZU UZU 0~0 0000 IIII ~ZZZ ZZZZ UUUU UUUU ~z ~z zz~ zz~ zzzz zzzz ~Z~ ~Z~ ZUU~ ZUU~ ~ UUU UUU z ~z~ ~z~ ~J u ~J r~z ~J OW u~ o. z ~J z~~uz uz~z~w ~uuuu~ w O"'- cz:::',---,' "'0 ~u 0000ooooo0000000 000000000000oo00 o00000000o000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 0000000000000000 ZZZZZZZZZZZZZZZ UUUUUUUUUUUUUUU W~Z~ZUUZ~Z~U ~Z~UZU~Z~UUUU~U .o ZZZZ UUUU ~Z~U UZU ZZZZ UUUU ~z zz~ ~ · 000 o. z z w ~ u w ~ EOEO~~UUUU ~ o ~ o ~ ~ moo o o ~ ~UZUZW~UUUU~ ~ZZ~WWZ~~ O-r- n.' ~,_... 14.1 1"-,4 LL_ '~'" '"'~ 0 ~:~. ,r'-', LLI ~, LL.I I'--- 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 000 c~ c~ c~ z z .~.. ,.-t- z Lt,.i (.-.~ Z (..~ 000 · · ! i · · · i I I 00o i i i ooot~ i i i 0ooo Mill ~zz ~z~ ~ o ooo J i ,i LL C> O~ ~ _J o. ~U ~ OW~ C'~~~O 00~ ~ ~ ~ ~ ~ z o u z LLI ~- u ~ ~~Z~~Z~O Z o0 u z o w w 0 u z u~J O::E: N 000000000000000000 000000000000000000 000000000000000000 000000000000000000 000000000000000000 000000000000000000 000000000000000000 000000000000000000 000000000000000000 000000000000000000 000000000000000000 000000000000000000 000000000000000000 0000000 0000000 00000000000 ~J N 0 0 0 0 0 U ~zo ~zo ZZU~U ZZU~U ~Z U~ ~Z w z I-- z ~:) 0<3: - w z N w O~ZZ ~~ oo Z Z ~0~000~ 0 0 o. u z o u 000 000 000 000 -< ..~ m 0 F'~ m ~~Z~O~Z~Z~ZZ O~Mmzmmmm~z=~ 0 -~- o "'50 (-~ "~ ~(DO0 ~ c:=omm m,m,- ¢- ::2 :~ (~ (I) 0 ('-) -,'--' iD, o' 0 Z'-r~ u~ 0000000000000000 ~0 o 0000000000000000 0000000000000000 u oo00o0o00000000o 000o00000oo00oo0 ~ ZZU~U ZZU~U 0 o. c- c- ,-Jz O~ zu -t-o I.-- i.~J ~ 0 w --lOc:Z:: o0 I.l I~ nn I--- 0 w LiJ Z 0 U Z ~Z~Z~Z ZZZ~O~O~O~~ oo u 0 ou~ OOU~ ~ZZZ~Z~ZUUUUZ~~U Z 0 w w >- w w ~0 · 0 0 ~"~ ,-~ 0 ~J L~JX LLZ 0000000000000000000 0000000000000000000 0000000000000000000 0000000000000000000 0000000000000000000 0000000000000000000 0000000000000000000 0000000000000000000 0000000000000000000 0000000000000000000 0000000000000000000 0000000000000000000 0000000000000000000 Z~U~ ~U~Z ~U~Z z ~ · --J lmJ LL 0 CI~ ~ ~ PROGRAM: LIS REVISION: 4.1 PART NUMBER: W5550-MICRO Start of execution: Thu 27 SEP 90 l:09pm WELL DATA FILE: C:\CLIFF\W04592.WDF ECC: 4592.00 COMPANY NAME: ARCO ALASKA INCORPORATED WELL NAME: D.S. 11 - 27 FIELD: LOCATION: Top of Well: Bottom of Well: Level Spacing: 11400.000 12090.000 0.500 NUMBER OF CURVES: 13 DEPTH CCL CLSN CN CNC LSN SPD SSN TEN TTEN CNRA CSSN GR COMPANY:ARCO ALASKA INCORPORATED WELL:D.S. 11 - 27 FIELD:PRUDHOE BAY COUNTY:N.SLOPE STATE:ALASKA RECEIVED OCT ! 9 1990 Alaska Oil & Gas Cons. Commission Anchorage TAPE INFORMATION FILE:PASS 1.001 FILE INTERVAL: START= 12090.000 END= 11400.000 DEPT GR SPD· TEN TTEN CLSN CSSN CN CNC CNRA LSN SSN CCL 12090.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 12065.000 72.834 16.998 129.445 737.374 21.330 261.455 26.014 30.014 0.082 85.319 261.455 0.000 12040.000 74.844 25.233 187.162 996.263 18.777 241.087 27.876 31.876 0.078 75.108 241.087 0.000 12015.000 83.609 25.997 84.548 1007.364 19.404 241.764 26.655 30.655 0.080 77.618 241.764 1.000 11990.000 34.800 25~997 36.003 1017.618 18.820 238.628 27.360 31.360 0.079 75.279 238.628 0.000 11965.000 26.634 25.997 -4.583 991.430 16.418 228.862 31.521 35.521 0.072 65.670 228.862 0.000 11940.000 67.816 25.997 -6.493 1000.052 15.042 212.533 32.170 36.170 0.071 60.167 212.533 0.000 11915.000 24.310 25.997 -17.689 1004.583 30.186 290.467 17.833 21.833 0.104 120.746 290.467 0.000 11890.000 94.757 25.997 -25.502 972.864 12.481 187.297 35.289 39.289 0.067 49.923 187.297 0.000 11865.000 75.725 25.762 -19.078 999.540 16.394 214.526 28.675 32.675 0.076 65.576 214.526 0.000 11840.000 49.415 25.997 -27.415 979.440 16.443 214.268 28.498 32.498 0.077 65.771 214.268 0.000 11815.000 23.933 25.997 -21.793 986.363 36.979 302.097 13.388 17.388 0.122 147.915 302.097 0.000 11790.000 24.894 25.997 -23.957 984.013 33.607 298.097 15.527 19.527 0.113 134.429 298.097 0.000 11765.000 25.344 25.997 -23.287 981.581 39.335 316.042 12.977 16.977 0.124 157.339 316.042 0.000 11740.000 19.776 25.997 -16.417 984.042 38.713 · 291.862 11.474- 15.474 0.133 154.853 291.862 0.000 11715.000 29.479 25.342 -30.107 970.643 35.683 302.251 14.305 18.305 0.118 142.732 302.251 0.000 11690.000 33.825 25.997 -19.328 984.262 42.061 324.337 11.995 15o995 0.130 168.244 324.337 0.000 11665.000 23.227 25.997 -32.426 971.083 49.090 355.683 10.589 14.589 0.138 196.361 355.683 0.000 11640.000 20.800 25.997 -25.522 975.761 58.699 367.442 7.659 11.659 0.160 234.796 367.442 0.000 11615.000 19.317 25.997 -19.507 982.396 53.270 12.843 0.150 213.080 354.843 0.000 354.843 8.843 11590.000 21.074 13.894 25.997 -30.649 962.273 49.278 0.143 197.111 345.627 0.000 345.627 9.894 11565.000 23.966 19.463 26.107 -25.868 954.274 31.783 0.113 127.131 281.251 0.000 281.251 15.463 11540.000 21.654 19.726 26.342 -11.732 978.260 31.104 0.112 124.416 277.923 0.000 277.923 15.726 11515.000 39.102 26.723 25.997 -24.548 964.255 21.396 0.089 85.584 239.810 0.000 239.810 22.723 11490.000 20.875 18.628 26.342 -28.630 956.081 35.552 0.117 142.209 304.904 0.000 304.904 14. 628 D.S. 11 - 27 DEPT GR SPD TEN TTEN CLSN CNC CNRA LSN SSN CCL CSSN CN 11465. 000 26. 456 20.500 11440.000 31.554 24.356 25.997 -25.328 960.685 0.109 117.249 269.322 25.997 -24.343 962.300 0.096 92.693 241.997 29 0 23 0 · 312 .000 · 173 .000 269.322 241.997 16.500 20.356 11415.000 112.522 0.000 0.000 -100.000 0.000 0.000 0.000 50.000 1.000 50.000 50.000 0.000 11400.000 -999.250 -999.250 WELL DATA FILE: C ECC: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 : \CLIFF\W04593.WDF 4593.00 -999 -999 .250 .250 -999.250 -999.250 COMPANY NAME: WELL NAME: FIELD: LOCATION: ARCO ALASKA INCORPORATED D.S. 11 - 27 Top of Well: Bottom of Well: Level Spacing: 11400.000 12060.000 0.500 NUMBER OF CURVES: 13 DEPTH CCL CLSN CN CNC LSN SPD SSN TEN TTEN CNRA CSSN GR FILE:PASS 2.002 FILE INTERVAL: START= 12060.000 END= 11400.000 DEPT 12060.000 12035.000 12010.000 11985.000 11960.000 11935.000 11910.000 11885.000 11860.000 11835.000 11810.000 11785.000 11760.000 11735.000 11710.000 11685.000 11660.000 GR SPD TEN TTEN CLSN CNC CNRA CCL LSN SSN -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 80.955 25.997 143.560 1014.851 17.563 31.340 0.079 0.000 70.250 222.577 54.679 25.997 55.479 31.788 0.078 1.000 1006.702 73.158 18.290 234.334 36.223 25.997 17.047 996.687 18.708 33.082 0.076 0.000 74.832 247.132 1000.501 67.326 66.170 25.997 -3.554 35.410 0.072 0.000 16.831 234.082 50.757 25.997 -12o975 994.906 21.000 29.318 0.083 0.000 83.999 252.791 1061.123 114.469 1050.719 43.293 25.567 25.997 -25.658 22.283 0.102 0.000 80.340 25.997 -25.806 44.634 0.061 0°000 28.617 279.569 10.823 177.200 78.752 25.997 -25.002 1053.475 14.094 35.065 0.072 0.000 56.374 194.574 36.010 25.997 -16.986 1064.622 22.605 27.185 0.088 0.000 90.419 256.716 36.239 25.997 -24.159 21.660 0.105 0.000 23.710 25.997 -24.828 18.379 0.118 0.000 23.078 25.997 -25.085 18.456 0.117 0.000 1066.024 119.871 1054.856 144.452 1049.781 138.362 1053.400 148.647 1054.689 134.548 1052.351 154.728 1062.030 231.597 27.412 25.997 -28.069 16.912 0.125 0.000 32.763 25.997 -24.277 20.205 0.110 0.000 27.804 25.997 -24.952 17.376 0.122 0.000 19.694 25.997 -17.684 12.881 0.150 0.000 29.968 286.675 36.113 306.763 34.590 294.698 37.162 297.788 33.637 305.811 38.682 315.867 57.899 386.426 CSSN -999.250 222.577 234.334 247.132 234.082 252.791 279.569 177.200 194.574 256.716 286.675 306.763 294.698 297.788 305.811 315.867 386.426 CN -999.250 27.340 27.788 29.082 31.410 25.318 18.283 40.634 31.065 23.185 17.660 14.379 14.456 12.912 16.205 13.376 8.881 11635.000 22.518 25.997 -29.878 1043.112 59.609 374.578 7.729 11.729 0.159 0.000 238.435 374.578 11610.000 22.224 25.997 -24.705 1046.070 53.996 369.349 9.375 13.375 0.146 0.000 215.983 369.349 11585.000 27.555 25.997 -25.830 1052.562 35.637 296.520 13.848 17.848 0.120 0.000 142.549 296.520 11560.000 24.969 26.997 -22.098 1050.499 29.505 274.359 16.840 20.840 0.108 0.000 118.020 274.359 11535.000 25.831 26.342 -22.769 1048.745 33.235 283.519 14.489 18.489 0.117 0.000 132.940 283.519 11510.000 21.568 26.888 -27.557 1041.623 26.367 278.162 20.685 24.685 0.095 0.000 105.469 278.162 11485.000 30.849 25.997 -27.614 1045.414 34.804 295.289 14.348 18.348 0.118 0.000 139.215 295.289 11460.000 27.522 26.997 -22.211 1056.729 29.397 272.259 16.726 20.726 0.108 0.000 117.587 272.259 D.S. 11 - 27 DEPT GR SPD TEN TTEN CLSN CSSN CN CNC CNRA CCL LSN SSN 11435.000 35.630 26.997 -26.779 1048.305 29.186 258.966 15.535 19.535 0.113 0.000 116.745 258.966 11410.000 0.000 0.000 -100.000 0.000 -1.000 50.000 0.000 0.000 0.000 50.000 0.000 50.000 11400.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 WELL DATA FILE ECC : C: \CLIFF\W04594.WDF : 4594.00 COMPANY NAME: WELL NAME: FIELD: LOCATION: Top of Well: Bottom of Well: Level Spacing: ARCO ALASKA INCORPORATED D.S. 11 - 27 11400.000 12070.000 O.500 NUMBER OF CURVES: 13 DEPTH CCL CLSN CN CNC LSN SPD SSN TEN TTEN CNRA CSSN GR FILE:PASS 3.002 FILE INTERVAL: START= 12070.000 END= 11400.000 DEPT 12070. 000 12045. 000 12020.000 11995.000 11970.000 11945.000 11920.000 11895.000 11870.000 11845.000 11820.000 11795.000 11770.000 11745.000 11720.000 11695.000 11670.000 GR SPD TEN TTEN CLSN CNC CNRA CCL LSN SSN -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 81.504 26.956 387.495 35.689 0.071 1.000 1064.397 61.893 15.473 216.460 47.918 26.003 181.816 1064.705 20.040 30.453 0.081 3.000 80.159 248.411 38.389 26.997 70.531 34.134 0.074 0.000 72.846 26.997 20.579 33.187 0.076 0.000 36.835 25.997 -4.965 36.838 0.070 0.000 63.291 26.997 -6.304 29.072 0.084 0.000 32.602 26.561 -25.127 21.670 0.105 0.000 87.798 25.997 -16.856 36.468 0.070 0.000 57.038 26.003 -24.362 24.175 0.096 0.000 1059.466 68.726 1049.976 72.654 1047.242 61.717 1051.883 79.381 1034.146 114.333 1043.143 54.861 1042.893 li6.54o 1051.935 123.265 32.641 25.997 -19.877 21.773 0.104 0.000 17.181 232.435 18.163 240.518 15.429 220.978 19.845 237.344 28.583 273.524 13.715 194.973 29.135 302.541 30.816 295.926 60.331 26.991 -23.510 1043.355 22.040 26.995 0.089 0.000 88.161 248.957 1039.507 155.748 29.283 26.997 -28.416 17.392 0o122 0.000 27.040 25.997 -32.857 18.004 0.119 0.000 26.292 26.962 -25.402 17.687 0.121 0.000 30.200 26.997 -18.978 18.842 0.116 0.000 22.516 25.997 -26.231 12.284 0.155 0.000 1024.132 132.967 1029.350 152.764 1033.794 152.390 1026.676 223.127 38.937 318.146 33.242 278.292 38.191 315.756 38.098 329.400 55.782 361.037 CSSN -999.250 216.460 248-.411 232.435 240.518 220.978 237.344 273.524 194.973 302.541 295.926 248.957 318. 146 278.292 315.756 329.400 361o037 CN -999.250 31.689 26.453 30.134 29.187 32.838 25.072 17.670 32.468 20.175 17.773 22.995 13.392 14.004 13.687 14.842 8.284 11645.000 23.663 26.555 -32.356 1014.445 59.369 372.615 7.707 11.707 0.159 0.000 237.478 372.615 11620.000 27.756 26.033 -21.227 1024.666 44.201 320.733 10.621 14.621 0.138 0.000 176.805 320.733 11595.000 21.702 26.991 -26.928 1017.977 50.513 347.712 9.505 13.505 0.145 0.000 202.051 347.712 11570.000 39.478 26.997 -13.313 1023.679 22.904 240.729 20.564 24.564 0.095 0.000 91.617 240.729 11545.000 29.021 26.997 -28.369 1012.983 29.050 277.072 17.573 21.573 0.105 0.000 116.201 277.072 11520.000 62.989 26.997 -30.778 1006.951 16.892 219.560 28.389 32.389 0.077 0.000 67.569 219.560 11495.000 25.217 26.997 -28.369 1007.694 33.154 294.631 15.578 19.578 0.113 0.000 132.615 294.631 11470.000 27.132 26~997 -9.424 1032.607 32.595 287.818 15.404 19.404 0.113 0.000 130.382 287.818 D.S. 11 - 27 DEPT GR SPD TEN TTEN CLSN CSSN CN CNC CNRA CCL LSN SSN 11445.000 30.026 26.997 -25.006 1008.823 29.877 267.681 15.800 19.800 0.112 0o000 119.509 267.681 11420.000 135.167 0.000 -100.000 0.000 17.039 228.762 29.794 33.794 0.074 50.000 68.155 228.762 11400.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 End of execution: Thu 27 SEP 90 l:10pm Elapsed execution time = 15.05 seconds. SYSTEM RETURN CODE = 0 RECE VED DIRECT DIOITAL LOGGING COMPUTER PROCESSED ANALYSIS LLLLLLLLLL LLLLLLLLLLL 1i ii . ~. ii ii -- .o ii ii iiiiiiiiii iiiiiiiiii SSSSSSSS S S S S :4 :q S :S S S :---: :::, A'.:; F, ::; :-."; :--, S ~ :-_',~ '._4'.5 b.;:5:5:5 S S SS S S S S S S S S S S S S S S ::; S S S D [) D~."~ F) D [::, D D .'.. 1U ! _t t. t D D D L:: D [:, D P 8' D U U U Li D D C, [:, U U U ij D D D [: U U U Li D D D [:, ij U U ij D [) [:, D ij i_i i.iU D D D D U Li U U Lb D D D U U U Li D D [': [': U U U U D D [:, D U U ij U [) [:, C, D ['~ [:, D D [': [:, UUUUUUULiUUUij [) [)[) [) LD D D D [) U U Li U U ij Li U Li Li M M M M Pt P1 P! M F't Pl hi M bi bi H i"i M H hi bi HM ,HH Mhi M bi H i',i hi M M H hi M H M M H P! M p! i"i bi Pi H H H N bi i:i ........ P1 P1 M Pl .hi M H hi P F'F' F'P F'F' F'F' F'i F' F' i::' P F' F' F' F'P F'i Pi:' i PP i F'PPPPPPPPF'i PF'PPF'PPPPPi p,p, P't-' I-'P' ii iii liil ii ii ii ii ii ii ii iiiiiiiiii tiiiiiiiii 0 0 O0 0 0 O0 O0 O0 O0 O0 ii iii 11tl ii Ii ii ii ii ii ii i i i 'ii i i iiiiiiiiii 00000000 O0 O0 O0 O0 00 O0 O0 VV O0 LI U O0 O0 0000 00 0 0 0 00 0 ii 1 1 'i i i ii ii i' ii i'i I t l! l! 1 t 'l 1 UU UU UU UU U U U U ~.J~ UU UU UU UU UU UU UU UU UU UU UU U U U U UUUUUUUUUJJUU U U Lt U U U U U L.i U 8 ::: '~: 9 88 S 8 :.q 8 8 8',388 8::: 88888 88 o ,:, 88888888 88888888 88 88 8888888 88o88 8888888888 ~G;]GGGGGGG~G Gt] GGGGG GG GG ~ C~] ~C;G6 GGC~G6 P' P'P' I"' i'" i-' h' P'i-' k" I-' )'-' I-' k' I-' f-' h' P' h' P' t-' t"' P'P' I'" 1-' k"h' t-' t'-' t'~ i'-' PPF'PPF'F'PPPPP 1., p, t-, 1.., I.-' t-, p' p, p, t-, I.~, p, PP PP PP I'" t'''~ l-,t~ ,S 8:388 :_:: 88 E: 888 98 8:3 ,= ,=, ,'_4 ::S 88888RSR 0 ,. C,, C-:Lq. 88 ,:, ,:, ,., o 88 L~ 8 ~:: 8 i"i i',i bi H H i'i i"i H Pi M i"i M i"i Fi H H M bi hi M M H N H i"i hi Fi NH r'l M M HM. MM 99999999 9 9999999999 ¥ ,:.4 9999999999 9 9 9 99 9 9 9 9 9 9 9 9 9 9 9 99 9 9 9 ~- * * * R E E L Fi E A. D E R * * * * S~r-vica n~me: &:]SFOi Previous. r~zei: HEADER Date: 89,"08,-'i 0 Or. igin: i3630~ Continumt. ion ~¢: O~ Pr.e'¢ i c, us tape Patti: 89/08,"~0 Origin: Comments Continuation .~: Oi File: name: .OOi Version Datm '. (~4 Film t..,:..,pm: L~] P~."mviou,: f'iim: Maxis:urn length: 1 !"~' - .- M f..; E M Cf'l id f'i FN C 0 U t',i STAT CTRY APl L¢~T i L ON G SECT T 0 b.i N RANG EK8 E[~F EGL LMF D M F R U N T tFiE DATE LCC S ON L U N FL LUL ENG I W i TN DD DL C:8D i CBLt TL] TCS TL~ BHT MT DFD ~V ~S DFPH RFi RMF l~Fo; RMC I NFORMAT I ON RECORDS F: 0 I'-t T E N T S U N l T ARC.:O ALASKA iNC ................. D,'S, ii-~7 ,::DSN) APl NLibi' 50-F~29--2i6~'-' F'RUE.~HOE BAY [)ATE LuL~biEp: O/'-u'.-'-~'.4. ................ NORTH SLOPE .................................... AL. ASKA .................................... Li S A .................................... 2~ 638,000 ............................................... 0 D~g, 0 M in, O, 0 S~c, N ........................ O Deg 0 Min, O, 0 Sec, !,1 ........................ i iN ..................................................... iSE ..................................................... 5S, OOO .................................................. FT 57, O00 .................................................. FT ':'¢: O00 .................................................. ~T MS i i30, 000 ................................................ i'36301 ................. NOR H ._LUFE NORTH ~LOPE YARBRO dORE AN,..'SAL EH ,, .... i 20e8,000 ................ FT o8, OOO ................ FT O. O00 ...................... FT O, 000 .................................................. FT i i400, OOO .............................................. FT i2080, OOO .............................................. FT O, OOO .................................................. HR i i , 300 .................................................. 0. O00 ................................................ 0,000 ............... PRODUCED 6'060 O, 000 0, O00 O, 000 O, UUlJ 0, 000 0.000 HR DEGF' DEGF CP OH hiM 0 Fi t,! M DEGF 0 0 ................................................... UI-! Plr't TYPE F: A T iS SiZE C 0 E': E F'.~ ge.: E R R F: R M N E H M L..~ T M C S S I_.' ~. NFORMRT ]: ON RECORDS C 0 N T E N T S LIN ] T DEGF TYPE S 4 C: A D E E R R 0 R 65 6 E: COMMENT RECORDS [~.!ell Location Comment. i: Weii Location Comment 2: l.,.tel ] Location Commer~t .3: t.,.!e_l t '.'...oc:stior, Comment 4.: I.de ! I Fi 1 e Comment i: T ! ED Gtell File Comment 2: i.,.teli File Comment 3: SURFACE: 45~' FSL 5.: 229' FEL INTO SCHLUMBERGER CBL DATED i -20-87 1 File Comment 4: :~. :'?: :'~-:~-:~. :~, :~. :~. :~-:~ :~, :~. :~:~ :~:~ ~:~ :~ :~:~: :'B :~ :~:~: :~:~ ~::~ :~:+: :~ :~ ~:~: :~:~: :~:%: ~ ~::+: :~ :%: ~+::~ :~:~ ~%: :~: :~:~ :~ :~:%: :~:~ :~:~ ~::~ :~:~ LIS tape ,.,.,r. itten b,.~: ANCHORAGE COMPUTING CENTER Ail curve and tool mnemonics u:sed are those which most closel~¢ match H;ailibur~ton cur-ye ar, d tool mnemonics, :~:~ ~; :~ ~::~ :~:~ :~ :%: :~:~ ~:~ :~::~ ;~:~ :~;~ :~:'~ :~:~: ~:~: ~:+: ~:~ :~: :$::~ ~:~: :~:~ :~:~ ~:~: :a:~ :+::~ :+: :+~ :~:~ :%::+: :+: :+~ :~:¢ :~;~ :'~:~ :~ :~ :~ :~ :~:'~ HALLIBURTON TO SCHLUMBERGER TOP 80TTOt~I MHEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH Fl' DEBT Fl' 1 i 358, O0 CCL DSN COL DSN 11~95,00 FDSN DSN CNTS FDSN DSN CNTS t i 395, O0 GR-D DSN APl GR--D DSN AP1 i i395, O0 NDSf4. DSN CNTS NDSN. DSN CNTS ii.".~95,00 NPHI DSi,t X NPHi DSN X 11395,00 f,IR¢:~T DSN f,IRAT DSN 1 t .7595,00 AV,SP COf"IPUT ,"-{ AVGP COMPUT ,".'; t 1 3'..=~5, O0 SDC, P COI"iPUT SDDP CO,~'tPUT ! ! .?,95: O0 DEPTH t2118 O0 2 098 75 2 098 75 2 098 75 2098 75 2098 75 2098 75 2098 75 ~: 0 :? o "'* *" -- DATA ENTRY FORMAT -] RAT 1 L TYPE SZZE CO[)E i6 i 66 0 i 66 ~'.~:¢* b.r-~lF, Y BLOCK LEGEND 4:*** '{": :'t': :~ :~ :~ :t: :-6. :-l-: :+: :-B :t'~ :'1.: ~ :'l': :.'¢ :~ :'l-: :.t': .~ :~ :-I': :4-: :t': :~ :.1.: :4-: :1-: :4-: · :t-: n~C:RZPTION TYPE ~. ~.,. i6 Datum s~,mci¢ication block sub-t.t,.,pm O Terminal. or. ( no more_ mntcims ) DATA FORM~ T ¢'PEC P '~ ' ._. I F I _.A T I ONo SER'./i CE SERVICE APl MNEM iD ORDER ~ LiNiT LOG AP1 AP1 AP1 FiLE TYPE CLASS MOD, '~ P RC: ::SIZE LVL SbiPL iNDiCATORS 0 0 0 i 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4 0 4 O. 4 0 4 0 4 0 4 0 4 4 0 4 O 68 68 68 68 68 000000 000000 U U U U U U 000 ~:~ 00 U Ij U U U U 000000 O00uuu 000000 U U U U U U 000000 000000 000000 O000F~O 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 UUUUUU UUUUUU DEPT ::5 L) D f" CC L. F D S N DA G R - D TA RECORD N D S N NPH i N R A T A V G P 098, i, 000, t900. it800. ii700, i i 600. 11500. 1i400, i. 750 i36 000 000 0 O0 ,764 000 i29 n 00 083 000 000 47.45 -1 , 000 7:7'.-37 8 048 8 097 8 041 8 056 8 082 8 090 i 4 O, 232 o29 ~..gg 340,062 795,26 i 337, 096 !89,292 -i , 000 22,454 O'7 46,57i i 8,850 i,_.. 08i 2557 ..... .-'-:3305 ..I",b4.:..8 7.2 R 38CJ96 937 40218 8Z~'._, 34964 484. 352 28,010 2i , 404 il 808 i3 7J.:, 6 080 3 357 6i4 2_4 t'"'"~-,=.. i 7i 8:3 6i 47 i50 049 03:3 7 02 0i7 42° 27i 487 29.459 '22, :39 0 i2, 0i4 i 3,9 i 9 6,iii 3 , 379 i2,42i 26.5 08 File nature; 8, G5FOl , OOi Maximum iength: i024 TRA I LER RECORD~_, File t. ppm:' LO Vet. sion ~: Nmxt ~iic: Date: Film n.~m¢: ,002 Vms-sion #: Date: Maximu~,~: length: 1024 Film type: LO Previous .F'ilm: 1 NFORM T ! ON RECORDS M FI E hi CON TEN TS UNIT T"?PE C:RT:] SiZE CODE ERROR CN td N FN COUN STAT C: T R Y AP i N LAT i L 0 N G SECT TOWN R~NG EKB EGL PD LMF DHF RUN TiHE DATE L. CC SON LUN FL LUL ENG i W i T N DD DL CBDi CBLi TLi BLi TCS TLAB B Fl T btRT biT DFD HV I DFPH DFL RMF MFST MFSS RMC ARCO A!.ASf<A !NC ................. D,S, I 1-27 (DSN) APl NUM: 50-0;.:.'_'9-2i63Lq PRUDHOE BAY DATE LOGGED: 07-02-@9 NORTH SLOPE RLf4:SKR .................................... U S ¢.. 2i638,000 0 Drag. OHin. O. 0 Sec, N ........................ 0 Deg, 0 M in, 0, 0 Sec. ki ........................ i5E, , , ,, ,, ,, ,, ,,,, ,, ,, ,, ,,,, ,, ,, ,, ,, ,,,, ,,,, ,, ,, ,, ,, ,, ,, 58, O O0 .................................................. 57.0 O0 .................................................. ZM, UUU .................................................. i~30,000 ................................................ ~,..' 2/89 1 ~67301 ................... ....... ' SLOPE ........... NOR TH NORTH SLOPE .... Y A R B R 0 JORDAN/SALEH .... ~ 000 i c'088 000 (~, ~:[ (I 0 .................. O, 000 i2080 000 O, O00 i i .300 .... .......... 0, .000 ............... · O 0 O O PRODUCED 6'666 ; ' ; ; : : ; O. 00 O 0 000 '0 0O0 0 000 0 O 0 O 0 000 U, U U U o o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o 0 o 0 0 0 0 F'T 0 FT O 3 FT 0 .'3 0 0 0 0 0 0 0 0 0 0 0 O 0 O O 0 O 0 0 0 O 0 0 FT 0 3 FT O 3 FT 0 FT O 3 FT 0 FT 0 Fi R 0 2 FIR O 4 DEGF 0 i DEGF O 0 2 0 LB/6 0 2 CP 0 2 0 '2 0 2 0 H M bi 0 2 OH FiM 0 2-. DEGK 0 2 0 2 OHMM 0 2 40 6~' 40 65 4O 65 'dU 0 65 34 65 4 65 "') F-q, 5 3 6 5 4 68 · '-i. 68 2 65 2 65 2 65 :'-! 79. iO 65 .... ~U ~.~ ZU 20 65 4 68 4 68 4 68 4 68 4 68 4 68 20 65 20 65 4 4 68 4 68 4 6 8 i2 65 4 60 I NFORMA T I ON RECORD©~., I'd N E M C: 0 N T E i',l T S U N ! T T Y P E C A T ;] S I .-Z E ,'1:0 D E E R R 0 R MCST DEGF 0 '::,..: ,4 6 8 0 2 i 2 6 5 0 '-"; 4 "'-' 0 3 4 68 C:OMMENT REuURD.=, Well Wall [da 11 ~_c u.~.t i or~ Com;T~er-,.~-,..~ ; Location Comz~ent. 2~ Lc, catior, Cc, m~ent ~ Location Com~mnt 4: TiED Film Cc,~,mmnt 1; Fil,s Comment.- File Comment 4: SUP. FACE: 45i" FSL g: 229" FEL INTO SF:HLLIHBERGER CBL DATED i--2~.~--,-,'~-',-', LiS tape ~,.~ritt. mn b,;..,~ ANCHORAGE COMPUTING CENTER Ail cur-ye .and tool ~ncamonics used are those which most closely/ ~at. ch ** Halliburton ,:ur-yin and tool mnemonics, HALLIBURTON TO SE:HLUHBERGER TOP 80TTOH MNEH SERVICE UNIT MNEH SERVICE UNiT DEPTH FT DEPT FT COL t. DSN CCL DSN F D ~ N 1 O S N C N T S F D S N D S', N C I'.1T S GR-'D i DSN APl GR'-D DSN APl N D S f'.l ~ D ~ N C N T S N D S N DS N C N T S NPH~. i DSN ,s'. NPHI DSM ,Z N R ¢~ T i D S N N R A T D S N DEPTH 11358 O0 1 I 358 O0 i i 358 O0 11358 O0 i 13.=;8 O0 '1 i ,~.~ 8O0 'i 1358 -00 DEPTH i21i8,00 121 08.75 ib:l 0¥. ,...., 121'0'~,~, 75 1 21 08,75 i 2 't 08,75 F'a ge !! D~TR FORMAT SPEC ~ F: ~ C~T ~ONS ENTRY T Y P E S i Z E C I:~ P E 16 i 66 0 i 6 ~ i2 TYPE DESCRIPTION i6 Datum stp. mc ii~' i cat. ion 0 Termina or " no mor. e biock sub-tppm entries [)ATA FORMAT cP~'C I F ! PA T i _LDN~ SERVICE SERVI C'E APl MNEM ID ORGER ~ UNiT LOG AP! AF'i APl FILE TYPE F:LASS MOD, F'RC # SiZE LVL SNPL RC !-'[-.:uu;-,5:$ iNC, l 0 o 0 2 0 0 0 i 0 0 0 i 0 0 0 i 0 0 0 i 0 0 0 i 0 0 0 i 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i 6 8 4 0 i 68 4 0 i 68 4 0 i 68 DA RECORDS DEP T CC: L FDSN G R - D N D S N NPHI N R P. T i4 1 21 08,750 i 21 O0, 000 12000.000 I i900, 000 11800,000 i i700,000 11600, 000 I 1500, OOO 1 i400, 000 -I -i ? 8 8 000 000 967 1 '; 0 047 8 Oli 8 055 8 096 8,1i9 i42, t9'2 145, 133 2!.3,86i 396,48 i 32 S, .'762 589,529 ? 97,27' 7 358,854 i ,:"~, 545 -1 ,000 · -i. 000 26,612 i6,633 41,304 30,493 15,247 21,622 t 28,348 '25(:, 06 445 ~._,~,2i 008 33_,.~3 1 09 369.'38 ._~.-'5""' 36 02.3 344 38667 0,47 4 0"" 77.-- q 9 '-"..,. ,_ ._'5,523 i 563 ,3 0683, 184. 27,6t 0 26 993 o3 602 I i 562 15 104- 6 ~ ~ 4 :T.', i 2 538 26 689 i68 i65 147 87 104 6i 92 163 882 554. 4..'_--,'4 37i 506 5i0 071 9i6 File name: &GSFOi , 002 M,~ximum l~ngth: 1024 ]'RAILER REC:ORD''~. o 'V~r-~ion #: File t?pm: LO Next f'ii~: i5 FiLE HEADER :4¢ :~: :-8. :~ W, :t¢ W- :~ :4~ :4~ ~ File name: . 003 length: i 024 S~I'"V i Ce Fia~e: Fila tppe: LO Yet-si on #: Date: !',IFORM T ON RECORDS MHEM FH L: U U bi STAT C: T F.': Y APiN LATi LONG SECT TOWN RANG EK8 EDF EGL. P LHF DHF R U N T Z hie D~TE LOC: SON L U N FL LUL Et, tGi WI TN DD C B D ~ Cbl.. ~ TLi BLI TCS TLAE'. 8HT MRT PiT NSS DFD MVI S DFPH DFL RH RHF i, iF.q~' HF:SS RHC C 0 i',f T E N T S U N I T r4Rt. U ALASKA INC, D,S, it-27 <DSN) APl NUN: 50-029-21638 ................ PRUDHOE BAY DATE LUUL;I=D~ O,-'-U;~-S9 ................ HU~,' ! t4 5LUP'b .................................... U S A 2i638, OOO ............................................... 0 Deg, 0 Min. O, 0 S6c, N ........................ 0 [:,rog, 0 M in, O, O Sec, L,J ........................ 28 ...................................................... I iH ..................................................... i5E ..................................................... 59. 000 .................................................. 57,000 .............. ' ....... 28,000 .................................................. HS ...................................................... i i -"0 000 7," 2/89 ................................................. -0 i3bJO! W- 50625 ............... .............................. SLOP .................................... NORTH SE. OPE ...... YARBF.:O , JORD AN,-:S ~L EH i2.088, OOO ........... t2088,.000 .......... O, O00 .............. O. 000 .............. i i 400,000 ............... i'r,r~qo 000 0,000 ii ,300 ................... O, 000 .................................................... O. 000 .................................................. PF..' 0 [:, UC E[:, ................................... FT FT FT FT HR HR DEGF' DEGF O00 ............... ,000 ..... O00 ..... 000 ..... 000 ..... 000 ..... 66b , ; : OHMN 0 H J"i bi OHHH TYPE C A T G 5!Zb_ 0 0 40 65 0 0 40 65 0 0 ,40 65 0 0 '20 6, 5 0 0 20 65 0 0 20 6,5 0 0 4 68 0 a 34 .6. 5 0 0 34 6 :' .. ." -..~ ..I O O .7; 65 0 0 .3 65 0 3 4 6 8 0 3 4 68 0 ~ '-' '- 0 3 2 65 0 3 '-'.2 65 0 0 2 79 0 0 4 68 O 0 8 65 0 0 2 ,'":9 0 0 i0 65 0 0 i 0 65 0 O 20 65 0 0 20 65 0 0 2O 65 0 0 20 65 0 3 4 68 0 ,.,~ 4 68 0 ~ 4 0 3 4 GE..' 0 3 4 6 8 0 3 4 68 0 2 4 68 0 4, 4 68 0 i 4 68 0 i 4 b,:,:'; 0 "} ") ' ,._ ~.U 65 0 2 20 65 0 ;2.-' 4 68 0 2 4 68 0 2 4 68 0 2 4 68 0 2 4 6 0 2 4 68 0 2 12 65 0 2 4 68 E R R 0 M N E H MCST MCSS CS BS ~ NFr}RMA T ~ .... ~]N REPORDc:. ~, C 0 N T E F.~ T S U N i T 0, 0 0 0 ................................................... :", tt ti l.t ................................................... 8,5 0 0 ................................................... DEC:F TYP E C: R T G U!~b. 4, i2 4 4 E R R 0 R i'7 COMMENT RECORDS Location Comment Location Comment Locetion Comment Location Comment File Comment F'ii~ Comment Film Comment File Comment SURFACE: 45I" FSL g: 229" FEL TIE[) INTO SCHLUMBERGER CBL [)ATE[:, 1-20-87, LiS tape wr. it. ter, b.q/: ANCHORAf2E COMPUTING CENTEF,' Ail curve and tool mnemonics used .ar.e those which most. closely, match H.a!liburton cur-ye .and tool mnemonics, :+.'* HALL IBURTON TO SCHLUHB~RGER TOP BOTT'ON MNEM SERVICE UN! T MNEM SERVICE UNIT DEPT'H FT DEPT FT CCL2 DSM CCL DSM F[:,SN;2 DSN CNTS FDSN DSN CNTS GR-D2 DSN APl GR-D DSN APl NOSH2 DSN CNTS NDSN DSN CNTS NPHi2 DS;N ,':..: NPHI DSN NR¢:~T2 DSN NRAT [:,SN DEPTH t 358 O0 1 ~72 75 1 372 75 1 372 75 I 372 75 t.372 75 1372 75 D E P "F H t2t18,00 12i Ol i 2i O!: 75 i2i Ol ,75 i2101 ,7'5 i21 O1 i2i Oi Page [)RTR FORMAT ENTRY TYPE i6 0 R i ZE TYPE DESCRIPTION ~6 ,...,~tum speci¢ication block sub-t~pm 0 ]'erminator ( no mor.~ mntr. ims, ) o E,:. iFI ATiON CODE 66 FORMAT sP£P. IF C T!ON .~:*** DATUH ~;P'~=uiFiC:ATiON BLOC:KS **** ~*' :~. :B :,'B- :B :x,: :~.: :~.: :+: :B :~: :~: **~ :,.B :+: :B :~,: :~ :4*: :~: **~ :~: *~*: :+: ~B **~: :+: :4': :~ :4*: **4*:. :4*: *.~ :~: :4*:. :4*:. :4*:. SER'V~CE SERVICE ~PI ~F'i MNEM iD OR©ER ~ UNiT LOG TYPE APl APl FiLE CLASS MOD ~ PRC ~¢ SiZE LVL Si'iPL PF.'OF:ESS iNDiC:A ! DEPT C: C: L FDSN L~ ~ - L) N D S N NPH i N R A T o 0 S 4 0 i 0 0 2 4 0 i 0 0 2 4 0 i 0 0 2 4 0 i 0 0 2 4 0 i 0 0 2 4 0 i 0 0 2 4 0 i CC L F D S i',l DA T A RECORDS ND SN NPH I NRAT 12101 12100 12000 I 1900 11800 1 ! 700 I i 600 t i 500 11400 750 000 000 000 000 000 000 000 000 -I -i 8 8 000 000 089 087 010 8 014 8 128 8 136 8 i09 ! 49, 055 ! :-"7,493 216,8i I 368,750 354,896 596,524 785, i 84 391 , 527 i 62,787 -1, 000 -i, 000 35,206 20.79! 47, i26 26,335 18,850 26,6i2 140,82S '25403, 070 25446. 574 33702,273 36846 , 2:3 i 3598.7. 078 38039,32 0 40140. 180 35338.7'.9.7 30i 33. 727 3_'30 98 0 23 277 i '2 87',--" t3 164 6 089 34...4 1 0 996 28,481 t59 i87 i 45 93 95 61 47 84 173 S 27 i77 776 707 095 060 942 645 598 File hemal -~,G~FOI._, , 003 M a ::< i m ~_,- m i ,'=. r-; g t h: i 02 4 ILER RECORDS Film t. ppe: LO Nm::<t f'i!c: Date: Datm: 89:"08/10 Or. igin: Continuation Ser.',~'ice name: &1]5FO1 r',ate' ....'~-'~.~,.-'08/10 Ocigin: C,::,ntinuation g: 01 Ne.::.,,'t t. ape' Comments TAPE , LVP OIO,H02 V£RIFICATION LISTING PAGE 1 ** REEL HEADER ** ~ER¥ICE NAME_ :EDIT PATE ~8/06/30 OR~GIN_:FLIC REEL_NAME 1728~2 CONTINUATION # PREVIOUS REEL COMMENTS. :EDIT LIS, ARCO PRUDHOE BAY~ DS ~1-27, AP! 50-029-21638 ** TAPE HEADER ** ERVICE NAME :EDIT ATE_:88/06/30 ORIGIN :FLit TAPE NAME 17280,2 CONTXNUATZON # 11 PREVZOU$ TAPE I COMMENTS IEDIT LIS, ARCO * FILE HEADER .** IbE .NAME :EPIT .001 SERVXCE NAME ~ERSXON ~ I001A02 PAT.E 188/06/30 MAXIMU~ LENGTH FILE TYPE lbo PREvIou~ FI,LE' ** INFORMATION RECORDS ** TABLE TYpE :CONS PRUDHOE BAY, 1-27,,i' API 50'029'21638 MNEM TUNI VALU DEF! CN ARCO ALASKA IN:* Company Name FN PRUDHOE BAY Fleld Name. WN D,S,. # 11-27 Well Name NATi Nation STAT ALASKA State or Prov,t, COUN NORTH SLOPE: County SECT ' section 'TOWN lI~ Township .ANG I ,Range Latitude, ,ATI ONG =Longitude OPER PEPPEL OPer&tor'a Co~, SON FSlA,, service orde,r ABXN A.P.I, Serial Num* TAB[,E TyPE :CURV LV'P OlO,H02 VERIFICATION LISTING PAGE ~NEM DEFI DEPT DEPTH CHANNEL * NPHI NEUTRON PORO&I* TNRA CALIBRATED THE* RTNR RAW THERMAL NE* RCFT RCFT RCNT RCNT GR Gamma Ray CCh Amplitude * ~! NEUTRO. POROSI* TNRA CAb,BRATEP THE* RTNR RA~ ~HER.AL NE* RCFT RCFT RCNT RCNT GR Gamma Ray CCh Amplitude * ~I NEUTRON PORO$I. TNRA CALIBRATED THE, RCNT RCNT OR Gamma. Ray Cb C'Cb Amplitude * ~PHI NEUTRON POROSI* DATA FORHAT RECORD ** ENT:RY BLOCKS TYPE 2 3 4 8 ! 1 15 0 SIZE REPR CODE ENTR' I 66 0 1 66 0 4 7 4 68 4 65' FT I 66 I I 66 ~ 4 6.5 FT I 66 68 1 66 I. 1 66 0 0,5000 DATUM SPECIFICATION BLOCKS 'NE, SERVICE SERVICE UNIT A AP1 API Fib'E SIZE· SPL REPR ' ID ORDER :# L~G C~PI' TYPE ASS MOD NO., FT O0 000 O0 0 ! 4 PU O0 000 O0 0 1 O0 000 O0 0 4. O0 000 O0 0 1 4 CPS O0 000 O0 0 .I O0 I 4 CPS O0 000 0 GAPI O0 000 O0 0 .1 4 O0 000O0 0 I 4 ~pH:'! TNRA RTNR RCFT a~ PS' PROCESS CODE~OCTAb) 68 0.000000'0000000 6~ 00000000000000 6S 00000000000000 6~ 00000,000000000 68 00000'000000000 ~8 00000000000000 8 00000000000000, 66 00000000000000 L, VP 010,H02 'VERIFICATION LISTING PAGE 3 NpH! PS 0o0 TNRA PSl PU ~§ 000 RTNR P$2 oo 000 RCFT PS2 CPS OO 00,0 RCNT PS2 CPS O0 000 GR P$2 GAP! O0 000 CUb PS2 O0 000 TNRANpH! PSo O0 000 PS~ PU O0 000 RTNR PS3 O0 000 RCFT PS{ CPS O0 000 RCNT PS3 CPS O0 000 GR PS3 GAP! O0 000 CC~ PS3 O0 00o NPHI bAV PU O0 000 ** DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE 2 8 ~ATUN SPECIFICATION~BbOCKS ~NEN SERVICE SERVICE UNIT API AP~ _ ID ORDER # bOG, TYPE uEPT FT O0 000 ~P~! PSi pU O0 000 mNR, A PS! O0 000 RT~R PS! .... O0 000 ~CF~ P$,l c~s O0 000 ~., .~ c.~ oo :ooo gR PS1 GAPI O0 000 ~c~.~i oo~oo ~,c.~ .~ cpsooooo ~R .e~ ~ ooooo CCh PS 000 ~PHI DS~ PU i~ 000 ~crT ~ c.s oo ooo oo 0 1 4 o0 0 I 4 o0 0 ! 4 o0 0 I 4 O0 0 1 4 O0 0 I 4 o0 0 I 4 O0 0 ! 4 O0 0 1 4, o0 0 ! 4, OO 0 1 4 oo 0 1 4 O0 0 I 4 O0 0 1 4 O0 0 1 4 REPR I~DE 66 73 66 68 66 66 APi API F,IbE CLASS ~OD NO O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 00 0 O0 0 o0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 ~ o ! 68 00000000000000 t 68 00000000000000 t 68 00000000000000 1 68 00000000000000 I 68 00000000000000 ! 68 00000000000000 ! 68 00000000000000 ! 68 00000000000000 ! 68 0000000000000§ ! 68 0000000000000 ~ 68 00000000000000 I 68 00000000000000 i ~8 00000000000000 ~ 8 00000000000000 ! 68 00000000000000 ENTRY o 0 9~ 1 0,5000 1 ! 4 ! 4 ' REPR PROCESS SIZE SPL CO~E (OCTAL) - ~ 00000000000000 I ~ 00000000000000 00000000000000 4~ I ~8 0000000000,0000 - ! ,"8 00000000000000 i68 0000000 000000 68 0000000~000000 68 O0 000000000 , ~ oo~ooooooooo · oooooooooooooo ~ ~ oooooooooooooo ~ s. oooooooooooooo ooo~ooo~oooooo ! ~i~ ooo ,oo,ooooooo ~ oooooooooooooo i ~. oooooooooooooo LVP 010,H02 VERIFICATION LISTING PAGE 4 RC"T PS~3 CPS O0 000 CcLGR PSps33 GAPI 000 000 0 000 NPHI I.,AV PU O0 000 O0 0 1 4 O0 0 ! 4 O0 0 ! 4, O0 0 1 4 DATA DEPT RCNT TNRA GR NPHI DEPT .NPH! RCNT TNRA DEPT RC.FT RCNT TNRA O£.PT NPH! DEPT ~CFT ReNT GR 12145 5000 NPH! -999 2500 RCNT -999 2500 TNRA -999 2500 GR -999 2500 RTNR -999 250O COb 12100 0000 NPHI TNRA 1813 5242 GR 3 2420 RTNR 97 7500 COb i2~.0000 NPH ,765:1 RCN{ 25~.9732 TNRA ,0908 3~,8446 ,3125 li65, 16, 2964. 27, )000 NPH'Z 1843 RCNT }314 TNRA ,', 11800,0000 NPH! i037,7529 RCNT 24,0024 TNRA 3159,4678 OR 2,2038 RTNR 45,71:86 COb 11.700,.0000 NPHZ '1753,9072 RCNT 10,4380 TNRA. 3569,0.063 GR I,:83:37 RTNR' 35,:1250 CCh 11600.,0000 2310.,79 RCNT "9 , 500 GR '9~' 500 RTNR . 500 CUb '9 . 500 NPH! 33,0549 TN'RA ~CFT 2519. 60 GR 4:, 436 CCh ,: 3614 RCFT '0, 32 NPHZ I 68 0000000000000.0 ! 68 00000000000000 1 68 00000000000000 1 68 00000000000000 -999 2500 RTNR -999 2500 COb -999 2500 RCFT -999 2500 NPHI '999 2500 RCNT -999 2500 i58 RTNR 95 RCNT 6022 1249 17 9257 RC,FT 1265 277 890~ RTNR Cob 3894 RCFT RCNT 1237 ,0670 RTNR ,.2161 RCFT RCN'T . ,.1860 NPH! 8609 10':1040 TNRA ,7621 RTN 3530,~632 I R ~N'R 34,2500 CCh ,9299 RCFT 2,05.,24. RCF? 1815,852:.3 RUNT -0,2'187 NPH! 10.5774 7.66?$ TNRA i,5526 RTNR 3970':3477 GR 27.0625 1,5814 RTNR 1,7037 RCFT 29,82B1 CCh "0.:.!196 NP'H! -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 3 2381 -0 3589 · 471 2404 33 53,11 ! 709 5527 239,3 841,2737, 26.2877 2486,4375 ,4466 ,2656 2,6044 '"0,60!6 458,487 ! i5,8676 810, :3076 1,834! 0,0103 {'762,10'25 l 0, :982.4 3.41.9,4575 1,6409 ,,'0 .' '~ 64 ! 222 , :0781 ',},4585 ~ # ~Oi~Ni,~NO~ DIq&t ~I~l:~O .. '0,~/90/"88 t 3NVN 2q'IJ Oqt 3dX& 3qIj )~0~i H&DN~ Nfl 001~666' OOt'~' 666'" OOf'~. 666" 00i~;.666" OOt:[ 666"' OOg~ 666- ~NDa OOt~ 666- IHaN OOg~ 666' &J3~ OOg~ 666' q33 OOg~ 666' 00~666- 00gZ~:666- 00g~:666- 00~'666- 00~1666- 666- qDD '00g::666,- 89 aN&8 00$~,666- VaNS aD 00g~.666= &N38 VaN& 00~,666' I'HdN &,~Da 00g~.666' ~J3~ ggi~ O~ ~N3a 86~£ 969 IHdN ~80: O- &J3~ ~609 IHdN gSO~'~O- qDD 0000 'ii' 8N&~ ~g '£ VSN& 6 L ~LI ~6I &NbU IHdN 009 oo~II ~'~ Ii'~ ~"°~ "'~,o :~''~ f159 g £I $iD~ 80 818E O' qDD ~9g9'1f &~DU 08it UD 0~£I V~Ni Om £E t VaN~ Lg6! &N~ 0~ I~ O0 g60£ &N38 ~T lHd~ 6~L~*L ~g68'90I~ &NDa L89 '~gg~ iHdN Lgg£*o' 9 2D~d DNI&9Iq NOI~¥3I~IB3A 20H'O;O dhq
