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Home My WebLink About182-20607/06/09 ~chfa~nber~er N0. 5297 +~ .~.,~~. , _ - ~~ 2~~~ Alaska Data 8, Consulting Services q~~y~+~ ~~~~ ~" `' Company: State of Alaska 2525 Gambell Street, Suite a00 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnk2n ATTPJ: Be4h 333 West 7th Ave, Suite 100 A~chorage, AK 99501 Mlell Job # Log Description Date BL Color CD • C ~ ~-06 AYTO-00035 GLS/PRODUCTION PROFIIE 05/12/09 1 1 07-338 B4C4-00003 SCMT 05/30/09 1 1 17-14 AVY5-00049 PRODUC ION PRO ILE G~.- 05/31/09 1 1 12-01 AYTU-00039 PRODUCTION PROFILE O6/01/09 1 1 04-43 AXWS-00011 IBPlCROSS FLOW CHECK - - ~. 06/0?J09 1 1 D-13,4 604C-00059 USIT 06/03/09 1 1 ~-112 82WY-00011 MEM PROD PROFILE "~ - O6/03l09 1 1 06-06 B04C-00061 USIT 06/04/09 1 1 12-1& AV1H-00014 PRODUCTION PROFILE 06/04/09 1 1 A-35 AY3J-00026 USIT ~- ~(p ~ 06/04/09 1 1 92-22 AXWS-00013 PROD PROF/GLS 06/05/09 1 1 12-16A AXWS-00014 PRODUCTION PROFILE O6/05/09 1 1 18-29~ 804C-00062 PSP XY-CALIPER LOG O6/06/09 1 1 C-12~4 AXWS-00015 SCMT ~- / O6/06/09 1 1 B-27A AXBD-00028 MEM PROD PROFILE 06/11/09 1 1 L2-13A AWJI-00036 MEM CNL & INJ PROFILE }'~ O6/17/09 1 1 L2-13A AWJI-00036 MEM PROD PROFILE f ~ 06/17/09 1 1 07-21 614B-00064 LDL O6/20/09 1 1 17'-O1A AYQQ-00030 SBHP SURVEY 06/11/09 1 1 01-25 AP3Q-00041 LDL O6l15/09 1 1 I-202 B2WY-00010 MEM PROD PROFILE ~- C,/ 06/O1J09 1 1 I~-103 AXBD-00027 MEM INJ PROFILE O6/OM09 1 1 GNI-03 AWJI-00034 MEM PRESS & TEMP SURVEY ~'}-.- 06/15l09 1 1 G-316 AWJI-00027 MCNL _03 04/30/09 1 1 15-29BPB1 09AKA0143 OH MWD/LWD EDIT - ~ ~~ 05/11/09 2 1 ~nJG W41~ItlV9YLGNlTC f1LliGlf 1 O i Jlt}IYIIYt7 NIVU ~1C1 URIYIIVU lJ1YC l.Vl'T CNlifl 1 V: BP Exploration (Alaska) Inc. Petrotechnicai Data Center LR2-1 900 E. Benson Blvd. ~ a ~' / i Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ' ~ ~ STATE OF ALASKA ~~~~~ ~~ ALA OIL AND GAS CONSERVATION COMt~ION 5, REPORT OF SUNDRY WELL OPERATIONS r`" "" '' ~~~~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ~_ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate Q ~ Re-enter Suspended Well ~ ° 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 182-2060 - 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-20877-00-00" 7. KB Elevation (ft): 9. Well Name and Number: 77 KB ~ PBU 12-18 - 8. Property Designation: 10. Field/Pool(s): ADLO-028330 ' PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 9858 - feet Plugs (measured) None true vertical 9242.74 - feet Junk (measured) 9515' 4/20/96 ~. a ci ~~~~~ ~ ~~~~ ~~ Effective Depth measured 9817 feet true vertical 9205 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" Surface - 110' Surface - 110' 1490 470 Surface 2689' 13-3/8" 72# I-80 Surface - 2689' Surface - 2689' 4930 2670 Production 9272' 9-5/8" 47# L-80 Surface - 9272' Surface - 8711' 6870 4760 Liner 861' 7" 29# L-80 8997' - 9858' 8468' - 9243' 8160 7020 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR-80 SURFACE - 8870' 4-1/2" 12.6# L-80 8910' - 9011' Packers and SSSV (type and measured depth) 9-5/8"X4-1/2" BKR S-3 PKR 8775' 9-5/8"X5-1/2" 8890' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 478 2255 5970 231 Subsequent to operation: 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory Development ~ ' Service Daiiy Report of Well Operations X 16. Well Status after proposed work: Oil '' Gas L~' WAG GINJ I~ WINJ ~'~ WDSF'L 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 10/27/2008 Form 10-404 R vised 04/2006 .r ~ r"?~ Submit Original Only ~'• ~t f 12-18 182-206 PFRF ~TT~C_HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 12-18 9/24/83 PER 9,414. 9,440. 8,838.82 8,862.27 12-18 9/24/83 PER 9,444. 9,452. 8,865.89 8,873.11 12-18 9/24/83 PER 9,456. 9,476. 8,876.73 8,894.82 12-18 9/24/83 PER 9,484. 9,504. 8,902.06 8,920.18 12-18 2/19/90 SQZ 9,414. 9,504. 8,838.82 8,920.18 12-18 3/17/90 RPF 9,414. 9,440. 8,838.82 8,862.27 12-18 3/17/90 RPF 9,444. 9,452. 8,865.89 8,873.11 12-18 3/17/90 RPF 9,456. 9,476. 8,876.73 8,894.82 12-18 3/17/90 RPF 9,484. 9,504. 8,902.06 8,920.18 12-18 4/18/91 APF 9,309. 9,312. 8,744.48 8,747.16 12-18 4/18/91 RPF 9,414. 9,440. 8,838.82 8,862.27 12-18 4/18/91 RPF 9,444. 9,452. 8,865.89 8,873.11 12-18 4/18/91 RPF 9,456. 9,466. 8,876.73 8,885.77 12-18 10/21/08 APF 9,304. 9,323. 8,740. 8,757.02 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET ~ SPR SAND PLUG REMO VED 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 • • 12-18 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 10/21/2008 """WELL SHUT-IN ON ARRIVAL'`** `SSV CLOSED, WING CLOSED. INITIAL T/I/O: 2000/2000/500. '` RIH WITH HEAD/ UPCT/ 2.88"--19 FT LOADED GUN. OAL = 30.3'. PERF '`INTERVAL 9304 - 9323 FT. SURFACE INDICATION OF GUN FIRING. ***JOB CONTINUED ON 22-OCTOBER-2008.""* 10/22/2008' T/I/0=2000/2000/500 Temp=S1 Assist E-Iine..Load & Kill well (Perforating) ''Pumped 5 bbls neat methanol spear, 290 bbls 1 % kcl and 76 bbls 60/40 !,methanol down TBG to attempt to free a-line and kill well. E-line on well at ';,departure. FWH s=vac 1480 560 10/22/2008''T/I/0= 0/1500/700 Temp=S Assist E-line stuck in tree (Perforating) Pumped I' 8 bbls meth down tubing to verify open path. """Job continued on 10-23-08 10/22/2008': """JOB CONTINUED FROM 21-OCTOBER-2008.""" TOOL STUCK AT CCL DEPTH OF 307 FT. ORIGINALLY STUCK AT 320 FT. BOP BOOGEY TO REPAIR STRANDED ARMOR. WAS ABLE TO PULL "UP AN ADDITIONAL 14 FT. NOTICED AFTER CLOSING THE RAMS THE `SECOND TIME THAT THE FIRST CLOSING SEVERELY DAMAGED THE `:LINE. THE LINE IS SMASHED AND SEVERAL OUTER WIRES CUT WHERE `:EACH OF RAMS CLOSED. LRS PUMPED TO KILL WELL PRIOR TO LIFT. BLEEDING DOWN IAlTBG TO PREPARE TO FREEZE PROTECT. ""'JOB NOT FINISHED. CONTINUED ON 23-OCTOBER-2008."** __... __ 10/23/2008 T/I/O=Vac/1100/740 SL Assist E/L, bleed AL and IAP to common line psi. °': Initial IA FL @ 6459' STA # 4 [SO] 346 bbls. Bled AL to common line ',,pressure, DSO continued bleed to 0 psi. Spool peace dropped and integral ''installed on IA. Continue to bleed IAP to common line pressure, flowline 'starting to freeze up. SI bleed RU LRS to pump methanal. Continue to bleed ':IAP to 270 psi, SI bleed. Bled OAP to 0 psi in 3 minutes all gas. OAP '`increased to 740 psi in 20 minutes. Final WHPs= 80/270/740. ``Valves are in control of EL. 10/23/2008 10/23/2008 *"CONTINUED FROM 22-OCTOBER-2008'`"" CONTINUED TO BLEED IAP TO FLOWLINE. PUMPED FLUSH ON IA AND FLUID PACKED. PUMPED ANOTHER KILL ON TUBING AND SPOTTED FLOW PRO ACROSS PERFS. WELL IS ON VAC ON TBG, IA AND OA=O PSI.. HELD SAFETY MEETING PRIOR TO STRIP OUT AND CUTTING CABLE OPERATION. """CONTINUED ON 24-OCTOBER-2008.*** `** Job continued from 10-22-08 WSR*** Assist E-line stuck in hole (perforating) Pumped 4 bbls neat meth and 30 bbls 60/40 meth down flow line to clear of obstruction. Freeze Protect flow line with 145 bbls 60/40 methanol. IA bled to 200 psi. Pumped 5 bbls meth, 335 bbls crude, 35 bbls 60/40 meth, 2 bbls neat meth to load IA. Pumped 2 bbls meth, 115 bbls 1 %KCL, 28 bbls hi-vis Flo-pro, 85 bbls 1 %KCL, and 47 bbls 60/40 meth to kill well. OA had to be bled to 0 psi periodically throughout job. (approx 400-600 psi every 20-30 mins.) '*' Job continued on 10-24-08 WSR*** 10/24/2008 *** Job continued from 10-23-08 WSR""" Assist Slick-line fish (Perforating) Monitor well head pressures. Maintained bleed on OA "'`* Job continued on `10-25-08 WSR*** 10/24/2008 **JOB CONTINUED FROM 23-OCTOBER-2008'`'`" BOP BOOGEY, CABLE WAS CUT, LEAVING APP. 10 FT OF CABLE FOR SLICKLINE TO LATCH ONTO. MASTER / SSV LEFT OPEN. PUMPIN SUB/BOPS, QUICK TEST SUB, CROSSOVER, AND NIGHT CAP LEFT ON TREE. GREASE SKID LEFT SHOULD SLICKLINE NEED TO PUMP GREASE. WELL TURNED OVER TO SLICKLINE TO CONTINUE FISHING OPERATIONS. """JOB COMPLETE""" FLUIDS PUMPED BBLS 26 NEAT 490 1 %KCL 333 60/40 1 DIESEL 850 TOTAL Schlumberger ¡~?-dok SCANMEP JAN 2 3 2007 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well Job# log Description Date Bl MPS-10A 11076475 CH EDIT SCMT (PDC-GR) 10/17/05 15-08Cl1 10942196 CH EDIT JEWELRY (PDC-GR) 03/01/05 Z-12 11513657 RST 12/06/06 1 l3-11 11533392 RST 12/31/06 1 AGI-10A 11485869 USIT 11/09/06 GNI-02A 11485873 USIT 11/15/06 GNI-02A 11485874 MDT 12/03/06 12-18 N/A USIT 11/17/06 NGI-07 A 11212892 US IT 10/13/06 DS 12-14Al1 11540230 CORROSION & CBl 12/18/06 01-23 11549351 USIT 12/16/06 WGI-09 11486172 USIT 12/03/06 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnica I Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: 01/22/2007 NO. 4112 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color CD 1 1 1 1 1 1 1 1 1 1 1 1 ( Alaska Data & 2525 Gambell S e Anchorage, AK 99503-2838 A TTN: Beth Received by: 1 . STATE OF ALASKA Rfc;~. AU\ OIL AND GAS CONSERVATION COM. ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program RECEIVED DEC 1 2 2006 n 181 Repair Well 181 Pull Tubing o Operation Shutdown Anchorage o Re-Enter Suspended Well o Other 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 028330 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Length Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 110' 2689' 9272' 861' 77' 9858 9243 9817 9205 99519-6612 o Plug Perforations 0 Stimulate o Perforate New Pool 0 Waiver o Perforate 0 Time Extension 4. Well Class Before Work: 5. Permit To Drill Number: 181 Development 0 Exploratory 182-206 o Stratigraphic 0 Service 6. API Number: 50-029-20877-00-00 9. Well Name and Number: PBU 12-18 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool feet feet Plugs (measured) None feet Junk (measured) 9515' feet Size MD TVD Burst Collapse 20" 110' 110' 1490 470 13-3/8" 2689' 2689' 4930 2670 9-5/8" 9272' 8711' 6870 4760 7" 8997' - 9858' 8468' - 9243' 8160 7020 '';;¡~~~'h v '.",1. "\:¡;; ~L.>.) ..;. 9309' - 9504' 8744' - 8920' 12. Stimulation or cement squeeze summary: Intervals treated (measured): 5-1/2" x 4-1/2", 12.6# L-80 /13Cr80 9011' Tubing Size (size, grade, and measured depth): 8770' 9-5/8" x 4-1/2" Baker 'S-3' Packer; Packers and SSSV (type and measured depth): Treatment description including volumes used and final pressure: Cut and pulled tubing from 8878'. Cut and puIl9-S/8" casing from 1930'. Run 9-S/8", 40#, L-80 tieback to surface. Cement with 121.5 Bbls Class 'G' cement 682 cu ft / 583 sx. Run new com letion 4-1/2", 12.6#, 13Cr80 to 8870'. 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 181 Daily Report of Well Operations 16. Well Status after proposed work: 181 Well Schematic Diagram 181 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 NIA if C.O. Exempt: Contact David Reem, 564-5743 306-139 Title Technical Assistant Printed Name Terrie Hubble Signature ~ Form 10-404 Revised 04/200D R 1 G \ N A L Phone Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-18 12-18 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 11/11/2006 11/28/2006 Spud Date: 12/26/1982 End: 11/11/2006 12:00 - 13:30 1.50 MOB P PRE Secure Well, Bridle Up. 13:30 - 15:30 2.00 MOB P PRE Move Rig Off OWDW-SW 15:30 - 00:00 8.50 MOB P PRE Sheared Off Bolts On Off Drillers Side Rear Stearing Arm Assembly, Clean and Repair. 11/12/2006 00:00 - 12:30 12.50 MOB P PRE Jack up Rig, Begin Moving Off Pad 3. Sheared Off Bolts on Drillers Side of Rig Rear Tires. 12:30 - 09:00 20.50 MOB P PRE Clean and Repair Sheared Off Steering Arm Bolts. 09:00 - 10:30 1.50 MOB P PRE Move Rig off of Pad 3 and onto DS 6. Lay Derrick Over and ready rig to move down road to DS 12. 10:30 - 13:30 3.00 MOB P PRE Travel to DS 12. 13:30 - 16:00 2.50 MOB P PRE Rig arrive on location at 13:30 hrs. Raise Derrick, Pull Booster Wheels and Install BOP's on Pedestal in Cellar. Rig Hoses to Stabbing Board. 16:00 - 17:00 1.00 MOB P PRE Lay Herculite and Rig Mats. 17:00 - 18:00 1.00 MOB P PRE Move Rig up onto well. Level and Shim. 18:00 - 19:30 1.50 MOB P PRE Remove Extra Fill Brought in for Pad Prep to Level Area for Slop Tank. Install Secondary Annulus Valve. RlU Rig Floor. 19:30 - 21 :00 1.50 MOB P PRE RlU and Take On Sea Water to Pits. RlU Little Red on IA. 21 :00 - 22:30 1.50 MOB P PRE RlU DSM Lubricator, Pressure up to 900 psi on Top of BPV Retrieving Tool Stuck at 54", Fluid in Tree Froze, Steamed Tree. 22:30 - 23:30 1.00 MOB P PRE Redress Retrieving Tool RIH Retrieve BPV, RID DSM, 500 psi on IA and 900 psi on Tubing. 23:30 - 00:00 0.50 MOB P PRE RlU to Bull Head Well. 11/13/2006 00:00 - 02:00 2.00 KILL P DECOMP PJSM With Little Red, Rig Crew and Truck Drivers, Test Lines to 3,500 psi for 5 minutes. Began Bull Heading Operations InitiallA Pressure = 800 psi Static 1,000 psi ICP. Initial TBG Pressure = 1,200 psi, ICP 1,370 PSI. Pumped 380 bbls Down IA and 214 bbls Down TBG at 5 BPM. Shut Down Pumping. 02:00 - 03:00 1.00 KILL N MISC DECOMP Veco Vac Truck Broke Down, Unable to Start and Pull into Position by the Rig, Backed In Empty Truck and Switched Load. 03:00 - 04:00 1.00 KILL P DECOMP Continued Bull Heading Operations, Pumped 210 bbls down IA and 186 bbl Down TBG. Shut Down Pumps, Flow Checked Well Tubing and Annulus on Vacuum. 04:00 - 04:30 0.50 KILL P DECOMP RID BID Circulating Lines, RlU Line From Cement Lined up to Fill Annulus. 04:30 - 05:00 0.50 WHSUR P DECOMP RlU FMC and Install 5" ISA BPV - required 3 attempts to get stabbed in. 05:00 - 06:00 1.00 WHSUR P DECOMP RlU and Test BPV From Below - Pumped 50 bbls @9 bpm to 520 psi. 06:00 - 07:30 1.50 WHSUR P DECOMP N/D Tree 5-1/8" Tree and 13-5/8" Adpater Flange. 07:30 - 08:00 0.50 WHSUR P DECOMP Install Blanking Plug into hanger threads, 5-1/8" Rt Hand Acme. Re-evaluate rig elevation vs height of tbg spool. To remove tbg spool for casing work the height is going to be too close - need additional height. Jack up rig and place 3"x12"s under rig to give additional elevation. 08:00 - 09:00 1.00 BOPSU P DECOMP Pull 13-5/8" x 13-5/8" 18" Flange from bottom of BOP's and place on tubing spool. Pick BOP's from Pedestal, pull studs and place on top of 13-5/8" Flange. Re-install studs and nuts. 09:00 - 12:00 3.00 MOB N HMAN DECOMP Pull Fluid from pits. Jack up rig and place 3"x12"s under rig. It was understood that location was to be built up one foot wI fill and then double rig mats were to be layed to place rig at the Printed: 12/4/2006 10:08:07 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-18 12-18 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 11/11/2006 11/28/2006 Spud Date: 12/26/1982 End: height required to work on high wellhead. Location was built as per agreement but only one layer of rig mats were layed. 12:00 - 15:30 3.50 DECOMP Continue Nipple Up of BOP's. Install Flow Riser. Take on fluid into pits. Continue to add 5 bbls 115 mins down IA. 15:30 - 16:00 DECOMP Rig Up to Test BOP's 16:00 - 18:30 DECOMP Test BOP's. Complete two test 250 psi 13500 psi for 5 mins each wI 4" Test Joint. Bleed down pressure from test to rig down test joint and pick up 5-1/2" test joint. Pressure not bleeding down. Seeing gas and fluid back through test joint eventually going to all gas. Change gauge on test manifold to small gauge, reading 40 psi. Bleed to tank, pressure slowly going down. Open Choke and then open pipe rams wI bag closed, pressure quickly down to zero. Still a small amount of gas pressure building when shut-in. 18:30 - 19:30 DECOMP Monitor gas pressure. No pressure on OA, IA on vac, - 10 psi build on tbg with shut-in for 10 mins. Noticed gas pressure on control lines. Bleed control lines to bleed tank. Pressure bleeds off quickly, all gas. Consult with town on options. 19:30 - 20:00 0.50 BOPSU DECOMP PJSM RID Test Equipment, RlU Blanking Plug Retrieving Tool, Pump Across Mud Cross. 0 Pressure On Choke Gauge. 20:00 - 20:30 0.50 BOPSU DECOMP Opened Hydril UD Test Joint, Monitor Well, Gas observed in riser wloil sheen. RIH wlBlanking Plug retrieval tool. Pull Blanking Plug, Well went on immediate vacuum draining BOP Stack. 20:30 - 21 :30 1.00 BOPSU DECOMP Monitor Well, Pumping 5 bbls every 15 minutes on TBG Side. 21 :30 - 22:00 0.50 BOPSU DECOMP RlU DSM Lubricator, pull BPV, RID DSM. 22:00 - 00:00 2.00 BOPSU DECOMP Pressure Test #2 Mud Pump t/3,500 psi, pump 390 bbls down Annulus at 10 bpm w/830 psi. Initial pressure on TBG side 30 psi, at 135 bbls pumped down annulus TBG pressure increased to 80 psi at 180 bbls pumped pressure increased to 120 psi, Bled off TBG pressure to Gas Buster, Continued to pump down IA. Lined up on Tubing Side and Pumped 226 bbls at 8 bpm Initial Circulating Pressure 220 psi. Tubing Pressure Increased to 390 Psi, Partial Returns obtained after pumping 560 bbl, Monitor Well. 11/14/2006 00:00 - 01 :30 1.50 BOPSU DECOMP NID Riser N/U Shooting Flange. 01 :30 - 04:00 2.50 BOPSU DECOMP RlU Slick Line, 2 - 5' pups, Pump In Sub, Wireline BOP's, Lubricator. 04:00 - 04:30 0.50 BOPSU DECOMP Pressure Test Wire Line Equipment to 3,500 psi. 04:30 - 05:00 0.50 BOPSU DECOMP RIH wI Dummy SSSV Plug for 5-1/2" Otis HRO Nipple. 05:00 - 05:30 0.50 BOPSU DECOMP Unable to go past 1,119', POOH wI plug. Plug Covered in Plastic Coating and Scale from inside of Tubing. Cleaned Plastic Coating off of Plug. 05:30 - 06:00 0.50 BOPSU DECOMP Waiting for 4.70" Drift. 06:00 - 07:30 1.50 BOPSU DECOMP M/U 4.70" Drift and RIH. Can't get thru the wellhead. POOH and M/U 4.625 and RIH. Run to SSSV Nipple and Tag at 2142' slm. POOH and UD Same. 07:30 - 09:00 1.50 BOPSU DECOMP Brush and Flush Tubing down to SSSV. Remove Plastic Coating for setting plug. 09:00 - 10:00 1.00 BOPSU DECOMP Pump 20 bbl High Vise Sweep and Chase with 80 bbls of sw. Returns from annulus at 60 bbls pumped. 10:00 - 11 :00 1.00 BOPSU DECOMP RIH and set plug in HRO Nipple at 2142' slm. POOH 11 :00 - 12:00 1.00 BOPSU DECOMP RIH and set prong assembly in plug body. POOH Printed: 12/4/2006 10:08:07 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-18 12-18 WORKOVER DOYON DRILLING INC. DOYON 16 11/11/2006 11/28/2006 Spud Date: 12/26/1982 End: Start: Rig Release: Rig Number: 12:00 - 12:30 0.50 BOPSU DECOMP RIH Set Prong in TBG Plug. POOH. 12:30 - 01 :00 12.50 BOPSU DECOMP RlU to test Tubing Plug to 3,500 psi. 01 :00 - 14:00 13.00 BOPSU DECOMP RID Slick Line Equipment. 14:00 - 14:30 0.50 BOPSU DECOMP RlU Riser Spool and Riser. 14:30 - 15:00 0.50 BOPSU DECOMP RlU To Test BOPE. 15:00 - 21 :00 6.00 BOPSU DECOMP Test BOPE to 250 psi Low Pressure and 3,500 psi High Pressure. Each Test was Held for 5 Minutes. AOGCC Witness of Test was Waived by Jeff Jones. Test was Witnessed by the Doyon Toolpusher and BP WSL. Test #1- 4" VBR Rams, TIW. Test #2- 4" Annular,KiII HCR, Dart Valve, Choke Valves 12, 13, 14. Test #3- 5.5" VBR Rams, Upper IBOP. Test #4- 5.5" Annular, Lower IBOP, Manual Kill, Choke Valves #9, #11. Test #5- Blinds, Choke Valve #5, #8, #10. Test #6- Choke Valves #4, #6, #7. Test #7- Choke Valves #2. Test #8- Choke Valve #3. Test #9- Upper IBOP, Choke Valve #1 Test #10- HCR Choke. Test #11- Manual Choke. Accumulater Test- 2,950 psi Starting Pressure, 1,800 psi After Actuation, First 200 psi in 18 seconds, Full Pressure in 1 Minute 20 Seconds. 5 Nitrogen Bottles at 2,150 psi. 21 :00 - 21 :30 0.50 BOPSU DECOMP RID BID BOP Test Equipment 21 :30 - 22:00 0.50 BOPSU DECOMP RID Riser and Riser Flange. 22:00 - 23:00 1.00 BOPSU DECOMP RlU Shooting Flange and Extendsion, Wire Line BOPs, Lubricator and Stuffing Box. Test Lubricator to 1,000 psi. 23:00 - 00:00 1.00 BOPSU DECOMP RIH to Retrieve Prong in SSSV at2,198'. 11/15/2006 00:00 - 00:30 0.50 BOPSU DECOMP Slick Line Work, POOH wlProng, M/U ROP Retrieval Tool. 00:30 - 01 :00 0.50 BOPSU DECOMP RIH to Retrieve Plug, POOH w/ROP UD Same. 01 :00 - 01 :30 0.50 BOPSU DECOMP RlDSWS 01 :30 - 02:30 1.00 BOPSU DECOMP N/D Shooting Flange N/U Flow Riser. 02:30 - 03:00 0.50 PULL DECOMP M/U Acme XO to Jt Drill Pipe, Engauge Hanger 9 rounds to make up. 03:00 - 03:30 0.50 PULL P DECOMP BOLDs 03:30 - 04:30 1.00 PULL P DECOMP Hanger unseated at 150,000#, Pulled Free at 175,000#, Pull Hanger to Rig Floor, RlU Circulating Lines. 04:30 - 05:00 0.50 PULL P DECOMP Attempt to CBU. Chemical Injection Line leaking at rig floor, Back Out Hanger and UD, 05:00 - 06:00 1.00 PULL P DECOMP Fill Hole, Establish loss rate of 60 bbllhr. CBU at 9 bpm w/820 psi wilth 0 losses. 06:00 - 06:30 0.50 PULL P DECOMP Monitor Well for 10 minutes Gained 5 bbls, Circ and diverted 40 bbls to cuttings tank at 9 bblslmin Monitor Well no gains no losses, RID BID surface lines. 06:30 - 07:00 0.50 PULL P DECOMP RlU Cameo Spooling Unit on Rig Floor. 07:00 - 22:30 15.50 PULL P DECOMP Pull and Lay Down 5.5" tubing, control Lines and Chemical Injection line, 1 SSSV, 10 GLMs, 1 Chemical Injection Mandrel, 216 jts Tubing, 1 Cutjt 20.20',228 Clamps, 16 SS Bands. Tubing had Heavy Scaling on outside of Pipe from jt # 195 to jt Printed: 12/4/2006 10:08:07 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-18 12-18 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 11/11/2006 11 /28/2006 Spud Date: 12/26/1982 End: 11/15/2006 07:00 - 22:30 15.50 PULL P DECOMP #205. Cut Jt Flared to 7" and Split Vertically approx 3" . 22:30 - 23:00 0.50 PULL P DECOMP RID Control Line Spooler and Tubing Handling Equipment. 23:00 - 00:00 1.00 PULL P DECOMP Clear and Clean Rig Floor. 11/16/2006 00:00 - 00:30 0.50 CLEAN P DECOMP Service Top Drive, Blocks, Draworks, Iron Roughneck and Pipe Skate. 00:30 - 01 :00 0.50 CLEAN P DECOMP Install Wear Ring. 01 :00 - 02:30 1.50 CLEAN P DECOMP P/U Clean Out BHA, Consisting of 8.5" Bit, 2 - 7" Junk Baskets, 9 5/8" Casing Scraper, Bit Sub, Bumper Sub, Oil Jar, Pump Out Sub, XO, 9 - 6" Drill Collars, XO, BHA Lenght = 319.37'. 02:30 - 09:30 7.00 CLEAN P DECOMP P/U 4" Drill Pipe from pipe shed 1x1. Well Bore Stable No losses. 09:30 - 10:00 0.50 CLEAN P DECOMP While RIH at 7,700 Lost Returns,M/U Top Drive, Pump 150 bbls at 9 bpm with 80 psi, Filling back side wlhole fill pump, returns after 130 bbls, BID T/D. 10:00 - 11 :30 1.50 CLEAN P DECOMP Continue to RIH fl7,770 to 8,853' filling hole at 60 bph. No Returns. 11 :30 - 12:00 0.50 CLEAN P DECOMP MIU Top Drive Obtain Parameters P/U weight = 187,000#, DN Weight = 167,000#, Tagged Stump @ 8,854'. 12:00 - 14:30 2.50 CLEAN P DECOMP POOH f/8,854' filling hole at 60 bph plus pipe displacement. 14:30 - 15:30 1.00 CLEAN P DECOMP Handle BHA UD Clean Out Assembly and Clean Rig Floor. 15:30 - 16:00 0.50 DHB P DECOMP M/U RBP Assembly Handle BHA. 16:00 - 19:00 3.00 DHB P DECOMP RIH to 8,833'. Filling Hole at 60 bph, no returns. 19:00 - 20:00 1.00 DHB P DECOMP Obtain Parameters P/U 190,000#, SIO 162,000#, Set RBP @ 8,833'. 20:00 - 21 :30 1.50 DHB P DECOMP Fill Hole, CBU @ 13 bpm w/3,290 psi. 21 :30 - 22:30 1.00 DHB P DECOMP RlU and Test RBP t/3,500 psi f/30 minutes on Chart. BID RID lines. 22:30 - 00:00 1.50 CLEAN P DECOMP POOH to 7,700' 11/17/2006 00:00 - 01 :30 1 .50 CLEAN P DECOMP Continue to POOH fl7,OOO' to 279'. 01 :30 - 02:00 0.50 CLEAN P DECOMP POOH w/3 stands Drill Collars, UD RBP Running Tools. 02:00 - 07:30 5.50 EV AL P DECOMP RU SWS For USIT and Corrosion Run, RlU Shooting Nipple, Wire line BOPs, Lubricator and packoff. 07:30 - 08:30 1.00 EVAL P DECOMP Attempt to test SWS surface equipment to 1,000 psi, leak on Otis Connection, R&R O-ring, Retest to 1,000 psi. 08:30 - 14:30 6.00 EVAL P DECOMP RIH w/USIT Log and CCL to 8,700'. Log up in Corrosion I Cement mode. Located Top of Cement at 2,000' 14:30 - 16:00 1.50 EVAL P DECOMP POOH, UD US IT assembly, Rehead Line RlU String Shot. 16:00 - 17:30 1.50 EVAL P DECOMP RIH wlstring shot. Fired Shot at Second collar above TOC 1,918'. POOH. 17:30 - 18:30 1.00 EVAL P DECOMP RlDSWS 18:30 - 19:30 1.00 DHB P DECOMP M/U RBP Assembly and RIH wldrill collars. 19:30 - 20:30 1.00 DHB P DECOMP RIH to 4,000' w/RBP. 20:30 - 21:00 0.50 DHB P DECOMP Obtain Parameters Up Weight = 108,000#, DN Weight = 112,000#, Set RBP at 4,001'. 21 :00 - 22:00 1.00 DHB P DECOMP RlU and Test RBP to 2,000 psi for 30 minutes. 22:00 - 23:00 1.00 CLEAN P DECOMP Displace Well to 9.8 ppg Brine at 13 bpm w/1700 psi. RID lines. 23:00 - 00:00 1.00 CLEAN P DECOMP POOH f/3975'. 11/18/2006 00:00 - 00:30 0.50 CLEAN P DECOMP Continue to POOH f/2,016' to 278'. 00:30 - 01 :00 0.50 CLEAN P DECOMP Stand Back 3 stds Drill Collars, UD RBP Running Tool. 01 :00 - 01 :30 0.50 DHB P DECOMP P/U jt 7" CSG, Dump 2,200# Sand on RBP, Element Depth 4,001' Top of RBP 3,996'. Printed: 12/4/2006 10:08:07 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-18 12-18 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 11/11/2006 11/28/2006 Spud Date: 12/26/1982 End: 11/18/2006 01 :30 - 02:00 0.50 CLEAN P DECOMP Service Top Drive, Draworks, Iron Rough Neck. 02:00 - 03:30 1.50 CLEAN P DECOMP P/U MIU Multi String Cutter BHA. BHA consists of Multi String Cutter, XO, Pump out sub, 9 - 6" Drill Collars, XO, BHA Lenght = 291.39'. 03:30 - 05:30 2.00 CLEAN P DECOMP RIH To 1,828' M/U Top Drive, Pumping 5 bpm at 500 psi. Found Collars at 1,844.86 and 1,887.86'. Making Cut at 1,908'. 05:30 - 06:00 0.50 CLEAN P DECOMP Cutting 9 5/8" Casing at 1,908'. 80 rpm, 1,500 ft-Ibs torque off bottom, 3,500 ft-Ibs torque on bottom, 6 bpm, 840 psi. 06:00 - 06:30 0.50 CLEAN P DECOMP POOH UD top single, BID TID, RlU Circulating Lines. 06:30 - 07:00 0.50 CLEAN P DECOMP PJSM wlRig Crew, Little Reds, Veco Truck Drivers on Circulating Out Arctic Pack. 07:00 - 07:30 0.50 CLEAN P DECOMP Pressure test surface lines and Little Reds equipment. 07:30 - 08:00 0.50 CLEAN P DECOMP Displace drill pipe wllittle red pumping 22bbls of 150 deg Diesel to 1,908' at 2 bpm w/900 psi, shut down Little Red. Close VBR rams, displace additional 35 bbls of Diesel w/Little Red pumping into the 9 5/8"x 13 3/8" Annulus at 2 bpm w/900 psi. Taking Returns to the Flow Back Tank, thin black arctic pack return at surface. 08:00 - 10:00 2.00 CLEAN P DECOMP Let Diesel soak for 30 minutes, pumping 23 bbls Diesel at 2 bpm w/860 psi, followed by 100 bbls 9.8 ppg brine at 9 bpm w/2,470 psi. Pumped 20 bbl Safe-Surf 0 pill at 5 bpm w/860 psi. Followed by 174 bbls 9.8 brine at 9 bpm w/2,470 psi. 10:00 - 11 :00 1.00 CLEAN P DECOMP BID RID lines and POOH f/1,876'. 11 :00 - 12:00 1.00 CLEAN P DECOMP POOH w/Dril/ Collars and Cutter assembly. 12:00 - 12:30 0.50 CLEAN P DECOMP Clear and clean rig floor,pull wear ring 12:30 - 14:00 1.50 CLEAN P DECOMP NID BOPs, NID spacer spool. 14:00 - 15:30 1.50 CLEAN P DECOMP Function pack off lock downs screws, while functioning LDS on CSG head well flowed less than 5 gals of diesel, with very small amount of Diesel getting on the ground between the surface casing and the secondary containment. The remainder on the Diesel was in secondary containment. Contacted 5700 and reported spill to Anchorage team on Incident. Remove pack off bushing from tubing spool. 15:30 - 17:00 1.50 CLEAN P DECOMP N/U tubing spool and BOPE, 17:00 - 18:00 1.00 CLEAN P DECOMP Make up Spear assembly and spear into 9 5/8" Casing. 18:00 - 18:30 0.50 CLEAN P DECOMP RlU casing equipment on rig floor. 18:30 - 19:30 1.00 CLEAN P DECOMP Circulate surface to surface 200 bbls at 12 bpm. 10 bbls Diesel back to surface. 19:30 - 20:30 1.00 CLEAN P DECOMP NID tubing spool, BOLDS, 9 58"x 133/8" annulus on vacuum, annulus left open for next operation. 20:30 - 21 :30 1.00 CLEAN P DECOMP Up weight to unseat slips = 230,000#, Pull Pack off and emergency slips off of 9 5/8" CSG. 21 :30 - 22:00 0.50 CLEAN P DECOMP Nipple up Tubing Spool. 22:00 - 00:00 2.00 CLEAN P DECOMP UD 9 5/8" CSG. Casing in good condition, no arctic pack coming out of hole on casing, clean pipe 11/19/2006 00:00 - 03:30 3.50 CASE P DECOMP Continue to POOH wI 9 5/8" CSG, Average breakout torque 37,000 ft-Ibs. Casing in good condition, no arctic pack at surface or on pipe. Pipe recovered, jt on emergency slips 23.69', 19.96' pup jt, 42 jts CSG, 19.96' Cut jt, Cut jt flared 03:30 - 04:30 1.00 CASE P DECOMP RID Casing Tools, Clear and Clean Rig Floor. 04:30 - 05:30 1.00 CASE P DECOMP RlU and body test Casing Spool and Tubing Spool Connections to 250 psi Low Test and 3,500 psi High Test. 05:30 - 06:00 0.50 CASE P DECOMP Install Wear Ring, Run in 4 LDS. Printed: 12/4/2006 10:08:07 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-18 12-18 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 11/11/2006 11 /28/2006 Spud Date: 12/26/1982 End: 11/19/2006 06:00 - 07:30 1.50 CASE P DECOMP Bring BHA tools to Rig Floor and Steam Same. 07:30 - 09:30 2.00 CASE P DECOMP P/U Wash Over BHA. BHA consist of Drag Tooth Washover Shoe, 1 - Jt 11 3/4" Wash Pipe, Washover Boot Basket, Double Pin Sub, Boot Basket, Boot Basket, 13 3/8" Casing Scraper, Bit Sub, XO, Bumper Sub, Jar, Pump out Sub, XO 9 - 6" Drill Collars, XO, BHA Lenght = 357.82'. 09:30 - 10:00 0.50 CASE P DECOMP Clear and Clean Rig Floor 10:00 - 12:30 2.50 CASE P DECOMP RIH w/11 3/4" Washover, Casing Scraper assembly. 12:30 - 13:30 1.00 CASE P DECOMP Obtain Parameters, Up Weight = 87,000# Down Weight = 87,000#, 20170 RPM, 2,000 8,000 ft-Ibs Torque, 2 bpm wI 60 psi. Tagged at 1,930' Washed over to 1,941 '. 13:30 - 14:30 1.00 CASE P DECOMP Pump 20 bbl Saf-Surf 0 pill followed by 20 bbl Hi-vis pill, pumped at 10 bpm w/550 psi. 14:30 - 15:00 0.50 CASE P DECOMP POOH with wash over assy. 15:00 - 17:00 2.00 CASE DECOMP Rack back drill collars, Lay down wash pipe and burn shoe. 17:00 - 17:30 0.50 CASE DECOMP Clear & clean rig floor. 17:30 - 18:00 0.50 CASE DECOMP P/U 9 5/8" cut joint from pipe shed (from previous run) Release spear & UD 18:00 - 20:00 2.00 CASE DECOMP M/U Baker back off tool for 9 5/8" casing. RIH with drill collars. 20:00 - 21 :30 1.50 CASE DECOMP RIH to 1900', fill pipe at 5 stand intervals. 21 :30 - 23:00 1.50 CASE DECOMP Set casing back off tool across collar @ 1930'. Activate tool with 1800 psi. Inital break on collar = 11500 ft Ibs of torque, back off collar 5 turns @ 4000/4500 ft Ibs of torque. 23:00 - 00:00 1.00 CASE DECOMP Drop ball on pump out sub and shear open, CBU @ 12 bpm @ 860 psi. 11/20/2006 00:00 - 00:30 0.50 CASE P DECOMP POH with Baker casing back-off tool. 00:30 - 01 :30 1.00 CASE P DECOMP Stand back drill collars, UD back-off assy. 01 :30 - 02:30 1.00 CASE P DECOMP P/U spear for 47# 9 5/8" casing, RIH with drill collars. 02:30 - 03:30 1.00 CASE P DECOMP RIH from 302' to 1908'. Obtain parameters, P/U weight = 85K, SIO weight = 77K, R/W = 80K. 03:30 - 04:00 0.50 CASE P DECOMP Engage fish with 3K, P/U and had 30K over pull. Slack off to 3K and rotate 5 turns, P/U with fish. Slack off and confirm fish on. 04:00 - 05:00 1.00 CASE P DECOMP POH with 9 5/8" cut joint fish. 05:00 - 06:30 1.50 CASE P DECOMP Lay down fish, length = 22' long. Make all service breaks on spear assy and lay down. 06:30 - 07:00 0.50 CASE P TIEB1 Pull wear ring, 07:00 - 09:00 2.00 CASE P TIEB1 RlU to run 9 5/8" Casing. 09:00 - 15:00 6.00 CASE P TIEB1 M/U and Run 9 5/8",40#, L-80, TC-II Casing. Avg MIU Torque 12,600 ft-Ibs, using Jet Lube Seal Guard on all Connections. 15:00 - 16:00 1.00 CASE P TIEB1 M/U Baker Triple Connect assembly to casing stub at 1,930'. 16:00 - 17:00 1.00 CASE P TIEB1 M/U 95/8" Cement Head, Pull Test Casing to 250,000# up weight, Pressure tested casing to 2,000 psi. Pressured up to 2,800 psi to open ES-Cementer. 17:00 - 18:00 1.00 CASE P TIEB1 Circulated 80 deg 9.8 brine surface to surface at 6 bpm w/370 psi. 18:00 - 18:30 0.50 CASE P TIEB1 PJSM with Rig Crew, SLB Cementers, HES Rep, Veco Truck Drivers, 18:30 - 21 :00 2.50 CEMT P TIEB1 Switched to SChlumberger, Pumped 5 bbls Water, 2 bpm, 100 psi, Shut in Cement Manifold, tested lines to 4,000 psi, OK, bled down pressure, pump cement to rig floor tee, opened cement manifold, pumped 126 bbls 15.8 ppg class G cement. Displaced with rig pumps 143.6 bbl 9.8 ppg brine at 6 bpm, up Printed: 12/4/2006 10:08:07 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-18 12-18 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 11/11/2006 11 /28/2006 Spud Date: 12/26/1982 End: 11/20/2006 18:30 - 21 :00 2.50 CEMT P TIEB1 to 860 psi, bumped plug pressured up to 1430 psi shift cementer. Held for 5 minutes checked floats, OK. 21:00 - 22:00 1.00 CEMT P TIEB1 BID RID lines and cement head, NID BOP stack, pump out 9 5/8" casing. 22:00 - 00:00 2.00 CASE P TIEB1 Attempt to set FMC emergency slips. actual OD of casing is between 9 11/16" and 93/4". 11/21/2006 00:00 - 01 :30 1.50 CASE P TIEB1 Attempting to set emergency slips, OD of casing between 9 11/16" to 9 314" working to set slips, slips set with 75,000# weight. 01 :30 - 02:30 1.00 CASE P TIEB1 RlU Wachs Cutter to cut 9 5/8" Casing. 02:30 - 03:00 0.50 CASE P TIEB1 UD cut Jt, remove TC-II x Buttress XO, Remove Riser, Remove BOPs to install Pack Off. 03:00 - 05:30 2.50 CASE P TIEB1 Install Pack Off, Due to Oversized Pipe had to replace inner seals. 05:30 - 09:00 3.50 CASE N RREP TIEB1 While using the Rig Hydraulic System it was noticed that the System had a Leak, after looking into it futher the leak was found under the Draworks, rig crew began clean up operations. notified 5700 reported spill of over 55 gals and that it was in Containment within the rig, contacted Anchorage Team on incident. Replace Hydraulic EZ Torque hose. 09:00 - 10:30 1.50 CASE P TIEB1 Set and N/U BOP Stack. 10:30 - 11 :30 1.00 CASE P TIEB1 Test 9 5/8" Pack Off to 2,500 psi for 10 minutes as per FMC procedure. 11 :30 - 12:30 1.00 CASE TIEB1 N/U Turn buckles and install Riser Assembly. 12:30 - 13:00 0.50 BOPSU TIEB1 Set FMC test plug and RlU to test BOPE. 13:00 - 15:30 2.50 BOPSU TIEB1 Leaking by test plug. Pull test plug and inspect rubber, set test plug and run in 4 lock down screws. Still leaking by test plug. Inspect and redope plug, run in all lock down screws. 15:30 - 20:00 4.50 BOPSU P TIEB1 Test BOPE, Choke Manifold Valves 1, 2, 3, 4, 5, 6, 8, 9, 11, 12, 13, 14, Choke Line Valves, Kill Line Valves, Floor Valves, Upper IBOP Valve and Lower IBOP Valve to 250 psi low pressure and 3,500 psi high pressure. Each test was held for 5 minutes. BOPE test was witnessed by Chuck Scheve of the AOGCC, Doyon Toolpusher and the BP WSL. Leak was noticed coming from the 31/8" Manually Adjustable Choke Valve. 20:00 - 22:00 2.00 BOPSU RREP TIEB1 Repair 31/8" Manually Adjustable Choke Valve. 22:00 - 22:30 0.50 BOPSU TIEB1 Test Choke Manifold Valves 7 and 10 to 250 psi low pressure and 3,500 psi high pressure. Each test was held for 5 minutes. Tests were witnessed by the Doyon Toolpusher and BP WSL. 22:30 - 23:00 0.50 BOPSU TIEB1 Pull test plug and install wear bushing. 23:00 - 00:00 1.00 CASE TIEB1 M/U 81/2" Bit Clean Out Assembly. 11/22/2006 00:00 - 00:30 0.50 DRILL TIEB1 Continue to M/U 8 1/2" Bit Cleanout BHA. 81/2" Bit, 7" Boot Basket, 7" Boot Basket, Bit Sub, Bumper Sub, Oil Jars, Pump Out Sub, XO, 9 x 61/8" DC's XO. Total BHA lenght = 315.72' 00:30 - 01 :00 0.50 DRILL P TIEB1 RIH with BHA #7 on 4" DP from 315' to 1,853' 01 :00 - 03:00 2.00 DRILL P TIEB1 Establish parameters, Up weight 82,000#, Down weight 85,000#, Rotating weight 80,000#,80 rpm with 1,500 ftllbs of torque, 650 psi pump pressure at 10 bpm. Tag top of Cement at 1,919'. Drill Cement and float equipment. 10,000# WOB, 80 rpm with 2,000 ftllbs of torque, 10 bpm with 650 psi. Pump High Vis Sweeps while drilling float equipment. 03:00 - 04:00 1.00 DRILL P TIEB1 RIH with BHA #7 on 4" DP to 3,960'. M/U Top Drive and tag Printed: 12/4/2006 10:08:07 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-18 12-18 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 11/11/2006 11/28/2006 Spud Date: 12/26/1982 End: 11/22/2006 03:00 - 04:00 1.00 DRILL P TIEB1 Top of Sand at 3,972'. Wash Sand to 3,975'. 04:00 - 05:00 1.00 DRILL P TIEB1 Pump 20 bbl High Vis Sweep, Displace well from 9.8 ppg Brine to clean seawater. 10 bpm at 650 psi. 05:00 - 06:30 1.50 DRILL P TIEB1 Monitor well, POOH with BHA #7 from 3,975'. 06:30 - 07:30 1.00 DRILL P TIEB1 Stand back 6 1/8" DC's, UD Clean Out assembly. 07:30 - 08:30 1.00 CLEAN P CLEAN MIU BHA #8, Reverse Circulating Basket Assembly. 77/8" RCJB, 2 x Boot Baskets, 9 5/8" Csg Scraper, XO, Bumper Sub, Oil Jar, Pump Out Sub, XO, 9 x 6 1/8" DC's, XO. Total BHA Length = 327.98' 08:30 - 09:30 1.00 CLEAN P CLEAN Test 9 5/8" Casing to 3,500 psi for 30 minutes. Good Test. 09:30 - 13:00 3.50 CLEAN P CLEAN RIH with BHA #8, Unable to get 9 518" Casing Scraper Past 9 5/8" 40# Casing I Packoff Top. Lay Down Casing Scraper. P/U Second 9 5/8" Csg Scraper from Baker, Still would not go through. Range of operation for both Csg Scrapers were 38# to 47# Csg. 13:00 - 14:30 1.50 CLEAN P CLEAN RIH with Reverse Circulating Junk Basket Assembly to 3,968'. 14:30 - 15:30 1.00 CLEAN P CLEAN Establish Parameters. Up weight 116,000#, Down Weight 115,000#, Rotating weight 116,000#, 20 rpm with 1,500 ftllbs Torque. 3.5 bpm with 1,150 psi pump pressure. Tag Top of Sand at 3,974' and Wash and Work RCJB to 3,978' 15:30 - 16:30 1.00 CLEAN P CLEAN Drop Dart and open Circulating sub. Pump bottoms up 1,770 psi pump pressure at 13 bpm. 16:30 - 17:30 1.00 CLEAN P CLEAN POOH from 3,978'. 17:30 - 18:30 1.00 CLEAN P CLEAN Service BHA #8 , Empty junk baskets. Recovered Nose piece from ES Cementer dart, and metal pieces from cementer and baffle plate. 18:30 - 20:30 2.00 CLEAN P CLEAN RIH with Reverse Circulating Junk Basket Assembly 3,968'. 20:30 - 21 :00 0.50 CLEAN P CLEAN Establish Parameters. Up weight 116,000#, Down Weight 115,000#, Rotating weight 116,000#, 20 rpm with 1,500 ftllbs Torque. 3 bpm with 1,450 psi pump pressure. Tag Top of Sand at 3,978' and Wash and Work RCJB to 3,990' 21 :00 - 22:00 1.00 CLEAN P CLEAN Drop Dart and open Circulating sub. Pump bottoms up 1,770 psi pump pressure at 13 bpm. 22:00 - 22:30 0.50 CLEAN P CLEAN Service Top Drive and Drawworks. 22:30 - 00:00 1.50 CLEAN N RREP CLEAN Top Drive Controls not functioning. Troubleshoot Top Drive. 11/23/2006 00:00 - 00:30 0.50 CLEAN N RREP CLEAN Top Drive Controls not functioning. Troubleshoot Top Drive. 00:30 - 02:00 1.50 CLEAN P CLEAN POOH with Reverse Circulating Junk Basket. 02:00 - 03:00 1.00 CLEAN P CLEAN UD Reverse Circulating Junk Basket Assembly. Recovered one piece of cement in RCJB. 03:00 - 03:30 0.50 CLEAN P CLEAN M/U HES 95/8" RBP Retrieval Tool. 03:30 - 05:30 2.00 CLEAN P CLEAN RIH with HES 95/8" RBP Retrieval Tool to 3,950', Establish Parameters. Up weight 112,000#, Down weight 115,000# 05:30 - 06:30 1.00 CLEAN P CLEAN Wash Sand from top of HES RBP. Tag RBP at 3,996'. Latch onto RPB and circulate high vis sweep at 13 bpm with 1,640 psi pump pressure. 06:30 - 07:30 1.00 CLEAN P CLEAN Unseat HES RBP and circulate high vis sweep around at 8 bpm with 450 psi pump pressure. 07:30 - 09:00 1.50 CLEAN P CLEAN Monitor well, POOH with HES RBP from 3,996' 09:00 - 09:30 0.50 CLEAN P CLEAN UD HES RBP and inspect RBP retrieving tool. 09:30 - 12:30 3.00 CLEAN P CLEAN RIH to 8,826' with HES RBP retrieving tool to retrieve HES RBP #2. 12:30 - 16:30 4.00 CLEAN P CLEAN Establish Parameters, Up weight 188,000#, Down weight 157,000#. Wash down at 10 bpm with 1,860 psi pump Printed: 12/4/2006 10:08:07 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-18 12-18 WORKOVER DOYON DRILLING INC. DOYON 16 Starn: 11/11/2006 Rig '~elease: 11/28/2006 Rig umber: Spud Date: 12/26/1982 End: 11/23/2006 12:30 - 16:30 4.00 CLEAN P CLEAN pressure. Latch onto RBP at 8,833' and attempt to unseat, would not release. Open bypass, lost 8 bbls of seawater, still would not release. Release from RBP. Relatch onto RBP and attempt to release RBP, would not release. Close Hydril and pressure up to 1,700 psi, bleed off pressure. RBP moved down hole to 8,846'. Work RBP, RBP came free. Lost returns. 16:30 - 00:00 7.50 CLEAN P CLEAN POOH from 8,846' laying down 4" Drillpipe. Pump 60 bph seawater plus double drill pipe displacement. 11/24/2006 00:00 - 01 :00 1.00 CLEAN P CLEAN POOH laying down 4" Drillpipe. 01 :00 - 02:00 1.00 CLEAN P CLEAN UD 6 1/8" DC's, UD HES 9 5/8" RBP. RBP was packed off around slip segments with fine sand and paraffin, not allowing the slip segments to move. 02:00 - 02:30 0.50 RUNCO RUNCMP M/U running tool and pull wear bushing. 02:30 - 04:00 1.50 RUNCO RUNCMP RlU to run 41/2" 13CR80 Tubing, RlU Torque Tum equipment and compensator. 04:00 - 18:30 14.50 RUNCMP Hold PJSM, Run 41/2",12.6#, 13CR80, JFE Bear tubing to 8,817'. Torque Turn all connections. Average MIU torque 4,440 ftllbs. Use Jet Lube Seal Guard pipe dope. 18:30 - 22:30 RUNCMP Establish parameters, Up weight 141,000#, Down weight 125,000#. Tag top of 5 1/2" tubing stub at 8,854'. Attempt to insert 4 1/2" muleshoe into 5 1/2" tubing stub. Unable to sting in. Work torque into string and attempt again. Slack off and tag top of 5 1/2" stub, attempt to rotate muleshoe onto 5 1/2" stub. Still will not go. RID compensator and RlU XO's to M/U Top Drive to tubing string. Attempt to rotate tubing string into 5 1/2" stub, still will not go. Remove one discharge valve and spring from #1 Mud Pump and pump at 3 bpm, attempt to sting in while pumping. Still will not go. Call Well Engineer and discuss options. Decision made to UD Tubing. 22:30 - 23:30 1.00 RUNCO DPRB RUNCMP RID circulating equipment and RlU compensator. 23:30 - 00:00 0.50 RUNCO DPRB RUNCMP UD 4 1/2", 12.6#, 13CR80, JFE Bear tubing from 8,854' to 8,600', using compensator. Still experiencing lost circulation. Pump 60 bph plus double pipe displacement. 11/25/2006 00:00 - 12:30 DPRB RUNCMP UD 4 1/2", 12.6#, 13CR80, JFE Bear tubing from 8,600', using compensator. Filling at 60 bph plus double double pipe displacement. 12:30 - 14:00 DPRB RUNCMP RlU and use Wach's cutter to cut and UD Bakerlocked assemblies. Packer assembly, X-nipple assembly #1, 1 joint of Vam Top tubing and Vam Top muleshoe. 14:00 - 15:30 1.50 DPRB RUNCMP RID 4 1/2" tubing handling equipment. Change out bails. Clear rig floor. 15:30 - 16:30 1.00 RUNCO DPRB RUNCMP Slip and Cut 123' of drilling line. 16:30 - 17:00 0.50 CLEAN N DPRB DECOMP Install Wear Bushing. 17:00 - 19:00 2.00 CLEAN N DPRB DECOMP M/U BHA #9, Spear Assembly for 5 1/2" tubing. Spear with 4 3/4" tapered mill nose, Bowen "C" Spear, Bumper Sub, Oil Jar, Circulating Sub, XO, 6 x 6 1/8" DC's, XO. Total BHA Lenght = 222.91 ' 19:00 - 00:00 5.00 CLEAN N DPRB DECOMP RIH with BHA #9 picking up 4" HT38 Drillpipe from 222' to 4,923'. Pumping 60 bph seawater while RIH. 11/26/2006 00:00 - 04:00 4.00 CLEAN N DPRB DECOMP RIH with BHA #9 picking up 4" HT38 Drillpipe from 4,923" to 8,824'. Still experiencing lost circulation, adding 60 bph seawater down annulus at 1 bpm rate. 04:00 - 05:00 1.00 CLEAN N DPRB DECOMP Establish parameters, Up weight 190,000#, Down weight Printed: 12/4/2006 10:08:07 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-18 12-18 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 11/11/2006 11/28/2006 Spud Date: 12/26/1982 End: 11/26/2006 04:00 - 05:00 1.00 CLEAN N DPRB DECOMP 155,000#. Slack off and tag top of 51/2" stub at 8,854'. Spear went into top of stub with no problems. P/U to 210,000#, then P/U to 220,000#, Jar, P/U to 250,000#, Slack off to 145,000#. P/U to 250,000# and Jar. Work up to 275,000#, Came free, Seal assembly pulled out at 10,000# - 25,000# overpull. Slacked off, could see seal assembly going back in with 10,000# to 15,000# weight. P/U could see seal assembly pull free of PBR. 05:00 - 07:00 2.00 CLEAN N DPRB DECOMP POOH with seal assembly, laying down 4" Drillpipe to 5,755'. Filling hole with 60 bph plus double pipe displacement. 07:00 - 09:00 2.00 CLEAN N DECOMP Pipe came wet, regained returns. Circulate bottoms up at 7 bpm with 1,080 psi pump pressure. Monitor well. 09:00 - 14:30 5.50 CLEAN N DECOMP POOH with seal assembly, laying down 4" Drillpipe from 5,755' to 222'. 14:30 - 16:30 2.00 CLEAN N DECOMP UD 6 1/8" DC's and Spear Assembly. UD Cut joint and seal assembly. Cut joint was split and belled, no indication of why muleshoe would not slide in. Send seal assembly to Baker to be reworked. 16:30 - 17:00 0.50 CLEAN N DECOMP Clear rig floor, pull wear bushing. 17:00 - 19:00 2.00 RUNCO RUNCMP RlU 4 1/2" 13CR80 tubing handling equipment, RlU compensator, RlU torque turn equipment. 19:00 - 21 :00 2.00 RUNCMP Wait on seal assembly to return from Baker. Removed bottom set of seals from seal assembly. Seal assembly had a half mule shoe on it from previous run. Organize X-Nipples and GLM's. Hold PJSM with all personnel involved. 21 :00 - 00:00 RUNCMP Run 41/2", 12.6#, 13CR80, JFE Bear tubing to 1,780'. Bakerlocked all connections below the packer. Used Jet Lube Seal Guard pipe dope. Torque Turn all connections, Average M/U torque = 4,480 ftllbs. 11/27/2006 00:00 - 08:30 8.50 RUNCO DPRB RUNCMP Run 41/2", 12.6#, 13CR80, JFE Bear tubing from 1,780' to 8,788' Used Jet Lube Seal Guard pipe dope. Torque Turn all connections, Average M/U torque = 4,480 ftllbs. 08:30 - 10:00 1.50 RUNCO RUNCMP RlU circulating head and pump down tubing, washing down to PBR at 8,878'. Confirm depth. Circulating rate 1.5 bpm with 70 psi pump pressure. 10:00 - 12:30 RUNCMP Figure space out. UD 3 Joints of 4 1/2" JFE Bear tubing, P/U XO tubing pup, space out pups, 1 joint of 4 1/2" Vam Top tubing. Torque Turn all connections. 12:30 - 14:00 1.50 RUNCO RUNCMP M/U FMC Jig Saw tubing hanger and landing joint. Land hanger in spool. RlU circulating equipment and reverse in 140 degree seawater at 3 bpm with 120 psi pump pressure in confirm circulation. Run in lock down screws. 14:00 - 18:00 4.00 RUNCO RUNCMP Reverse circulate in 250 bbls of 140 degree seawater followed by 116 bbls of inhibited seawater. Pump pressure went from 120 psi at 3 bpm to 600 psi. Bleed off pressure and troubleshoot problem. Inspect surface equipment and lines, no problems found. Line up to pump down tubing pressured up to 350 psi. Bleed off pressure and discuss options with well engineer. Discission made to pick tubing string up and finish reversing in inhibited fluid. 18:00 - 18:30 0.50 RUNCO RUNCMP Back out lock down screws on tubing hanger. 18:30 - 21:00 2.50 RUNCO RUNCMP Unseat hanger and pick up on tubing string 3'. Up weight 145,000#. Reverse in inhibited seawater at 3 bpm with 120 psi Printed: 12/4/2006 10:08:07 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-18 12-18 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 11/11/2006 11/28/2006 Spud Date: 12/26/1982 End: pump pressure. Pump a total of 470 bbls of inhibited seawater. Recovered some sand returns on bottoms up. 21 :00 - 21 :30 RUNCMP Land FMC tubing jigsaw hanger. Down weight 120,000#. Run in lock down screws. 21 :30 - 00:00 RUNCMP Drop 1 7/8" ball and rod down tubing. Pressure up on 4 1/2" tubing to 3,500 psi for 30 minutes. Good test. Bleed tubing down to 1,700 psi and shut in. Pressure up on annulus to 3,500 psi for 30 minutes. Good test. Bleed down tubing, DCR valve sheared at 900 psi, bleed down to 0 psi. 11/28/2006 00:00 - 00:30 0.50 WHDTRE UD landing joint. Install 5" FMC ISA type BPV and test from below to 1,000 psi for 10 minutes. Good test. 00:30 - 02:00 WHDTRE NID BOPE. Stand back BOP stack on pedestal. 02:00 - 04:00 WHDTRE Clean neck of tubing hanger, N/U FMC Gen III, 135/8" x 4 1/16", 5,000# adaptor flange. Set Tree and Bolt to adapter. 04:00 - 05:00 1.00 WHSUR P WHDTRE Test Adapter Neck Seal to 5000 psi. No Test. 05:00 - 06:30 1.50 WHSUR P WHDTRE Remove adapter, Change Out Seals and Re Set Adapter. 06:30 - 08:00 1.50 WHSUR P WHDTRE Re-pressure Test Adapter Neck Seals to 5000 psi for 15 mins; Good Test. 08:00 - 09:30 1.50 WHSUR P WHDTRE Rig Up DSM and Pull TWC, Set Test Plug. Pressure Test Tree to 5000 psi. Good Test. Pull Test Plug. 09:30 - 10:00 0.50 WHSUR P WHDTRE PJSM with Little Red Hot Oil. Rig Up Little Red and PT lines. 10:00 - 12:00 2.00 WHSUR P WHDTRE Freeze Protect Well. Pump 140 bbls diesel down IA at 2 bpm at 700 psi. 12:00 - 13:00 1.00 WHSUR P WHDTRE Line up hoses and U-Tube diesel freeze protect between IA and tubing. 13:00 - 14:00 1.00 WHSUR P WHDTRE Install FMC 5" ISA type BPV and test from below to 1,000 psi for 10 minutes. 14:00 - 15:00 1.00 WHSUR P WHDTRE NID secondary annulus valve, secure well and cellar. Rig released at 15:00 hrs Printed: 12/4/2006 10:08:07 AM 4-1/16" 5M FMC GEN 3 AXELSON 77' . 12-18 FROM DRLG - DRAFT ~OTES: ***CHROME TSG*** DA TE REV BY COMMENTS 11/28/06 JDMlPA G DRl G DRA FT CORRECTIONS TREE = WELLHEAD = ACTUATOR = leB. ELEV '" BF. ELEV '" KOP= Max Angle = Datum MD = Datum TVD '" 9-5/8",40#, L-80 TC-II Fully cemented to surface. 5000' 33 @ 6200' 9456' 8800' SS 113-3/8" CSG, 72#, L-80, ID'" 12.347" Minimum ID = 3.725" @ -9020' 4-1/2" HES XN Landing Nipple LOCATOR SEAL ASSY MULESHOE w/o SEALS TOPOF7" LNR I 14-1/2" TBG-PC, 12.6#, L-80, .0152 bpf,ID= 3.958" I 19-518" CSG, 47#, L-80, ID = 8.681" I ÆRFORA TION SUMMARY REF lOG: BHCS ON 01/7/83 ANGLE AT TOP ÆRF: 27 @ 9309' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 3-3/8" 8 9309 - 9312 0 04/18/91 2-1/8" 8 9413 - 9440 0 03/17/90 3-1/8" 4 9433 - 9437 S 02/19/90 2-1/8" 8 9443 - 9452 0 04/18/91 2-118" 4 9455 - 9475 0 03/17/90 2-1/8" 4 9483 - 9503 0 03/17/90 I PBTD I 9817' I 7" LNR, 29#, L-80, .0371 bpf, ID 6.184" I 9858' DATE 01/13/83 06/18/90 01/03/02 02/25/03 10101/05 12/18/05 REV BY COMMENTS ORIGINAL COM PLETION LAST WORKOVER RNfTP CORRECTIONS JMP/KK WAr-fER. SAFETY NOTE EZLlPAG WAIVER SF1Y NOTE DELETED AHlTLH TREE/WH CORRECTION NEW 9-5/8" TCII CSG FROM 1930' TO SURFACE 1993' -4-1/2" HES "X" NIP,ID= 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LA TCH PORT DATE 6 3599 3599 0 MMG OCR RKP 0 11/27/06 5 5441 5421 22 MMG DMY RK 0 11127106 4 6459 6293 32 MMG DMY RK 0 11/27/06 3 7355 7056 31 MMG DMY RK 0 11/27/06 2 8170 7766 31 MMG DMY RK 0 11/27/06 1 8670 8189 32 MMG DMY RK 0 11/27106 I 8741' 1-14-1/2" HES "X" NIP, ID=3.813" I 8775' IÎ~~8" X 4-1/2" BAKERS-3 9Cr I 8806' /"4-112" HES "X" NIP, ID - 3.813" Pulled I 51/2" 17# L-80 tubing stub 8878' 8890' 8910' H5-112" BAKER SEAL ASSY I H9-5/8" X 5-112" BAKER FB-1 PKR I 1-15-1/2" X 4-112" XO 1 8999' H4-1/2" OTIS XN LANDING NIP, ID = 3.725" 9515' FISH-IBPW/CAC03CAP (LOST DOWNHOLE -04/20/96) PRUDHOE BA Y UNfT WELL: 12-18 ÆRMfT No: "1822060 API No: 50-029-20877-00 SEC 18, TION, R15E, 1.45' FEL & 2705.53' FNL BP Exploration (Alaska) Well 12-18, Sundry Number 306-139 . ,~"'(.ð~ . Subject: Well 12-18, Sundry Number 306-139 From: "Reem, David C" <ReemDC@BP.com> Date: Fri, 18 Aug 2006 10:43:52 -0800 To: Winton Aubert <winton...;aubert@admin.state.ak.us> Winton, as we discussed on the phone this morning, BPXA has changed the planned workover scope for Prudhoe well 12-18. The new scope includes cutting the 9-5/8" casing just above the logged top of cement in the 9-5/8" x 13-3/8" annulus, running new 9-5/8", 40#/ft, L-80 premium threaded casing tied-back to surface and fully cementing this new casing in place. We do not intend to run a 7" tie·back liner as outlined in the earlier scope (Approved Sundry # 306-139). Please adjust your copy of 12-18's Sundry to reflect the new scope. If needed, we can supply a new application. Thanks. Dave Reem WellslWorkover Engineer 564-5743 (w) 632-2128 (c) '., '. ..., f, ;~>--' :'--<; ~..I{~ {'.A~~'\.~~~'.;tj) ";)''wJ'''~. ~" ~.....- ('. C) (, .~~ {,) V 1 of 1 8/18/2006 11 :07 AM e e I~ ,~ L[· ~ FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA ORAND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 ., "'Á'N' N¡'-¡f'\ {\ (",,¡ ....,.." ¡~. '''''V . ., "'0" C 0:1 \ i{> J; J.., 0 (p Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 12-18 Sundry Number: 306-139 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this It¡ day of April, 2006 EncL oTJ, S//c¡·~Ú!le-.f/Ir ~ ~1(1 . STATE OF ALASKA . W4A- 411~rZ..Ot:){ç. ALASKA èM. AND GAS CONSERVATION CO~ISSION APPLICATION FOR SUNDRY APPROV~fCE'VED 20 MC 25.280 APR 1 4 2006 1. Type of Request: 0 Abandon o Suspend o Operation Shutdown o Perforate ~er . o Alter Casing / S Repair Well o Plug Perforations o Stimulate' eî~j~ fU~~~IICommission o Change Approved Program S Pull Tubing o Perforate New Pool o Waiver 0 Time Exten!ï19Phorage 2. Operator Name: 4. Current Well CI~: 5. Permit To Drill Number ~ BP Exploration (Alaska) Inc. ~ Development 0 Exploratory 182-206 -- ;:S. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20877-00-00 /' 7. KB Elevation (ft): 77 9. Well Name and Number: PBU 12-18/ 8. Property Designation: 10. Field I Pool(s): ADL 028330 Prudhoe Bay Field I Prudhoe Bay Pool 11, .... <i ...... 'i "i'/ i .;·i/i 'M¡:::I' .~¡ .... .. ./iy',.'i'//' ../ , '" . Total Depth MD (ft): Total Depth TVD (ft):1 Effective Depth ~ (ft): Effective Depth TVD (ft)· Plugs (measured): Junk (measured): 9858 9243 9817 / 9205 NIA 9515' Casinq Lenqth Size MD r TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 2689' 13-3/8" 2689' 2689' 4930 2670 Intermediate Production 9272' 9-5/8" 9272' 8711' 6870 4760 Liner 861' 7" 8997' - 9858' 8468' - 9243' 8160 7020 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade; I Tubing MD (ft): 9309' - 9504' / 8744' - 8920' 5-1/2" x 4-1/2". 17#x 12.6# L-80 9011' ~. Packers and SSSV Type: 9-5/8" x 5-1/2" Bafi3r FB-1, Packers and SSSV MD (ft): 8890' .,-/ 5-1/2" Otis HRQ SSSV Nipple 2198' 12. Attachments: 13. Well Class after proposed work: / o Description Summary of Proposal 0 BOP Sketch o Exploratory ~ Development o Service o Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 10, 2006 / ~Oil o Gas o Plugged o Abandoned 16. Verbal Approval: Date: o WAG OGINJ OWINJ o WDSPL Commission Representative; 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Reem, 564-5743 Printed Name ¡ð\Ivid Reem Title Drilling Engineer ')<:, /£P- Date #I¡)OÇ, Prepared By Name/Number: Siqnature Phone 564-5743 Sondra Stewman. 564-4750 . Commission Use Only Conditions of approval; Notify Commission so that a representative may witness I Sundry Number: '3010 -I. '3Q , o Plug Integrity æ(8op Test o Mechanical Integrity Test o Location Clearance Other: n s. t ßOPE to 3 ':;00 I" , . RBDMS BFl APR 2 0 1006 Subsequent Form Required: LO w~~ APPROVED BY 4-/fr ðP Approved By: COMMISSIONER THE COMMISSION Date Form 10-403 Revised 07/2005 V 1/ Submit In Duplicate RIGIN AL e e Well Status: Shut-in Ivishak gas-lifted producer. Well has confinned inner x outer / annulus communication when on gas-lift. The IA x OA leak path is not believed to be through the wellhead. Well is secured with a PXN plug in the tubing tail. Proiect: Retrieve existing 5.5", 17#, L-80 AB-Mod completion, run 7", 26#/ft, L-80 tie- back liner to surface and fully cement same, re-complete well with 4.5", 12.6#, 13Cr-80 VamTop tubing. Provide AOGCC field inspectors 24-hr notices as required to witness BOP tests and MITlA post packer setting. /i 1. MIRU (Ei. Pull BPV, set and test TWC in tubing hanger. ND tree and adapter flange.èÑU BOPE. Test annular to 250 psi (low)/3500 psi (high), remaining BOPE / to 250 psi (low)/3500 psi (high) per BP and AOGCC regulations. 2. Fully circulate through the pre-RWO tubing cut with heated seawater. / 3. Pull 5.5", 17#/ft, L-80 AB-Mod down to the tubing cut just above the packer. 4. Mill over packer and recover same. /' 5. Run 7.5" tie-back polish mill and 9-5/8" casing scraper. Dress tie-back receptacle at . 8997'md. 6. Set 7" RBP at ~9050'md and stack ~30' of20x40 river sand on RBP. 7. Run USIT log to find TOC in 9-5/8" x 13-3/8" annulus. 8. Cut and pull 9-5/8" from TOC logged on the USIT. /" 9. Run 13-3/8" scraper to the 9-5/8" stub. 10. Run 7", 26#/ft, L-80 tie-back liner (top ~2900' to be TC-II, remainder to be BTC-M) / with ported seal-stem shoe-track. 11. Split stack and land 7" on emergency slips in existing FMC Gen3 casing head. 12. Fully cement tie-back liner to surface./ 13. Cut off excess 7" casing and install secondary pack-off. 14. NU stack and pressure test same to 250 psi/3500 psi per BP/AOGCC regulations. / 15. PT casing to 3500 psi for 30-minutes (charted). 16. Mill up shoe track and wash down to the RBP. 17. PullRBP. / 18. Run new 4.5", 12.6#/ft, 13Cr-80 Yam Top completion. Set and test packer to 3500 psi (tubing and inner annulus) for 30-minutes each (charted). /' 19. RDMO 4ES. 20. Tie well in and place on gas-lift production. )It s p ~ "2. ~¿fc (> G \,J 6Ä- TREE = CALICO FMC/MCBlOY I SAFET OTES: , WELLHEAD = FMC GEN 3 12-18 ACTUA TOR = AXELSON KB. ELBI = 77' BF. ELBI = KOP= 5000' I 2198' -15-1/2" OTIS HRQ SSSV NIP, 10 = 4.562" I Max Angle = 33 @ 6200' . Datum MD = 9456' GAS LIFT MANDRB..S DatumlVD= 8800' SS ST MD lVD OBI TYÆ VLV LATCH PORT DATE 1 3012 3012 1 CA MMG RK 113-3/8" CSG, 72#, L-80, 10 = 12.347" I ~ . 2 4608 4608 5 CA MMG RK 2689' 3 5652 5611 31 CA MMG RK 4 6335 6188 33 CA MMG RK L 5 6951 6711 32 CA MMG RK 6 7416 7109 30 CA MMG RK Minimum ID = 3.725" @ 8999' 7 7755 7406 28 CA MMG RK 8 8097 7704 31 CA MMG RK 4-112" OTIS XN Landing Nipple 9 8439 7994 33 CA MMG RK 10 8669 8188 32 CA MMG RKP CHEMICAL MANDRELS C 1ST MD IlVD OBI I TYÆ VLV I LATCH PORT DATE I I 1 876118266 32 I CA-MMG-L TS DOME I RK 10.188 02/10/921 l I 8878' -15-1/2" BAKER SEAL ASSY I J I 8: ....... 8890' 1-19-5/8" X 5-1/2" BAKERFB-1 PKR I ~ 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, 10 = 4.892" I 8910' I- - TOP OF 4-1/2" TBG-PC I 8910' \ 8910' -15-1/2" X 4-1/2" XO I TOPOF 7" LNR I 8997 l- I I I . 8999' -14-1/2" OTIS XN LANDING NIP, 10 = 3.725" I ~ 9010' -14-1/2" BAKER SHEAROUT SUB 1 14-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, 10 = 3.958" I 9011' ..... .... 9011' -14-1/2" TUBING TAIL I I 9-5/8" CSG. 47#, L-80, 10 = 8.681" I µ ~ I 9002' H ELMO TT LOGGED 04/01/91 I 9272' ÆRFORA TION SUMMARY 0 REF LOG: BHCS ON 01/7/83 ANGLE AT TOP ÆRF: 27 @ 9309' 0 Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 3-3/8" 8 9309 - 9312 0 04/18/91 I 2-1/8" 8 9413 - 9440 0 03/17/90 3-1/8" 4 9433 - 9437 S 02119/90 ] 2-1/8" 8 9443 - 9452 0 04/18/91 2-1/8" 4 9455 - 9475 0 03/17/90 2-1/8" 4 9483 - 9503 0 03/17/90 ] 0 -, , 9515' FISH - IBPW/CAC03 CAP I (LOST DOWNHOLE -04/20/96) PBTD I 9817' 17" LNR, 29#, L-80, .0371 bpf, 10 - 6.184" I 9858' DATE RBI BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/13/83 ORIGINAL COMPLETION WELL: 12-18 06/18/90 LAST WORKOVER ÆRMIT No: '1822060 01/03/02 RNlTP CORRECTIONS API No: 50-029-20877-00 02/25/03 JMP/KK WANER SAFETY NOTE SEC 18, TION, R15E, 1.45' FEL & 2705.53' FNL 10/01/05 EZLlPAG WANER SFTY NOTE DELETED 12/18/05 AHlTLH TREElWH CORRECTION BP Exploration (Alaska) TREE = . VVELLHEAD = ACTUA TOR = KB. a.EV = BF. a.EV = KOP= Max Angle = Datum MD = Datum lVD = 4-1/16" 5M FMCGEN3 AXELSON 77' 5000' 33 @ 6200' 9456' 8800'SS 113-3/8" CSG, 72#, L-80, 10= 12.347" 7", 26#/ft, L-80 tie-back liner fully cemented with class "G" cement to -2500', 12 ppg LiteCrete to surface BTCM up to 2900', TC-II to surface I TOP OF 7" LNR I 14-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, 10 = 3.958" I 19-5/8" CSG, 47#, L-80, ID = 8.681" I 12-18 Proposed -2100' H4-1/2" HES "X" NIP, 10= 3.813" 9-5/8" casing cut off just above the 9-5/8" x 13-3/8" External Casing Packer GAS LIFT MANDRELS MD lYPE ST 1 2 3 4 5 6 4.5" x 1" 4.5" x 1" 4.5" x 1" 4.5" x 1" 4.5" x 1" 4.5" x 1" VLV DC!< DlA9M DUM\ttY DUIVMY DUIVMY DUM\ttY -8880' 1-14-112" HES "X" NIP, 10 = 3.813" -890'0 H7" X 4-1/2" BAKER S-3 9Cr PKR -8925' H4-1I2" HES "X" NP, 10 = 3.813" I -9020' H4-112" HES "XN" NIP, 10 = 3.725" IPBTD I 9817' PERFORATION SU~RY REF LOG: BHCS ON 0117183 ANGLE AT TOP PERF: 27 @ 9309' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 8 9309 - 9312 0 04/18/91 2-1/8" 8 9413 - 9440 0 03/17190 3-1/8" 4 9433 - 9437 S 02/19190 2-1/8" 8 9443 - 9452 0 04/18/91 2-1/8" 4 9455 - 9475 0 03/17/90 2-1/8" 4 9483 - 9503 0 03/17/90 17" LNR, 29#, L-80, .0371 bpf, 10 = 6.184" I 9858' DATE REV BY DATE 01/13/83 06/18/90 01/03/02 02/25/03 10/01105 12/18/05 REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER RNITP CORRECTIONS JMP/KK WAWERSAFETY NOTE EZUPAG WAWER SFTY NOTE DELETED AI-VTLH TREEIWH CORRECTION COMMENTS Minimum ID = 3"725" @ -9020' 4-1/2" HES XN Landin Nipple 9515' FISH - IBP W/CAC03 CAP (LOST DOWNHOLE -04/20/96) PRUDHOE BA Y UNIT VVELL: 12-18 PERMIT No: '1822060 API No: 50-029-20877-00 SEC 18, TKlN, R15E. 1.45' FEL & 2705.53' FNL BP exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU' Julie Heusser, ~ Commissioner ~[3~ Tom Maunder, ~ P. i. Supervisor""v' .~i~;..~ \ FROM: Chuck Scheve; SUBJECT' Petroleum Inspector DATE: May 7, 2001 Safety Valve Tests Prudhoe Bay Unit Drill Site 12 Monday, May 7, 2001' I traveled to BPXs Drill Site 12 and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 21 wells and 42 components with 1 failure. The surface safety valve on well 12-12 had a slow leak when pressure tested. This valve was serviced and retested by the operator on this date. Bill Preston (lead DS operator) performed the testing today; he demonstrated good test prOcedures and was a pleasure to work with. A walk through 'inspection of the well houses on this pad was performed during the SVS testing with no problems noted. All well houses inspected were reasonably clean and all equipment appeared to be in goOd condition. Summary: I witnessed the semi annual SVS testing at BPXs Drill Site 12. PBU DS 12, 21 wells, 42 components, 1 failure 2.3% failure rate 29 wellhouse inspections Attachment: SVS PBU DS 12 5-7-01 CS X Unclassified Confidential (Unclassified if doc. removed ) Confidential SVS PBU DS 12 5-7-01 CS Alaslm Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Bill Preston AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Pmdhoe / PBU / DS 12 Separator psi: LPS 160 HPS 5/7/01 We~ Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 12-01 1790230] 12-02 1790320! 12-03 1790410 160 1501 150 P P OIL 12-04A 1811870 160 150 150 P P OIL 12-05 1790550 12-06A 1920540 160 150 150 P P OIL 12-07A 1811750 160 150 140 P P OIL ,, 12'08B 1811670 160 150 140 P P OIL 12-09 1800930 160 150 125 P P OIL 12-10A 1920890 160 150 150 P P OIL 12-11 1810730 12-12 1810830 160 150 90 P 4 oIL 12-13B 1960170 160 ' 150 '150 P ' P OIL .. 12-14A 1981460 160 150 150 P P OIL 12-15 1830320 160 150 150 P P OIL 12-16A 1931480 160 150 150 P P OIL 12-17 1830040 160 150 150 P P OIL t~2~t8~'~'~ .... ~1~22060 160 150 150 P P OIL 12-19 1821980 . 12-20 1821910 ,. 12-21 1840480 12-22 1840600 160 150 125! P P oil ,,. , . 12-23 1840580 , 12-25 1831660 12-26 1840140 160 150 125 P P OIL i12-27A 1990390 12-28A i 199033~ 160: 150 170 P P OIL · 12-29 1840320 12-30 188'1420 ' ' . 12-31 1890010 , 12-32 1890110~ 160 1501 150 P P OIL , 12-33 1890100 12-34 1941370 'i60 150 '150 P' P OIL 12-35 1951300 160 150 100 12-36 1951580 160 150 150 P P OI~ RJF 1/16/01 Page 1 of 2 SVS PBU DS12 5-7-p4.~C_S Well Number Wells: iii i Permit Number 21 Separ Set PSI PSI Components: i~i]~o~.~l~,~ L/P Test I~t ] Date]Oil,W ,~,1 TripCode I Code I Passed I ~ASo~CYCL~ I 42 Failures: 1 Failure Rate: 2.38% I-'i 90 Remarks: Surface Safety Valve on well 12-12 had slow leak when pressure tested. RJF 1/16/01 Page 2 of 2 SVS PBU DS12 5-7-01 CS ARCO AlaskA, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-27-92 REFERENCE: ARCO CASED HOLE FINALS 11-22 2-23-92 Prod Prof Rlln I~/~ ? * 12-4A 3-7-92 Prod Prof' Run ~ _ ~ ~12-5 2-14-92 Jewelry Rim ~12-5 2-14-92 Prod Prof R~m ~° ~-z~g 12-18 2-23-92 Collar Run ~)-/~ 12-25 2-14-92 Jewelry Run ~/-/~ 13-8 2-7-92 Prod Prof R~m o%~I/~ 13-12 3-9-92 Gas Entry Ru_u ~l~ ~ 13-23A 2-22-92 InJ Profile R~m ~z~ 13-24 2-22-92 InJ Profile R~m ~- ?/ 13-25 2-27-92 InJ Profile R~m 1, 2"&5" Camco 1, 5" Camco 1, 5" Camco 1, 5" Camco l, 5" Camco l, 5" Camco l, 5" Camco 1, 2"&5" Camco l, 5" Camco 1, 5" C_,axnco 1, 5" CAMCO Please sign and return the attached copy as receipt of RECEIVED BY Have A Nice Day! Sonya Wallace ATO-1529 .... RECEIVED _ A R~992 APP R OV E D Alas~~ ~a~ Cons. Commission Trans# 9207~-72'-'-Anc'h°rage # CENTRAL FILES # CHE~ON D&M # EXTENSION EXPLORATION # EXXON M2hqATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ~KA TEXACO * The correct API# for 12-4A is 50-029-20384-01. STATE OF ALASKA ALASK/~C~IL AND GAS CONSERVATION Cr~-",'lMISSlOl~ J~ J~ REPOR'i .JF SUNDRY WELL OF_RATIONS 1. Operations performed: Operation shutdown ~ Stimulate Plugging , Perforate X Pull tubing Alter casing Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 452' FSL, 926' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 2418' FSL, 120' FEL, Sec. 18, T10N, R15E, UM At effective depth 2555' FSL, 17' FEL, Sec. 18, T1 ON, R15E, UM At total depth 2568' FSL, 7' FEL, Sec. 18, T10N, R15E, UM J5. Type of Well Development Exploratory Stratigraphic Other 6. Datum of elevation(DF or KB) 77 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-18 9. Permit number/approval number 10. APl number 50 - 029-20877 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9858 feet Plugs(measured) 9242 feet Effective depth: measured 9817 feet true vertical 9205 feet Junk(measured) Liner 861' 7" 9858' 9205' Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 20" 1880# Poleset 110' 110' Sudace 2653' 13-3/8" 1900 sx Fondu & 400 sx PF 'C' 2689' 2689' Production 9242 9-5/8" 500 sx Cl 'G' & 300 sx PF 'C" 9272' 8709' Top job w/100 sx Cl 'G' 325 sx CI 'G' Perforation depth: measured 9309-9312'; 9414-9440'; 9444-9452'; 9456-9467'; 9484-9504' true vertical 8744-8747'; 8839-8863'; 8867-8874'; 8878-8886'; 8903-8921' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8910' MD; 4-1/2', 12.6#, L-80, PCT tail @ 9011' MD Packers and SSSV (type and measured depth) Otis HRQ @ SSSV 2198' MD; Baker FB-1 packer @ 8890' MD 13. Stimulation or cement squeeze summary ~ ~"*~ I ~,~ ''~ ;" 14. Intervals treated(measured) Treatment description including volumes used and final pressure /~\~3F{ -- t~ ~ ~'~ ~ ,ias/<a (~il ~ ~_~ ~.-.~.... Representative Daily Averaae Production or Iniection Data ~llCl~,~r~,,,~ OiI-Bbl Gas-Md Water-Bbl Casing Pressure '~i~ng Pressure Prior to well operation 2401 2150 3563 - 294 Subsequent to operation 2433 5800 4599 - 342 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas.~. Suspended.._. Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88/,,~-'' cc: S. Wallace/DS Engr/J. W. Peirce Title ~'~'/~'/~- Date ~/'Z'"~/~' ',2------. SUBMIT IN DUPLICATE DS12-18 Perforating Summary of Operations 4/18/91 MIRU perforating unit, pressure tested BOPS to 3500// and lubricator to 2500//. RIH with 3-3/8" gun. Perforated (4 spf, 90 deg phasing) 9444'-9452' and 9456'-9466' MD with well flowing. POOH. All shots fired. RIH with 3-3/8" gun #2. Perforated (4 spf, 90 deg phasing) 9420'- 9440' MD with well flowing. POOH. All shots fired. RIH with 3-3/8" guns #3A and #3B. Perforated 9414'-9420' MD (4 spf, 90 deg phasing) and 9309'-9312' MD (2 spf, 180 deg phasing) with well flowing. POOH. All shots fired. Secured well. RD. Returned well to production. (All depths reference 1/7/83 SWS BHCS.) RECEIVED APR - Alaska Oil & Gas Cons, Anchorage ARCO Ahsk~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-6-92 REFERENCE: ARCO CASED HOLE FINALS ? 9-2s 1-23-92 1-18-92 1-24-92 1o18-92 2-8-92 1-26-92 1-26-92 1-20-92 2-7-92 2-3-92 1-26-92 13-16 12-19 2-9-92 17-1 1-25-92 Production Profile ~ 1, Static Temperat'm~ ~ L iF' Prod Profile Run 1, InJ Profile Run 1, 2'&iF' Leak Detect Run 1, Prod Profile Ibm 1, iF' Lesk Detzct J~n 1, Prod Prof/Jewelry Run 1, iF' Prod Profile l~m 1, iF' Prod Profile Run 1, InJ Profile Run 1, iF' InJ Profile Run 1, iF' InJ Profile lhm 1, iF' Inj Profile l~m 1, iF' Inj Profile Run 1, iF' Prod Profile l~m 1, iF' Prod Profile Run 1, iF' Calnco Camco Camco Camco CaulCO Camco Camco Camco Camco Camco Camco Camco Camco Camco Ca]nco · Camco Csznco Please sign and return the attached cOpy as receipt of data. RECEIVED RECEIVED BY Have A Nice Day! Sonya Wallace ATO- 1529 oii PR 0 1 1992 & Gas Cons. Oommission APPROVED _-~.~' Anchorage Trans# 9205~-F' # CENTRAL FILES # CHEVRON D&M # EXTENSION E~PLORATION # EXXON MARATHON # MOBIL ' * The R-n Date on this log is 1-23-92. #PHILLIPS PB WELL FILES R&D # BPX # STATE OF ~KA TEXACO STATE OF ALASKA ALASK!~"!L AND GAS CONSERVATION C MISSION REPORT oF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 452' FSL, 926' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 2418' FSL, 120' FEL, Sec. 18, T10N, R15E, UM At effective depth 2555' FSL, 17' FEL, Sec. 18, T10N, R15E, UM At total depth 2568' FSL, 7' FEL, Sec. 18, T10N, R15E, UM 5. Type of Well Development Exploratory Strafigraphic RECEIVED OCT 1 4 1991 Alaska Oil & Gas Cons, Commission Anchorage 6. Datum of elevation(DF or KB) 77 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-18 9. Permit number/approval number 82-206 10. APl number 50 - 029-20877 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9858 feet true vertical 9242 feet Effective depth: measured 9817 feet true vertical 9205 feet Casing Length Size Conductor 81' 20" Su dace 2653' 13-3/8" Production 9242' 9-5/8" Plugs(measured) Junk(measured) Cemented 1880# Poleset 1900 sx Fondu & 400 sx PF 'C' 500 sx Cl 'G' & 300 sx PF 'C' Top job w/100 sx Cl 'G' Measured depth True vertical depth 110' 110' 2689' 2689' 9272' 8709' Liner 861' 7" 325 sx CI 'G' 9858' 9205' Perforation depth: measured 9309-9312'; 9414-9440'; 9444-9452'; 9456-9467'; 9484-~9504' true vertical 8744-8747'; 8839-8863'; 8867-8874'; 8878-8886'; 8903-8921' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8910' MD; 4-1/2', 12.6g, L-80, PCT tail @ 9011' MD Packers and SSSV (type and measured depth) Otis HRQ @ SSSV 2198' MD; Baker FB-1 packer @ 8890' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Dally Average prQdu~ignorlnjection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 1150 1566 3477 - 2087~,~ 4977''''~'' 8047 ...... - Tubing Pressure 307 298 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X.~_ Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 7RI/R .I~A ~.. .C;W .IWP DS 12-18 DESCRIPTION OF WORK COMPLETED FRACTURE TREATMENT OF SAG/Z4 8/30/91 - 8/31/91- MIRU & PT equipment to 4300 psi. RIH w/CT & pumped 40# gelled sand slurry containing a total of 4,900 lbs of 20/40 mesh sand, to isolate lower open perforation intervals, at: 9444 - 9452' MD (Z4) 9456- 9466' MD (Z4) 9466 - 9467' MD (Z4) 9484 - 9504' MD (Z4) Ref. Log: BHCS 1/7/83. Tagged a final top of sand plug at 9494' MD. 9/1/91 - 9/2/91' MIRU & RIH w/CT to pump an additional 1450 lbs of 20/40 mesh sand, to fully isolate the lower perforation intervals (listed above). A final tag indicated the top of sand at 9477' MD. 9/4/91 - 9/6/91' MIRU & RIH w/CT & pumped 1300 lbs of 20/40 mesh & 300 lbs of 100 mesh sand, to fully isolate the perforations (listed above). Made bailer runs to adjust final sand top to 9432' MD. 9/7/91 · MIRU & PT equipment to 9000 psi. Pumped a Hydraulic Fracture Treatment using 12/18 mesh & resin coated proppants, through the upper perforation intervals located above the sand plug, at: 9309 -9312' MD (Sag) 9414 - 9440' MD (Z4: Ref. Log: BHCS 1/7/83. Bottom 8 feet sand covered). Pumped: a) 300 bbls Gelled Pre-Pad, @ 60 bpm, followed by b) Shutdown. ISIP @ 1500. Resumed pumping: 0 Ol' 1 4 199t Alaska 0ii & Gas Cons. Gomt~'~ss'~on 'Anchorage c) 400 bbls 40# Pad, @ 25 bpm, followed by d) 440 bbls' Crosslinked Slurry @ 1-10 ppg proppant concentrations, followed by e) 184 bbls Flush, followed by f) Shutdown. Placed _48j_500 lbs of 12/18 proppant, followed by~__25,6_Q_0.. !b~ of rqsJn_._c0ated proppan_t into the formation, for a total of 74,100 lbs of proppant placed into the formation. Rigged down. 9/10/91 · Performed a sand plug/proppant fill cleanout. Tagged bottom at 9779' MD. Placed well on production w/AL & obtained a valid welltest. ARCO ALAgKA, INC. ( P~O. BOX i00360 ' ~-~NUH~R~-~GE ALASKA 995~0 DATE' 5-22-~t REFERENCE. ARCO CAGED HOLE F-'iNAL:$. S-22 ~ 2-28-90 GR ~-'-~ 4-~-ot $.r4L CCL 6-7 i 2-5-9,-3 TEMP/$F'INNER '~o 5-4-9t LEAK DETECT 9-S i2-i S-90 CORR GR 9-45 t '~-t-- 0-90 '- TEMF' t o_~ i '~-'~o-o¢.) GR i 2-8B ~-i.., e-e1.- , VE~'T'r LOG,,,,. i'-2-i8 5-3-9i F'ROD. PROFILE t2-29 5-5-9i F'ROD, PROFILE i4-i3 5-t-9i INJ, PROFILE i 6-6 5-6-9! COLLAR/F'EF,'F t 6-9A 5-5-9t CBT i6-gA 5-5-9! -~ CET [' ER t 6-9A ~-6-9I PA.,K REC 18-!t 5-4-9t - GAS DETECTION RUN t , 5' RUN t , 5 · RUN i , 5" RUN t, 5' RUN i , 5" RUN t, 5' RUN i, 5" R U N ~' 5" RUN i, 5' RUN t , ~" RUN t, 5' RUN t, ~'' RUN t , 5 ' RUN i, 5 ' RUN i, 5 ' PLEASE SIGN AND RETURN THE ATTACHED 'COF'Y Ag RECEIPT OF DATA, RECEIVED BY ...... _ /.~ HAVE A NICE DAY! ~UNNY WALLACE APPROVED ______ ATO-1 529 'TRAN$~ 9t HR~J A'FI_A$ HR$ CAMCO HR$ HR$ HR$ ATLA£ CAMCO CAMCO CAMCO AI't_AS ~£CH $CH $CH --- CAMCO DISTRIBUTION CENTRAL FILES ~ RHILLIF'$' F: _F':, , ~..H,-vRON PB WELL F'IL.E£' D & H R & D EXTENS'ION EXPLORATION $ BPX EXXON ¢ STATE OF ALAg.'KA MARATHON TEXACO MOBIL THE AF'I$ FOR 5-20 I~J 50-029-22i · RECEIVED N~A'Y 2 3 1991 Alaska Oil & Gas Cons. Commj~ion ......... Anchorage ... P !iii F;,' F F;.'. li!] C: 0 R D i... IE A K L:' ii:.: i- iE C -F .[ 0 N '" "'1 t ..'.. r, .,- r.:, i::' ~:., c- ... ..... L. ]'It'-...' / L. ': I N ..J !ii: C 'i" T () i',,.' .... 'Ii .a ."'t ..-...r-.--. ,.-- I;i == [ i-Ir',/ I-"t'.l":~" (;. A 5'~....,.' ~' F' 'i" f'! A i':.~ i} R i~.. i...,::":.....":' r"i..., ..:, ,..:,, ,.,. i::' E R !::' ~:" ~::' ;""'"" ~''' i t.. l... %.- L.-' i ~ ~... i' I "".'""::' F:' !:il ?.; F:' -..- ;..... i..., i ~ ./ I iq j i~. C '!" i ''''~ -..~1~. ~" I"} i ~ /:~ I:;= i;;' I:'~ © i::' :.'!;,'F ~ll ~! "i" ]. l"i:.'.~ ! : . .. n .~, ..:. -. I::' ~:;.'. 0 D U C '!" i (.) N .... I..... I... · P i:;.'. 0 D U C 'i" i 0 i',! f'; ~"1 F' !;.'. 0 D U C T ! C..' N i'; i" :' '~ / ~ ' ,.,dl...L.t.~F,:-F LRF:' F:' Ii: R F: I:;,' E C 0 I';:. D I N J E C T ! 0 N ! N J E C T iii 0 N ................. ..... L,I ¥ AY F-'LEA:i-;'I? :~;'I'(:.;N ANt)' RIETUI;,'N THE A'I"iAL:HI:."D ;'";:"' ,.,.., :. t., [.~. I ~ ,' ':" '0 Bv . · .i A"..: E · A N I C E D A '¥' ! R Ii.=. C Iii: i F:' i" 0 F:' D A 'i" A. ;::'?HAR,-]N W I !...;ii:ON A '¥ 0 -- i 5 '2 9 A P P R 0 V E I) 'i"I:;-.'AN,S':~ 91 i '2'.:.,~ I) 12 T R I B U 1' I 0 N c,~,s C°m~ L STATE OF ALASKA --_. ALASKA ~'--~.AND GAS CONSERVATION CC. AISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging , Perforate )(' Pull tubing Alter casing Repair well Other X 2. Name of Operator 5. Type of Well 6. Datum of elevation(DF or KB) Development X 77 RKB feet ARCO Alaska, Inc. Exploratory 3. Address Stratigraphic 7. Unit or Property P.O. Box 100360, Anchorage, AK 99510-0360 service Prudhoe Bay Unit 4. Location of well at surface 8. Well number 452' FSL, 926' FEL, Sec. 18, T10N, R15E, UM 12-18 At top of productive interval 9. Permit number/approval number 2418' FSL, 120' FEL, Se(::. 18, T10N, R15E, UM 82-206/9-1077 At effective depth 10. APl number 2555' FSL, 17' FEL, Sec. 18, T10N, R15E, UM 50 - 029-20877 At total depth 11. Field/Pool 2568' FSL, 7' FEL, Sec. 18, T10N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9858 feet Plugs(measured) true vertical 9242 feet Effective depth: measured 9817 feet true vertical 9205 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 20" 1880# Poleset 110' 110' Surface 2653' 13-3/8" 1900 sx Fondu & 400 sx PF 'C' 2689' 2689' Production 9242' 9-5/8" 500 sx CI 'G' & 300 sx PF 'C' 9272' 8709' Top job wi100 sx CI 'G' Liner 861' 7" 325 sx CI 'G' 9858' 9205' Perforation depth: measured 9414-9440'; 9444-9452'; 9456-9476'; 9484-9504' true vertical 8839-8863'; 8867-8874'; 8878-8896'; 8903-8921' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8910' MD; 4-1/2', 12.64t, L-80, PCT tail @ 9011' MD Packers and SSSV (type and measured depth) Otis HRQ @ 2198' MD; Baker FB-1 packer @ 8890' MD 13. Stimulation or cement squeeze summary R E ~ ~, I 'V C ~ Intervals treated(measured) See attached Treatment description including volumes used and final pressure ^~o,tm air & Gas Cons. C0m~'tss'~0~ 14. Representative Daily Average Production or Injection Data ......... 'Arlch01'ag~ Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut i.n. Subsequent to operation 4439 4626 1507 -- 246 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed [~~- '~, ~ Z.//o/~. Title Sr. Area Operations Engineer Date / ~' ..... ~ ........ ~"qJl Ir'~l, il'"l- I~1 nl tnt i~"~ A"l-f-' Form 10-40z Rev 06/15/88 1~0'7 /'"',1~ A I I ~,. SUBMIT IN DUPLICATE DS 12-18 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR WATER SHUT-OFF 2/1 5/90: MIRU CTU & PT equipment. RIH w/CT & washed perforations at: 9414 - 9440' MD Ref. Log: BHCS 1/7/83. 9444 - 9452' MD 9456 - 9476' MD 9484 - 9504' MD Pumped: 100 bbls Seawater, followed by, 72 bbls 12% HCl, followed by 517 bbls Seawater Flush. Displaced CT w/75 bbls Meth Water. POOH. Rigged down. 2/19/90: A CTU Squeeze was performed as follows: MIRU CT & Cementing Equipment. PT equipment to 4000 psi. RIH w/CT and fluid packed wellbore w/354 bbls of seawater. Pumped 70 bbls of acid resistive cement, squeezing perforations at: 9414 - 9440' MD Ref. Log: BHCS 1/7/83. 9444 - 9452' MD 9456 - 9476' MD 9484 - 9504' MD Placed 33 bbls of cement behind pipe, at 2500 psi maximum squeeze pressure. Contaminated cement w/contaminant. POOH. RD. 2/20/90: Cleaned out contaminated cement from wellbore. 3/17/90: Reperforated: 9414 - 9440' MD 9444 - 9452' MD 9456 - 9476' MD 9484 - 9504' MD Ref. Log: BHCS 1/7/83. Well would not flow. Shut in well. 5/30/90 - 6/19/90: Rig Workover (reported under a separate Report Sundry : Apprvl # 90-281). 7/8/90 - 7/9/90: Replaced DGLV's w LGLV's. Returned well to production w/gas lift, and obtained a valid production te~, E C E ~ V ~ ~1 DF_C 1 1 Alaska Oil .& G~s Cons. Oorr~m~ssio~ Anchorage ARF. O AL. AgKA: ZNC, F'~ 0., BOX 'i ,::_'.,,:~,S6,:-D A N C ia.' 0 R F"~ G E, A L A S K A DATE 995i ~'3, . 0/I ,~ ~as Con~ 4t~c,'lor~£O' 6braeaiSsioa ,, ........ f .... ~., ..... A,.,_...,. CAGED FtOLE FzNAL.C-: F'!..EAgiE gIGN AND RETURN THE ATTACHED F.:ECEiVIED,_,'":'Y - _~~~'~- ~"~ '~'; '" ~' A ;'"l i F' I:: i3 t~ Y ~ SAL. L."f "F' ~"~'" ....... H .J r- ,- ~: t..-r... E f;..' ATO- ! 5 2".=:' F,:U N i , RUN i, R U N R I Ii'...! RUN i.. '.5 !:;..' U i"-! i , 2. RUN ~, , ~_,. RUN · ,.; i ,, .," RUN i , "-';: IN:I I N i , RUN i , RIJi',I · -. .,.~' RUN i, """_.. COF'Y AS RFSCF":[F'T OF DF~'FA fl 11 fl ii n ,? C: I.'i Z C: ~"! S' C: H ,':':~ C i"! A "f' L. A ,i';: A i'l_ A ,? C H $ C H ,? C H ATI_AS' ATE. Ag D 15'i'R I BUT I ON g (::~= i'J'r i::A L~.,,, FiLEg ¢ PHILLIPS' g ISHFVRON F'B WELL F'II_..EZ D & H · .". · ,,."~- E'~"TFN e l ON,, ,.:. .... EXF'LFiR.A T I FiN. :$ BF'X .,. '-v:.,-~- i · ,- E,-.,-.. Jr'-! ~ g'TA'FE UF AI_AS-'K A HARATHON TE-"XACO ~" MOBIL STATE OF ALASKA ALA,br~ OIL AND GAS CONSERVATION COMMI,~,~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed' Operation Shutdown __ Alter casing Repair well Stimulate Pull tubing X Plugging __ Perforate Other X Workover 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 452' FSL, 926' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 2418' FSL, 120' FEL, Sec. 18, T10N, R15E, UM At effective depth 2555' FSL, 17' FEL, Sec. 18, T10N, R15E, UM At total depth 2568' FSL, 7' FEL, Sec. 18, T10N, R15E, UM 5. Type of Well: Development _.X. Exploratory _ Stratigraphic _ Service 6. Datum elevation (DF or KB) 77' RKB 7. Unit or Property name Prudhoe Bay Unit feet 8. Well number 12-18 9. Permit number/approval number 82-206/90-881 10. APl number 50-029-20877 11. Field/Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured true vertical 9858' 9242' feet Plugs (measured) None feet Effective depth: measured 9 81 7' true vertical 9205' feet Junk (measured) None feet Casing Length Conductor 81 ' Surface 2653' Intermediate Production 9242' Liner 8 61 ' Perforation depth: measured Size Cemented Measured depth True vertical depth 2 0" 1880# Poleset 1 1 0' 1 1 0' 13-3/8" 1900 sx Fondu & 2689' 2689' 400 sx PF 'C' 9-5/8" 500 sx Class G, 9272' 8709' Top job w/100 sx PF 'C' & 300 sx PF 'C' 7" 325 sx Class G 8997'-9858' 8468'-9205' 9414'-9440', 9444'-9452', 9456'-9476', 9484'-9504' true vertical 8839'-8863', 8867'-8874', 8878'-8896', 8903'-8921' Tubing (size, grade, and measured depth) 5-1/2"/4-1/2", L-80, tbg w/ tail @ 9011' Packers and SSSV (type and measured depth) OTIS 'HRQ' @ 2198', Baker 'FB-I' pkr @ 8890' 13. Stimulation or cement squeeze summary None Intervals treated (measured) Treatment description including volumes used and final pressure 'JUL t '. ?f~ .-'~ 14. N/A Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation 15. Attachments *WORKOVER WELL HISTORY Copies of Logs and Surveys run __ Daily Report of Well Operations X* 16. Status of well classification as: Water Injector m Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 05 Title Drilling Analyst Date '"7-//- ¢]~ SUBMIT IN DUPLICATE ARCO and Gas Company Well History - Initial Report - Daily Inatmctiona: Prepare and submit the "Initial Repert" on the first Wednesday after a well I1 apudded or workover oporatlonl ere Itlrlad. Daily work prior to SPudding should be summarized on the form giving inclusive dates only. rcounly, parish or borough District ~B-~CO ALASKA INC. NORTH SLOPE Leas~ or Unit Fi. Id PRUDHOE NY ADL: 28330 Auth. or W.O. n~S3196 j'ri,e WORKOVER I 50-029-20877 Complete record for each da_y reported AUDI 4 IState AK I Well no. D~ 12-18 - -~ AR3B-459-1-D The above is correct D.AILY: 527,1276 c~: $266~ 273 For fo~ prep~a~on~% distribution, see Procedures M~ual, Section 10, Drilling, Pages 86 a~d 87. NU BOP MW: 8.6 Seawater MOVE RIG FROM DS 5-9. RU ON TREE. CIRC SEAWATER DOWN TUBING AND OUT ANNULUS TO KILL WELL. SET BPV. ND TREE, NU BOPS. INSTALL TEST PLUG. TEST BOPS. DAILY:S82,952 CUM:$82,952 ETD:S82,952 EFC:$1,165,000 · RIH W/OVERSHOT MW: 8.6 Seawater ND BOPS. CHNG OUT RING GASKET BTW MUD CROSS AND BLIND RAMS. TST BOPS TO 5000 PSI. PULL TST PLUG. MU LNDNG JT. PULL 60K# OVER STRING WGHT TO PART TEG. PULL HNGR TO FLOOR AND LD SAME. CIRC CRUDE OUT OF ANNULUS. POOH, LD 5-1/2" TUBING. CLOSE RAMS AND PRESS TST 9-5/8" CSG ABOVE PKR TO 3000 PSI F/ 30 MIN. MU OVERSHOT ON 3-1/2" DP AND RIH. DAILY:S38,400 CUM:$121,352 ETD:S121,352 EFC:$1,165,000 RIH W/OVERSHOT MW: 8.6 Seawater RIH W/OVERSHOT ON DP. TAG TOP OF CUT TBG@ 8804' MD. ATTEMPT TO ENGAGE TBG STUB W/O SUCCESS. POOH. MU SPEAR AND RIH. TAG FISH AND ATTEMPT TO SPEAR TBG W/O SUCCESS. POOH. MU MILL CONTROL AND HOLLOW MILL BELOW OVERSHOT AND RIH. DAILY:S26,528 CUM:$147,880 ETD:S147,880 EFC:$1,165,000 RIH W/REP MW: 8.6 Seawater RIH W/OVERSHOT. TAG FISH @ 8804' MD. MILLED OVER TOP OF FISH AND ENGAGED TaG STUB. PU ~ RELEASE FISH W/25K# OVER STRING WEIGHT. POOH. RECOVERED TUBING, SEAL ASSEMBLY, PER, AND K-ANCHOR. MU BAKER REP AND RIH. COULD NOT SET REP @ 3000' MD. POOH, MU SECOND BAKER RBP AND RIH. ATTEMPT TO SET @ 3000' W/O SUCCESS. POOH, MU HALL RBP AND RIH. DAILY:S26,616 CUM:$174,496 ETD:S174,496 EFC:$1,165,000 LD 9-5/8" CSG MW: 8.6 Seawater RIH AND SET RBP@ 3000' TST REP TO 3000 PSI F/30 MIN. SPOT 70' SAND ON TOP OF BRIDGE PLUG. POOH. RU EL. RUN CBL/CET/GR/CCL F/2900' TO SURFACE. RD EL. RIH W/CSG CUTTER. ATTEMPT TO CUT 9-5/8" @ 1965' W/O SUCCESS. POOH, CHANGE CUTTERS. RIH AND CUT 9-5/8" CSG @ 1965' MD. POOH. BOLDS. PULL 9-5/8" PACKOFF. SPEAR 9-5/8" BELOW HANGER AND PULL 9-5/8". LD HANGER. POOH, LD 9-5/8" CSG. DAILY:S64,501 CUM:$238,997 ETD:S238,997 EFC:$1,165,000 POOH W/9-5/8" CASING YM: 8.6 Seawater POOH, LD 9-5/8" CASING. MU 8-1/2" BIT AND RIH TO TOP OF CSG STUB @ 1965' MD. CBU. POOH. MU HYDRAULIC CSG BACKOFF TOOL AND RIH. SET BACKOFF TOOL AND PRESS DP TO 3200 PSI. BACKOFF 9-5/8" CSG @ 2030' MD 6 FULL TURNS. RELEASE TOOL A/TD POOH. MU SP~ FOR 9-5/8" AND RIH. SPEA/~ CSG STUB @ 19~5' ;~ A~ FiNiSH ~ACK~NG Ouw CO~Ci'AO~ ~ 2030: mu. ETD:S266,273 EFC:$1,165,000 Drilling Supt. INumberall dally well history forms consecutively no. as they are prepared for each well. z iPage I 06/01/90 (1) TD: 0 PB: 9817 SUPV:DAC 06/02/90 (2) TD: 0 PB: 9817 SUPV:DAC 06/03/90 (3) TD: 0 PB: 9817 SUPV:DAC 06/04/90 ( ~) TD: 0 'PB: 9817 SUPV:DAC 06/05/90 (5) TD: 0 PB: 9817 SUPV:DAC 06/06/90 ( ~) TD: 0 Pa: 9817 SUPV:DAC IARCO W.I. oporetor ARCO 0,0000 Spudded or w.O.AcCEPTbegun ]Date 5/31/90 iH°ur 1500 HRS IPrior statusif aW.O. Date and de*pth as of 8:00 a.m. ARCO and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforaling, show formallon name in describing work performed. Number all drill stem tests sequentially. Attach description of ali cores. Work performed by Producing Seclion will be reporfed on "lnlerl~t" sheets unlil final completion. Report official or representalive test on "Final" form. 1) Submit "Interim" sheets when filled out bul not less frequently Ihan every 30 days, or (2) on Wednesday of Ihs week in which oil siring is set. Submit weekly for workovers and Iollowing setting of oil string] until complelion. Field Date and depth as of 8:00 a.m. , ARCO ALASKA INC. Icounty or Parish NORTH SLOPE I PRUDHOE BAY ILease or Unit DS 12-18 I Complete record for ea~l~j~'l, wl~e drilling or workover in progress 06/07/90 ( TD: 0 PB: 9817 SUPV:GLC 06/08/90 ( TD: 0 PB: 9817 SUPV:GLC 06/09/90 ( TD: 0 PB: 9817 SUPV:GLC 06/10/90 ( TD: 0 PB: 9817 'SUPV:GLC 06/11/90 ( TD: 0 PB: 9817 SUPV:GLC 8) JSlate AK IWell no. o) ].1) ATT~T BACKOFF 13-3/8 MW: 8.6 Seawater FINISH LD FTA #13, CUT JT, 1 FULL JT W/COLLAR DOWN(HAVE PIN LOOKING UP). RIH W/SCRAPER TO 2025' MD AND CIRC HOLE CLEAN. POOH. RIH W/13-3/8" RTTS AND SET AT 37' MD. ND BOPE AND TBG SPOOL. CUT OFF BRADENHEJ%D. WELD 1 JT TO 13-3/8" STUB. ATTEMPT TO BREAKOUT 13-3/8" CASING. DAILY:S27,430 CUM:$293,703 ETD:S293,703 EFC:$1,165,000 NU TUBINGHEAD MW: 8.6 Seawater ATTEMPT TO BACKOUT 13-3/8" BELOW HANGER W/O SUCCESS. CUT OFF 13-3/8" AND 20" BELOW BASEPLATE. DUG CMT FROM AROUND 13-3/8". WELD 13-3/8" COLLAR TO STUB AND BACKOUT 13-3/8" 3' BELOW GL. MU NEW JT OF 13-3/8" TO STUB AND PRESS TST TO 2000 PSI. ROUGH CUT 13-3/8". WELD ON 20" LANDING RING. SET 13-3/8" SLIPS AND MAKE FINAL CUT. TST ALL WELDS. Nil 4-PORT FMC GEN III TUBINGHEAD. DAILY:S27,056 CUM:$320,759 ETD:S320,759 EFC:$1,165,000 RUNNING 9-5/8" CASING MW: 8.6 Seawater NU BOPS AND TEST SAME. RETRIEVE PKR AND STORM VALVE. RIH W/11-3/4" WASHPIPE AND PUSH JUNK BELOW TOP OF 9-5/8" STUB INTO 9-5/8" X 13-3/8" ANNULUS. POOH. TEST 13-3/8" CASING AND ANNULUS TO 2000 PSI. MU SCREW IN SUB AND 9-5/8" CASING AND RIH. DAILY:S136,048 CUM:$456,807 ETD:S456,807 EFC:$1,165,000 POOH W/MILLS MW: 8.6 Seawater FIN RIH W/9-5/8" CASING. DISPL HOLE W/8.5 PPG OBM. SCREW INTO 9-5/8" @ 2031' ATTEMPT TO TEST 9-5/8" CASING. CIRCULATE @ 3 BPM, 750 PSI. RU ELECTRIC LINE AND RIH W/SPINNER. CONFIRM LEAK @ 2031' MD. RD EL. BACK OFF 9-5/8" @ 2031' AND POOH, LD 9-5/8" CASING. MU 11-3/4" OUTSIDE MILL AND 8-1/2" INSIDE MILL AND RIH. WORK MILLS OVER AND INTO 9-5/8" CASING STUB @ 2031'. POOH. DAILY:S27,232 CUM:$484,039 ETD:S484,039 EFC:$1,165,000 POOH W/BACKOFF TOOL MW: 8.6 Seawater LD MILL. MU 8-1/2" MILL AND RIH. PUSH JUNK INSIDE 9-5/8" CASING TO TOP OF SAND @ 2936' MD. POOH SLOW. MU 11-3/4" WASHPIPE AND RIH. WORK WASHPIPE OVER STUB AND WASH OVER OUTSIDE OF 9-5/8" CASING TO 2091' MD. POOH. MU TRISTATE BACK OFF TOOL AND RIH. SET TOOL ACROSS 9-5/8" CONNECTION @ 2075' MD. BACK OFF CONNECTION FIVE FULL TURNS. RELEASE TOOL AND POOH. DAILY:S59,507 CUM:$543,546 ETD:S543,546 EFC:$1,165,000 The above ia correct Drilling, Pages 86 and 87 Drilling Supt. Number all daily well hislory forms conseculively ~Psge no. as they ere prepared for each well. I AR3B-459-2-B .. ;v'" '":"~ '?"." '- ':' '." ?-': ':.'~-' '~?~':'~:-': ~' ;"'-'-', -.: ..7:.',:.~"' ? ~. ~ - ;:'2'~ -' .~'~?.- ~'7..--~ '? ::---.'-j:'~: ,': :-'j' --'." '."-'-: ~-.:--~; ::-,'." :' :-'"~.-' '~-~.~ ~" .'. v. :...: :-.., .:'-';.,-,..-:::, ~ -, ,. ~., ~',. %:'. ~. , -. ...... '.- ,..,.-~ - · ,... ,:.- '.-. ........ ~ ..... , : .. .......... . ...... ARCO. and Gas Company Daily Well History--Interim Instruolions: This form is used during drilling or workover operations. If lasting, coring, or perforeling, show formation name in describing work performed, Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Seclion will be reported on "lnlerlm" sheets until final completion. Report official or representalive test on "Final" form. 1) Submit "Interim" sheets when filled out bul not less frequently then every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting ol oil strinG until complelion. Dislrict Field ARCO ALASKA INC. PRUDHOE BAY County or Parish NORTH SLOPE JState AK Lease or Unit DS 12-18 Iwe. no. Date and depth as of 8.'00 a.m. Complete record for eac~hi~e drilling or workover in progress 06/12/90 (12) TD: 0 pB: 9817 SUPV:GLC 06/13/90 (13) TD: 0 PB: 9817 SUPV:GLC 06/14/90 (14) TD: 0 PB: 9817 SUPV:GLP 06/15/90 (15) TD: 0 ' PB: 9817 SUPV: GLP 06/16/90 (16) TD: 0 PB: 9817 SUPV:GLP 06/17/90 ( 17) TD: 0 PB: 9817 SUPV:DAC The above is correct Drilling, Pages 86 and 87 SET SLIPS ON 9-5/8" MW: 8.6 Seawater POOH W/BACKOFF TOOL. MU SPEAR AND RIB. ENGAGE 9-5/8" STUB AND BACK OUT SAME. POOH, LD JOINT OF 9-5/8" CASING. MU SCREW IN SUB ON 9-5/8" CASING AND RIB. DISPLACE HOLE W/8.5 PPG OHM. SCREW INTO 9-5/8" STUB. PRESSURE TEST 9-5/8" TO 3000 PSI. SET EXT CSG PKR. PU BOPS, DROP SLIPS ON 9-5/8". DAILY:S28,981 CUM:$572,527 ETD:S572,527 EFC:$1,165,000 POOH W/JET BASKET ' MW: 8.6 Seawater SET SLIPS ON 9-5/8". CUT OFF LANDING JOINT. NU PACKOFF AND FMC GEN IV TBGHD. TEST PACKOFF AND FLANGE TO 3.500 PSI. TST 9-5/8" CSG TO 3000 PSI F/30 MIN. MU REV JET BASKET AND RIH. TAG JUNK/SAND @ 2932' MD. DISPLACE OBM OUT OF HOLE W/SEAWATER. WORK BASKET OVER JUNK AND WASH TO 2952' MD. POOH, RECVD CENTRALIZER PIECES. RIB W/JET BASKET. WASH OVER JUNK TO 2965' MD. POOH, RECVD CENTRALIZER JUNK. RIH W/GET BASKET. WASH OVER JUNK TO 2980' MD. POOH. DAILY:S72,971 CUM:$645,498 ETD:S645,498 EFC:$1,165,000 POOH W/RBP MW: 8.6 Seawater POOH W/JET BASKET, RECVD CENTRALIZER JUNK. MADE TWO MORE RUNS W/JET BSKT, RECOVERING CENTRALIZER JUNK EACH TIME. RIH W/MAGNET TO 2996' MD. POOH, NO RECOVERY. RIH W/OS AND REV BSKT TO 2996' MD. POOH, NO RECOVERY. RIB W/ RETRIEVING TOOL F/REP. LATCH AND RELEASE RBP. POOH. DAILY:S28,278 CUM:$673,776 ETD:S673,776 EFC:$1,165,000 RIH W/6" BIT MW: 8.6 Seawater POOH, LD RBP. MU 8-1/2" PKR MILL AND RIH. MILL OVER PKR @ 8931' MD. CBU, POOH. LD PKR ASSEMBLY. MU 6" BIT AND RIH. DAILY:S109,317 CUM:$783,093 ETD:S703,776 EFC:$1,244,317 RIH W/PKR ON DP MW: 8.6 Seawater RIH W/6" BIT. TAG FILL @ 9709' MD. WASH FILL TO PBTD @ 9803' MD. REVERSE CIRC HOLE CLEAN. POOH. MU BAKER FB-1 PKR AND TAILPIPE ON DP AND RIB. DAILY:S28,393 CUM:$811,486 ETD:S811,486 EFC:$1,165,000 RIH W/5-1/2" TUBING MW: 8.6 Seawater RIH W/PKR. SET PKR @ 8890' MD. TEST PKR TO 3000 P~I F/30 MIN. POOH, LD DP. MU 5-1/2" COMPLETION ASSEMBLY AND RIB. DAILY:S26,968 CUM:$838,454 ETD:S838,454 EFC:$1,165,000 AR3B-459-2-B .. JNumber all daily well hialory forms ]Page no. as Ihey are prepared for each well. conseculiveiy ARCO, Jnd Gas Company Daily Well History--Interim nitrucflane: This form is used during drilling or workover operations. If testing, coring, or psrforeling, show formalion name in describing work pedormed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Saclion will be reported on ' nlerlm' sheets until final completion. Report official or representative test on "Finil" t~orm. 1) Submit "ll~lerlm" sheets when filled out but not less frequently Ihan every 30 days. or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following salting of oil string until complelion. District Field /LRCO ALASKA INC. PRUDHOE BAY Counly or Parish Lease or Unit NORTH SLOPE Istate AK DS 12-18 Well no, Date and depth as of 8:00 a.m. 06/18/90 ( TD: 0 PB: 9817 SUPV: DAC Complet ...... d f .... c~[~yfhi~je drilling ..... k .... in prog .... 18) PREP TO RELEASE RIG MW: 8.6 Seawater RIH W/5-1/2" TUBING. STING SEALS INTO PKR AND TEST TO 1000 PSI. SPACE OUT AND LAND TUBING HANGER. TEST TUBING AND PKR TO 3000 PSI F/30 MIN. FREEZE PROTECT TOP 3000' OF TUBING AND ANNULUS W/DIESEL THRU ORIFICE IN TOP GLM STATION. LD LANDING JT. SET BPV. ND BOPS, NU TREE. TEST TREE AND ADPTR TO 5000 PSI. SHEAR SUB IN PKR TAIL W/3800 PSI. PREP TO RELEASE RIG. (OTIS 'HRQ' @ 2198', BAKER 'FB-i' PKR @ 8890', & TT @ 9011') DAILY:S201,866 The above is correct ~ ~ Signatu~~ ~:~. For form prepa'r~.ation and distribution se~ Procadures Manual ,Section 10, Drilling, Pages 86 and 87 CUM:$1,040,320 ETD:S1,040,320 EFC:$1,165,000 ]Title Drilling Supt. AR3B-459-2-B INumber all daily well history forms consecutively IPage .o. as they are prepared for each well. ARC .~iland Gas Company Daily Well History-Final Report Inllruclionl: Prepare and submit the "Final Report" on the first Wednesday after allowable hal been Illlgned or well II Plugged, Ablndonld, or Sold. "Final Report" should be submitted also when operations ere suspended for an indefinite or appreciable length of time. On workovers when an official test Is not required upon completion, reporl completion and representative test data in blocks provided· The "Flnll Report" form may be used for reporting the entire operation if space is available. J Accounting cost center code District County or Parish IStele ~1~CO A~g~,~K~ TN'C. Lease or NORTR S~PE I AK Field Unil Well no. PRUDHOE BAY ADL: 28330 DS 12-18 lite Auth. or W.O. no. AS3196 WORKOVER API: 50-029-20877 Operator Spudded or ~/.O. begun IA.R.Co. W.I. Date Date and depth as of 8:00 a.m. ARCO Old TD Released rig rrotal number of wells (active or inactive) on thi~ 0 0000 Icoet center prior Io plugging end / · labandonment of this well IHour IP,~or ltatus If a W.O. 5/31/9o/ 1soo ~$ ACCEPT Complete record for each day reported AUDI 4 06/19/9( ( 19) TD: PB: 981 SUPV: DAC RELEASE RIG · RELEASE RIG @ 0600 HRS, 6/18/90. MW: 8.6 Seawater DAILY:S158,346 CUM:$1,198,666 ETD:S1,198,666 EFC:$1,165,000 INew TD PB Depth Date J K nd of r g Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official relervoir name(s) Potential test data Well no. Date Reservoir Producing Interval OII or gas Tell time Production Oil on tilt Git per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Grevlty Allowable Effective date correcled \ Drilling Supt. For form p~reparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. I Number all dilly well hlllory forml consecutively j Page no. as they ere prepared for each well. . · . . .. . ARCO ALASKA, INC. P.O. BOX J00S60 ANCHC)RAGE, ALASKA 995J 0 DATE · 6/J 2/90 REFERENCE' ARCO CASED HOLE FINALS t-9 6-6-90 COLLAR RUN 2-3 6-6-90 COMP~ NEUTRON G/R RUN °-t0 6-6-90 COMP NEUTRON G/R RUN '2-t3 6-9-90 COLLAR RUN o -~ 6-8-90 COLLAR RUN S-20 6-7-90 COMP. NEUTRON G/R RUN 3-22 6-7-9~ COMP. NEUTRON G/R RUN 4-t6 6-7-9~ COMP. NEUTRON G/R RUN 4-23 6-8-90 COMP. NEUTRON G/R RUN 4-24 6-8-90 COMP. NEUTRON G/R RUN 5-6 6-t0-90 COMP. NEUTRON G/R RUN 7-9 -6-9-90 COMF'. NEUTRON G/R RUN 7-9 6-9-9~ ~ DIFF. TEMPERATURE RUN 7-34 6-9-90 COMP. NEUTRON G/R RUN J2-~8 6-4-9~ CET RUN t2-t8 6-4-9~ CBT RUN J6-22 5-29-90 CBT RUN t6-22 5-29-90 G/R RUN 46-22 5-29-90 CET RUN WGI-5 6-3-90 PERF RECORD RUN WGI-6 5-30-9~ F'ERF RECORD RUN WGI-7 6-t-90 PERF RECORD RUN WGI-8 6-2-90 F'ERF RECORD RUN ATLAS ATLAS A'I'LAS' Al'LAS ATLAS Al'LAS ATLAS ATLAS ATLAS ATLAS ATLAS Al'LAS A 'i"L A,S' Al'LAS SCH SCH SCH SCH SCH SCH $CH SCH SCH PLEASE SIGN AND RETURN THE AT~A~,W4ED COPY AS RECEIPT OF DATA. RECEIVED BY __~ HAVE A NICE DAY' ' OiL_ & Cons. _ SALLY HOFFECKER APPROVE .... ATO-iS29 TRANS~ DISTRIBUTION CENTRAL FILES CHEVRON ~ D&M EXTENSION EXXON MARATHON MOBIL EXF'LORATION ~ PHILLIPS F'B WELL FILES R & D ~"' BF'X STATE OF ALASKA TEXACO ANCHORAGE, ALAS'KA 99"';-t DATE- 6/7/90 REFERENCE- ARCO CAZED HOLE FINALS' F'WDWi -? ~-=.-?o-q~f.-~ '~'r_.:lilEEZE F'ERF RIlN t , n'" .... - ..... :.- .... ,-, _. .... PWDW!-2 5-29-90 BRIDGE PLUG 3'ETTING REC RUN i, 5" i-ii 6-2-90 COMF' NELJTRON G/R RUN i, 5" i-26, 6-2-9;._-') COMP NEUTRt]N G/R RUN t, 5' i--29 6-.~-'..'/(:) CFIHF' NEUTRON G/R RIJN :5-27 ~-24-9 '=," ¢ ¢ COMP NEUTRON RUN i, .. 4-.S-~'._, _,~-t o-o,.?). .. F'O~T '[_NJ ]"EMP RUN. t, ,..':-~' 6-2 5-2~-9,:.3, COMP NEUTRON RUN 7--i A 5.-24-9¢ COMP NEUTRCIN RUN t 2-i 8 5-.5;3-9,'3 COLLAR RUN i8-t? D-2~-90 COMP NEUTRON -- RUN t , 5:' i8-t 9 ~-2;3-':76, COMP NIEUTI;:ON RUN t , D' F'LEAS'E ~'IGN AND RETURN THE ATTACHED COPY AS RECEIF'T OF DATA. RECEIVED BY HAVE: A NICE DAY! JUN 1 4 1990 SALLY HOFFECKER Alaska Oil & Gas CODS. A T O- ~ 5 2 ~ AF'F'ROVE~ I'RAN$~ 9e2t3 ,~; C'. I-.I ;£CH A'f LA~.: A '1"1_ A.? A T L A ;"_:-' H R £' ~' C H *"CH A- '" '~:' ~'CH S'CH DISTRIBUTION ~~ CENTRAL FILE$ ~ CHEVRON D & M ~ EXTENSION EXPLORATION ~ EXXON MARATHON · ,,- MOBIL PHILLIPS F'B WELL FILES R & D BF'X STATE OF ALASKA TEXACO ~ OIL AND GAS CONSERVATI~ COMMI~5,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing .~. Repair well Change approved program_ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing X Variance _ Perforate _ Other ~X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 452' FSL, 926' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 2418' FSL, 120' FEL, Sec. 18, T10N, R15E, UM - At effective depth 2555' FSL, 17' FEL, Sec. 18, T10N, R15E, UM At total depth , 2568' FSL, 7' FEL, Sec. 18, T10N~ R15E~ UM 12. Present well condition summary Total Depth: measured 9858' feet Plugs (measured) true vertical 9242' feet 6. Datum elevation (DF or KB) RKB 77' 7. Unit or Property name Prudhoe Bay Unit feet 8. Well number 12-18 9. Permit number 82-2O6 .10. APl number ~.~. 0-029-20877 11. Field/Pool Prudhoe Bay Field Prudhoe Bay Oil Pool None Effective depth: measured 9817' feet Junk (measured) true vertical 9205' feet None Casing Length Size Conductor 81 ' 2 0" Surface 2653' 1 3-3/8" Intermediate Production 9242' 9- 5/8" Liner 8 61 ' 7" Perforation depth: measured 9414'-9440', Cemented Measured depth 1880# Poleset 1 1 0' 1900 sx Fondu & 2689' 400 sx PF 'C' 500 sx Class G, 9272' Top job w/100 sx PF 'C' & 300 sx PF 'C' 325 sx Class G 8997'-9858' 9444'-9452', 9456'-9476', 9484'-9504' True vertical depth 110' 2689' 8709' 8468'-9205' true vertical 8839'-8863', 8867'-8874', 8878'-8896', 8903'-8921' Tubing (size, grade, and measured depth 5-1/2"/4-1/2", L-80/N-80, w/tail @ 9032' Packers and SSSV (type and measured depth) Baker 'SAB' pkr ~ 8947'~ Camco BAL-O sssv ~ 2153' 13. Attachments Description summary of proposal X Detailed operation program BOP sketch 14. Estimated date for commencing operation June 1, 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas _ Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed L~ ~;~,L/.~,_.,q , Title Drillin~ Analyst _(') - -- FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so ~e, presentative may witness Plug integrity __ BOP Test ;~1 Location clearance ~ Mechanical Integrity Test ~ ' ' Subsequent form require 10-'/~ Date Approved by the order of the Commission Form 10-403 Rev 06/15/88 LOHN!E C. Rh11'rH IApproval No. x..proved 0o9¥ Co~ Date (--~'Y SUBMIT IN TRIPLICATE DS 12 - 18 WORKOVER PREUMINARY PROCEDURE OBJECTIVES: · Pull the 5-1/2" completion and retrieve the PBR. · Mill and Retrieve the 9-5/8" 'SAB' permanent packer at 8,947'. · Replace the Braden Head and cut, pull and repair the 9-5/8" casing. · Clean out the 7" liner to PBTD at 9,817'. · Run a new 9-5/8" permanent packer and 5-1/2" completion. PRIOR TO RIG-UP: Coordinate with the wireline group and perform the following slickline work: · Pull the Camco SSSV at 2,153'. · Pull the DV from GLM ~'9 at 8,789'. PROCEDURE: 1. MIRU AUDI 4. Kill and displace the well with 8.5 ppg seawater. 2. ND Tree. NU and test BOPE. 3. Shear the PBR. Pull and LD the 5-1/2" completion. 4. Retrieve the PBR and K-anchor. 5. RIH with a mill and PRT. Mill and retrieve the Baker 'SAB' packer at 8,947'. 6. Set a 7" CIBP in the liner at +_9400'. Pressure test the 7" liner and 9-5/8" casing to 3,000 psi. Isolate leak(s) with a 9-5/8" test packer as required. Set a 9-5/8" RBP at +_3000' and spot 50' of sand on top. 7. Run a CBL to find the top of the cement in the 13-3/8" X 9-5/8" annulus. Cut and pull the 9-5/8" casing above the 13-3/8" casing shoe to_+2500'. ND the BOP stack, remove the braden head, 13-3/8" mandrel hanger and pup. Screw in a joint of 13-3/8" casing, cut and weld on a new braden head. Install a new tubing spool, NU BOPE, and tie-back the 9-5/8" casing. Retdeve the RBP at_+3000'. 10. Mill the 7" ClBP and dean out the 7" liner to PBTD at 9,817'.. 11. Set a 9-5/8" permanent packer and 4-1/2" tailpipe assembly at _+8,925'. POH and LDDP. . . 12. Run a 5-1/2" completion string with a treater string and GLM's. Freeze protect and land the tubing. 13. ND BOPE. NU and test the Tree. BHP = 3675 psi at 8800' TVD (8.0 ppg equivalent) 13-5/8" 5000 PS! BOP STACK ANNULAR PREVENTER 6 PIPE RAMS 5 BLIND RAMS 4 TUBING HEAD 3 1.13-3/8' CASING HEAD 2.9-5/8" CASING HEAD 3.5000 PSI TUBING HEAD 4. 13-5/8"- 5000 PSI BLIND RAMS 5.13-5/8" - 5000 PSI PiPE RAMS 6.13-5/8" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 2500 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURETO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD'VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. DAM 8/4/89 REVISION OFll/21/86 BOP SCH FOR:AUDI 4,NORDIC 1 ARC~ AL. AYKA INC. F'~O. BOX i00.360 ANCHORAGE, ALASKA DATE' REFERENCE' ARCO CASED HOLE FINALS t -:25 .3-t 8-9~ F'FC RUN 4-.3 t .3-8-90 TEMP RUN 7-2~ .3--i 4-9(~ F'ERF RECORD RUN ,'-.~o .3-t4 9~ PERF RECORD' RUN ,-~-.? .3 iS-OQ COMPLETION RECORD RUN 9-24 .3-7-9,3 PRODUCTION PROFILE RUN i2-i8 S-i7-9(~ F'ERF RECORD RUN ~ 2-27 S-t 7-9(-) F'ERF RECORD RUN ~4-i8 .3-t8-90 PERF RECORD RUNS ~ 6-4 S-2t -9(D COLLAR RUN ~6-t9 .3-8-9(D LEAK DETECTION RUN PLEASE SIGN AND RETURN THE ATTACHED COF'Y AS RECEIPT OF DATA~ RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-~529 ATLAS CAMCO SCF! $CH SCH CAMCO SCH SCH SCI..I ATLAS CAMCO DISTRIBUTION CENTRAL FILES ~'- PHILLIPS CHEVRON F'B WELL FILES D & M R & D EXTENSION EXPLORATION ~ ~ BF'X EXXON ~ ' STATE OF ALASKA MARATHON .,.~'TEXACO MOBIL ARC(3 ..... ~"" . ~L.~.:~.~I{A, ]:NC F', 0. BOX 'i ;.D'"5:56':'} ANCHORAGE, ALAG'KA DATE' 3-2i-90 REFERENCE' ARCO F'RESZURE DATA ~-~ i--24-9~ BHF'--~TATIC HR~ 4-6 2-5-98 BHF'--$TATIC GRADIENT CAMCO 4-28 ~.-~;~..7-9~D BHF'--$TATIC GRADIENT CAMCO 4--S0 2-ff~3-90 BHP--$TATIC GRADIENT CAMCO 4-Si 3-~-90 BHF'--$TATIC GRADIENT CAMCO 4--S2 ~~.% 9¢ BHP--$TATIC GRADIENT CAMCO 9-8 t-2~-9r5 BHP--$TATIC GRADIENT CAMCO 9-S~ 2-i~-9~ BHF'--$TATIC GRADIENT CAMCO 9-~2 2-~-9¢ BHF'--$TATIC t2-i~ ~+-+--26-89 BHF'--$TATIC GRADIENT CAMCO t'2-tt tt-25-89 BHF'--ZTATIC GRADIENT CAMCO ~2-i4 i2-4-89 BHP--ZTATIC GRADIENT CAMCO ~'2-~8 2-~4-9~ BHF'--ZTATIC GRADIENT CAMCO 12-50 t2-29-89 BHP--FLOWING GRADIENT CAMCO IS-27 2-~6-9~ BHP--FLOWING GRADIENT CAMCO tS-S~ 2-~-9~ BHF'--FLOWING GRADIENT CAMCO 13-33 2-t5-9~ BHF'--~TATIC GRADIENT CAMCO ~6-5 ~-~?-9~ BHP--~TATIC GRADIENT CAMCO F'LEAZE SIGN AND RETURN THE ATTACHED COPY A,S RECEIPT OF DATA, RECEIVED RECEIVED BY __~__~ MAR ~ ? I990 HA YE A N Z CE DA Y ! Alas~a.Oil .S Bas go~s. ~~S~ ~ ZALLY HOFFECKER ~Q~_~ APPROVED(~__ AT0-t529 TRANS~ 9e~t7 DISTRIBUTION CENTRAL FILES ~ ' PHILLIPS CHEYRON F'B WELL FILES D & M ~ ~ R & D EXTENSION EXPLORATION ~ BPX EXXON ~ STATE OF ALASKA MARATHON '~ TEXACO MOBIL ARCO Alaska, In Prudhoe B~_. Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 7, 1990 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-18, Approval No. 82-206/9-416 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Sincerely, D. F. Scheve DFS/CMH/jp Attachment CC: J. Gruber, ATO-1478 PI(DS 12-18)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASK"-'31L AND GAS CONSERVATION (--' ~IMISSION t'~,,~.; REPOR'I OF SUNDRY WELL OPERATIONS' 1. Operations performed: Operation shutdown Stimulate Plugging Perforate Pull tubing Alter casing Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 452' FSL, 926' FEL, Sec. 18, T10, R15E, UM At top of productive interval 2814' FSL, 120' FEL, Sec. 18, T10N, R15E, UM At effective depth At total depth 2568' FSL, 7' FEL, Se(::. 18, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service Other X 6. Datum of elevation(DF or KB) 77 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-18 9. Permit number/approval number 82-206/9-416 10. APl number 50 - 029-20877 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9858 feet 9242 feet Plugs(measured) Effective depth: measured 9817 feet true vertical 9205 feet Casing Length Size Conductor 80' 20" Su dace 2612' 13-3/8" Production 9195' 9-5/8" Liner 861' 7" Junk(measured) Cemented 1880# Poleset 1900 sx Fondu & 400 sx PF 'C' 500 sx CI 'G' & 300 sx PF 'C' 325 sx CI 'G' Measured depth True verticaldepth 80' 8O' 2689' 2689' 9272' 8709' 9858' 9242' Perforation depth: measured 9414-9440'; 9444-9452'; 9456-9476'; 9484-9504' ± --* true vertical 8839-8863'; 8867-8874'; 8878-8896'; 8903-8921' :":~:~'~!~.~ '.'iii & (las OOnS~ C0h!r~isSiO,~ A,churaga Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8960' MD; 4-1/2", 12.6#, N-80, PCT tail @ 9032' MD Packers and SSSV (type and measured depth) Baker SAB Hydrostat packer @ 8947' MD; Camco Bal-0 SSSV @ 2153' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attachment Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 0 0 0 1300 910 3800 Tubing Pressure 0 237 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ,'"/~,~', -¢~-~/¢_.u~Title Operations Engineering Manager Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE DS 12-18 JET PUMP INSTALLATION DESCRIPTION OF WORK COMPLETED 10/2/89 - 10/3/89: MIRU, and RIH to pull LGLV's in stations gl, 2, 3, 5 & 10. Located DGLV's in stations gl, 2, 3, & 5. Station gl0 left open for Packoff / Jet Pump installation Located nipple reducer in landing nipple. POOH. Rigged down. 10/7/89 : MIRU, and PT BOP's to 3500 psi. RIH and set tubing patch at 8860' MD (top packer) to 8880' MD (bottom packer) over station gl0, located at 8865' MD. POOH. Rigged down. 10/9/89 : MIRU, and PT equipment to 2500 psi. RIH and latched sleeve in GLM packoff. POOH w/ sleeve. RIH w/Jet pump , and located assembly at 8830' MD. POOH. RD. 10/11/89 : MIRU, and RIH to latch Jet pump. POOH w/Jet pump assembly. Attached SSSV to assembly, and RIH to relocate Jet pump assembly at 8827' MD. POOH. RD. 10/19/89 : MIRU, and PT to 3000 psi. RIH to pull Jet pump. POOH w/Jet pump. Corrected problems with the pump assembly, then RIH and relocated pump at 8828' MD. POOH. Rigged down. Jet pumped and produced the well. The pump was pulled and a squeeze was performed in February 1990, under Sundry Approval g 9-1077. D A 7' E · '3- 2 .- 9 (s:, F' ]: 'F.':.:/F'i:;.'.ODijC-[' :[ F'JN F:'ROF I LE .iD !:.- ,.-- T'BQ CUTTER ,P ~.-r -F~.'./.~.,-,~"~T.,!, r r, '..J ,_.._. _. i f" 'r, .,. ,..,, ,T nk, F' R O !::'-r.~. i_E F'FC-CCL. C O L i_ A R ..-'" .":' ~!": F,' i:: i N J E C T ! 0 N i::' i:;.: 0 F' I L. E Z N J E r': 'T i O NF' R O F- ]': L_ E I N J '.,-.':' C 'i".,. -...'r r',, N, F' -'.:-;.: 0 ,r-" ?.,. ,__,..~ ~::' ;-.FiLl F'EPF ,-, c,-, ,---, ::, ;-,, TBG PATCH RECOF.'.D P' ~-:'^~-" SiGN AND F'.:E;-U,~'N THE ATTACHED nr',::,v " ,R £; F ATA .... ._~.:,~.._ , -' ,_.U, , A:':: E [:IF'T 0 D ' ~ F,:ECEZViED BY __~ HAVE A NiCE DAY'! MAR - 8 !990 · :" /'- ' i %: f.'f'~F-:'~'E:".--',.'/F..--"', -" ':' :'~ '- ~-' ' ~:" ~ ' '-'-'" ~-" Alaska 0il & Gas Cons. ,, .... --eom~SSi0-~ ¢'., 'r i'"~ -- ~ ~.' 9 o T F,' A N "':' :~- 9 ;'.'~; c.:, A ....... ~"-' Anchorage DISTRIBUTION -~' CEN ~ i;.:Ai, _ FILEZ' -"-,,.r':_ H E V R ri_. N D & M · =- :'",'TENZ l ON EXF'LORAT l ON · ~ ~' ¥ ~' 0 N MARATHON ,.~- MOBIL. F'H ILL i P ::':,' '"'i F'B WELL F'~.~.-~ R * ~ ' Bi:;'X STATE nF aL,".~2KA TEXACO AF;.:CO ALA,S"KA, INC.. P: 0, BOX i E:";E:' .5 ;", '3' ANCHORAGE, ALA~TKA DATE ' 2-i -96, I;.:EFEF,'ENCE' ARCO CA'Z..'ED HOLE i='iNAL.~.' - - ,.., u,... L :~. R, F'ER~- · 5 -~¢';; t 2,'-",-9n ;---n, -" '/ :" RUN '~ ~'" 4-i ':';' i -i ~ c,,..-,, iNJECTiON,.,--£,U, iNNER I.;,'lj¢..! ,i ,:,-, · '*,-- ~ E: i -,':.- ~ ;:''- 'f'E;.*iP RLJN -- · ._. ,j ~.' 6-'-2 i _?¢:;_c,n COLI AR I;;~ iN ~ ~; · ~ --' ," ','" ~ ~.-' 8-2 i-?'''*'-¢';'¢':;.,_... ...., VERTiLOG i:;,:UN i, ~""~, -'-.~ ..... '"- PtJN i., _; , ,.~ I -"~ e-9,'-"~ COi'~i-'LE'¥T(')N RECORD , """ ':~.. - i '~. i - '~, '7 - ':;', ,'-',._. V E F:'.: T l L ~'"~.. G. ,', ,_-..; _,.~';' ,.': ...,°, ,'~ R U i"'.J, i ,...,~":" 9-i 'i i-i '7-~',":;, ... VERT:[LOf]. "'?" ;, i';UN 'i , ';'".; · i i -6 i (')-?-89 F'EF;.:F RECORD RtJNS' i &2, i 2-i 8 i ,3,-?-89 n;'~i! ¢-~, 'f'O SET AVA PATCH i;,'IJN · _,- ~,_.: z_. ~...~.,; ,., ..~.. 4 .5-.5'2 ! -?-9,:) CCL RUN. i 4--.5i t -i 4-9,:':.'- PER. F R. ECORD RUN i , ~" i 6-2 !-..-'"7-~n, .., COLLAR/F'ERF R. UN t PLEASE i-~.iGN AND RETIJRN THE ATTACHED COPY A3' RECEIF"f' OF' DATA. RECEIVED BY HAVE A NICE DAY! ~r.-~L,_ ~ HOFFECKER ATO- i 529 FEB - 9 990 · gii& Bas'Cons. AF'PROVED ~_ DISTRIBUTION CENTRAL FILES ~'~,-~' ~.I',~UN D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL PI4 ILI_I P~" PB WELL FILES R'& D BPX STATE OF AL.A;:£KA TEXACO ;"t ] i_id,.:- H F:..' ~,* !.-I, R,S' A'¥'i.. A;:¢ :'::'~ "f' L.. A ,? :!;' C A f' L. A A"!" I_ A ;:? HL,? H F;.'. ~.: HR,? 5' C I-'t A TI_A;:? ARCO Alaska, Inc. Prudhoe Ba~ ,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager December 15, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-18, Permit No. 82-206 Dear Mr. Chatterton' Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/CMH/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 12-18)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA .-----., 0 RIG IN A L ALASK,~-'~LAND GAS CONSERVATION C, ,MISSION APPLIOA, ION FOR SUNDRY APPROVALS 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 Vadance Perforate X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. BOX 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 452' FSL, 926' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 2418' FSL, 120' FEL, Sec. 18, T10N, R15E, UM At effective depth At total depth 2568' FSL, 7' FEL, Sec. 18, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 9858 feet Plugs(measured) 9242 feet Other X feet 6. Datum of elevation(DF or KB) 77 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-18 9. Permit number 82-206 10. APl number 50 - 029-20877 11. Field/Pool Prudhoe Bay. Oil Pool R ECIEIV tT:O Effective depth: measured 9817 feet true vertical 9205 feet Casing Length Conductor 80' Su dace 2612' Production 9195' Liner 861' Perforation depth: Junk(measured) Alas1(8 0il & G~ts- . Anchorage Size Cemented Measured depth True vertical depth 20" 1880# Poleset 80' 80' 13-3/8" 1900 sx Fondu & 2689' 2689' 400 sx PF 'C' 9-5/8" 500 sx Cl 'G' & 9272' 8709' 300 sx PF 'C' 7" 325 sx CI 'G' 9858' 9242' measured 9414-9440'; 9444-9452'; 9456-9476'; 9484-9504' true vertical 8839-8863'; 8867-8874'; 8878-8896'; 8903-8921' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, CT @ 8960' MD; 4-1/2", 12.6#, N-80, PCT tail @ 9032' MD Packers and SSSV (type and measured depth) Baker SAB Hydrostat packer @ 8947' MD; Camco Bal-0 SSSV @ 2153' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation December 1989 16. If proposal was verbally approved Oil. x Gas Name of approver Date approved Service 17. I herel:)y)certify that, the foregoing is true and correct to the best of my knowledge. Signed ~//~~1~ Title Operations Engineering Manager FOR COMMISSION USI= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- ~d.~ 15. Status of well classification as: Suspended IApproval No. Approved by order of the Commissioner UlilGINAL SIGHED :aY LONNIE C. SI~llTH Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPL DS 12-18 CTU Cement Squeeze Intended Procedure AFE # AP 6125 Subcomponent AFE # KS 1401 Obiective: To cement squeeze and reperforate Zone 4 perforations and channel for WSO. 1. RU WLU, test lubricator, and pull SSSV. Pull jet pump assembly from DWP packoff at 8856' md. Set TPI blanking sleeve in DWP assembly. POH and rig WLU down. 2. RU pump unit and do fullbore 12% HCL acid treatment to remove scale/cement from perforations and channel. Overdisplace acid with seawater. 3. RU coiled tubing unit and test lubricator/BOPS. 4. Squeeze cement the perforations 9414' - 9504' (overall) BHCS (1-7-83) and contaminate cement in wellbore. Wait on cement _+ 18 hours after squeeze. 5. Clean cement/contaminant from wellbore to PBTD of ___ 9817' md. RD CTU. 6. After +_ 2 weeks, RU ELU and reperforate the Zone 4 intervals: 9414-40', 9444- 52', 9456-76', and 9484-9504' BHCS, FSD using 2-1/8" gun. RD ELU. 7. RU WLU and pull sleeve from DWP. Reset jet pump assembly with SSSV. RD WLU. 8. Bring well in, test and return to production. Well Data BHP: 3700 psi @ 9459' md (8879' tvd) BHT: 205° F @ 9459' md Min ID: 2.25" SEL nipple @ 9020' md Capacity: Tubing to 9032'md tail = 209 bbls 7" casing to btm perf @ 9504' = 17.5 bbls Rathole volume: 9504-9817' md = 11.6 bbls Total well capacity: 238.1 bbls H2S: 8 ppm 11-89 · ~ .~ , ~ [?,~_~ (]OilS-. COT~,.,~ ~'~ Anchorage Spud Date.. 12-26-82 ~riginal RKB~ 77' fop of Sadlerochit: 9406' Maximum Hole Angle: 334 Angle Through Sod.' Annulus Fluid: 9.6 NaCI & Diesel Reference Log: BHCS 1-7-83 ANNULAR COMMUNICATIONS: PROBLEM WELL. 9 5/8' X 13 3/8' COMMUNICATION TO AL All Depths are RKB MD to Top of Equipment. - Ar o Alaska Inc.- Prudhoe Bc' leld · ?1#: ~20877-(30 Well Type: Producer Completion Date: 1-11-83 New I~ Workover 1'3 Hanger Type: FMC Gen III Hanger: 31' 259 12 Jewel~ I 2153' 2 8856' 3 8933' 4 8947" 5 896(7 6 902~ 7 9031' 8 903Z 9 10 11 6 7J~ 10 Camco BaI-O SSSV Nipple ID-4.625' AVA 'DWP' Straddle Pack Off Baker PBR Assembly Baker SAB Hydraset Packer Crossover: 5-1/2 x 4- I/2 ~ DI~5 Nlpple ID=3.813" Baker Bullet Nose Shearout Sub Tubing tall: 4-1/2' ELM tubing tall not logged Minimum Ii~, Cc~ng and Tubing AVA 'DWP' Stradcle Pack Off ID=2.812' 13 3/8" 72s* L-80 0 2689 9 5/8" 47e L-80 0 9272' 7" 29~ L-80 8997' 98,58' 5 1/2" 17~ L-80 0 8960 4 1/2' 12.6~ N-80 896(7 9032r Casing Casing Liner PC Tub~g PC Tub~3g Taa 288T (2887') 1 CA-MMIG CA DUM 4830' (48293 2 CA-MMIG CA DUM 6274' (6137) 3 CA-MMIG CA DUM 7334' (7038~ 4 CA-MMIG CA DUM 7981' (7603') 5 CA-MMIG CA DUM 8(]59'(7671') 6 CA-MMIG CA DUM 84~ (790F) 7 CA-MMIG CA DUM 8479' (80283 8 CA-MMIG CA DUM 8789' (82903 9 CA-MMIG CA DUM 8865' (83553 10 CA-MMIG 10-3-89) RK RK RK RK RK RK RK RK RK PBTD = 981)" TD = 9858' 11 9414-9440 4 25 4 9-24-83 9;~L94~ 4 8 4 9-24-83 9456'9476 4 ~ 4 9-24'83 9484'9504 4 2D 4 9'24'83 Datum 8700' SS = 9345' ~ 8a30' SS = 94,%' MD Revision Date:. 10-8-89/by GWJ Reason: Set AVA 'DWI~ Straddle Padc(~ Previous Revision: 10-5-89 Well 12-]8 6 5 4 3 2 COILED TUB[Nt~ UNIT BOP E0U ! PMENT 1. 5000 PSI 7" WELLHEAD CONNECTOR FLAhO£ 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI4 1/16" STUFFING BOX 3 L i HIRELINE BOP EOUIPHENT 1. 5000 PSI ?" WELLHEAD CONNECIOR FLANGE 2. 5000 PSI WIRELIN[ RAMS (VARIAEIL[ SIZE) 5. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ARCO ~laska, Inc. Prudhoe Ba; 3ineering Post Office Bvx 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager May 23, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-18 Permit No. 82-206 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. This is a resubmittal on a corrected form. Very truly yours, D. F. Scheve DFS/CMH/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 12-18)W1-3 R Er'_ C E I'¢ MAY 2 5 1989 Alaska 0il & Gas Cons. Comrnissior~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompany AR3B--6132-C STATE O~ ALA:SI<,A ,ALASKA~:q~L AND GAS GONSERVAT~ON G~,M~$$~ON APPL O/. FOR SUNDFIY Al-, ROVAL$ 1. Type of Request: Abandon Suspend ~ Alter casing Repair well Change approved program 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 452' FSL, 926' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 2814' FSL, 120' FEL, Sec. 18, T10N, R15E, UM At effective depth At total depth 2568' FSL, 7" FEL, Sec. 18, T10N, R15E, UM Operation shutdown Plugging Pull tubing Variance 5. Type of Well Development . X. Exploratory .... Stratigraphic ---. Service Re-enter suspended well Time extension Stimulate perforate Other X 6. Datum of elevation(DF or KB) 77 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-18 9. Permit number 82-206 10. APl number 50 - 029-20877 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9858 feet R E [ E IV E ~ true vertical 9242 feet Effective depth: measured 9817 feet v'lkY 2 5 ;]9 9 true vertical 9205 feet Junk(measured) Alaska 0il & Gas Corm. CommissiorJ Casing Length Size Cemented IVleasure~l~le True vertical depth Su dace 80' 20" 1880# oleset 80' 80' Intermediate 2612' 13-3/8" 1900 sx Fondu & 2689' 2689' 400 sx PF 'C' Production 9195' 9-5/8" 500 sx Cl 'G' & 9272' 8709' 300 sx PF 'C' Liner 861' 7" 325 sx CI 'G' 9858' 9242' Perforation depth: Plugs(measured) measured 9414-9440'; 9444-9452'; 9456-9476'; 9484-9504' true vertical 8839-8863'; 8867-8874'; 8878-8896'; 8903-8921' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, CT @ 8960' MD; 4-1/2", 12.64, N-80, PCT tail @ 9032' MD Packers and SSSV (type and measured depth) Baker SAB Hydrostat packer @ 8947' MD; Camco Bal-0 SSSV @ 2153' MD 13. Attachments Description summary of proposal .x Detailed operations program BOP sketch x 14. Estimated date for commencing operation I May 1989 16. If proposal was verbally approved Name of al)prover Date approved Service 17. I hereb,,v'jcertify that t~ foregoing is true and correct to the best of my knowledge. // _/J/J/? Signed ,~. ~? z~_~///~,... Title Operatk)ns Engineering Manager FOR COMMISSION H~I~ ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test .. Subsequent form. re.,q.u~ 1~ L0~m~ ~.0~i~E~'- St~n,~ Approved by order of the Commissioner 15. Status of well classification as: Oil ~ Gas Suspended . .-"-,p pr oved Copy Returned Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE DS 12-18 Jet Pump Installation Intended Procedure Proposal: To install jet pump assembly in well to provide artificial lift assistance for production maintenance. The assembly will be installed across an existing gas lift mandrel. Power fluid(water)will be pumped down the tubing/casing annulus and the well will be produced up the tubing. The annulus recently passed a mechanical integrity test. 1. RU WLU, test lubricator, pull safety valve, pull dummy valve from gas lift mandrel @ 8865' and pull plug from DB-6 nipple @ 9020' md. 2. Install reducer nipple in DB-6 LN @ 9020' md. RD WLU. 3. Set tubing patch with ported nipple across GLM @ 8865' md using conductor line unit. 4. With WLU, install jet pump assembly in ported landing nipple @ +8865' md. 5. Place well on production, using SW injection system for power fluid source pumped down the. 5-1/2" x 9-5/8" annulus. Test pump without safety valve. 6. After satisfactory test, RU WLU, pull jet pump and rerun jet pump assembly with safety valve screwed into lower end of pump. Safety valve will be held open by power fluid pressure from the annulus. 7. Return well to production on artificial lift. Well Data: BHSP 3700 psi @ 9459' md BHST 205° F @ 9459' md H2S: none reported Minimum ID: 3.813" @ 9020' md RECEiVE, E;:, MAY 2 5 ]989 Alaska Oil & Gas Cons. Commissio~ Anchorage RECEIVED Oil & Gas Cons. Anchors. ge SpUd Date: 12-26-82 Original RKB: 77' Top of Sadlerochit: 9406' Maximum Hole Angle: 33~ Angle Through Sad.. ~,nnulus Fluid: 9.6 NaCI &Dlesel Reference Log: BHCS 1-7-83 All Depths are RKB MD to Top of Equipment. Arco Alaska Inc. - Prudhoe Ba~-4;ield ~'~,PI#: ~-20877-00 Well Type: Producer Completion Date: 1-11-83 New !~ Workover I-1 Hanger Type: FMC Gen III Hanger: 31' Jewelry 1 2153' 2 89'33' 3 8947' 4 8960' 5 9O'2O' 5 9O2O' 6 9031' 7 9032' Camco BaI-O SSSV Nipple ID-4.625" 11 10 5 6,7 8 9 10 11 25-~ Baker PBR Assembly ~ ~, Baker SAB Hydroset Packer ~ ~'C ~ i~/ ~i Crossover: 5-1/2 x 4-1/2 Camco DB-6 Nipple ID--3.813" ivIA¥ 2 5 ]989 Set plug in DB-6 nipple 3-9-87 Baker Bullet Nose Shearout Sub Alaska 0il & G:~s Cons. C;01Tim~o~ _. Tubing tail: 4-1/2" Anchorage ELM tubing tail not logged yet. Minimum ID: 9020" Camco DB-6 Nipple ID-3.813" Casing and Tubing Size ~ ~ To~ Bottom JZ~T.C~tLG~ 13 3/8" 72# L-80 0 2689' Casing 9 5/8" 47# L-80 0 9272' Casing . 7" 29# L-80 8997' 9858' Uner 5 1/2" 17# L-80 0 896(7 PC Tubing 4 1/2" 12.6~ N*80 8960' 9032" PC Tubing Tail Gas Uff Infom~atlon ~ Stn. Mandre~l Valve '~y.g.~ Latch Port ~z: . 2887' 1 CA-MMIG' TEL N15R RK 1/4 4830' 2 CA-MMIG TEL N15R RK 1/4 6274" 3 CA-MMIG TEL N15R RK 3/8 73,~" 4 CA-MMIG CA Dummy RK 7981' 5 CA-MMIG TEL N15R RK 7/16 8059' 6 CA-MMIG CA Dummy RK 8409' 7 CA-MMIG CA Dummy RK 8479' 8 CA-MMIG CA Dummy RK 8789' 9 CA-MMIG CA Dummy RK 8865" 10 CA-MMIG TEL . Orifice RK 7/16 TRo 1663 1696 1863 12 12 Perforation Data Interval ~ FT SPF 9414-9440 4 26 4 9 .,~fi. ~-9452 4 8 4 94,56-9476 4 20 4 9484-~ 4 20 4 9-24-83 9-24-83 9-24-83 9-24-83 PBTD = 9817' TD --- 9858' Datum 8700' SS = 9345' MD 88[]0' SS = 9456' MD Revision Date: 5-1-87 (GD#47) Reason: GLV Design Previous Revision' 3/87 ~ 12-18 6 5 4 2 CO]LED TIJB ING BC)FI' EOU ] PI'I,E:NT 1. 5000 PSI ?" WELLHEAD CONNECTOR rLAhG£ 2. 5000 PSI4 1/16" PiP[ RAMS 3. 5000 PSI4 1/6" HYDRAULIC SLIPS 4. 5000 PSI4 1/6" SHEAR RAMS 5. 5000 PSI4 1/6" BLIND RAIDS 6. 5000 PSI4 1/16" STUFFING BOX 2 RFCFIV'~r'~ MAY 2 5 Oi! & Gas Cons. Commission Anchorage 1 RECEIVED 1. 5000 PSt 7" WE L L HEAD CONNECIOR r LANG£ 2. 5000 PSt WIRELINE RAUS (VARIABLE SIZE) .3. ~OOO PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF F',.O. BOX i "'1'" : 9 9'.:. F,r.~t. HORA(]-E ALA~'K A DATE - 4-26-89 __ REFERENCE' ARCO CA~'ED HOLE FINALS i -5 4-7-89 t .-! (3 4-7-89 i -t 2 4/5-6/89 t-t7 4-8-89 ~'---_.. ~ ;'~,~ S-27--89 5-i i 4-t-89 6-S 4-i -89 7.-22 S-~1 -89 c'-i, i '5-~3-89--. i I-8 4-5-89 ~ i8 4 i0 89 t 4-32 t5-6 4-9-89 t 8-2(3 4-3-89 PRODUCTION PROFILE PRODUCTION F'ROFILE/F'ITS' PRODUCI'ION PROFILE PRODUCTION PROFILE TEMP/GAMMA RAY GAMMA RAY/i"EMF' SURVEY GAMMA RAY/TEMP SURVEY GAMMA RAY/TEMP SURVEY PRODUCTION PROFILE INJECTION PROFILE PITS GAMMA RAY/i"EMP SURYEY LEAK DETECTION GAMMA RAY/TEMP SURVEY RUN RUN RUN RUN [-:.'.UN RUN RLJN RUN RUN RUN RUN RUN RUN RUN F'LEA~'E SIGN AND REI'URN THE ATi'ACHED COPY A£' REE;EIF'T OF' DATA' RECEIVED BY -~ -D- -~I_F-_L~L~ SALLY HOF'FEC' -- ' AF'F'ROVED _ ATO-i 52° ~ Alaska Oil & Gas Cons. Commiss;oll TRAN$~ 89 · Anchorage CAMCO CAMCO CAMCO CAMCO CAMCO CAM(]{] CA~qCO CAMCO C: A i'.i C O CAMCO CAMCO CAMCO CAMCO CAMCO DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL F'ILE~ R & D BF'X STATE OF ALASKA TEXACO * THE CORRECT AF'I~ FOR 1-5 IS 50-029-20G76. ARCO ALASKA, INC F:'~O, BOX i ANCHORAGE, ALASKA 995t t: DAI'E' 4--26-89 REFERENCE: 4-29 5-'-i ¢,' 6--S tt-i6 t i-i '? i i -..t 8 i t -24 i'2-. t 8 t ")-"~6~. ,.. i 3-t iS-te iq-ii i 4-i :2 i -1--2i i S.-i eA i5-i9 t 5.-2:2 I:- .-) · i .>'- .. D t8-4 t8--8 PLEASE ARCO PRESSURE DA I'A 4-i-89 BHP--$1'AI'IC GRADIFN'T' Ol'I 2-'22-89 BHF'--FLOWiNt~ GRAD.lENT l.,AH[, ..) - ") "~ ' C ... S-.~., -.8 ? nHF: ..... SI'AI'IC GF~ADIENT CAMCO 4-'t '-89 BHF ..... STATIC GRADIENT CAMC, O 4-t7-89 BHF ....... STATIC GRADIENI' CAHCO 4-t7-89 BHP--S'FATIC GRADIENT CAHCO 4-"i7-89 BHF ....STAI'IC GRADIENT CAMCO S-"2~-89 BI"IF ..... STATIC GRADIENT CAMCO 4-i~-89 BHF ...... ,S'I'AI'IC GRADIENT CAMCO 3'-3G-89 BHF ....STATIC GRADIENT O'FIS 4-2-89 BHF ...... STATIC GRADIENT OTIS 4-3-89 BHP--STATIC GRADIENT OTIS 4-t-89 BHP--SI'Ai'IC GRADIENI' Ol' I,S' 4-3-89 BHF'--SFATIC GRADIEN'F 4--4-89 BHF ....STATIC GRADIENI' CAMCO.. 4-2-89 BHF ....S'FATIC GRADIENT CAMCO 4-'2-89 BHF ....STATIC GRADIENT CAMCO 4-2-89 BHF ..... STATIC GRADIENT CAMCO 4-3-89 BHF ....STATIC GRAD]ZEN'[ CAMCO 3-29-89 BHF'--S-fAI'IC GRADIEN I' OTIS 3-29-89 BHF ..... STATIC GRADIENT CAMCO 3-'3~-89 BHP--STATIC GRADIEN F O'I' I,~ S-'29-'89 BHF ....STATIC GRAI)IENI' CAHCO S-29-89 BIqF'--SI'AT I C GRADIENT CAMCO N AND REI'URN THE AT"fACHED C.)FY AS RECEIF'T OF I)AI'A RECEIVED BY HAVE A NICE DAY! SAL. LY HOFFECKER AT0-t529 , ~ ~ . FRANS~ 891~77 ~_~Im Oil & G~s Co,~. Commi~sio~ '" ' Anclmrage DISTRIBUTION CENTRAL FILES ~" PHIl_LIPS CHEVRON F'B WELL. FILES D & M ~ R & D FXTEN$ION EXFLEJRAIION ~' BPX EXXON ~ STALE OF' ALASKA MARATHON ~' I'EXACO MOBIL ARCO Alaska, If, Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 August 1, Reference: 1984 ARCO Cased Hole Finals DoS. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D°$o D.S. D.S. D.S. D.S. D.$. 3-6~-'~ 6-10-84 Diff Temp 3-19--~ 5-25/26-84 Spinner Survey 3-22~ 6-29-84 Spinner Survey 6-10'- 7-4-84 Temp Log 7-3-- 7-6-84 Temp Survey 7-18--~ 7-4/5-84 Spinner 7-24- 4-19-84 Spinner 9-18--- 6-21-84 Diff Temp 12-15'-~ 4-13-84 Spinner 12-18- 4-14/16-84 Spinner 13-1/' 6-17-84 Diff Temp 13-10~'6-22-84 Temp Log 13-12-~ 6-18-84 Diff Temp 13-13~'-5-31-84 CFS/Spinner 13-16J'~4-12-84 Diff Temp 13-27>/ 6-2-84 CFS/Spinner 13-28--- 6-3-84 CFS/Spinner 13-28~-- 6-3-84 Temp Survey 13-28f 7-8-84 Temp Log 13-33~- 6-22-84 Diff Temp 13-33-f 6-23-84 Spinner Log 14-3~ 6-30-84 Diff Temp 14-21- 7-7-84 Caliper Log D.S. 14-24/ 3-25-84 Caliper Log D.S. 14-34-'/ 5-19-84 Spinner Log D.S.. 17-10j 6-17-84 Diff Temp ~~~l.ease sign and return the attached copy as data. Run 1 5" Otis Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" GO Run 1 5" Camco Run 1 5" GO Run 1 5" Go Run 1 5" Camco Run 1 5" GO Run 1 5" GO Run 1 5" GO Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 4 5" Camco Run 1 5" Camco Run 1 5" Camco receipt of Kelly McFarland ATO-1429F · Trans. 9301 DISTRIBUTION Chevron D & M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mob i 1 Mobil E Phillips Prudhoe Bay Well Files R& D Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 June 14, 1984 ~ Reference: ARCO Cased Hole Finals ,,- D.S. 1-21 5-4-84 ,-D.S. 1-25 5-26-84 ~D.S. 2-17 3-28-84 ~D.s. 3-13 5-21-84 ,-D.S. 3-27 5-18-84 ,,D.So 4-1 5-6-84 ,-D.S. 4-4 5-14-84 ~D.S. 5-8 ~-5-84 ,-D.S. 6-4 5-30-84 ,-DES. 7-20 4-18-84 ,,D.S. 12--16 5-20-84 ,-D.S. 9-4 5-7-84 ~,,D.S. 7-25 4-22-84 ~D.S. 7-22 4-20-84 ~D.S. 12-18 6-1-84 ,-D.S. 12-23 5-19-84 ~D.S. 14-2 5-3-84 ~D.S. 14-25 5-18-84 ,'D.S. 14-32 5-20-84 ~D.S. 14-34 6-5-84 ,,, D.S. 17-1 5-24-84 Epilog Spinner Log Spinner Log/Basket Flowmeter CFS/Spinner ACBL/VDL/Signature/GR Epilog CH CNL Epilog CP1/TDT-M w/listing Spinner PLS Epilog Spinner Spinner CPL/TDT,M w/listing ACBL/VDL/Signature/GR Epilog CFS/Spinner CFS/Spinner CPL/TDT-M w/listing Collar/Perf Log Run 2 5" DA Run 1 5" Camco Run 2 5" Camco Run 1 5" GO Run 1 5" DA Run 2 5" DA Run 1 5" GO Run 1 5" DA 5" Sch Run 1 5" Camco Run 1 5" DA Run 1 5" DA Run 1 5" Camco Run 1 5" Camco 5" Sch Run 1 5" DA Run 3 5" DA Run 1 5" GO Run 1 5" GO 5" Sch Run 1 5" GO ' P/~lease sign and return the attached copy as receipt of data. Don't Forget Dad on his day! Kelly McFar land ATO-1429F Trans. # 242 DISTRIBUTION ~hevron D & M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mobil Mobil E & P Phillips Prudhoe Bay Well Files R & D Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 June 14, 1984 Reference: ARCO Magnetic Tapes --~-34 4 30--84 ~- D.S. 14-34j 4-30-84 --D.S. 9-23~ 3-4-84 . D S ~-~Q ~'-~-Q~' .~D.S. 12-18 / 4-22-84 .~.S. 12-23J- 6-7-84 ~.~DoS. 4-4~ 6-11-84 TDT Lis #69200 w/listing OH #69242 w/listing TDT~.~ns~mr ~*=m'~' --~:-ti -~ wi ~ ~g TDT Lis #69193 w/listing OH #281794 w/listing CH/CNS #281792 w/listing Run I Sob-- Run 1 Sch Run 1 Sch Rur~-2---S~h---- Run 2 Sch GO GO lease sign and return the attached copy as receipt of data. Don't Forget Dad on his day! Kelly McFarland ATO-1429F Trans. # 230 DISTRIBUTION Chevron D & M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mobil Mobil E & P Phillips Prudhoe Bay Well Files R & D Carolyn Smith Sohio .State of Alaska ARCO Alaska, Inc. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 June 1, 1984 Reference: ARCO Cased Hole Finals D.S. 1-9~ 4-20-84 s. ' ~.s. ~-~.~× ~-~-~ ~U~ D.S. 4-13~4-~ ~ D~- i~ 4- 2~ TDT CH CNL TDT CN/MSN/GR CET Log TDT TDT TDT ~ PLS PLS u . ~ . I - z z ~,/ / 4--2-2-9---84 ~.s. ~-~~,~-~-~ ~.s. zz-~ ~-~-~ ~~ D.S. 12-17~ 5-20-84 Spinner ~~. ~% D.S. Z2-Z8~4-22-S4 TDT ~ ~/~~D.S. 12-21~z 5-2-84 AC~LZVDL/Signature/GR ~ D.S. 13-16~ 4-12-84 Spinner ~ D.S. Z~-~/~ S-~-S~ C./~S./S~ ~ ~~% 4-30-84 TDT D.S. 16-8~, 5-10-84 CET D.S. 16-9/J 5-13-84 Collar/Perf NGI ~ZZ~/ 4-Z7-84 CET ~' 4- Z9-84 EPL 5" Sch Run 5 5" GO Run 2 5" Sch Run 2 5" DA Run 1 5" Sch Run 3 5" Sch Run 1 5" Sch Run 1 5" Sch Run 1 5" DA Run 1 5" DA Run 1 5" GO Collar/Perf Log S i~r/Basket Flw Mtr.. Run 2 5" Camco · DT _3 Run 2 5" Sch Run 1 5" Otis Run 2 5" Sch Run 1 5" DA Run 1 5" Camco Run 3 5" DA Run 1 5" GO Run 1 5" Sch Run 1 5" Sch Run 1 5" Sch Run 1 5" GO Run 1 5" Sch Run 1 2" Sch Please sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. #221 D&M Have A Nice Day[ DISTRIBUTION .. "~/s. Co~s. ~_ · N Mob~[ ' '~nCh . t~u~ . M0bil E & P °rage Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Phillips Prudhoe Bay Well Files R & D Carolyn Smith Sohio State of Alaska aRGO AlaS~,.~ ' , ' : .: ' l'v ~' A:~,~,'*" ~Q -:~'~?.:JC.~par'v ARCO Alaska, Inc./--". Post Office .. 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 17, 1984 Reference: ARCO Pressure Data D.S . D.S. D.S. D.S. D.S. D.S D.S D.S D.S D.S D.S D.S D.S. D.S. D.S. DoS. D.S. D.S. D.S. D.S. D.S. D.S. 3-19f 4-9-84 3-22/ 4-9-84 3/ 3-2 4-9-84 4-!/ 3-17-84 6-4 f 1-25-84 1-25-84 6-7f 1-15-84 1-15-84 6-18/ 12-27-83 6-23/ 8-11-83 7-20/ 4-18-84 7-21/ 4-29-84 7-22 / 4=20-84 4-20-84 7-24 4-20-84 4-21-84 7-25/ 4-22-84 7-26' 4-28-84 12-7A/ 4-14-84 4-14-84 12-15" 4-13-84 4-13-84 12-18f 4-15-84 4-16-84 13-13/ 4-12-84 13-15/ 4-.13-84 13-16/ 4-12-84 13-33/ 41-5-84' 18-7 '/ 3-14-84 3-14-84 se sign and return Static Camco Static Camco Static Camco Static Camco PBU GO Common Data Base Report PBU GO Common Data Base Report Horner Plots w/listing Sch Horner Plots w/listing Sch PBU Camco PBU DA PBU Camco Common Data Base Report PBU " Camco Common Data Base Report PBU Camco PBU DA PBU Otis Common Data Base Report ~BU Camco Common Data Base Report PBU Camco Common Data Base Report Static DA PBU DA Pressure Draw-Down Camco Static DA PBU DA Common Data Base Report the attached copy as receipt of data. Kelly McFarland · ATO-1429F Ghevron Trans. % 187 D &M Drilling Exp. Services Ext. Exploration Exxo~ Getty Marathon Have A' Nice Day! Mobil E & P ,- , /~'.~~ --r.,r~ ?~7 '~ ~ '~)~ Phillips "~r ~., Prudhoe Bay Well Files ..v?,~ "' ' ' R& D Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc. Prudhoe Bay ~_,]gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer February 8, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 12-15 DS 12-16 DS 12-17 DS 12-18 Permit No. 83-32 Permit No. 83-11 Permit No. 83-4 Permit No. 82-206 Enclosed are the Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS/JCD/lmi Enclosures cc: SOHIO Alaska Petroleum Co. File 100.0 ARCO AlasKa, Inc. I~, · Subsidiary of AllenlicRichfieidCompsn.,, " STATE OF ALASKA ALASKi .ILAND GAS CONSERVATION WELL COMPLETION OR RECOMRLETION REPORT AND LO 1. Status of Well Classification of Service Well OIL I-] ;~( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number / ARCO Alaska, Inc. 82-206 / 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20877 4. Location of well at surface 9. Unit or Lease Name 452'FSL, 926'FEL, Sec. 18, T10N, R15E, UM Prudho¢ Bay Unit At Top Producing Interval 10. Well Number 2418'FSL, 120'FEL, Sec. 18, T10N, R15E, UM At Total Depth 11. Field and Pool 2568'FSL, 7'FEL, Sec. 18. TiON. R15E. UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0il Pool 77' RKBI ADL 28330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 12/26/82 01/08/83 01/l q/1~'~ N/A feet MSL 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+ FVD) 19. Direction~[Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 9858'MD 9242'TVD 9817'MD 9205'TVD YES [] X NO [] Nipple 0 2go55MDI 1800'(Approx) 22. Type Electric or Other Logs Run DTT./BUCS/N~O, T~Dt/C~/N~O/Cal, 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5f~ H-40 Surf. 80 ' 30" 1880fA Poleset 13-3/; '." 72.0# L-80 Surf. 2689' 17~' 1900 sx Fondu & 400 ;x Permafrost C 9-5/8~ 47.0fA L-80 & Surf. 9272' 12~' 500 sx Class G & 300 sx Permafrost C S00-95 7" 2.9.0# L-80 8997' 9858' 8½" 325 sx Class G 24. Perforations open to'Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9414-9440'MD 8762-8785'ss 4spf 5~" 9032' 8947' 9444-9452'MD 8789-8796'ss 9456-9476'MD 8800-8818' ss 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9484-9504'MD 8825-8843' ss DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A Ref: BHCS 1/8/83 · . . 27. PRODUCTION TEST Date First Production : i Method of Operation (Flowing, gas lift, etc.) 1-17-84I Flowing Date of Test Hours Tested PRODUCTION FOR OIh-BBh GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO 1-22-8/ 12.2 TEST PERIOD' * 2699 1409 30 43I 652 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL :OIL GRAVITY-APl (corr) Press. 77~ NA 24-HOUR RATE I~ 4754 3098 0 27.0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. '-' . GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MFAS. DEPTH TRUE VERT. DEPTH GOR, and time Of each phase. Top Sadlerochit 9406 ' 8831' N/A O/W Contact 9716' 9113' Base Sadlerochit Not Reacl ~d 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .... ~ Title Regional En~i neerDate 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". ARCO Alaska, inc. Post Office?-'-~ 360 Anchorage, ~ska 99510 Telephone 907 277 5637 October 17, 1983 Reference: Arco Pressure Data D.S. 4-5 9-7-83 9-7-83 D.S. 4-11 7-24-83 D.S. 4-15 8-11-83 D.S. 12-15 9-24-83 D.S. 12-16 9-24-83 D.S. 12-17 9-24-83 D.S. 12-18 9-25-83 D.S. 12-19 9-25-83 D.S. 12-20 9-26-83 D.S. 15-12 9-21-83 9-21-83 Pressure Build-up Pressure Build-up Data Sheet Pressure Build-up Static Survey Static Survey Static Survey Static Survey Static Survey Static Survey Static Survey Pressure Build-up Pressure Build-up Data Sheet Camco Otis Sch DA DA DA DA DA DA Otis 'P~~lease sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 578 Chevron D &M Dallas Drilling Exxon Getty Marathon MobiI DISTRIBUTION North Geology ~hillips Pru~hoe Bay R & D Caroline Smith Sohio ~$tate of Alaska ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 253 4248 Donald F. Scheve Regional Operations Engineer October 3, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 30bl Porcupine Drive Anchorage, AK 99501 Re: D.S. 12-15 D.S. 12-16 D. S. 12-17 D. S. 12-18 D.S. 12-19 D. S. 12-20 Permit No. 83-32 Permit No. 83-11 Permit No. 83-4 Permit No. 82-206 Permit No. 82-198 Permit No. 82-191 Dear Mr. Chatterton: Attached are "Subsequent" Sundry Notices detailing work on Drill Sites 12-15, 12-16, 12-17, 12-18, 12-19, 12-20. Very truly yours, D. F. Scheve Regional Engineer DFS:la cc: Sohio Petroleum Co. File 100.0 ARCO Alaska, Inc. is a Subsidiary o! AtlantlcRIchfleldCompany STATE OF ALASKA ~. ALASK .)IL AND GAS CONSERVATION (' MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska' Inc. 3. Address P. O. Box 100360, Anchorage, AK 9951.0 4. Location of Well 452' FSL, 926' FEL, Sec. 18, T10N, R15E, O~i (Surface) 2418' FSL, 120' FEL, Sec. 18, T10N, R15E, UM (Top Prod) 2568' FSL, 7' FEL, Sec. 18, T10N, R15E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. ADL 28330 7. Permit No. 82-206 8. APl Number 50- 029-20877 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 12-18 11. Field and Pool Prudhoe Bay Field prndh~. Ray Oi 1 pnnl Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate} Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) k~ Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating 24 September 1983. RU perforating unit, pressure test surface equipment. RIH with gun #1, shot 9483-9503' MD, 4 spf. Flowed to tank for clean up, monitored rate and took shakeouts. POH, all shots fired. RIH with gun #2, shot 9455-9475' MD, 4 spf. Flowed to tank. POH, all shots fired. RIH with gun ~3, shot 9433-9439' & 944319451' MD, 4 spf. Flowed to tank. POH, all shots fired. RIH with gun #4, shot 9413-9433' MD, 4 spf. Flowed to tank. POH, all shots fired. RD. Secured well 24 September 1983. All depths referenced to CBL 11 January 1983. 14. I hereby c,9~tify that the foregoing is true and correct to the best of my knowledge. Signed ..... Title R~_~'~on~ ] ~.ng~ n~r The space below for Commission use Conditions of Approval, if any: Approved by_ By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Prud'hoe Bay- .~ineering Post Office Box' 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer September 12, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: DS 12-15 DS 12-16 DS 12-17 DS 12-18 DS i2-19 DS 12-20 Permit No. 83-32 Permit No. 83-11 Permit No. 83-4 Permit No. 82-206 Permit No. 82-198 Permit No. 82-191 Dear Mr. Chatterton: Enclosed are "Intention" Sundry Notices detailing work proposed on Drill Sites 12-15, 12-16, 12-17, 12-18, 12-19, and 12-20. Very truly yours, D. F. Scheve Regional Engineer DFS/JCD/la Attachments cc: Sohio Petroleum Co. Well File 100.0 ARCO Ala=ka, Inc. Il a Subildlary of AtlanllcRIqhfieldCompany STATE OF ALASKA .... ALASK, ~ILAND GAS CONSERVATION C .vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LL :;E~ 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-206 3. Address 8. APl Number P. O. BOX 100360, Anchorage, AK 99510 50-029-20877 OTHER [] 4. Location of Well 452' FSL,-926' FEL, Sec. 18, T10N, R15E, UN (Surface) 2418' FSL, 120' FEL, Sec. 18,-T10N, R15E, UM (Top Prod) 2568' FSL, 7' FEL, Sec. 18, T10N, R15E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 77' RKB 6. Lease Designation and Serial No. ADL 28330 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 12-18 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate [~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing []- Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit sand from the Prudhoe Bay unit. Upon perforating, the well will be flowed to a tank for cleanup. The perforated intervals will be given in the subsequent report. All wireline work will be done through a 5000 psi WP BOP/Lubricator, 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 perforated Intervals: 9414-9440' MD (26') 9444-9452' MD (8') 9456-9476' MD (20') 9484-9504' MD (20') ref: BHCS 01/08/83 14. I hereby certify that the~foregoing is true and correct to the best of my knowledge. Signed _~),~, .~~(J - L ~A ~ Title R8gional ~,ngiD.88r The space below for Commission use ~ Date Conditions of Approval, if any: Approved by. 0~1,~ ~Ti,~L SIGNED [~Y LONNIE C. SltllTIi Approved Copy ~etur~ed By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, inc. ~"' ~"-- Post Office 8o'x' 360 Anchorage. Alaska 99510 Telephone 907 27.7 5637 May 26, 1983 Reference: Arco Cased 'Hole Finals D.S. 2-lA-" 11-28-82 D.S. 4-15 / 4-1-83 D.S. 5-7 - 4-14-83 D.S. 6-3 -- 4-13-83 D.S. 7-3' 12-3-82 D.S.. 7-11f' 12-4-82 D.S. 7-14×. 12-5-82 D.S. 7-18 1-9-83 D.S. 7-19 1-28-8'3 D.S. 12-1" 12-2-82 D. S. ~:12 ~ 1.8.-" 1-11 - 83 D.S. 13-18" 3-23-83 D.S. 13-34~ 4-2-83 D.S. 14-17' r 3-27-83 D.S. 14-19 J 12-9-82 D.S. 14-21- 3-25-83 CN/MSN/GR CH CNL CH CNL CH CNL CN/MSN/GR CN/MSN/GR CN/MSN/GR ACBL/VDL/GR ACBL/VDL/GR CN/MSN/GR ACBL/VDL/GR EPL TDT EPL CN/MSN/GR EPL Run 7 5" DA Run 8 5" Sch Run 10 5" Sch Run 7 5" Sch Run 3 5" DA Run 8 5" DA Run 8 5" DA Run 1 5" DA Run 1 5"' DA Run 3 5" DA Run 1 5" DA Run 1 5" Sch Run 1 5" Sch Run 1 5" Sch Run 2 5" DA Run 1 5" Sch lease sign and return the attached copy as r'eceipt of data. Kelly McFarland AFA-403 Trans. # 361 NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON DISTRIBUTION EXXON MOBIL GETTY D &.M STATE OF ALASKA DALLAS ~M ITl-l_ ..,;r~ ~. (, .,r.,- [ \/r- !!303 '~!.'isk~ Oil .~ '~-;s (::,,: ~.~',~,1,~' .:~. , Ar~.:h,,',~hiL. ARCO Alaska, Inc. ~ Post Office B~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 15, 1983 Mr. C. V. Chatterton Commissioner state of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are monthly reports for February on these drill 1-25 1E-18 7-20 1E-19 7-21 1G-5 12-15 1G-6 12-16 1Y-12 12-17 1Y-13 13-2A 1Y-14 15-3 1Y-15 cIRI Wolf Lake Well #1 Ravik State #1 sites' Also enclosed are well completion reports for' 1-24 1E-21 2-8 . 1E-22 7-18 1F-1 7-19 1G-7 12-18 WSW-IO 13-9 WSW-11 1E-20 Tract Well 24-11-14 We also are including subsequent Sundry Reports for 2-8, 7-18, 12-18, and 13-9. ARCO Alaska, Inc. is a subsidiary of AtlanlicRichfieldCompany ~ STATE OF ALASKA '-'--. 0 i!~ 16 [~ A L ALASKA .... : AND GAS CONSERVATION CC MISSION 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, 82-206 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20877 4. Location of well at surface 9. Unit or Lease Name 452' FSL, 926' FEL, Sec. 18, T10N, R15E, UM Prudhoe Bay Unit At Top Producing IntervaliVE F_~. JVEJ~/F~£D I 10. Well Number At Total Depth , ~?.. i" 11. Field and Pool 2568' FSL, 7' FEL, Sec. 18, T10N, R15E, UM -' Prudhoe Bay Field 5. Elevation i'n feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 77' RKB ADL 28330 , 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 1 2/26/82 01/08/83 01/19/83 N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where sssV set I 21.Thickness of Permafrost 9858'MD,9242'TVD 9817'MD,9205'TVD YES [] NO [] Nipple ~ 215~et MD 1800' (Approx) 22. Type Electric or Other Logs Run D IL/BHCS/NGD, LDT/CNL/NGD/Cal , CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 80' 30" 1880# Pol eset 13-3/8" 72.0# L-80 Surf 2689' 17-1/2" 1900 sx Fondu & 400 sx Permafrost C 9-5/8" 47.0# L-80 & Surf 9272' 12-1/4" 500 sx Class G & 300 sx Permafrost C S00-95 7" 29.0# L-80 8997' 9858' 8-1/2" 325 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD} PACKER SET (MD) None 5-1 / 2" 9032 ' 8947 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 2~./A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ Flow Tubing Casing Pressure . . CALCULATED.l~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None '~'J~'~ Oil o Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 2§. ,~ ~i~ - 30. GEOLOGIC MARKERS FORMAT'ION TESTS . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 9406' 88:31 ' N/A O/W Contact 9716' 9113' Base Sadlerochit Not Reached 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ Title Area Drilling Engr. 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- 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". DS 12-18 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0900 hrs, 12/26/82. Drld 17-1/2" hole to 2700'. Ran 67 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2689'. Cmtd 13-3/8" csg w/1900 sx Fondu & 400 sx Permafrost C. ND 20" Hydril & diverter. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 10.7 ppg EMW - ok. Drld 12-1/4" hole to 9286'. Ran 219 jts 9-5/8" 47#/ft, L-80/S00-95, BTC csg w/shoe @ 9272'. Cmtd 9-5/8" csg w/500 sx Class G. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 9843'. Ran DIL/BHCS/NGD f/9834'-9272' & LDT/CNL/NGD/Cal f/9834'-9272' continued W/CNL/NGD to 13-3/8" shoe. ContinUed drlg to 9858' TD (01/08/83). Arctic packed 9-5/8" x 13-3/8" annulus. Ran 21 jts 7" 29#/ft, L-80, BTC csg f/8997'-9858'. Cmtd 7" lnr w/325 sx Class G. Drld cmt to 9817' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Ran CBL f/9817'-8897'. Ran 5-1/2" completion assy w/tail @ 9032' & pkr @ 8947'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced tbg to diesel (backflowed 30 bbls into annulus). Dropped ball & set pkr. Nipple for SSSV @ 2153'. Secured well & released rig @ 1800 hrs, 01/13/83. Gyroscopic Survey ran 01/19/83. JG' sm 02/02/83 GRU1/DH17 A R C 0 A L A'.E;~.'. A, I N C:. Dr:; 1.2, WELL NI:~: 1S GMS ,_lOB NF~: AC.)i PRUDHLaE £~AY, NCIRTH '.--;LOF'E; GM'.'_-;, 0-7017 MD, .SURVEY¢~R: CORAM, MILLER DATE RUN: I'T.~-,_IAN-~E:3 rz:AMERA NF~: 121:3 5-'?0 F~EG. A/I_I NO: 11'~5 2" GYRO NO: F'-ORE%IGHT N .=, 4._ W VERTICAL ::;E¢:TION r':ALr':l ILATED 'IN F'LANE OF PROF'r3SAL ' ' ~;! - DIRECTIr'~N: N 26 DE~ 19 MIN, 'E ~, , REE:ORf'~ OF SURVEY ARC:O AL..A.=,k.A-, INC, ................................ DS 12, WELL itiO: 1:3 GMS F:'RUDHOE BAY, NORTH SLOPE, ALASKA ........................................................................ COMF'UTAT I ON ..... PAGE-NO'; ..... ,J 0 B hi Ci: A 018:3 R 0 :=: 4 ::'-:- R G T I M E D A T E 10: 1 :--: :: :".: 9 22-- F E B-:5: :".: 'TRUE ' MEASURED DRIFT DRIFT F-:FH_IR'.5;E VERTICAL VERTICAL SUBSEA R E C T A N G LI L A R C L. 0 S U R E DOGLE 'DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD' C 0 0 R D 'I .... 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' .93 1267.7:3 7277. ,03 1207".36 N 418.43 E 1277. :--:1 N 19 7 E )0( 0 .' 2.'. 0.3/: 0.2~. 1.0( 100. 7445. 12 13!4.48 7368.12 1251.73 N 10('). 75:32.7'P 1:362.24 7455.7'.-.? 12'P7.'27 N 0, 7.. 0.7.. 0.7~ 433.78 E 13:24.75 N 17 7 E 0~'2.'. 44'.-.?. 8:3 E 137:--:.05 N 19 7 E 1.1] 8000. 30 0 N 22 0 E lOC), 7/_-.I?.,72 I411.4/_-. 7542.72 1343.41 N 4/:.7.54 E 1422.4-5 N 17 11 E 1,2~ 81 (]_ O_. 3 A. 30 N ,'~'-"-' 0 E 1 (')_ (]._ 77 o/-,_. 1 r). 1461 .6'-.?. 762 ? .1 (]. 1 :_--:'? 0 . 1 ~'--' N 48/-,_. 42 E 1472 .77 N 1 :--:200. 31 45 N 22 0 E 100. 7791.71 1513.23 7714..71 14.38.05 N 505.78 E 1524.40 N 1 '-'-". ' . . '"F. ............ ~/- Z. 77?? .... 526', . ._-, ) 'E i .~'] :--:300 .... ~.' 15 N 24' 0 E LC)r). ..... 7876.._I ~._:.z..13 .51 "148'6]-'83 N' 48'E 1577;'27 'N 19 8400. 32 45 N 26 0 E 100. 7760.:--:5 t617.85 7883.85 ~535.52 N 54'?.19 E 1630.77 N 1 :--:500. :32:30 N 27 0 E 86C)0. 3:2 15 N 27 0 E 8700. :_::2 15 N 28 0 E ,=,,:,00. 31 45 N 2S,' 0 E 8'700. 31 0 N :32 0 E 100. ,q,_ 04._.=, ...... 07 1A73 7A 7?68 ,:]7 1583-.-77 N 00 · :z: 12 S.". 53 1727.30 C-:052.53 1631 · 4 ::: N 00. 8214. 10 178(].65 8137. 10 167:--:.81 N 00.' --8298.70 1833.,':.0 8221.70 1725.38'N 00. 8384.28 1 :--::--:5.52 8:_--:07.28 1770.23 N 57:3.24 E 1684.':32 "N'I'P 54 E '-0';-5'.- 597.55 E 1737.4.7 N 20 7 E 0.2', 622. I'? E 17':.-~0.40 N 20 20 E 0·5" 647.48 E 1:=:4-2.:::7 .... N '20 34. E 67:_::.'PC) E 1874. 16 N 20 50 E 1.7.. ?000. 2? 15 N 3:0 0 E 7100. 28 30 N 32 0 E 7200. 27 0 N 34. 0 E 'P300. 26 30 N 37 0 E 7400 '-' = 45 N .z:,.? . ~._, ,_ .. (] E 100.' 8470.77 19.'2_-:5; 54 E::z:'F,":3.77 - 1E:137'25 N ........ 69~;. 75'--E 1$..'43;-58 ..... N 21 -6 E ........... 270': 100. '- .=,.=, ---'. 34- .?,' ::'.:3 . ,:: .... L:, 1 .67 848.1 34 1854.64 Iq 724.62 E 1':.-¢'?1. 17 N 21 20 E 1.2: 100. 8/_-.4L-.. 83 202'.-?. ? I '.--:569.83 18~3.68 N 747. ':.77 E 2036.7? N 21:3/_-. E 1.71 100. 8736. 13 2074. I'F.¢ 865F.¢. 13 1,o29.85 N 77/_-.. 74 E 2080_),'30 .... N 21 55 E ..... 2."3( 1C)0. 8:::'-.'.~.':72 2117.15 C-:748.72 1':-~/_-,4.07 N 804.45 E 2122.43: N 22 16 E 0.7', A R CCi A L A :F-:K A, I N C. D'S 1::2, WELL NC]: 18 GMS PRUDHOE BAY, NC[RTH SLOPE, ALASKA dC[B NO: A0183R0:343-RG COMF'LITAT I ON PP~GE '~'NO, T I ME DATE 10: 1:2:: :2: ~, 22- F E B-83 '1 TRLE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL '.:_:UBSEA R E C T A N G U L A R C L 0 S U R E DOGLE DEF'TH ANGLE""DiREE:T"r'i"iN-"EE~i]TR .......... DEF'TB .... .:,E_.TION TVD C 0 0 R D I N'"'"P[-T'~E--S-Ti'I'L--~TANCE ......... DI'R.'ECTIi]N--'SE~ERI' FEET D M D M FEET FEET FEET FEET FEET FEET D M DG/100 9.'=, (') 0 .,:.'-'.j '=' 0 N '"4 ::: ~'i'-E 10.~'i ............. · "".::¢"-"; ~l _. '.z.'-' 7 .."'"' :1 .... =' 9 (:) 4 ,..:,,:-,.:.'"'"'-'":',::, 2 7 1 9':.':' 7 ~ '~'1~ N '-' '-' 1 ._ "'E - -..,:... ............. -. ¢/60 cED ~ 4 .:: C N 37 0 E 100. ~-~ 007 08 2' 2 c.~ ). l 1 8'F/:2:0 08 20 ~:(] c:.~ hi 856.61 E 2 ? c~ 4.. 10 N 22 .=, 2 E 0.65 · ~ ..... o.-. ~ 7:3 702 . 206 ... '-] '~ . ?700. 24 15 N .~A 0 E 100. ?¢A9~: 17 ~,.4C. 1 17 4 cdc] N ._c. 1 16 E 2244· 22 N 23 7 E 0 4.8 . ? 14-:':. ::.0 ..::Z6g. '"':' 9066 9750. 24 d N 36 O"'E 5(] " ~ '"" N z..-', I ..... .: ....... .,:..,. ,-'.-,- · 15 ~'""" ) P R 0._1E C T E D T 0 'P :5:17. 9 817 2 4 ('D N c,/. 0 E 6 7 ,::, s.., (].=i, 01 ---:,,-, o ~ .u.., 2'--.,' ('D ' 0 ,["D 0 · ..,=. .... 7 4 '::' 12 L-: (:, 1 21 ('~ 2 F,":-' N ':',' O'F.,' 1 ? E-- 7 4 N 2::: 2:3 E THE FEd_LOWING STATION I~B PRO',IEE:TED FOR INTERPOLATION VALUES. )-.: ..... :,. 24 0 N 36 0 E 41. 9242.4F- 23()4 18 .9165 46 zl16 07 N 918.97 E 2307 01 N :z.:: '..3'F7 E "'\,~ ,'. · .. . FINAl_ F:LF~'.::I_IRE_ __ - DIRECTIAN'.' ' N 2':'._. T~EGS '~':',-._, HIi',I~: 30 -:.E_.o"" 'R'-' E ' '" . DISTANC:E: .2.'_-:0'7.01 FEET '" ' ·.. ,, ~ 0. C)O ARC:O ' F.., ALA.:,KA~ INC:. DS 1 2~ WELL NO: 1 c, GMS . IF~B NA: AO1 ~ .... ¢"' .. ..... =,.",R .~.:,43-RG F'RUDHOE 'BAY, NORTH SE'OPE, ALASKA ~'- ) ':"/"-' ~ - -"- GM'.=-;', (:-.~ ,=,17 MD SURVEYFIR F:ORAM., MILLER f'IATE RUN: 1 ?-.JAN-83 · - ._-,./. o CAMERA NF~: 1'.-"1:2: .=;,-'-.".',[') ..... DEA, A/U NO: 11o.'=;,. ._ """,_.. GYRO NO: ... ..... FORE':"'._, I GHT: N' ,.., ".~.M""'... w RECORD OF I NTERF'OLA-I"ED SURVEY ~R["'~O ALA'._~:~A I I NC:, 12, WELL'NO: 18 GMS :"RUDHOE BAY, NORTH SLOPE, ALA._~k.A .JOB NO: AO18:--:RO343-RG T I ME DATE 10: 1._F,'. :t 3 22-FEB-8:]-: MARKER ....... TRUE SUBSEA CODE MEASURED VERTICAL MD-TVD VERTICAL R E C T A N G IJ L A R C L 0 S U R E ~-o, ,, ........ ~ .... ~, , . ........... NAME DEPTH 'DEPT'R D'I'FF DEF'TH C: "'"'0- ..... N T""E""S D I .=,T~NCE £ I RECT I ON FEET FEET FEET FEET FEET FEET D M TOF' '.:;AR'~'_ . R I'VER c..,'2':'.,,7';",¢~¢~. . . . '",=,7"'"'._-,..:,. 4'::'...., '"'='._,6...'~'"""~'"'=', ,_,/:o .~ .... /:,-. 4.._,'=' ..................... i c ,-,,~, .¢ ....=, ................. 77 N 77,..,.'="-'-c/'-":: .=, E ..07"-' '-"/..:. ,U,~J N .z.'-" 1~5._ .. ................ E TOP SHUBLIK A ~ .... '= 1'~:"::8.41 N 7:93,/--.7 E ".,,¢~,9¢~ N .,::..,.. 1 E . o7 ........ ~ 56/-, 4 8/:,81 ~..:,.z....., 00 '-' .'=,~ ~'"' ~'":' ..... ' · · · '" I .'-, '"" '-' ) 33 ~'-'9 " . TOP .=,HJBLIK B ?/347. C)0 8778 .... . c,.:, ._ 6,=,. 7 ,=,7( 1. 1945. $~4 N ¢¢,; . 76 E :z 100 0? N 22 5 E T~DP'""SHI2IBLiK C 936%-.'00 o ¢ ~ .4. ! :]~,-.. 10 N 7.-. 4./._ E z 1(]7·/:..=. N ..z y E . . ~ ,_.7 y4.4 y 570,'5 TOF' SADLERE[CH I T 94¢)/:,.. 00 ,_.°°":-' 1,_,..., · 3:4 574 .7 c,,... -,. .34 19/-. _./-_,. O'F,' N 8¢)/-,. _, 05 E 2124 .9(]. . N 22 1 o,_, TOP ZONE :3 9652. O0 '.-'.)054.45 TOF' ZONE 2 9711.00 9108.21 O/W CONTACT 'F¢716.00 9112.77 PBTD 781'7'.-00 .... 7205~ 01 TD ..085:3.00 '.-.",'242:, ::46 597.6 8977,45 2048.08 N :_=',/_','.-.-/;:3SE 2224;".'7.'6' N 23 'O"E ........... ..'.z. 4._. /-.1N .,:_._ E /-,¢~2_. .8 ?/031 . 21 2067 ./:,4 N c,c,.':.,,_,,_,._,. ~:0_ E .... o . _ .-:,?,' ,.-.~. 603.2 ?035.77 206.9.2;~ N 885.00 E 2250.60 N 2:3 ,.r/ E /:,1'2,'0 '.-T* 128 .(:il .................... 2102 ;'"58 ~'N ?~0S~ :;" 17. "'~ E 22?0,74 N" '23~'23"E 615.5 9165.46 2116.07 N '.~18. ?*'? E 2307.()1 N 23 2';' E J -~9858 Eastman Whipstock A PETROLANE COM~ REPORT of SUB-SURFACE DIRECTIONAL SURVEY ,, ARCO 3~S]~r INC. . CONI~ANY DS 12w Well NUmber: 18 WELL NAME JOB NUMBER Prudhoe BaY, North Slope, Alaska ~.OCATION TYPE OF SURVEY DATE Teleco/Directional- . JAN2 4.[~ 26-De0-82 Single Shot Alask~ Oil a Gas Cons. L;omrnJssiorJ Anchorage SURVEY BY Controlled Drilling Consultants (Dale Hendrix ) OFFICE ............ AF~CO_iALLA$t!.'.g~ ..... INC, ,, D.S 12, WELL NO: 18 TELECO£DSS , (hDC) PRIJDHOE BAY, NORTH SLOPE, ALASKA TELECO,, 4695-883f; MD, DSS, S;222-S;843 MD DRILLED BY D HEND~I X '(CONTRLLED DRI,LL!NG CONSULTANTS RI_G: VERTICAL SECTION CALCUL A PETROLANE COMPANY RECORD OF SURVEY RADIUS OF CURVATURE METHOD ,,, t ARCO ALASKA, INC. DS 12, WELL NO: 1.9 TELECO/DSS C:OMF'LITAT I ON ( CDC ) T I ME DATE ,, PAGE NO. ' I F'RUDHOE BAY, NORTH SLOF'E, ALASt(A ' .' 14: '~',.,,:,: 32' : I~-,.IAN-,:,.:,~" '"'-' , ~ TRUE " MEASURED DRIFT DRIFT c:oURSE VERTICAL VERTICAL SUBSEA R E C: T A N O U L A R C: L 0 S U R E YiCiGLEIO DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION .TVD FEET D M D M FEET FEET FEET FEET C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERIT FEET FEET D M DG/100F O. 0 0 0 0 4500. 0 0 0 0 4695. 46:52. 5002. 4 12 N 60 24 E 9 6 N 56 0 E 8 18N23 6E O. 0.00 4500. 4500. O0 195. ~'4L, 94' 83 157. 4850.72 150. 49998. 9999 O. O0 -77. O0 ' .. O. O0 4423.00 5. 992 .4617'. 83' 2i. 35 '4773.72 43.13 49921.9999 0. O0 O. O0 O. O0 0. O0 3':' 53 'N ~": 2'1 ..... E 13.10 N 21.66 E 30.36 N 35. 990 E O. O0 0 0 O. O0 0.. 00 0 0 0,00 '~.14 --N 6G 24 E ..... 2~I._',~F- 25.31 N 58 49 E 3. 14 47.02 N 49 47 E 3~31 50995. 11 18 N 14 0 E 5300. 17 48 N 12 54 E 993. 50990.63 205. 5288.95 58.80 5013.63 45.35 N 40. 993 E 108,99~ 5211.995 995.,41 N 52.91 E 61.099 N 42 4 E 1099.10 N 299 1 E 5516. 24 54 N 16 24 E 5700. ~0~ 30 N 19 18 E 6,2399. ~o 0 N 199 36 E 216. 54899.99~ 184. 5652.84 5399. 6111.14 t85.993 5412.9~ 171.43 N 270.499 5575.84 252.80 N 552.06 6034.14 520.22 N 72.78 E 998. 998 E 1 .~3.42\ E 186.24 N 23 0 E: .3.34, 271.499 N .'21 2..':: E .-'~:. 13 555.02 N 20 24 E 0.46 6548. 31 48 N 18 30 E ' 30' 7080. 31 36 N 18 12 E -7507. 29 42 N 18 30 E 76991. 28 24 N 17 30 E 79983. 299 42 N 20 0 E E:502. 32 24 N 25 36 E 8654. 32~30 N 27 42 E 716. 62995 04 676 72 N E ~lllll~ 6;3~,2. O~ 2.~ . . ~47.46 519. 8052.70 1704.73 797~~[~~YN 580.86 E 152. 8180.997 1786.28 8103.997 1687.44 N 720.55 N 20 .5 E "0.43 1000.02 N 199 36 E 0.¢)~.: 1217.65 N 199 2:3 E 0.]~ 130L-,.997 N 199 17 E 144,'_-':.73 N 199 14 E 1715.86 N 19 47 E 617.44 E 17996.86 N 20 6 E 0.75 0.61 O. 76 0.74 o~¢~.',. 31 42 N 28 42 E 9222. 26 48 N 34 0 E 9843. 23 0 N 36 0 E 185. 8337.699 1884.54 826,0.699 1774.08 N 383. 8671.75 2070.83 8599~.75 1933.799 N 621. 99234.992 23299.24 99157.992 2147.992'N 66,3.8'/ E 18994.23 N 20 31 E 761..199 E 207:'-:.21 N 21 29 E 9911.13 E 2333.18 N 22 59 E 0.52 1.45 0.63 ) FINAL [.LOG JRE DIRECTION N 22 DEGS 599 MINS 10 SECS E DISTANCE: 2333.18 FEET ARC. O ALASKA, INC. lIS 12, WELL NEt: 1.9 TELEC:O/DSS DR!FT CHART"S RELATiED DATA FILE ( CDC: ) F'RUDHOE BAY, NORTH SLOPE, ALASKA '._:;URVEY FILE NUMBER 1538 BOTTOM HOLE Ac-.;CjEMBLY VALUES USED FOR DEPTH ,ARE MD DEPTH DESCRIPTION i10.00 2710.00 4500. O0 516:3.00 5749.00 6612. O0 STRAIGHT HOLE ~i[,BI~,Y Eastman __ I ~ [mYNA [mR ILL ~"~'??~i!:?::i? ~'-~-~ANGLELo~KEDBUILDAssEMBLASSEMB~A~B'[~ ~y ~ Whipstock A ~T~O~NE ~NY DRILLING DAYS VALUES USED FOR DEPTH ARE MD DAY DEPTH 110.00 2¢:J50. O0 :3 4 .5 2710. O0 3109.00 4875.00 ,..-:./ 10 11 5257.00 6497. O0 7.:,,_ ,:,, 00 7772. O0 .'3'711.00 ':~':"¢'/' 00 .. ~. ,_,-_, · 12 13 '.-.? 2:{:6.00 9:378.00 WEIGHT ON BIT VALUES~i,USED FOR DEPTH ARE MD DEPTH WEIGHT 110. O0 2710.00 4500, O0 O, O0 50. O0 O. O0 "~' / '" O0 6 612.....D 0 ,70. O0 65. O0 70. O0 REVOLUTIONS PER MINUTE KIEPTH r.P.H. 2710.00 1:30.00 4,500. O0 O. O0 VALUE:_-': USED FOR DEPTH ARE MD . Whtpstock A PE'I'ROLANE COMPANY 516:3.00 100.00 ~ c,,. . · _74.-. O0 120 O0 661 '.-.- '. O0 120. O0 Suggested form to be inserted in each "Active" well folder to d~.eck for timely compliance with our regulations. ' Operator, Well Name and Numbe~ Reports and Materials to be received by: ~>: Required Date Received _ , Completion Report_ Yes Well History' Yes ,Samples .... Mud. Core Chips . ...... ,. COre Description /"//~.,::"C~. "- RegiStered Survey Plat Inclination Survey ///:-.~. . .... .. Directional Survey Drill St~n Test Reports . Production Test Reports · .,. - Digitized Data · STATE OF ALASKA ALASKA (J~L AND GAS CONSERVATION CO~vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~X 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-206 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20877 OTHER [] 4. Location of Well Surface: 452' FSL, 926' FEL, Sec. 18, T10N, R15E, UN 5. Elevationinfeet(indicate KB, DF, etc.) 77' RKB 6. Lease Designationand Serial No. ADL 28330 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 12-18 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool 12. Check Appropriate Box To indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other [] Other [] Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Spudded well ~ 0900 hfs, 12/26/82. Drilled 17-1/2" hole to 2700'; ran, cemented & tested 13-3/8" casing. Drilled 12-1/4" hole to 9286'. Ran 212 jts 9-5/8", 47.0#/ft, L-80, BTC casing & 7 jts 9-5/8", 47.0#/ft, S00-95, BTC casing w/shoe @ 9272'. Cemented 9-5/8" casing w/SOO sx Class G cmt. Drilled 8-1/2" hole to 9843'; ran logs. Continued drilling to 9858' TD; ran, cemented & tested 7" csg. Ran 5-1/2" completion assembly. Secured well & released rig ~ 1800 hours, 01/13/83. 14. I hereby certify that the foregging is true and correct to the best of my knowledge. Signe Title ^rea Drilling F'ngineer The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRU2/SN4 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Bc~...360 Anchorage, ~: ~a 99510 Telephone 907 277 5637 February 23, 1983 Reference: Arco Open Hole Finals D.S. 7-18 1-6-83 1-6-83 1-6-83 i 1-6-83 1-6-83 D.S. 12-18 '1-8-83 1-7-83 .. 1-7-83 1-8~83 1-8-83 1-8-83 CPL/Cyberlook BHCS DIL/SFL FDC/CNL/GR (Raw) FDC/CNL/GR (Poro) CPL/Cyberlook BHCS DIL/SFL LDT/CNL/GR (Raw) LDT/CNL/GR (Poro) Natural Gamma Ray Spectrascopy Run 1 5" Scb Run 1 2 ''' & 5" Run'l 2" & 5" Run 1 5" Run 1 5" Run 1 5" Sch Run 1 2" & 5" Run 1 2" & 5" Run 1 5" Run 1 5" Run 1 5" sign and return the attache~ copy as receipt of data. Kelly McFarland AFA-403 Trans. # 163 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS soHIo MARATHON CHEVRON EXXON MOB I L GETTY D&M STATE OF ALASKA DALLAS Alaska Oil & l',';,:~ i~I}$11!)I ixi,,., '""'llltllt,$$~Or, · "' AR~O Alaska, Iq~.--... Post Offi~. ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 10, 1983 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anch~orage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton- Enclosed are monthly reports for January on these drill sites' 1-24 1E-20 7-18 1E-21 7-19 1E-22 7-20 1F-1 12-17 1G-6 12-18 1G-7 13-9 1Y-13 13-98 WSW-IO WSW-11 Tract Well 24-11-14 CIRI Wolf Lake Well #1 Ravik State #1 Also-enclosed are well completion reports for' 2-11 1E-23 7-17 1F-2 12-19 1F-3 13-11 1G-8 13-21 WSW,8 13-24 WSW-9 The survey for 2-22 needs 'to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including subsequent Sundry Reports for 1-24A, 2-11, 13-21 (3 reports), and 13-24. ARCO Alaska Inc. is a subsidiary of AllanlicRichfieldCompany STATE OF ALASKA ALASKA ;L AND GAS CONSERVATION C~ AMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wellx[~] Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-206 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20877 4. Location of Well atsurface 452' FSL, 926' FEL, Sec. 18, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 77' RKB 6. Lease Designation and Serial No. ADL 28330 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 12-18 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool For the Month of January ,1983 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0900 hfs, 12/26/82. Drld 17-1/2" hole to 2700'; ran, cmtd & tstd 13-3/8" csg. Drld 12-1/4" hole to 9286'; ran, cmtd & tstd 9-.5/8" csg. Drld 8-1/2" hole to 9843'; ran logs, Continued drlg to 9858' TD; ran, cmtd & tstd 7" csg. Ran CBL & 5-1/2" completion ass),. Secured well & released rig @ 1800 hfs, 01/13/83. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set ~ 80'. Instld w/1880# Poleset. 13-3/8", 72.0#/ft, L-80, BTC csg w/shoe @ 2689'. Cmtd w/1900 sx Fondu & 400 sx Permafrost 9-5/8", 47.0#/ft, L-80/S00-95, BTC csg w/shoe @ 9272'. Cmtd w/SOO sx Class G. 7" 29 O#/ft, L-80, BTC csg f/8997'-9858' Cmtd w/325 sx Class G SEE DRILLING HISTORY 14. Coringresumeandbriefdescription None 15. Logs run and depth where run DIL/BHCS/NGD f/9834'-9272' LDT/CNL/NGD/Cal f/9834'-9272' CBL f/9817'-8897' continued W/CNL/NGD to 13-3/8" shoe 16. DST data, perforating data, shows of H2S, miscellaneous data N/A Alaska 0ii &.., Gas C0ns, Af~;,Sorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~'/'~f~~"f'~*~ TITLE Area Drilling Engineer DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 G R U 2 / N R 2 Submit in duplicate DS 12-18 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0900 hrs, 12/26/82. Drld 17-1/2" hole to 2700'. Ran 67 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2689'. Cmtd 13-3/8" csg w/1900 sx Fondu & 400 sx Permafrost C. ND 20" Hydril & diverter. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 10.7 ppg EMW - ok. Drld 12-1/4" hole to 9286'. Ran 219 jts 9-5/8" 47#/ft, L-80/S00-95, BTC csg w/shoe @ 9272'. Cmtd 9-5/8" csg w/500 sx Class G. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 9843'. Ran DIL/BHCS/NGD f/9834'-9272' & LDT/CNL/NGD/Cal f/9834'-9272' continued W/CNL/NGD to 13-3/8" shoe. Continued drlg to 9858' TD (01/08/83). Arctic packed 9-5/8" x 13-3/8" annulus. Ran 21 jts 7" 29#/ft, L-80, BTC csg f/8997'-9858'. Cmtd 7" lnr w/325 sx Class G. Drld cmt to 9817' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Ran CBL f/9817'-8897'. Ran 5-1/2" completion assy w/tail @ 9032' & pkr @ 8947'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced tbg to diesel (backflowed 30 bbls into annulus). Dropped ball & set pkr. Nipple for SSSV @ 2153'. Secured well & released rig @ 1800 hrs, 01/13/83. JG:sm 02/02/83 Al[-~sko. Oil,:~':' Gas Cons, ¢omrr~ssbr~ Anchorago GRU1/DH17 ARCO Alaska, inc. Post Office B?~-..3,.60 Anchorage, A. ~a .99510 Telephone 907 277 5637 January 21, Reference: 1983 Arco Directional Data D.S. 7-18 · D.S', 12-18 12-28-82 Single Shot 12-26-82 Single Shot EW EW .// ~/Plea se sign and return the attached copy as receipt of data. · Kelly McFarland AFA-403 Trans. # 072 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON .EXXON MOBILE .......... -'- -' ~-. GETTY D & M ~~itj~.~? STATE OF ALASKA DALLAS .JA~'~'2 ~ ~.~;~ ' ":-'-: --" .~ia~, & Gas Oo~:~. ~mm~ Po~st Office 'Box 360 Anchorage. A>"~,ka 99510 Telephone 9C ;7 5637 January 20, ReferenCe: 1983 Arco Magnetic Tapes and Listings D.S. 14-7 * D.S. 12-18 .' I :' :.,',, !'~ d' "~'-: (-'~ j ?&'4 Z:r" ii.'"' 9-17-81 . NLL # 875 DA 1-8-83 OH tape # 66270 Run 1 Sch -! "Ds / - - / ?' .xr., -- * Exxon & Sohio, 1 copy already sent by Schlumberger. /Please sign and return the attached.copy as receipt of data. Kelly McFarland AFA-403 Trans, # 069 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBILE GETTY D&M STATE OF ALAS,.KA DALLAS ~/~ Caroline Smith ARCO Alaska. Inc is a SubslOiary of AllanlicRichfielOCompan-; ARCO Alaska, Incr~''''~ Post Office ._ .,x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 13, 1983 Mr. C. V. Chatterton Commi s s i one r State' of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive ~ Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. ChattertoD' Enclosed are monthly reports for December on these drill sites' 1-24 13-14 1G-7 2~11 13-98 1G.8 7-16 1E-22 WSW-8 7-17 1E-23 WSW-9 7-18 1E-24 WSW-IO 12-18 1F-2 Tract Well 24-11-14 12-19 1F-3 CIRI Wolf Lake Well #1 · 13-11 1F-4 A1 so enclosed are well completion reports for' 1-22 13-13 1-23 14-6 6-24 1C-1 7-15 1C-IOGI 12-20 1E-25 13-6 The survey for 2-22 needs to be reran; a completion report 'for this well will be submitted when an approved survey is received. We also are including subsequent Sundry Reports for 7-17, 13-6, 14-6 and 1C-1. Since the information on the Wolf Lake and Tract wells is of a confidential nature, we would appreciate it if you could store it in a secure area. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JGL28:llm Attachments JAN ~!aska Oil & Gas Cons, ,Mchorage ARCO Alaska. Inc. is a subsidiary of AtlanticRichfieldCompany - ' ~ .,~---. STATE OF ALASKA ALASKA ~_ .L AND GAS CONSERVATION CC.,,MISSION MONTHLY REPORT OF DRILLINO AND WORKOVER OPERATIONS · Drilling well Workover operation [] Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box :360, Anchorage, AK 99510 4. Location of Well 452' FSL, 926' FEL, Sec. at surface 5. Elevation in feet (indicate KB, DF, etc.) 77' RKB 18, TION, R15E, UM 6. Lease Designation and Serial No. ADL 28:3:30 For the Month of. December ,19 82 7. Permit No. 82-206 8. APl Number 029-20877 50-- 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. .12-18 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0900 hfs, 12/26/82. Drld 17-1/2" hole to 2700'; 13-:3/8" csg. Drld 12-1/4" hole to 5774' as of 12/:31/82. ran, cmtd & tstd SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressur9 tests 20" 91 5#/ft, U-40, weld conductor set ~ 80'. 1:3-:3/8" 72 0#/ft, L-80, BTC csg w/shoe @ 2689', Permafrost C. Instld w/1880# Poleset. Cmtd w/1900 sx Fondu & 400 sx SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run None to date 16. DST data, perforating data, shows of H2S, miscellaneous data N/A I17. I hereby certify that the foregoing is true and correct to the best of my knowledge. J AN 1983 Alaska 0il & Gas Cons. Commission Anchorage SIGNED ?' -/ //~'~ Z,'~ ~_ ~ ---~J TITLE Area Drilling Engineer DATE /O ,// .,-~ :~ NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~,O4 GRU 1/MR 17 Submit in duplicate DS 12-18 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0900 hrs, 12/26/82. Drld 17-1/2" hole to 2700'. Ran 67 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2689'. Cmtd 13-3/8" csg w/1900 sx Fondu & 400 sx Permafrost C. ND 20" Hydril & diverter. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 10.7 ppg EMW - ok. Drld 12-1/4" hole to 5774' as of 12/31/82. JG' sm 1/05/83 GRU1/DH17 Alaska Oil & 6as Cons, Commission ARCO Alaska, Inc Post Office bux 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 5, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' DS 12-18 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose changing the 9-5/8" casing program by running both L-80 and S00-95 casing. Since we estimate starting this work soon, your prompt approval will be appreciated. Sincerely, M. A. Major Area Drilling Engineer MAM/JGL22'llm Enclosures ARCO Alaska. Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL ~X COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-206 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20877 OTHER [] 4. Location of Well Surface: 452' FSL, 918' FEL, Sec. 18, T10N, R15E, UH 5. Elevation in feet (indicate KB, DF, etc.) 77' RKB 12. 6. Lease Designation and Serial No. ADL 28330' 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 12-18 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [~X Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes changing the 9-5/8" casing program by running both L-80 and S00-95 casing. L-80 casing will be ran to approximately 8857' MD, and S00-95 will be ran from approximately 8857' MD to 9164' MD. Verbal approval received from Jim Trimble, AOGCC, 01/05/83. J,/ N 0 7 1983 Alaska Oil ~', Gas C'om3. Cofp, rrli.s.;io,q 14. I hereby certify that the .f.oregoing is true and correct to the best of my knowledge. Signed // / - .~- Title Area Drilling Engineer The space below for Commission use Date Conditions of Approval, if any: Approved by (~,? .~-,~--~ COMMISSIONER Form 10~,03 ~ GRU1/SN12 Rev. 7-1-80 Approved Copy RehJrned By Order of the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Thru: MEMORANDUM State of ALASKA OIL ~TD GAS CONSERVATIO~ COMMISSION V/. ~~t~ DATE: January TO: C . rton_/ Cha~~ j,~>~ FILE NO: Lonnie C. Smith! TELEPHONE NO: Commi s sione r FROM: E~-~%r W. Sipple, Jr. Pe t~e um Inspector Alaska 6, 1983 SUBJECT: ¥'Jitness BOPE Test on ARCO's DS 12-18 Sec. 18, T10N, R15E, U[,~i Permit No. 82-206 Rowan Rig 26 ~ue.sday, December 28., 1982 - I traveled this date from Rowan 41 (subject of another report) to Rowan 26 to witness a BOPE test. -.~en I arrived at Rowan 26 they were in the process of cementing the casing. The BOPE test commenced on December 28, 1982 at 5:10 p.z~.~. and vms concluded at 8-35 p.m. There were two failures, the inside valve on the mud cross and the inside BOP. I filled out the A.O.G.C.C. BOPE inspection report which is attached. ,~ .. In sum~.-~ary, I ~itnessed the BOPE test on ARCO's DS 12-18 Ro~n Rig 26. Attachment: Mr. Steve Cameron of ARCO called, they have a new inside BOP, it tested to 5000 psi. The inside valve on the mud cross is on order, they will call the A.O.G.C.C. office %,~.en it is installed and. tested. 02-001 AC Rev.10/79~ 4/81 :-~ STATE OF ALASKA OIL ~ CAS CO~'ISERVATI~ :!~ rff~,lbLISSION B .O.P.E. Inspection k Location: Sec /~ Dril linq Contractor Location, Ceneral Well Sign ,- Ceneral Housekeeping Peserve pit Rig '.30 PE Stack ~ ~ 70o ~%nu ~a r Preventer Pipe Rams B ~ind e [~ Valves Kil 1 ~e Val~s o~ Test Pres sure 2 7o ~ ooo S"oO o -~0o o 3o~o permit # gL- ;~% Casing Set @ 1~ ~ ft. ,Representative St ~ ~11 O, arge ~es ~re ~ 0 O0 psig ~) incr. clos. pres. 200 psig. O ~n~/ sec. ~11 Cha~e ~ess~e ~tta~: ~~n ~Lsec. Cont~ls: ~ster ~z~a ~,~ ,~ R~te ~ Blinds ~;itd] cover ........................... Kelly and Flor 'Safe~ Valves - ~r Kelly--Test ~essure ~r Kelly. ~ Test ~es~e ~11 ~pe o/~__Test [~es~re I~ide ~P ~N~/&~ Test ~es~re " Choke F~nnifold ~ ~ Test ~essure ~O~O ~. Val%~s / ~ No. flanges ~_~__ ~j~t~le ~okes [~aui~lly operat~ ch~e Repair or Replacement of failed oquipmant to be made within, 3 days and Inspector/Cc~nmi~sion office notified. ~~ ' .. _[.M[I[ (-t)ll ~,0, ~.CC ~.1~.~-1~.~- I,~'~,~ ~f~Tr~ >.l ~,~ V~lv~ ~ Distribution orig. - AO&CCC cc - Operator cc - Su~sor r) ~ 1982 ..eeer~:~ber 8, Mr. Mark A. "- ' Area Drilling Engineer ARCO Alaska, Inc. P. ©. Box 360 Anchorage, Alaska 9.~10 Re: Prudhoe Bay Unit DS 12-18 ARCO Alaska, Inc. Permit No. 82- 206 ~ ' ~' ~18' Sec. 18 TIO~; R15E Sur. L~c. 4~ ~-~, ~ FEL, , , , . Bt~ole Loc. 251~'FSL, 93'FWL, Sec. 17, TIOH, R15E, Dear }~r ~-~ ~ · . ~ ~, or · Enclosed is the approved application for permit to drill the above referenced well. If coring_ is conducted, a one cubic inch ~ ~ _. c.a~.p from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containin~ ~ ~ t~.e digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska amd their drainage systems bare been classified a~ important for the spawning or migration of anadromous fish. Opezations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Cede). Prior to co~amencin~. operations you ~ay be contacted by the Habitat Coordinator~"s Office, Department of Fish and Game. w ~= f the State is prohibited by AS 46 Pollution of any .ate~ o . , Chapter 3, Article 7 and. the rezulations promulzP, ted thereunder (Title 18, Alaska Adn~inistrmtiv~ Code, Chapter 70) and by the Federal !~ater Pollution Control Act, as amended. Prior to com~mncing operations you may be contacted by a representative of the D p~ +~- Environmental Conservation. ~e~.ar~nent of ..... To aid us in scheduling field work, please Dotify this office ~.~o ~ ' ~a!latinn of the blowout 24 ~,,~o prior to co~encim_~, zn~ ~ Mr. Mark A. Mmjor Prudhoe Bay Unit DS !2-i8 -2- December 8, 1982 prevention equipment so tb~t 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 Cor~_~mission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspehsion or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yD!n%s, . - .'. i ~ ~ " / 7;' .C.V. ~h~tt-r ,'on J .Y oi~a o ..... ~- ~airman of Alaska Oil and Gas Conservation Comaission Enc lo sure cc~ Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. CVC: be ARCO Alaska, inc. Post Oflice Anchorage,. ,ka 99510 Telephone 907 277 5637 December 2, 1982 Mrs. El'aine Johnson State of A1 aska ' Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: ConduCtor As-Built Location Plat - Drill Site 12, Wells 15-19 Dear Elaine- Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG'sm Enclosure GRU2/L52 ££CEIV£D DEC 06 1,982 Alaska Oil & Gas Cons 4nchora~ Comm/s,/o~ ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany . ii° ,P IS I HEREBY CERTIFY THAT I AM ' PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS-BUILT SURVEY MADE BY ME, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT, AS OF: 12/15 12/16 12/17 12/18 RECEIVED z2/z9 ~'~' 49th Y= 5,930,400.95 X= 696,720.53 LAT= 70'12' 50.660" IfkN(~ 148' 24' 47.771" NW COR CEIJAR BOX ET~VV = 41.6' Y= 5,930,520.80 X= 696,708.71 LAT=- 70'12' 51. 842" IfkN(~ 148'24' 48.024" NW OOR CELLAR BOX ~FV = 41.9' Y= 5,930,639.98 X= 696,696.63 LA2~ 70'12' 53.017" IDN(~ 148'24' 48. 284" NW COR CELLAR BOX E~Tf = 42.0' Y= 5,930,759.49 X= 696,684.78 LAT= 70'12' 54.195" LONG= 148'24' 4~. 538" N-W COR (?,Ti'.TAR BOX FT~-7~ = 41.7' Y= 5,930,879.28 X= 696,672.84 LAT= 7(>~,12' 55.376" ION(P= 148'24' 48. 794" Alaska Oil &~__,Gas Cons, Com,~ ..... ; ~ COR CMI3AR BOX ~ = 41.4' ~,r,r'~~ , .... . _,_'_, ............................. .... A Alaska nc. o, $ub~Jdiary of Afl.th; Rte, hfield Comgen~ .. ..... NO~:I SLOP[ ~~-~ BAY ARCO Alaska, Inc. Post Office Bc,~ Anchorage, Alaska 99510 Telephone 907 277 5637 November 23, 1982 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' DS 12-18, Permit to Drill Dear Mr. Chatterton' Enclosed is our application for Permit to Drill DS 12-18 and the required $100 filing fee. Attachments to the application include a plat detailing the section and plan views of the proposed wellbore; a proximity plat showing the subject wellbore's position to the nearest well drilled; a discussion of nearby wellbores; a sketch and description of the BOP equipment; and a sketch and description of the surface hole diverter system. Sincerely, M. A. Major Area Drilling Engineer MAM/JG: sm Enclosures GRU2/L45 ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA .... ALASKA L,,L AND GAS CONSERVATION CO,,,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~( DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC I--I SINGLE ZONE [~X MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 452' FSL & 918' FEL, Sec. 18, T10N, R15E, UM At top of proposed producing interval 2374' FSL & 25' FWL, Sec. 17, T10N, R15E, UH At total depth 2513' FSL & 93' FWL, Sec. 17, T10N, R15E, UH 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 77', PAD 41' I ADL 28330 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewi de Surety and/or number #8088-26-27 9. Unit or lease name Prudhoe Bay Unit 10. Well number i~;:DS 12-18 11. Field and pool Prudhoe Bay Field Prudhoe Bay 0i1 Pool Amount $500,000 13. Distance and direction from nearest town Deadhorse 0 miles ~ 16. Proposed depth(MD & TVD) ' 9818'MD, 9227'TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT4500 feet. 14. Distance to nearest property or lease line 2906 feet 17. Number of acres in lease feet . 251 2 20. Anticipated pressures MAXIMUM HOLE ANGLE 29.5 o (see 20 AAC 25.035 (c) (2) 15. Distance to nearest drilling or completed 2-11 well @ 5280' MD = 93 feet 18. Approximate spud date 12/20/82 ,21 Proposed Casing, Liner and Cementing Program 3521 psig@__ Surface 4140 psig@ 9?27 ft. TD (TVD) SIZE 'Hole Casing Weight 20" 91.5# ~0" i7-1 / 2" 2-1/4" /2" 13-3/8" 9-5/8" 7I1 72# 47# 29# 22. Di~scribe proposed program: CASING AND LINER Grade Coupling H-40 Welded L-80 Butt L-80 Butt L-80 Butt Length SETTING DEPTH MD TOP TVD 80' 36' I 36' 2667' 33' I 33' I 9203' 30' ~ 30' I 885' 8933 ' 18457 ' I MD BOTTOM TVD 116'1 116' t 2700' 2700' I 9233' 18719' I 9818' Ii 9227' QUANTITY OF CEMENT (include stage data) 2000 # Poleset 2300sx Fondu + 400 sx PFC 500sx Class G 1st Stage 300 sx PFC 2nd Stage 400sx Class G ARCO Alaska, Inc., proposes to directionally drill this well to 9818' MD (9227' TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be installed and tested. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2", 17# L-80 tubing, packer, and gas lift mandrels will be run. Provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. The packer will be set above the Sadlerochit. A Sundry Notice will be submitted when the well is to be perforated. A surface diverter will be installed and operationally tested prior to spud and at least daily thereafter. See attached proximity analysis 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED 7f~"~'~/F'"~ TITLE Area Drilling Engineer The space below for Commission use DATE CONDITIONS OF APPROVAL Samples required Mud log required I DirectionaISurvey required APl number t--lYES ~NO i--lYES ~]'NO t [~YES []NO 50- O L ~- 'L ~ ~'~ 7 SEE COVER LETTER FOR OTHER REQUIREMENTS Permit number APPROVED BY~//~ ..A/~ Form 10~01 GRU2/PD29 Approval date ,COMMISSIONER by order of the Commission DATE December 8, 1982 Submit in triplicate DS 12-18 PROXIMITY ANALYSIS There are 3 wells within 200' of DS 12-18 (as planned). They are DS 12-11, DS 12-4, and DS 12-9 in order of occurrence. Please refer to the attached diagrams' 1. DS 12-18 comes within 182' of DS 12-4 at 4820' MD on DS 12-18. This occurs before DS 12-4 is actually crossed. At the crossing point, this figure increases to 771'. 2. DS 12-18 comes within 93' of DS 12-11 at 5280' MD on DS 12-18. This occurs shortly after kickoff. At this point, DS 12-18 will be led to the left (away from DS 12-11), which will actually increase that distance. 3. DS 12-18 comes within 141' of DS 12-9 at 5620' MD on DS 12-18. At this point, DS 12-18 will still be led to the left (away from DS 12-9), which will increase that distance. JG'sm 11/23/82 GRU2/AWP4 13-5/8" BOP STACK DIAGRAM I .ANNUL:AR PREVENTER BLIND RAMS Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultane'- ously and record the time and pressure remaining after all units are closed with charging pump off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. PIPE RAMS SPOOL PIPE RAMS 13-5/8" BOP Stack Test 1. Fill BOP stack and manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark running joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close a~nular preventer and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a, 250 psi low pressure test for a minimum of 3: minutes, then test at the high pressure. 5o Increase presure to 3000 psi and hold for a minimum of_ 3 minutes. Bleed pressure to zero. . 6. Open annular preventer and close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pres- sure to zero. 7. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. g. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to zero. Open bottom set of pipe Il. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. I5. Check operation of Degasser. 16. Record test information on blowout preventer test form. Sign and send to Drilling Super- v i sot. 17. Perform complete BOPE test once a week and functionally operate 8OPE daily. SURFACE HOLE DTVERTER SYSTEM ARCO ALASKA ]'NC'. SCHEMAT'fC _~ IO" HYD. OPR. BALL VALVE ~ ~ WE,L,L BORE (SEE DETAIL) ./~ f~-'- lO HY?. OPR. BALL VALVE ,/ /'"-/' I ALL 90 TURNS ARE "TEE" ~ I CUSHION I I I~LL RESERVE PIT AREA NOTE' FLOWL INE F DR ILL lNG RISER L 20" 20O0 PSI WP ANNULAR PREVENTOR L-l...~r~ I o. HYDRAULIC OPERATED.BALL VALVES 'Valves on diverter lines open automati- cally when the annular oreventer is closed. 20" CONDUCTOR PIPE "DETAIL" 2026010203 CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. , ~(,, ITEM APPROVE DATE (1) Fee < ;': ..,.... . , ,oc ' (? t~ru 8) (3) Admin ~-5/_~'~-~ .~ (~ ihTM11) '"" "~ '"''' (4) Ca s g ~~ /2'2- (12 thru 20) (21 thru 24) 1 6. 7. 8. 0 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Is well to be located in a defined pool ...... Is well located proper distance 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 well bore plat included ............ Is operator the only affected party .............................. Can permit be approved before ten-day wait ....................... YES NO · · · ;" ,,% REMARKS Does operator have a bond in force .................................. order needed Is a conservation ...................................... Is administrative approval needed ................................... Is conductor string provided ....... Is enough cement used to circu{;;~'g~ go~dug;gr '" ''''''' ''''''''and'surface''''''''' Will cement tie in surface and intermediate or production strings .. Will cement cover all known productive horizons ........ ............ Will surface casing protect fresh water zones ....... · .............. 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 abandonment procedure included on 10-403 ........... Is adequate well bore separation proposed .......................... Is a diverter system required . . . Are necessary diagrams of dive;;~; ~'~; ~i;~;'~;;;~ Does BOPE have sufficient pressure rating -Test to Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional 'requirements ............................................. Additional Remarks: 'x o ~Z HO Z Geology: Engineering: HWK ~~._ LCS~BEW :,~TA JKT RAD~----- JAL . MTM HJH .,, rev: 08/19/82 INITIAL GEO. UNIT ON/OFF' POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. 3~ : i'X'Tb¢,t<'T]'C': I.~.IC,~tF.I., i:'i,O C(')'P,'",P,~i~Y (lUO (')0(t O28 ('>65 2 f'J tj k' ,-' .:,~ tL)i.2 T i.,,1 f; L~ i',7'~ P 1! .... () () (I, (t () (.) l, i 2 06 fi = = :~.Ooi bP.l(.; = = ,;t,~:; t:3 1,55C' ~3 bS,0 {5IF "00 lc 60,(.' i~15 ! , ~'.. ..... 1.96(; i~ 52,0 [.:'~ 0.497 (a ~6,0 OF ,t !, 6 t',, l, },' 4 ') 3 ~.., O DATA 5 P L>OTA RNRA SP N P ii I FCNL POT a NRAT R A i R A 't ; P ~PH1 ~Cal, ) 0 'r ,A { N R A ~RAT F£mL ?OTA R~tRA NRAT DEPT SP NPHI FCNI,, NRAT P 0 T A N R A 'f 9500. 0000 SFLb' 38,843'1 I bD 0, O02,:~ SCa 22,8281 CGR -999. 2500 92 00 .'0 000 ,)F l.,i.:; -999,~b0:0 -999.2500 i") g. ~.~ r:, -999,2500 P:EF -999:., -999, 5{)0 5.3 'I I. 1 ,,~" r',, ~,< 82,2560 4.1992 ........ 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CGR "99~, 2500 -999,2500 -~99.250u :559,00o u -999. 2500 -999. 2500 -999.2500 · -999,2500 ~,'~1, .'.999.2500 -999,250i) -99'J,'2500 299':~, 250o 9 9 9,25 0 0 31.~895 573, ...%.' 000 ' 9 9 ¥ ,, 22 b (.: t..:' L: -' 9 q q o ? 5 ~' ,' "i" ;. i'il,! - 9 9 ~, z 5 ~.) u C C, t~ 54., [:, '4.3 ;5 ,f7 ;'~ -999. ,'.'i ~, bg~b 4:1 ~. 25 u 0 · ',999, A .,h U C' - ~ 5)~.~ o 2500 - 999 o 2.5 t.,~ -,999.25OO -99~, 25U0 .tt~, $301 -9'49 , 25(',' 0 ... 99 ,.~, 2 5 u 0 · ,,999,25(:;,(7) L'I"'~ I'11111 i I iI:-I il! [:-11 '"'999. 250o IL!' q <-: 9, "'' 5 G 0 f?'i~ =999.2L',UO I~ h I.) b - 9'~ 9.25 {.,",.~ 6¢). 2';~, 13 D g P T SF N P l.t I NRA 7' PO'FA Rf,,iR A -999. 2500 -999.25u0 - 999,2500 -999. 2590 ~i 17. 2500 -999,250O -9ci9. 2560 -999 o 2500 -999, 47 07 03 31.t[2 J b (., -999,2,,h, u6 - 999,2 5 00 2999,, 2500 99t~. 2500 - 99~, 25 o o 3 t~ 'i. 2 b o 0 i . I'-~ ~ I~1ii1 il;Iii! [;-] I DEPT SP ~ P H ]' N R A 'J Pt3 ~',[ A OEPT SP NPH I FC['*L N R A T -999,2500 -999.25o0 -999.2500 · -999, z,50u -999. 2500 39. I bU2 3 9 8,2,5 0 0 -999.25U0 -CO9. 2500 - 999.2 5 0 (:,' b -999,25(,0 I~¢a!'; -999.2500 15 ~ 3,0 U 0 u -999,2506 · -g99.25u0 -q99.25GC -9~ · 250O -999,25()L) 41.79o9 329. 0900 -9q9,2500 -99~. 2bO0 -999. 2500 - 9 ti; '9.2 b 0 0 3 I. 8906 ~49, l)t) u U -999.25O0 -999,2500 -999,2500 -999. 2500 -9'.9'~. 2500 332. 500,0 - 99 9. P., 5 (, ~ 0 -999,2500 -999.25(~0 .-.999.2r' C 4,~ o79'1 ,43 .. 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OOt~O FCr~i~ -9c~9. 2500 -9t¢9.25t)U -999.2500 -999.2500 54,29~9 241,3750 -999. 2500 -999. -9~.~...2500 -999. 2500 -9 .gg, 25C-0 41,~457 3 ] L}. 2500 - 999. :250 (; -999,2500 -999,2500 -999,2500 -9¥9. 2500 3 4 b, 5 o 00 -99'~, 2509 - 999.25 0 0 -999,2500 -999. 2500 ~2.9 ), 9q 393. b ('3 (,~ (.~ -999.2500 -~9~, 2500 .- 9 '9 9 , 2 b 0 (; - 999,2 iJ 0 375 ' 0 (')()() ~ . . ) E P 'I' 4200 o 0 t ~ (.~ t) 5 t;" ~Ct~L -999.2bU0 PF, F' -999.2600 CALl ~O'l' A -999.2bU0 3GR -999.250(~ CGR ~,'RA 4.722'1 {RAT ~.J750 -~99.25o0 YCaI, -999.2bU0 PkiF -999,2b00 CabI ~RAT -999.25U0 - LGk ?OT~ 999 2500 RNRA 4, O00U 8GR 30,5 ! 56 ~.~Ct'~L O L, p T 3 9 O 0. u u 0 0 SP -999,2500 ~PMI -999 2500 F'CNI., -999' 25o0 PO'I:A 9991 500 NRAT 4. ~ 164 OEPT SP P 0 T -999 259U ):}Rt~[: : -99:9 R~t:[,~e3 ~.099,250U - 999.2' 500 8 G F' '999,25:00 C G' ~ - 999.2 r.~ o 0 i',~ p H i -999. -999,, 2500 -999. 2500 -999.2560 -999. 2500 309, ,,,999,2500 -999. 2500 -999.25t)0 -999.2SuO -999,25i)0 ,<~8. 5840 -999. 250o -999 ,, ~500 - 999.2500 - 999,2500 99 ¥. 2500 54,052::7 -999. 2500 -9¥9 25t 0 <42.9~99 30z. ~'P -999 251i0 (.;.~ ~99 FC~L -999,2500 P&~ -999,2bu0 CALl' PO'fA -999. 2500 8Gi~ -999, ~RA'r 4, u~OO~ DEP"r SP N P d 1 F C b~ L, N R A 7' 32, 00.0 ~..'1 (. 0 S '999,2500 . .2 -999. 2500 FEI -99g-2500: - 999.2500 '999,25b0 SP NPH 1 N R A T POT A - 9 9 '9,2 5 {.~ o C; R '9 9 9 * z. 50 0 o I . . ,. ,.. _ -999,,25oo -999. 2500 -999 ' 25C~0 '~C~'~'. ,,~ .~... - ~ 9 9 · 2 5 0 u 8 C4 R - 999.2 5 (2:0 ~ it,: ik "., ., 9:¢, 25U0 .t 2. 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I !. 6~ 68 6~ 6~ 6~ 6~ 6~ 6~ 6n 6~ 6n 6~ 6n 6~ q q o · ,.9. 500 -0o9. 2500 990. ~ 500 -o9~, 2500 -999.2500 -09~.~. ?509 21.64 ~; 5 t22.gj75 ~ 34. ~75o 21 274. 5000 2g0'~2~5 99S,~792 ~.6,1 005 ~92.n'1~4 ~35.1274 ! ~. 2un~ 237. 3750 ! 7,4,45 3 1q.203~ 19,46~g 1~.7344 17.7()31 16.7'175 2~. 37~() I ' , 9'/, 1.~. ?20. °9~ ~ T ~ ~ T ?NAT -m99. ?5{)0 -999.~500 -q99. 2500 -990, ~500 -999.25~0 49.7061 ~, 6934 i ,1:5. ~375 ~., 72 ~ 7 :I 33.0000 ~,3~"24~2 ~. 7296 ~41.5000 39.~375 m. 3.6t2 ~2.7266 ~,3844 9O, 3750 ~.3270 95.4092 ~.7245 13.3125 70. ~.7266 8~. 1250 2.~4~2 ~3.o0~0 2 ~6.~500 54.%625 9~.6~75 9q. 46.q,q -99g.2500 -999,2500 -099 250O -099 2500 21. 2500 -99g 2500 -g99.~500 '999,~500 -~99,~500 -999,~500 1~.!0al 24~,5562 216,5 0 246, 0 17.7207 265o9~19 18 0127 ~ 54: ?930 13,49~9 14,~779 166.84~7 13,7144 176,5313 13,8912 195,06~5 16,4531 221.7500 16.~906 ~24.3750 16.4844 ~20,12~0 16,~.406 22~.0000 1~,71~8 ~11.0000 13 265!9844 13 7500 ~75.7500 751.o3~3 ?5o · 7500 :1 ?, 7492 t. 4'7. ?,04. 6504 3n. 229,1250 233. 3~..~75 27, 177 2~,. ~53 '1, ~23 27. 5938 ~ 4, q, 3750 2¢4. 574'2 1 32. 2500 ,. ~/~ ,,'1' TD ~,q' 2 95, ~750 ~1 5.3945 77.8125 -o9e.2500 -999.25¢0 -09o.25r0 ~;TDT ~,t T O T .~SrC '~TDT [!'T D T 1,3,49~2 280,5000 13.5703 273.S000 2'1,4844 34;,0000 2 ,4023 358.5938 28,32~1 399;5000 27.~89~ 370; 27,~625,338 40~'5625 352,0313 ~3~5000 367,2500 367.0000 36., 78 24,1.602 362,6563 -g99.7500 385 0000 -099~2500-999,2500 -g99.2500 ggg,~500 ~999,~500 -a9g.2500 -~9~.2500