Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
188-123
PLuG=zJ~G & LO~%T!ON ~L.:.%R~C~_ REPORT Sta~a cf A!ask~ , , ~o ~ ~ /3_5 Signe6. Date 02---. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMrv~SSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged back for Sidetrack 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 188-123 301-184 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21875-00 4. Location of well at surface 9. Unit or Lease Name 2653' SNL, 1573' WEL, SEC. 09, T10N, R14E, UM ~:~..~.~,~ Prudhoe Bay Unit At top of productive interval { ~j~; ~ 1902' SNL, 2451' WEL, SEC. 16, T10N, R14E, UM ~-- ~~--.__. ~. 10. Well Number At total depth ~ - 14-40 2967' SNL, 2804' WEL, SEC. 16, T10N, R14E, UM ~ ~' ~{~::' 11 Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and S"~?i'~'N(5'.~ ....... ' Prudhoe Bay Field / Prudhoe Bay Pool RKB = 74' ADL 028314 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 11835 9086 FTI 11786 9081 FTI [] Yes [] NoI N/A MDI 1900' (Approx.) 22. Type Electric or Other Logs Run SID, CNO, ERW, GR, MWD, CBT, CET 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 103' 30" 260 sx Arctic Set (Approx.) 13-3/8" 68# / 72# K-55 / L-80 Surface 4116' 17-1/2" 250o sx cs III, 600 sx'G', 200SX CS II Top Jop 9-5/8" 47# L-80 Surface 10875' 12-1/4" 600 sx Class 'G' 7" 29# L-80 10564' 11834' 8-1/2" 350 sx 'G', Lnr Lap sqzd with 240 sx 'G' ,, 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) , SIZE DEPTH SET (MD) PACKER SET (MD) None 4-1/2", 12.6#, L-80 10640' 10515' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11447' P&A with 111 Bbls Class 'G', Squeezed to 1000 psi 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Not on ProductionI N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER'BBL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, P0rosity, fractures, aPparent dips and presence of oil, gas or water. Su m,t oo o o., EC[IVE D J/4N I '? Alaska 0il & Gas Cons. [;0mmissi0~. Anchorage Form 10-407 Rev. 07-01-80 ORiGiNAL Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. , Top of Sag River 10693' 8878' Top of Shublik 10803' 8902' Top of Sadlerochit 11238' 8991' HOT 11580' 9059' RECEIVED Alaska Oil & Gas Cor~s. Cor~t[!lissior~ Anchorage 31. List of Attachments: Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 14-40 188-123 301-184 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Permit No. / Approval No. 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ( RIGINAL Well: 14-40A Rig Accept: 11/25/01 Field: Prudhoe Bay Field / Prudhoe Bay Pool Rig Spud: 11/29/01 APl: 50-029-21875-01 Rig Release: 12/05/01 Permit: 201-135 Dril!in~) Rig: Nordic 1 PRE - RIG; WORK 08126101 PPPOT-T Passed, Pressure Test Swab valve, Master valve and wing. 09/02/01 Dummy off Gas Lift Mandrels. 09/06101 - 09108101 Make-up 3" Bali-Drop nozzle and stab on Well, Pressure testing IRON. Tag PBTD at 11580' ctm. Mix 17 ppg Class 'G' 66 bbls - (10 bbls 17 ppg Neat cement, 50 bbls 17 ppg with 20 ppb aggregate, 6 bbls Neat 17 ppg) cement. Squeeze 35 plus bbls behind pipe to build squeeze pressure to 500 psi. Shut down and let cement setup for I hour. Try bringing squeeze up to higher squeeze pressures. Pump away and run in hole for tag at 11325' ctd. Order up cement, and POOH, check and clean nozzle of aggregate debris. Run in hole, tag cement top at 11327' ctd. Mix up 45 bbls additional cement (5 bbls Neat 17 ppg, 30 bbls with Aggregate and 9.7 bbls Neat). Squeeze 23 - 25 bbls behind pipe with 1000- PSI whp. Cleaning out with Biozan to 11113' ctm. Pull out of hole replacing voidance with Biozan. Run in hole with 3" JSN and jet clean the wellbore at 3 bpm. Initial tag at 10720' ctm, pump 10 bbls Biozan sweep and punch down to tag hard cement at 11119' CTM. Wash jewelry and tree on way out of hole. 09/10/01 Attempt to drift with 2.83" Centralizer and TEL, got to 9633' WLM, worked tools down to 9651' WLM, Pull out of hole. Run in hole worked tools down to 9833' wlm lost jar action. Dropped Kinley cutter pull out of hole with Kinley cutter attached to end of wire. 09/12/O 1 Rig up braided line make two-wire finder runs - recover 10" wire, 09/13/01 Attempt to fish tool string with braided line. Make two attempts with wire grabs. 10120/01 Fished out Slickline tool string from 9914' sim (Lost 09/10/01 ). 10/27/01 Run in hole with motor and 2.63" Venturi junk basket. Tagged bottom at 11119' ctmd, made several tags to clean up bottom. Pull out of hole with Venturi. Recovered cement and cement chunks, no wire grab fingers. Run in hole with 3" Metal muncher mill (24.7' OAL), Rotate through patch at 9673' elm, tag cement at 11128' ctd, mill to 11131.4" ctd with 18 stalls, pull out of hole to check mill and motor, motor not working properly. Make up new motor, same mill (looks good) and add circ Sub (25.74' OAL). Rotate through patch. Mill from 11122' ctd to 11138' ctd with 38 stalls (10 stalls at 11138') erratic work on motor, grabbing but with clean pick ups. 14-40A, Pre-Coil Tubing Drillir,~ Page 2 10/28/01 Milled to 11138' ctmd. Circulate Bio sweep off bottom and pull out of hole to inspect motor and mill. Found severe wear pattern on outer face of mill with substantial loss of cutting material. Suspect junk in hole. Motor was in good shape. Discussed options with Nordic Company Man. Elect to run 2.80" parabolic diamond mill (same as used for pilot holes). Run in hole with 2-3/8" Inteq motor and 2.80" mill. Mill to 11155' ctd with 3 stalls. Pump 16 bbls Bio, pull out of hole chasing returns at 80%. Freeze protect tubing with 40 bbls 60/40 MW. Pressure test open perfs, WHP climbs very slowly at 0.3 bpm. Pumped additional 20 bbls 60/40 MW during pressure test. At 280 WHP, come off pump, held pressure for 30 minutes. Left well shut in and turned over to Drill Site Operator. :ii ' ·: il , , Legal Well Name: 14-40 Common Well Name: 14-40A Spud Date: 11/25/2001 Event Name: REENTER+COMPLETE Start: 9/12/2001 End: Contractor Name: NORDIC CALISTA Rig Release: 12/5/2001 Rig Name: NORDIC 1 Rig Number: :::,:~.:: ··:·Date ~ Fmm-.T0 Hours:: Acti~i~i :::C~e' ~.NPT.~ .:.:Please...~.:,:: :. ~.:: ~,.~ · .~. Description of Operations · .~; :L ',' ..... :' _: :.' : ~. ,,' ~ :',' ':~:~ . "~. ~:' : ' ' : ;'"" ~'''''' :.i ::!i: :;:; :~:::i:;:.': :.~:' ': :~"":"i~ ~ :' "~:;~:.~ .:..: ' .' · ~ . . · ' · · * * 11/21/2001 16:00 - 00:00 8.00 MOB N WAIT PRE Wait on Weather on DS 15. Wind to high to lay down wind walls. Wind at 20-265 mph. 11/22/2001 00:00 - 00:00 24.00 MOB N WAIT PRE Continue to standby on weather on DS 15. 11/23/2001 00:00 - 06:00 6.00 MOB N WAIT PRE Continue to wait on wind. 06:00 - 06:45 0.75 MOB P PRE Weekly safety meeting for night tour. 06:45 - 18:00 11.25 MOB N WAIT PRE Wait on wind. 18:00 - 18:45 0.75 MOB P PRE Weekly safety meeting for day tour. 18:45 - 00:00 5.25 MOB N WAIT PRE Continue to wait on wind. Winds 15 gusting to 30 at 18:00. 11/24/2001 00:00 - 00:30 0.50 MOB N WAIT PRE Continue to wait on wind. windw moderating. Now at 14 gusting to 22 mph. 00:30 - 01:00 0.50 MOB P PRE Winds moderating, hold PJSM for laying over wind walls and derrick. 01:00 - 14:30 13.50 MOB N WAIT PRE Continue to wait on wind. 14:30 - 14:45 0.25 MOB P PRE Safety Meeting. 14:45 - 17:00 2.25 MOB 3 PRE Lay down wind walls. Scope down derrick, lay down derrick. 17:00 - 21:00 4.00 MOB ~ PRE Move from DS 15 to DS 14. 21:00 - 21:45 0.75 RIGU 3 PRE Safety meeting prior to raising wind walls and derrick. 21:45 - 00:00 2.25 RIGU 3 PRE Raise derrick, scope out same. Raise wind walls. 11/25/2001 00:00 - 00:45 0.75 RIGU 3 PRE Continue to raise derrick and wind walls. 00:45 - 01:10 0.42 RIGU ~ PRE Move rig in over well. 01:10 - 01:30 0.33 RIGU ~ PRE Nipple down tree ~p. 01:30 - 05:30 4.00 RIGU 3 PRE Nipple up BOP stack. Rig a~pt at 01:30 AM. PU injecter, MU goosene~. 05:30 - 08:00 2.50 RIGU 3 PRE Be~ crew set up be~ and cuEings tank, and hardline to flowba~ tank. Changing packoffs. 08:00 - 10:00 2.00~ RIGU P PRE Stab CT into inje~er. Cut off 150 ff of CT. 10:00 - 20:30 10.50 BOPSU~ P DECOMP Pe~o~ initial DOPE pressure / fun~ion test. Test Witnessed by AOGCC inspe~or John Crisp. Repla~d leaking 3" Iow torque valve on drain line. Filled rig pits with 2% KCL water and 1/2 ppb Biozan. Se~i~d injeMor head. 20:30 - 21:30 1.00 BOPSUF P DECOMP Pull test CTC to 26klbs, PT to 3500 psi. Fluid pack coil, PT Inner reel valve. 21:30 - 21:45 0.25 CLaN P DECOMP safety meeting prior to picking up first drilling BHA. 21:45 - 22:15 0.50 CLaN P DECOMP MU BHA ~1 to clean out ~ment from old well bore. WF straight motor, Hughes bi ~ntered 2.75x3.0" bit. 22:15- 00:00 1.75 CLaN P DECOMP RIH with BHA~I 11/26/2001 00:00- 00:30 0.50 CLaN P DECOMP Continue RIH with BHA ~1. 00:30 - 02:00 1.50 CLaN P DECOMP Weight check at 11000'=29klbs. Tag up at 11158' CTM, corre~ to last tag of 11155'. Pick up, free spin=1150 psi at 1.6 bpm. Begin milling from 11155'. 02:00 - 03:00 1.00 CLaN P DECOMP 11160.5', 02:00 update. Drilling hard ~ment. 1.7 in/out, 200 3si motor wo~. Only making about 5 fph. Drilling 17 PPG Aggregate ~ment [20 PPB Agg.]. 03:00 - 04:00 1.00 CLaN P DECOMP 11190', 03:00 update. Drilling ROP up to 30 fph now. 1.76/1.7/1335 psi. 04:00 - 05:00 1.00 CLaN 3 DECOMP 11200', 04:00 update. Drilling ROP now at 10 fph. 1.7/1.7/1300 psi. 272 bbls in pit. 05:00 - 06:00 1.00 CLaN ~ DECOMP 11214', 05:00 update. Drilling ROP 15' for last hour. 1.6/1.5/1300 psi. 272 bbls in pits. 06:00 - 08:30 2.50 CLaN P DECOMP 11221', 06:00 update. Drilling ROP 7' for last hour. 1.7/1.6/1380 psi. 268 bbls in pits. Drilled to 11,270 ~ by 0830 Printed: 12/10/2001 11:17:38 AM iiiiiiii · : ii iii: . ! :il i Si:sumffi:a Re:po :. ,,,. , , , , Legal Well Name: 14-40 Common Well Name: 14-40A Spud Date: 11/25/2001 Event Name: REENTER+COMPLETE Start: 9/12/2001 End: Contractor Name: NORDIC CALISTA Rig Release: 12/5/2001 Rig Name: NORDIC 1 Rig Number: i}i!iil}i'~t6'! ii' ?.: :' FrO~, TO. Hbfirs ~ti~i~ C~b :N~ :. :~ase. i:-:: ": : i.:: .::;;:' '.':.~: :...i: ::: Description Of .... Operations · 11/26/2001 06:00- 08:30 2.50 CLEAN P DECOMP hrs. Ave. ReP = 20 FPH. 08:30 - 14:00 5.50 CLEAN P DECOMP Mill 17 PPG, Agg. CMT. Ave ReP = 11 FPH. 1.7 / 1.7 BPM, 1500 psi. Drilled to 11,330 ft. 14:00- 17:30 3.50 CLEAN P DECOMP Mill 17PPG, Agg. CMT. Slow drilling, 15 FPH. Drill out of aggregate at 11,365 ft. ReP increased to 60 FPH. Full returns. Drill to 11,400 ff. CTD. Circ. 15 bbl high vis pill to clean hole. 17:30- 19:30 2.00 CLEAN P DECOMP POOH for MWD Pilot hole BHA. 19:30 - 19:45 0.25 CLEAN P DECOMP Tag up at surface, lay down BHA #1. 19:45 - 20:00 0.25 STWHIP P WEXIT Safety meeting to discuss window milling operations. 20:00 - 20:45 0.75 STWHIP ~ WEXIT MU BHA #2, Pilot hole BHA with MWD, Sperry Orienter, 1.75 deg WF motor, D331 DSM. 20:45 - 21:10 0.42 STWHIP ~ WEXIT RIH with BHA #2 21:10 - 21:30 0.33 S'i'WHIP ~ WEXlT Shallow hole test of MWD and orienter. All ok. 21:30 - 22:55 1.42 STWHIP ~ WEXIT Continue to RIH. 22:55 - 23:15 0.33 S'I'WHIP ~ WEXIT Tagged up at 11169', picked up heavy. RIH, tagged up at 11161'. Humm? Pick up. Kick on pumps to 1.7, Free spin=2300 psi. Ream top of pilot hole. Fell through easily. RIH to 11240'. 23:15 - 23:45 0.50 STWHIP N DFAL WEXIT Try to start tie in logging pass down at 11240'. No pulses from MWD tool. Try pumps down/up. No success. Pull up above top of pilot hole. Pumps down/up again. Still doesn't work. POOH for new pulser. 23:45 - 00:00 0.25 STWHIP N DFAL WEXlT POOH to troubleshoot MWD problems. 11/27/2001 00:00 - 01:15 1.25 S'I'WHIP N DFAL WEXIT POOH to troubleshoot MWD. 01:15 - 01:55 0.67 STWHIP N DFAL WEXlT Tag up at surface. Troubleshoot MWD. Found damaged piston in pulser. Change out pulser. 01:55 - 02:20 0.42 STWHIP N DFAL WEXIT RIH with BHA #2. 02:20 - 02:30 0.17 S'I'WHIP N DFAL WEXIT Shallow hole test ok. 02:30 - 04:00 1.50 STWHIP N DFAL WEXIT Continue to RIH with BHA #2. No problems RIH through top of cement sheath. Ran down to 11240' easily. 04:00 - 04:25 0.42 STWHIP P WEXIT Log tie in pass down from 11240'. 1.7 bpm, 60 fph. Tag up at 11254'. Stop log, try to clean out hole to 11400'. Note - We are in interval of perforations. Could be hanging up on cement nodes at perfs? Hard to believe with a D331. Pickups have been clean. No Tie-in made. 04:25 - 06:30 2.08 S'I'WHIP ~ WEXlT Mill down from 11253'. Tag up at 11255' and stall. Tool face 90L. Pick up, take 4 clicks. Tag up/motor work again. Take 4 more clicks. Tag up at 11257'. Acts like a chunk of cement that we are chasing down hole. Keep after it. Very grabby on the stalls. Not getting much mill on bottom time. Keeps stalling. Last tool face 75R. Take 5 more clicks. TF 165R. Still stalling at 11254'. Assume it is a chunk of debris from the top of the cement sheath. Continue milling/stalling on it. 06:30 - 09:30 3.00 STWHIP P WEXIT Chasing debris down hole. Ream ahead at 1-3 FPM to 11,350 ft. Several stalls at 11,350 ft. 09:30 - 10:30 1.00 STWHIP ~ WEXIT Work thru spot at 11350 ft. Ream in hole to PBTD at 11402 ft. Back ream to 11240 ft. 10:30 - 11:30 1.00 STWHIP P WEXIT Log Tie-in with GR. Added 5.5 ft to CTD. 11:30 - 12:00 0.50 STWHIP P WEXIT Orient TF to Low side. 12:00 - 15:00 3.00 STWHIP P WEXIT Mill cement. 1.7 / 1.7 bpm, 2950 psi, TF = 170L, ReP = 25 Printed: 12/10/2001 11:17:38AM i: : ! ii,i!. Pe: ionS: :sum a ''i .:Rep°rt. . , ,, , Legal Well Name: 14-40 Common Well Name: 14-40A Spud Date: 11/25/2001 Event Name: REENTER+COMPLETE Start: 9/12/2001 End: Contractor Name: NORDIC CALIST^ Rig Release: 12/5/2001 Rig Name: NORDIC 1 Rig Number: !i~r°~ii~O· iH~:i:~i~: C~ Np~:: :Phase i. ~ :. : .:::Description.of Operations. 11/27/2001 12:00- 15:00 3.00 STWHIP P WEXIT FPH. 3000~ WeB. Mill cmt to 11424 ft. 15:00 - 17:00 2.00 STVVHIP P WEXIT Mill cement. 1.7 / 1.7 bpm, 3000 psi, TF = 170L Mill to 11442'. 17:00 - 17:30 0.50 STWHIP P WEXIT Orient to 10L. 17:30 - 19:30 2.00 S'I'WHIP P WEXIT Mill cement ramp w/HS TF from 11442' and contacted 7" @ 11449.5' 1.7/3200/10L. PUH and flag at 11300' EOP 19:30 - 21:15 1.75 S'I'WHIP P WEXIT POOH for window mill 21:15 - 22:00 0.75 STWHIP P WEXIT Change out motor and mill. Pilot mill gauged 2.77" 22:00 - 00:00 2.00 STWHIP P WEXIT RIH w/BHA #3 (2.5 deg motor w/2.74" window mill) 11/28/2001 00:00 - 00:45 0.75 STWHIP P WEXIT RIH at min rate thru cement sheath at 40'/rain, clean. Check depth at flag and no corr. RIH at min rate to tag at 11448.7' CTD. PUH and check TF at 30L. Start pump 1.6/2710 and tag at 11447.0'. PUH 1' and chk TF @ 32L 00:45 - 01:50 1.08 STWHIP P WEXIT Try one click and got 4. PUH 10' and orient around 01:50 ~ 07:00 5.17 STVVHIP P WEXIT Get 5L and will live with it. RIH and tag at 11446'. Flag CT. PUH 1'. Begin time milling by schedule 1.6/2540/5L 13.6k. Mill to 11447.0' at 5L-10R 07:00 - 08:35 1.58 STWHIP! P WEXIT Milling window. 1.6/2750/9L 11.0K 08:35 - 09:00 0.42 STWHIP P WEXIT Milling window. At 11448.5', got back major weight from 9.8K# to 11.9K#. TF jumped from 7R to 25R. 09:00 - 10:30 1.50 STWHIP P WEXIT Mill ahead at 10' per hr to 11452'. Begin stacking weight again. Pump 10 bbls bio sweep. 1:1 rtns. Started stacking wt again at 11450'. Stack 6K# with 100-200 psi mtr work. Not drilling off. 10k# over pulls when picking up. 10:30 - 11:00 0.50 SI'WHIP P WEXIT Back ream at 0.5'/min. 11:00 - 11:30 0.50 STWHIP P WEXlT RIH. Tag at 11452'. 200 dpsi mtr work, but no drill off. Only 11:30 stacking wt 6k-7k down) - 13:00 1.50 STWHIP P WEXIT POOH to check window mill. 13:00 - 14:00 1.00 STWHIP N DPRB WEXIT Inspect mill. Clear evidence of having crossed center line. Re-run mill on 1.75 deg motor. 14:00 - 16:00 2.00 STWHIP N DPRB WEXlT RIH. Shallow test mwd. Continue in hole. Tag at 11450' 16:00 - 16:45 0.75 STWHIP N DPRB WEXIT Orient to 5L. RIH. Tag up short of flag. 16:45 ~ 17:15 0.50 STWHIP N DPRB WEXIT Log gr tie in down from 11240'. Add 4' correction. 17:15 - 17:30 0.25 STWHIP N DPRB WEXIT Tag at 11455.7' corrected. (1' from flag) TF at 60R. 17:30 - 18:30 1.00 STWHIP N DPRB WEXIT Orient around to HS. 18:30- 19:15 0.75 STWHIP N DPRB WEXIT Ream window area to TD 1.6/2600/10L. Drill formation from 11455.7' to 11468.0' Unless otherwise verified TOW is 11447' and BOW is 11452' 19:15- 21:05 1.83 STWHIP N DPRB WEXlT POOH for tapered mill 21:05 ~ 22:30 1.42 STWHIP P WEXIT LD motor and mill. MU new motor and used tapered mill. Change out BHI MWD tool 22:30 ~ 00:00 1.50 STWHIP P WEXIT RIH w/BHA #5 (1.75 deg WF motor, 2.73" tapered mill with 1" OD bald cap) 11/29/2001 00:00 - 00:50 0.83 STWHIP P WEXIT Continue RIH w/BHA #5 00:50 - 01:10 0.33 STWHIP P WEXIT Tag at min rate at 11450' un corr. PUH and chk TF at 110L. Orient to HS 01:10 - 02:45 1.58 STWHIP P WEXIT 1.5/2460/8L Ream window area. Had 3 stalls at 11447.3', then RIH to TD at 11464' at 27L. See flag at 11458' which means we're on depth with previous run. Get a click and backream up. Repeat thru 42R. Dry run, clean 02:45 - 04:25 1.67 STWHIP :~ WEXIT POOH for drilling assy 04:25 - 05:40 1.25 DRILL ~ PROD1 Change motor, MHA, MWD probe and restrictor Printed: 12/10/2001 11:17:38AM i ; !ii,. i ii: r iens..Summa .RePort.. , , , Legal Well Name: 14-40 Common Well Name: 14-40A Spud Date: 11/25/2001 Event Name: REENTER+COMPLETE Start: 9/12/2001 End: Contractor Name: NORDIC CALISTA Rig Release: 12/5/2001 Rig Name: NORDIC 1 Rig Number: .Dat~::' Fr~T~:; :: ,.:..: ::.... ?H6UrS!>'.A:. ~ ~ti~l~::;COde:i NP~ ;Pha§e.::.' :"..-'i':':~ ...;: '.:. Description of Operations ,, :~ : 11/29/2001 05:40 - 07:45 2.081 DRILL P PROD1 RIH w/BHA ~6 (1.15 deg motor) SHT 07:45 - 08:15 0,50 DRILL P PROD1 Log GR tie in from 10810'. Add 1' correction. 08:15 - 08:45 0,50 DRILL P PROD1 RIH to previous tie in point at 11240'. Log gr again to verify on depth with orignal tie in point used to mill window. No correction. 08:45 - 09:00 0.25 DRILL P PROD1 RIH. Tag TD at 11464'. TF at HS. 09:00 - 09:45 --' (~,75 DRILL P PROD1 Drilling. Begin displacement to mud. 1.7/1.6/2800 psi fs / TF:HS Drill to 11495'. 09:45 - 10:15 0.50 DRILL P PROD1 Tool face flopping to Iow side. Orient several times. TF~tfll erratic. Formation ? Fault ? Bad orienter ? Finally~bilized at 80R. 10:15- 11:30 1.25 DRILL P PROD1 Drilling. 1.7/1.6/2650fs/TF: 120R 100-150~15h ReP Drill to 11610' 11:30 - 12:00 0.50 DRILL P PROD1 Orient around to 80R. 12:00 - 12:30 0.50 DRILL P PROD1 Short trip to window. 12:30- 13:30 1.00 DRILL P PROD1 Drilling. 1.6/1.6/3300/TF:120R 1~-150 fph. Drill to 11710'. 13:30 - 14:15 0.75 DRILL N HMAN PROD1 Re-log interval due to mwd probit. 14:15 - 15:00 0.75 DRILL :~ PROD1 Drilling. 1.7/1.6/3200/TF:I~I~ 100-150 fph. Drill to 11775'. 15:00 - 15:15 0.25 DRILL = PROD1 Orient to 80L at 11864~/ 15:15 - 16:30 1.25 DRILL 3 PROD1 Drilling. 1.7/1.7/320~/"TF~130 fph. Drill to 11900'. 16:30 - 16:40 0.17 DRILL :) PROD1 Orient to 105L~ 16:40 - 17:00 0.33 DRILL :) PROD1 Drilling. 1.7/~0 fph. Drill to 11923'. 17:00 - 17:15 0.25 DRILL :~ PROD1 Orient to,13~,, .............................. 17:15 - 17:45 0.50 DRILL = PROD1 Drilling0 f hp. Ddll to 11955'. 17:45 - 18:00 0.25 DRILL P PROD1 ShoAxJ,ffp to window. Hole smooth. 18:00 - 19:30 1.50 DRILL P PROD1 ~/Losing 3 bph PVT 230 Get wn to 84 deg at 12016' and build back up. Drill to 12060' RO/ and stacking 19:30- 20:10 0.67 DRILL P P Wiper 20:10 - 20:25 0.25 DRILL P P~D1 Log tie-in down from 10810' 1.6/2440/25R 20:25 - 21:05 0.67 DRILL P FRED1 No corr, RIH. RIH thru window at 41L, clean 21:05 - 21:45 0.67 DRILL P ~ PROD1 Drilling 1.6/2550/30L 60-90'/hr Went thru a shale at 12050' Drill to 12105' 21:45 - 22:10 0.42 DRILL P PROD1 Orient around 22:10 - 22:50 0.67 DRILL P J PROD1 Drilling 1.7/2680/80L Drill to 12127' and stacking 22:50 - 23:10 0.33 DRILL4~ PROD1 Wiper back thru shale area to 12000' 23:10 - 00:00 0.83 DRILL PROD1 Drill/spud/feather/stack Try to make some hole from 12127'. // Drill to 12138' 11/30/2001 00:00 - 01:10 1.17 DD[~J~'L P PROD1 Continue attempting to make hole from 12138-43' and stacking 01:10 - 02:00 0.83,J~RILL P PROD1 Wiper to window from 12143' 02:00 - 02:30 0.,,SE DRILL P PROD1 Resume drilling at same slow rate. Start new mud 02:30 - 03:10/67 DRILL :) PROD1 Love new mud. After 20 bbls new mud out of bit P rate was back to 100'/hr and string wt went from -5.2k to 4.2k. Drill to 03'~ 12220' 1.7/2950/67L 03:10- 0.50 DRILL ~ PROD1 Orient around 03:40;,~'3:50 0.17 DRILL ~ PROD1 Drilling 1.7/2800/130L to 12242' 03:5~- 04:15 0.42 DRILL = PROD1 Orient around to right 0~.15 -05:10 0.92 DRILL = PROD1 Drill to 12304' 1.7/2800/104R ~5:10 -06:00 0.83 DRILL ~ PROD1 Wiper to window 06:00- 07:00 1.00 DRILL P PROD1 Drillling. 1.7/2820/150R In shale. SIowdrilling. 07:00-07:15 0.25 DRILL P PROD1 Orientto 160R. 07:15- 08:00 0.75 DRILL P PROD1 Drilling. 1.7/1.7/2950/160R Drill to 12388'. 40-50 ReP. Printed: 12/10/2001 11:17:38AM ,,,~'~ STATE OF ALASKA ~ ALASK,, .)IL AND GAS CONSERVATION COM~..,CSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon I-I Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 2653' SNL, 1573' WEL, SEC. 09, T10N, R14E, UM At top of productive interval 1902' SNL, 2451' WEL, SEC. 16, T10N, R14E, UM At effective depth 2920' SNL, 2789' WEL, SEC. 16, T10N, R14E, UM At total depth 2967' SNL, 2804' WEL, SEC. 16, T10N, R14E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) RKB = 74' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 14-40 9. Permit Number 188-123 10. APl Number 50- 029-21875-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 11835 feet true vertical 9086 feet Effective depth: measured 11786 feet true vertical 9081 feet Casing Length Structural Conductor 103' Surface 4042' Intermediate Production 10801' Liner 1284' Size 20" 13-3/8" 9-5/8" 7" Plugs (measured) Junk (measured) Cemented 2150# Poleset 2500 sx CS III, 600 sx 'G', 200 sx CS II, Top Job 600 sx Class 'G' 350 sx Class 'G', 240 sx Class 'G' Liner Lap Sqz MD TVD 103' 103' 4116' 4020' 10875' 8916' 10564' - 11834' 8845' - 9086' Perforation depth: measured 10690' - 10800', 11235' - 11580', 11275' - 11300', 11400' - 11450' true vertical 8877' - 8901', 8991' - 9059', 9001' - 9007', 9029' - 9038' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 10640' RECEIVED JUL 0 3 ; 001 Alaska Oil & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) 9-5/8" x 4-1/2" Baker 'DB' packer at 10515'; 4-1/2" AVA SSSV Landing Nipple at 2020' 13. Attachments [] Description Summary of Proposal 14. Estimated date for commencing operation August 6, 2001 16. If proposal was verbally approved Name of approver Date Approved [] Detailed Operations Program I15. Status of well classifications as: [] Oil [] Gas [] Suspended Service [] BOP Sketch Contact Engineer Name/Number: John C~ub~, ,~4158 Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the fo~g~)~g/is ~:r~.J~nd correct to the best of my knowledge ._ / / . Signed JohnCubbon /J~,~ Tit, lo CT DrillingEngineer Date C'ondi'ti'o~l;"of Approval:' Noti'fy (:~0~;11is;i;n"~'o' 'rePresentative may witness ] .......... App~uvd~ ,~u. Plug integrity BOP Test Location clearance ] (-~ ~ I, [ ~'1 Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission ORIGINAL SIGNED BY Commissioner Date Form 10-403 Rev. 06/15/88 ~ ,.Tayior '7~'~1~l ~1~i:)!l~ ! ~,! ~ I Submit In Triplicate bp June 21,2001 To: Attention: Subject: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Tom Maunder Petroleum Engineer Well 14-40A CTD Sidetrack Prep BP Exploration Alaska Inc. Drilling & Wells Coiled Tubing Drilling Team Well 14-40 is scheduled for a through tubing sidetrack to be drilled with coiled tubing. The following summarizes the procedure required to prep 14-40 for drilling and is submitted as an attachment to Form 10-403. A schematic diagram of this proposed completion is attached. 1. Tree wing & master valves will be tested. 2. Using slickline, the tubing will be drifted and the gas lift mandrels will be dummied off. 3. Inner Annulus will be liquid packed and pressure tested. 4. Service coil will abandon the current perforations (10,690'-11,580' MD) with 17 ppg cement. The cement plug will extend approximately 100 feet above the proposed KOP, which will be at approximately 11,450'md (8,964' TVDss). 5. Service coil may then mill a 2.8" window out of the 7" liner. Slickline, wireline & service coil prep work is expected to commence August 6, 2001. Coil tubing drilling operations, as detailed below will commence August 15, 2001. ]. A 3" sidetrack, --1500' long will be drilled out of the 7" liner, high side into the Zone 4 reservoir. 2. The sidetrack will be completed with a 2-3/8", solid, cemented & perforated liner. John Cubbon CT Drilling Engineer Tel' 564-4158 Fax' 564-551 0 Cell' 240-8040 cubbonjr@bp.com Well File Petrotechnical Data Center Terrie Hubble TREE= FMC GEN IV WELLHEAD= FMC ACTt~TOR= AXELSON KB. ELEV = 75' BF. ELEV = _ Max Angb = 85 ~ 11724' _ . Datum MD = 10672' Datum TVD= 8800' SS IMinimum ID = 3.250" @ 9673' I 4-1/2" TBG PATCH I I 14-40 2020' SAFETY NOTES: WAIV~ WELL. T x IA x OA COMIVlJI~._,ATION TO A/L. FTS WFIL IVITIA FAILle). AOGCC FTS REDURES A/l_ OPERA~N H '1/2' ^v^ sssv "m-~ ID = 3.81" I GAS LIFT MANDRELS TYPEMAN MMG MMG MMG MMG MMG MMG MMG MMG MMG MMG ITOP OF 7"LNR 10550' 4-1/2"3BG-PC, 12.6#,L-80,0.0152bpf, ID=3.958" H 10640' I 9'5/8"~'47#'L'80'D=8'681"H 10875' PERFORATION SUMMA RY REF LOG: IVlVVD CNL m 11119/1988 ANGLEATTOP PERP. 76 @ 11240 I~bte:. Refer to P~oduc~on IDB for hisforical perf data SIZE SPF INTERVAL OpnlSqz DATE 4" 4 10690-10800 O 01105/89 4" 4 11235-11580 O 01105/89 2-7/8' 4 11275-11300 O 02117/01 2-7/8' 4 11400-11450 O 02/17/01 7" LI~I~ 29#, L-80, 0.0371 bpf , ID =6.184" ~--~ 11786' 11834' 11835' 9673' 9750' 10515' 10629' 10639' 4-112" TBG PATCH, ID: 3.250" ACROSS GLM #9 (SET 03106192) H H H L i10640' i HH 11830' 4-1/2" OTISX hiPR. E, ID=3.81" I 9-518"X4-1/2" BAKERDBPKR ID:4.75" I 4-1/2"OTISXNNIR=LE ID=3.72" I 4-1/2" BAKERSHEAROUTSLB I 4-1/2" TUBNGTAL I ELIVD - LOGGED 4/21194 H BROKEN LATCH J DA'IF_ REV BY C, OM~ DATE REV BY COIV~ ,, 11/23B8 ~L 01107B9 LAST WORKOV ER 1/10/2001 SIS-~;IA,~ dONVERTEDTOC, ANVAS , 02/27/01 SIS-MD FINAL 04/19/01 RN/TP OOI~,ECTIONS PRUDHC~ BAY UNIT WELL: 14-40 PERMIT No: 88-123 AP~ I',b: 50-029-21875-00 Sec. 9, T10N, R14E, 2804:68 FB_ 2961.54 FNL BP Exploration (Alaska) FMC GEN IV WB_LHEAD= KB. ELEV = :. B.EV = Max Angle = 85 @ 11724' Datum MD = 10672' SAFETY NOTES; WAIVta;~ED WE].L T x IA I x OA COMMUNICATION TO A/L. FTS WE].L MFflA FAILED. AOGCC FTS REQUIRES AlL OPEgRAI~ON fMinimum ID = 3.250" @ 9673' 4-1/2" TBG PATCH 2020' GAS LIFT MANDRELS TYFE MAN MMG MMG MMG MMG rvWiG MMG MMG MMG rv~G ITOPOF 7"Lh~l--[ 10550' 4-112"TBG-PC, 12.6~, L-80, 0.0152bpf, ID=3.958" ]--~ 10640' 9673' I1 9750' ]-~ 1os15' pi 4-112"'[BGPATCH, ID=3.250" ACROSS GLM#9 (SET03/0~92) 4-1/2" OTIS X NIPPLE, D= 3.81" 9-5/8" X4-1/2" BAKBRDB PKR, ID=4,75" ] 10600' t'-[Top of Proposed 2-3/8" Liner 10629' ]-'~ 4'1/2"O'RSXNNIPPLEID=3.72" 10639' I-~ 4'I/2"BAKERSHEAROUTSUB I 10640' I--[ 4-1/2"TUBINGTAIL ] 10649' I--[ B-MD-LOGGED4/21194 ] 9-5/8" CSG, 47#, L-80, ID = 8.681" 10875' (Peff's to be P&A'd prior to Sidetrack) F~JtORA ~ON S UMM~ RY R~: LOG: MWD CNL on 11/19/1988 ANGLEATTOPPERF: 76 @ 11240 Note: Refer to Production DB for historical perf data 2-7/8" 4 11275-11300 02/17101 12-718'l' 4 I 11400-11450 02/17/01 Perforations 10,690'-10,800' 15.8 ppg cement top at approx. 11,250' 11450' ] [ CementRampKOP(TOW) I Perfs P&A'd w/17 ppg Cement 2-3/8" L-80 LINER, Cemented & Perforated 11830' tq BROKEN LATCH ] 11786' 29#,L~80,0.0371bpf,ID=6.184" ]--[ 11834' -- 7" LN~ 11835' DATE 11/23188 01/07/89 1/10/2001 02/27/01 04/19/01 REV BY COMMENTS II DATE ] REV ByI CO~ ORIGINAL COMPLETION / 06/21/01 t pcr 114-40A ST Proposal LAST WORKOVE~ ]] ] SkS'OAA I CONY ERTED TO CANVAS l] I ] PRUDHOE BAY UNFF WB_L: 14~40A STProposal APl No~ 50.029~21875-01 Sec. 91 TION, R~4F. 2804.68 FEL 2961.54 FNL BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development_X RKB 75 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 196612 Stratigraphic_ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 2653' FNL, 1573' FEL, Sec. 9, T1 ON, R14E, U M (asp's 674933, 5937679) 14-40 At top of productive interval 9. Permit number / approval number 2411' FNL, 2612' FEL, Sec. 16, T1 ON, R14E, UM (asp's 674025, 5932621) 188-123 At effective depth 10. APl number 50-029-21875 At total depth 11. Field / Pool 2962' FNL, 2805' FEL, Sec. 16, T10N, R14E, UM (asp's 673845, 5932062) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11835 feet Plugs (measured) true vertical 9086 feet Effective depth: measured 11558 feet Junk (measured) true vertical 9056 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 103' 20" 2150# Poleset 103' 103' Surface 4042' 13-3/8" 2500 sx cs m. 600 sx Class G, 4116' 4020' & 200 Sx CS II Production 10801' 9-5/8" 600 Sx C~ass G 10875' 8916' Liner 1284' 7" 350 Sx Class G 11834' 9086' (liner lap sqz'd w/24 Sx Class G) Perforation depth: measured 10690' - 10800'; 11235' - 11580'. RECEiv :. true vertical 8876' - 8900'; 8991' - 9059'. ~ ~j 0 1 200 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 PCT @ 10640' MD. Alaska Oil & Gas Cons. Packers & SSSV (type & measured depth) 4-1/2"9'5/8" AvAX 4-1/2"SssvBAKER@ 2020'DB PACKERMD. @ 10515' MD. Anchorage Commission 13. stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 165 2853 2876 - 251 Subsequent to operation 263 3224 3446 - 250 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __X Gas __ Suspended __ Service 17. I hereby certity that the for,~going is true and correct to the best of my knowledge. //. Signed~/~l,,~,e,,,,,,,~(,_~ Title: DS 14 Surveillance Engineer Date February 27, 2001 BrancLe~rFrance ?/r/ Prepared by Paul Rauf 564-5799 ~ Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 14-40 DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 12/25/2000: 12/28/2000: 2/16/2001 - 2/17/2001- RIH & drifted to 10728' ELM (HAW). PPROF w/DEFT to 11558'. 100% production f/interval 11320' - 11340' MD. MIRU CTU. PT'd equip. RIH w/CT conveyed perforating guns & shot the following reperf intervals: 11275'- 11300' MD (Zone 4) Reference Log: MWD CNL 11/19/1988. 11400' - 11450' MD (Zone 4) Used 2-7/8" carriers & all shots @ 4 SPF, random orientation, & underbalanced press. POOH w/guns - ASF. RD CTU. Placed well BOL & performed a well test. Alaska Oil & Gas Cons. AnChorage Commission Page 1 THE MATERIAl_. UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 24, 2000,, E E PI~ EW M A T ER IA L U N D ER TH IS M A R K ER C:LOILIhM~LM.DOC 13:08 F rom-EOC go?$$gsgl? T-827 P.OI/Ol F-2?3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS _ _ Type of Request; Al~andon Alter casing Z Repair well Stimulate Change approved program Pull tldblng ~ Other , 2, Name of Operator ARCO Alaska, In~. P.O, ~lOX 100.360 Adchorage Ak 99510-0360 Type of Well Development Exploraton/ Stfatig~a~hic Servic~ 12. Suspend ~ Operation shuldown R,_....~ll~er suspended Well -- Plugging -- Time exte~l$1oll variance X Perforate · ' 6, Datum of Elevation (DF OR KB) 73' RKB 7. Untt or Property Prudhoe Bay Unit Location of wall at surface 26S6' FNL. 1574" FEL, Sec, g, T10N, R14E, UM At top of prOduClive interval 2411" FNL, 2612," FEL, Sac. 16, ¥1ON. R14E, UM At effective Oepth 2358' FSL, 2504' FWL, Sec,. 16, T10N, R14E, UM At tolal depth 2312" FSL, 24§0' FWL, Sac. 16, T16N, R14E, UM ,. PreSent well c,0ndldon Summary Total depth: measured 11,035 feet true vertical 9,085 feel Well nunll;;~r 14-,40 Permit number 88-123 10. APl number ~0.029-21875 11, Field/Paul Prudhoe 8a¥ Oil Pool Plugs (measured) Effective depth; measures ~ 1,786 feet Junk (measured) ~tue vertical 9.081 feet Casing Length Size Camante~l Measured depth True vertical depth Con(luc. tor 115' 20" 2150 # POleSet 103' Sudece 4083' 13-3/8" 2500 sx CS II1 & 600 Sx Class 4116' G- top job w/200 sx CS II Production 10643' 9-~/8" 600 sx C] 'G' 10875' Liner 1284' 7" 350 sx Class 'G' 10550-11834' Liner Lap sqzd w/2~ sx Class 'G' Perforation eeptll: measured true vertical Tul~lng (size. grade, aha measure, depth) Packers and SSSV (type and measured oepth) 166g0-10800'; 1123~.11580' §876~g00'; 8gg1-g058' 4-1/Z', 12.6~. L-80. PCT (~} 10640' MD; Baker'DB" ~a~er @ 10515' MD; AVA $$$V (~ 2020' MD 13, Aflachments Description summary of proposaI ~X Detailed operatiOnS p~gram __ BOP sketch 15. S~us of well classification as: 14. Estimated data for commellc,lng operation Da~p_f.Sl~ndr7 app?val 16. If proposal was venally eppro~d Oil X Gas Se~vl~e Name 0.f aPPr°ver Date approved 1 ?', 1 lqereoy certify that the foregoing is true anU correct tO tim best et r~y knowledge. F~-M~-[.~-.~fON" U S E ONLY 103' 4020' 8~15' 8834-9084' ORIGINAL Suspended C011diti0~l Of approval: Notify Commission SO representative may witness Plug Integrity__ BOP teS~__ LOcmi0n r_Jeamnce__ echanical Integrity Test Subsequem form requi~ea 10- ^ppmved by order of tt~e Commissioner ORIGINAL SIGNED BY Robert N. Chdstenson Commissioner Form 10-403 RevO6/1518B J. Detlllefs / J. Anders. 907-65g-510;~ - PR~ 24 ':"i: ?-~ :i'''~ :'.~ :' /:: DS 14-40 Waiver Request SUNDRY DISCUSSION AND ACTION PLAN 4/26/99 DISCUSSION Well 14-40 is an oil-producer that exhibits tubing x 9-5/8" annular communication and flow-to-surface capability. There is a non-retrievable patch (set in '92) across gas-lift mandrel #9 at 9673'. A Kinley caliper survey run 4/8/99 shows tubing above patch to range from good to fair (9 jts.) condition, max penetration is 36%. A Leak Detection Log has not been run, as the leak is suspected at the patch. The well also has a small IA x OA communication to gas lift gas, which has been handled with the ARCO internal waiver process since 3/92, allowing the OA to equalize with the IA not-to-exceed 2000 psi. Annual (passing) MITOA's to 2000 psi have been performed, and will continue. Based on the remaining reserves, the well is not a workover candidate. There are no sidetrack targets from this wellbore. The well has been shut-in since 3/1/99 because of the flow-to-surface condition. Forecasted remaining reserves are 170 MBO with remaining life through 2002. The well is currently responding to offset MI injection. Responses have typically lasted three to four months. This waiver request is to allow continued production (with artificial lift) for an indefinite period. The request is supported by the following: · A passing combination MIT (T x IA) was performed on 4/30/99 to 3000 psi against an inflatable bridge plug, set in the tubing tail. This indicates the 9-5/8" casing and packer have integrity. · The maximum IA pressure will be limited to 2000 by the ARCO internal waiver process. · The wellhead has integrity, as per positive packoff testing on 4/26/99. · The 13-3/8" casing also has integrity, based on a passing MITOA on 02/18/99 to 2000 psi. · The IA will not be exposed to wellbore fluids while on artificial lift. ACTION PLAN 1. Allow well to resume production, using artificial lift, 2. Perform a CMIT T x IA to 3000 psi at a 2-year interval, 3. Perform an annual MITOA to 2000 psi, 4. Monitor wellhead pressures daily, 5. Shut-in the well should MIT's or pressures indicate further problems. ARCO ALASKA, INC. Tubing.PC ~ Casing ,-~ Casing ~ W$$$V~ Gas Lift Mandrel 1 -- Gee I. Iff Mandrel 3 Gas l,lft Mandrel 3 Gas Lift Mandrel 8 -- Gas Lift Mandrel/Valve O -- NiP -- PKR ~ ,~ Prudhoe Bay t4-40 ............ ) ....... . . ..,......, ....... ~.~ ....... 7-;~,.:~' '..r,%?,, .r~,;., :' ';'~, ....... ' ...... . ,.i' ",:' ',, :". ;.,'.,','. ~'.'I!:i;!?i,'!~.';,.'..':"II:'.: I.~,.;~,.:I!.!~.".!::'~,' .,!I:~, ,:.. ': ,, ,~/',J! .... APt: ~00292187500 Well T~e: PROD Angle (~ TS; 70 deg ~ 11240 $$$VType: Orl9 Compitn: 11/23188 Angle (~. TD; 85 deg ~ 11835 Annular Raid: 9.2 Brine l,ast W/O: 1/7/89 Rev Reason: Tag Referenoe Log: MWD CNL Ref Log Date: 11/19/88 l,ast Update: 4/2019~ LastTeg; 10826' ELM TD: 11~35 flKB Lest Tag Date: 3/16199 Max Hole 85 deg (~ 11~35 ..,..A...ngla: ........... ,~,.,: ,. ,~..-., ..... :.,...,~;: ,....-.,.~....i;-:: T.l,,':;::;:' :;;.'~'.",. :::i~,~,r?'~.'2,' a;~tl.iir,'atl;N~iis ;~.'.';'i':?.' :;' 'i. :. ;;i '.':i....,':?......' ..... ' ,." , ..' ,',~ ,,' '," ..... ~"" ' "'.'" ................ ' ....... ' .... Date Note Welvered Well: 9X13 CommUHc~tlon to A/L, (04/92). Marcit Gel lqz 1'1/~4/93 9673 Min ID = 3,250" (4-1/2" Tubing Patch (Set 03/06/92)) TTL .E, LM ~ ~0628: ELM Tubing Tail (Logged 02./27/90} .D,e.t.e. ru.n:..1981~-11-23 :J3~h~r!~lu~~',''~'~[~ll%;l~tc')' 2 JEWELRY ' " ID Depth TVD Type Description 3.5~0 2020 2020 W$SSV 4~1/2" AVA SSSV Nipple 3,~50 9673 8536 PATCH 4-1/2" Tubing Patch (Set 03/06/02) 3.810 ~750 8576 NIP 4-112' Otis X Nipple 0,000 10515 883t PKR 9,518" x 4-1/2" Baker DB Pecker 3.720 10629 886t NOGO 4-1/2" Otis XN Nipple 0,000 10639 8854 $OSUB 4.112" Baker $hearout Sub 0,000 10640 8864 TTL 4-112" Tubing Tail ............. ~ ......................... . ..... '"~'~" ~i,-,.~,'~ ~t",~:~ ~'" l.~l~;[~:l~lstl.:~:;[:~:.:i!.... :.;..!:?.:,.:.::.. ~.: :;:., :.: ;":'". ','."..!::,. :::" '/.,:'.... ,:: .. :'.':r.'';:,,::,': "..'...'::!:.; ;~: ,':','., :, .' :,.,' ':,,',,',,, :..,,:'' :',': ......... "."' Depth Description Comment F SH' ~lroken Latcll (lost 10/27/91} ,~ ~ / ~ ..... 11830 FISH .,, ; ............ .,.,...~.,..-...~ ....... ,~'";, i~' "< ~,, ,:'y:'l ~".':.);~,~:, , Si=e Weight Grade Top Btm Feet Description 9.625 47.00 L,So 0 10875 10875 Casing 13,375 72.00 L-80 0 4116 41t8 Casing 7.000 29,00 L-80 10550 11834 1284 Liner .... · -.., ..... ~.,, ., ,.,.~ ......... }', ',,:" °?~': ",' , ,, ,, .... ,, , .... ,.,.. ~.. , ., ~ ~ .,... , . , . ,.. ,.. , ~ , ~ ,,~i~it~t~g.:~,'i~ig~i:iF~t~,,.,.i~::. . ...... ,,:.. ........................ ~ize Weight Grade Top Btm Feet Description 4.500 12.60 L-80 0 lO640 10640 Tubing-PC .. i,~.....,:,~.,-.-...t '. ....................... ) ~,,.~... ".r-, ....... w',. """, , '~'-',". ,i3a$'!~/~' Marji~.',~lsNiii~§,'.'..'i:.': :': "; ": ......... ... !. ':, ¥."': ,"'i i,.,,: i.'; .,:', :!'~"~'i,,,,,.;. "':,.! ',::',!,i,',i .! !',.,,.:. ",:?, 3 .'....'...!, '..~: .,.....*', .' lin MD TVD Man Man VMfr VType VOD Latch Port TRO Date VIv Mfr Type Run 3~2.3 3~99 CA MMG DMY 0.0 O,000 0 4760 4602 CA MMG CA DIrtY 1.5 RK 0.000 0 914/93 6024 5703 CA MMG DMY 0,0 0.000 0 ?402 6899 CA MMG CA DMY 1.5 RK 0.000 0 5/19t95 7976 7384 CA MMG DMY 0,0 0.000 0 ~,~3 ?~24 CA MMG CA DlVlY 1.5 RK 0,000 0 11tl60 8660 7899 CA MMG CA DMY 1.5 RK 0.000 0 1/1/60 9576 ~483 CA MMG DMY 0,0 0.000 0 9666 8547 CA MMG MMH OV 1,6 0.000 0 10/27/91 (1) Commem 1. Broken Latch; Patch (Set, 03/06/92) ...... "interval TVD zone ltatusFeetlPF Date TyPe Comment t069o- 8876,8900 SAG O 110 ~t 1/`5~89 IPERF 10800 1 t235 - 8991 - a0,~9 ZONE O 345 4 1/,5/89 IPERF l,tsso ~,(~0¢ NOGO Liner TTL Perf J Perf -- ---- FISH lgZ-:I ZO/ZO'd At'm: Problem Well Specialist, PRB 24 PO BOX' 10036{) Anchorage, AK 99510~0360 Fa]( · re= Blair Wondzell From,- J(3e Anders / Jerry Dethlefs 659-5102. Fax: 276-7542 Paaes: 1 plus cover Phone: 279-1433 Date: 05t03/99 Re: Well 14-40 Sundry Request CC: .__ ® Comments: Hi Blair. Thanks for the call back. I reviewed 14-40's OA pressure buildup rate. From 2/18/99 to 3/1/99, the OA increased from 0 to 500 psi. The IA pressure was at approximately 1500 psi. The build rate when on AL would be around 40 psi/day. Attached is a wellbore schematic. Give me a call if you have any questions. Thanks for the hetpl 4-40 Waiver Request Subject: Well 14-40 Waiver Request Date: Sat, 1 May 1999 18:12:34-0900 From: "PRB Problem Wells" <P 1041 ~mail.aai.arco.com> To: Blair_Wondzell~admin.state.ak.us Hi Blair. My name is Joe Anders, I'm Jerry Dethlefs alternate, working the Problem Well Specialist position in Prudhoe for ARCO. Jerry had discussed getting waivers to produce wells with tubing by IA leaks that flow to surface. We've prepared a well for your review. Well 14-40 was SI 3/1/99 after failing a no-flow test on the IA. It is a gas lifted well with tubing by IA communication that happened to be undergoing an EOR response when we tested it. We feel it is a good waiver candidate because: - Good 9-5/8" & 13-3/8" integrity. We set an IBP and successfully pressure tested the IA to 3000 psi. - A non-retrievable patch prevents repairing any deep leaks, - Remaining reserves don't justify tubing replacement, - It is likely the GOR will decrease within the next 2-3 months to a more typical waterflood GOR of 500-1500. It's been our experience that a well at that GOR will easily pass a no-flow test. Attached are files containing Sundry form 10-403 and a Sundry Discussion and Action Plan. Hard copies of these documents with additional attachments such as wellbore schematic, production plots, etc. were mailed 5/1/99. Please call if you have any questions or would like to discuss the well conditions. I will be returning to Anchorage Wednesday and we can get together if you would prefer to review in person. Thanks for the help! Joe Anders Problem Well Specialist 659-5102 (See attached file: 14-40 Sundry Attach.doc) (See attached file: 14-40 10-403.xls) I Name: 14-40 Sundry Attach.doc [-) 14-40 Sundry Attach.doc Type: Winword File (application/msword)l Encoding: base64 Description: Mac Word 3.0 14-40 10-403.xls Name: 14-40 10-403.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: base64 Description: Microsoft Excel 97 1 of 1 5/3/99 8:19 AM 0 Well t4-40 RMI/GDWFI Plot ARCO Alaska, Inc. P.O. Box 100360, A~-,uhorage, AK --------+ 9-20 -- 6 9-29 9-33 11-6 11- - ~ST~ 2-26 3-28 4-09B i 14-09B 4-40 5-7A ~ 15-7A 5-32 16-18 18- 26ST1 8-27 04-27-94 !./~lnject Profile i 1, 5" 02-19-94t /' Vertiloc~ i I 5" 04-11-94 ! JPerf Record .~, 1 ,5" 04-20-94 i ~'~Perf Record ~ Sch Sch Sch , Sch 1 5" 04-15-94i /~..eak Detect [ 1, 2"&5" Sch 04-26-94 I / Perf Record I 1, 5" Sch 04-19-94 t /"Completion ~ 1, 5" Sch i 05-01-94 i/ Iniection Profile i 1, 5" i 04-23-94 I/ Patch i 1 5" 1 5" 1 5" I 5" 1 5" 1 5" 04-21-94 1~' Production i 04-11-94t / TDT-P 04-10-94 CTU Conveyed 05-01-94 I/' PDC & Static i 04-18-94 1,/ Patch ! Sch 1,2" 5" Sch 04-22-94 CTU Production i 04-23-94 ~CTU Production i 1, 5" Sch Sch ., Sch Sch Sch Sch Sch 99510,~ ~, DS#6-22A the correct depths are Btm. 10473/Top 10465 DS#9-19, the correct APl# is 50-029-20260-00 DS#18-28ST1 the correct APl# is 50-029-22329-00 Number of Records: 53 · DeGrey Distribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon State of Alaska Mobil Please acknowledge receipt by signing and returning a copy of transmittal. Date: ARCO AlasKa, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA ALASKA" '"AND GAS CONSERVATION 0¢ ¥11SSION REPORT SUNDRY WELL OPF_.HATIONS 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 el.e, vation(DF Development X 75 RKB ARCO Alaska, Inc. Exploratory 3. Address Stratigraphic 7. Unit or Property P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2656' FNL, 1574' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 2411' FNL, 2612' FEL, sec. 16, T10N, R14E, UM At effective depth 2358' FSL, 2504' FWL, Sec. 16, T10N, R14E, UM At total depth 2312' FSL, 2488' FWL, sec. 16, T10N, R14E, UM Service Prudhoe Bay Unit 8. Well number 14-40 9. Permit number/approval number 88-123 10. APl number 50 - 029-21875 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11835' feet 9085' feet Plugs(measured) Effective depth: measured 11786' feet true vertical 9081' feet Junk(measured) Casing Length Size Conductor 80' 20" Su dace 4083' 13-3/8" Production 10843' 9-5/8" Line r 1284' 7" Perforation depth: Cemented 2150# Poleset 2500 sx CS III & 600 sx Class G - Top job w/200 sx CS II 600 sx Class G 350 sx Class G Liner lap sqzd w/24 sx Class G measured 10690-10800'; 11235-11580' true vertical 8876-8900'; 8991-9058' Tubing (size, grade, and measured depth) 4-1/2", L-80, 12.6#, PCT @ 10640' MD Measured depth True vertical depth 103' 103' 4116' 4020' 10875' 8915' 10550-11834' 8834-9084' RECEIVED DEC 2 1 199Li Alaska. 0ti & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) Baker "DB" Packer @ 10515' MD; AVA SSSV @ 2020' 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 Reoresentative Daily Averaae Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 437 1001 4033 -- Tubing Pressure 299 Subsequent to operation 484 ~" 897 1418 -- 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run I 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~ "~ '" --~ ~*-~'~ ~-' (~~'~'-- Title Engineering Supervisor Form 10-404 Rev 06/15/88 1084/7 RHL/GSS cc: SW, JWP 264 SUBMIT IN DUPLICATE~ 14-40 DESCRIPTION OF WORK COMPLETED MARCIT GEL SQUEEZE FOR WATER SHUTOFF 1 1/1 4/93 - I 1/18/93: A 5 day Fullbore MARCIT Gel Treatment for Water Shutoff was performed as follows: MIRU CTU & PT equipment, then pumped the fullbore Gel Treatment in stages, through the perforation intervals located at: 10690 - 10800' MD (Sag) Ref Log: MWD CNL 11/19/88. 11235 - 11580' MD (Shublik/Z4) Stage #!: a) 2000 bbls MARCIT Gel (crosslinked 3000 MG/L concentration) @ 2 bpm, followed by Stage #2: b) 5500 bbls MARCIT Gel (crosslinked 4500 MG/L concentration) @ 2 bpm, followed by Stage #3: c) 3026 bbls MARCIT Gel (crosslinked 6000 MG/L concentration) @ 2 bpm, followed by Stage #4: d) 741 bbls MARCIT Gel (crosslinked 9000 MG/L concentration) @ 2 bpm, followed by Stage #5: e) 100 bbls MARCIT Gel (uncrosslinked 3000 MG/L concentration) @ 2 bpm, followed by f) 300 bbls Seawater Flush, followed by g) 100 bbls 60/40 Methanol Water, followed by h) Shutdown. Rigged down. Returned well to production w/gaslift & obtained a valid welltest. .Note: A possible future Stimulation Treatment &/or Sidetrack are currently being evaluated. RECEIVED DEC 2 1 199;~ O~l & Gas Cons. Commission Anchoring, ARCO Alaska~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 8-10-93 REFERENCE: ~_____1-30 ~L_~- 1 ~4-40 97_~.~.~ 9-13 ~-26 ~ -42 ~1-12 ~11-18 ~11-2~ 7~¢0 ~-1 ~-1 ~7-1~ ~7-19 7-14-93 7-5-93 7-11-93 7-17-93 7-17-93 7-10-93 7-6-93 7-6-93 7-8-93 7-11-93 7-3-93 7-3-93 7-9-93 7-4-93 7-4-93 7-8-93 7-2-93 7-16-93 7-16-93 7-5-93 7-6-93 7-9-93 7-13-93 7-12-93 Completion Record ~~,°5" Perf Record ~)0o~zf~ Run 1, 5" InJ Profile ~ vo-~c~ R~m 1, 5" Perf Record~'~I~'~z~ Run 1, 5" PrA ~-~1~ IIl~-ll~ R~n 1, 5" O~ ......I -- P~/~J ~offieaU~~,,n 1, 5" Sch Sch Sch 8ch Sch Sch Sch Production Log~-~OSOR~m 1. l"&5" 8ch Completion Record Run 1, 5"~>-c~sS$Sch Perf Record ~/~o-~5~q9 R~m 1, 5" Sch Perf Record )z%o-~ ~ Ru_n 1, 5' Sch Perf Record%~O-a~t~c~ R~m 1, 5" Sch Leak Detect~-'~°~ R~_m 11 5" hh Completion Record R~m ; 5" ~x~-~SC~c Le~_k Detect Run 1, 2" o- ~0~5 Sch Leak Detect ~oo-5c~o Rlln 1, 2"&5" Sch Dual Burst TDTP Run 1, Perf Record t~co- tz~5f~ R~_m 1, 5" Sch Tie-In Log- IBP to~%d~b~R~m 1, 5" 8ch Leak Detect ~-~%~o R~m 1, 2" Sch Perf Record ~~~ R~m 1, 5" Sch Inj P/oflle/Data Frac R,m 1, 5'~ s~- ~ ~zSch Perf Record ~o-~0~ I Run 1, 5" Sch Leak Detect ~- ~ ot~ Ru_n 1, 2" 8ch Please sign and return the attached copy ~s receipt of data. RECEIVED BY ~_~_ _~ , Have A Nice Day! sony. APPROVED ATO-1529 Trans# 9308i ' # CENTRAL FILES # CHEVRON # CLINT CHAPMAN # BPX # EXXON # STATE OF ALASKA # MOBIL * The correct top logged Interval for 11-22 is 380 feet. REPORT SUNDRY WELL OPEHATIONS 1. Operations performed: STATE OF ALASKA ALASKA'~'~. AND GAS CONSERVATION CC ~'-~IISSION Perforate Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well 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 2656' FNL, 1574' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 2411' FNL, 2612' FEL, Sec. 16, T10N, R14E, UM At effective depth 2358' FSL, 2504' FWL, Sec. 16, T10N, R14E, UM At total depth 2312' FSL, 2488' FWL, Sec. 16, T10N, R14E, UM 12. Present well condition summary Total depth: measured 11835' feet true vertical 9085' feet Effective depth: measured 11786' feet true vertical 9081' feet Casing Length Size Structural 80' 20" Surface 4083' 13-3/8' Production 10843' Liner 1284' Perforation depth: Plugs(measured) Junk(measured) Other X 6. Datum of elevation(DF or KB) 75' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-40 9. Permit number/approval number 88-123 10. APl number 50 - 029-21875 11. Field/Pool Prudhoe Bay Oil Pool Cemented 2150# Poleset 2500 sx CS III & 600 sx Class G - Top job w/200 sx CS II 9-5/8" 600 sx Class G 10875' 7" 350 sx Class G 10550-11834' Liner lap sqzd w/24 sx Class G measured 10690-10800'; 11235-11580' true vertical 8876-8900'; 8991-9058' Tubing (size, grade, and measured depth) 4-1/2", L-80, 12.64f, PCT @ 10640' MD Measured depth 103' 4116' Packers and SSSV (type and measured depth) Baker "DB" prk @ 10515' MD; AVA SSSV @ 2020' MDR 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure True vertical depth 103' 4020' Prior to well operation Subsequent to operation 8915' 8834-9084' ECEIVED 14. 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations MAY 1 2 1992 Alaska Oil & Gas Cons. Como ;Anchorage Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 439 807 4890 -- 408 939 4124 16. Status of well classification as: Oil ~ Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ' Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 P,25/8 SLW cc: SW. JWP Tubing Pressure 257 276 Date ~'~'~//~//~ ~-- SUBMIT IN DUPLICATE 14-40 TUBING PATCH INSTALLATION DESCRIPTION OF WORK COMPLETED 3/6/92: RIH & set a 4.5" OD tubing patch from 9673 to 9694' MD across GLM # 9. POOH. RD. Returned well to production w/gaslift & obtained a valid production test. ARCO ~IA~I~A: Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-20-92 REFERENCE: ARCO CASED HO!~- FINALS 2-16 3-34 5-34 (g-32 g-sz t9-32 14-40 16-9A 2-25-92 Pert' Record Rnn 1, 5" 2-29-92 CCL (Tubing Cutter} Run 1, 5" 3-1-92 Packer Positioning Run 1, 5" 3-7-92 Verttlog 7" Casing Rnn 1, 5" 3-7-92 Vertilog 9 5/~' Casing. Run 1, 5" 3-8-92 PFC/GR Rnn 1, 5" 3-6-92 Tubing Patch Rnn 1, 5" 2-25-92 Perf Record Run 2, 5" Sch Aths Sch Aths Aths Arks Sch Sch Please sign ~nd return the attached copy as receipt of data. RECEIVED BY Have A Nice Day! Sonya Wallace ATO- 1529 # CENTRAL FILES # CHEVRON . D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL .. # PHILLIPS PB WELL ~ R&D # BPX # STATE OF ALASKA TEXACO RECEIVED APR 0 1 1992 Alaska 0il & Gas Cons. Commission Anchorage ARCO ALASKA, INC. F'.O. BOX ~,~OS6~) ANCHORAGE, ALA3'KA 995J~} DATE' t 2-SI-91 REFERENCE' ARCO CA~.'ED HOLE FINALS' / it-~<5 ~it-im-et ~F'ROD F'ROFILE ,~--~"~,tf-t8~it-tT-gt,/,//F'R~D PROFILE ~-¢~i'! 22 i-i4-9i ~. GA~ LEAK DETECT ~-/'.i3-28 i-it-gl ~ LEAK ~E'I'ECT ~-Y~t4-2 ~ii-t-gi ~ PROD PROFILE ~~t4-i-4 /t~-st-gt ~ LEAK DETECT i4-i4 ~ii-8-9i~ LEAK DETECT ~~ ~-/~i4-27 Wii-t-gi W INJ PROFILE ~/-/~ i 5 i 5 t e-3e-gi F'ROD PROFILE ~_%~* t7 2 ~ i i-2-~t ~ CCL TIE-IN TUBING F, ATCH - RUN t, 5" RUN i , 5' RIJN t , 2'&5' RUN t, 2'&5' RUN t , 5:' RUN t, .5' RUN t , ~-"~'" RUN i , 5" RUN t , 2' RUN t, 5 · RUN t , 5' F'LEA~E SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. RECEIVED BY ~__j~' HAVE A NICE DAY! ~U~.YA WALLACE ATO-i~'~- AF'F'ROVED ~ ~ -~~~ ~ F,'HN~'-~ 9 i CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CA~Uu CHMCO CAMCO CAMCO CAMCO DISTRIBUTION '" CENTRAL H'rLE~ ...-"' CHEVRON DaM ~ EXi'EN$ION EXPLORATION · '~ EXXON MARAI'HON ~- MOBIL '"' F'HILLIF'~ F'B WELL FILE£.' R & D '- BPX · ~ ,~:TATE OF ALASKA .TEXACO * THE CORRECT API$ FOR t7-2 I$ 5~-~29-2~486. RECEIVED JAN 'l 0 199 Alaska Oil & Gas Cons. Commission Anchorage ARCO AI...A~'KA, IN F',O, BOX lOOS60 ANCHC)RAC;E, AL.A~,'K A 995t'0 DATE: S-t 5-90 RE:'FERE:NCE: ARCO CASEI) HOLE FINALS' t.-.S S-" t 0--'9() t -7 S-9-90 t -'24 S-" 4'"' 90 t .-S4 t t-t 7-89 :3....28 t O-t :.~....89 5-9 t t-S t 4-40 2-27-9"J t 5- t t 2-..S t -89 t 7-S S-9--90 WGI-.5 WI; I--5 S- 6-' 90 COL. L. AR/PE:RF · "" ~1 '~ .... COI_I_AR/F ERF" COL. L. AR F' I T $ [-.'i F:' I L 0 G COLLAR COLLAR/PERF PRODUC'¥ION GAMMA I)$N DUAL BURST TD'¥-P COLLAR CBT CET RLJN t, RUN t , RUN t, RLJN t , R UN t , RUN I , RUN t , RUN ~ , RUN t, RUN t, RUN t RUN t, RUN ~ , PI-EASE SIGN AND RETURN THE A'rTACHED COPY AS RECEIPT OF DATA. RECEIVED .BY HAYE A NICE DAY! SALLY HC)FF'EECKER AT0-t529 5" 5" 5" 5 ' ,5" 5" 5" I "&.5" 5" 5" 5" 5" 5" A 'F L.. A.S' A"i'I_A~' A 'l'l... A,'~' C A It C 0 A 'I' L. A.S' ATI..A,.~; ATI..A,.~' F'IL.S' $ C H A'TL.A~' $CH 6'(];F.i DI.$TRIBUTION CENTRAL FILES ~ ~ F'H I I_L I F',~' CHEVRON F:'B WELL FILES D & M R A D' EXTENSION EXF'LORATION ~: BPX EXXON ..~ ~'['ATE OF ALASKA H~R~THON ...* 1'EX,CO MOBIL ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 27, 1989 C. v. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Request for Waiver - Drill Site 14-40 Production Profile Dear Mr. Chatterton: ARCO requests a waiver under Order 213, Rule 2, for the referenced production profile requirements on the new Prudhoe Bay Unit DS 14-40 well. The waiver is requested due to the high angle completion of 85 degrees through the Sadlerochit interval located at 11235'-11580' MD (8991'-9058' TVD), and Sag River interval located at 10690'-10800' MD (8876'-8900' TVD). The increased risks involved in obtaining production logs conveyed with coiled tubing, and poor data quality in the high angle tubulars, warrant this request. Alternative diagnostic measurements will be investigated as indicated by well performance. If you require additional information, please contact me at (907) 263- 4248. D. F. Scheve Manager, PRB Operations Engineering DFS/KRF/ry :063 cc: T. B. Gray, BP Exploration R. E. MacDougal, Exxon D. D. Smith, ATO-1670 M. L Bill, ATO-1550 RECEIVED OCT o 1989 4taska Oit & Oas Cons. C0mmiss/0n Anchoraff,a ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C ARC(} ALASKA: !NC P~ O, BOX i ANCHORAGE: ALASKA DATE' ~-t ~--89 REFERENCE' ARCO PRESSURE DATA 2-2 4-t8 4-24 7-3~, 9-t 9-4 9-4 9.-4 9---7.z,, i 9-.S2 ti-iS i2-9 ~-5 i 4--:3'? i4-38 i 4-40 i8-iS i8-i5 F'WDW2-i -i i-89 2-i 8-88 2-i ,2,-88 2-'2 i -88 2-i 7-88 i-24-88 i-iS-89 2-S,:-}-88 -i 5-89 2-:5,3-88 i-24-88 -i -89 -7-89 i 2-i 7-88 "~-1 -89 -;~i -89 -Si -89 -2S-89 i °-S-88~ 2-i -88 i-i9-89 BHP--F'LOWING CF<AD IENT BHF'--Fi_OWING GRADIENT BHP--STATIC GRADIENT BHF'--STATIC GRADIENt' BFiF'--FLOW ING GRADIENT BHP--FLOWING GRADIENT BHP--STATIC GRADIENT BI-tF'--F'L..OW l NG GRADIENT BHF'--STATIC GRA[:,IENi BHF'--F'LOW l Nr;- GRADIENT BHP--SI"AI' I C GRADIENT BHF'--:';:i-ATIC GRADiEN 'F BHF'--FLOWING GRADIENT BHP--FLOWING GRADIENT BHP--STATIC GRADIENT BHP--S'i'ATI C GRADIENT BHF'--SI'AT lC GRADIENT BHF'--STATZC GRADIENT BHP--STAT IC GRADIENT BHF'--STAI'ZC GRADIENT BHP--STATIC GRAD IEN"F PI_EASE SIGN AND RETURN THE ATTACHED COF'Y AS RECEIPT CAMCO CAMCO OTIS OTIS CAMCO CAMCO CAMCO C A M C 0 OTIS C A M C O CA~UO CAMCO CAMCO CAMC[) OTIS OTIS OTIS OTIS CAMCO CAMCO CAMCO OF DATA. RECEIVED BY HAVE A NICE DAY! SALLY HOFF'ECKER AT0-t529 'f'RANS AF'F'ROVED __~j.~_ · .....~ ~: · .: ....... Cons. Vii ~j.~b Abska & Ccmmissio~ Anchorage sD~'~T R I BUT I ON CENl~RAL F ILE~.~': ~:. EXTENSION EXF'LORATION EXXON HARATHON MOBIL F' H I L L I F' $ PB WELL FILES R & D SAF'C STATE OF ALASKA TEXACO , TI--tE CORRr-._-CTED AF'I~ FOR THIS BHF' REF'ORT IS 5¢,-(')29-2t56,8, ARCO ALA£KA, INC. ,~. P.O. BOX teOJ6e ANCHORAGE, ALASKA 995te DATE' t-t9-89 REFERENCE: ARCO DIRECTIONAL DATA ~2-3(') ~2-J~-88 MWD DIRECTIONAL ~'URVEY ,]08¢6'?'4 ~4-3'? 9-25-88 MWD DIRECTIONAL SURVEY d08¢~'54 4-J8 ~-2~-88 MWD DIRECTIONAL SLJRVEY J08~59 4-39 ~2-8-88 MWD DIRECTIONAL SURVEY .J08~669 ~4-4~ ~-2~-88 MWD DIRECTIONAL SURVEY J08~664 PLEASE SIGN AND RETURN THE ATTACHED COF'Y A,_~,'ECEIF'T~ OF DA'FA HAVE A NICE DAY! SALLY HDFFEUKER AT0-~529 Naska 0tl & Gas Con=. Commission Anchorage AF'PROV -' . ...... D I STR I BLil' I ON TELECO TELECO TELECO TELECO TELECO CENTRAL FILES CHEVRON D & M EXTENSION EXPLOR'ATION EXXON MARATHON MOBIL F'F! t I_L ;[ F'S ~- F'B WELL FILES (2 COF'IE~¢.) R & D · ,,-"" SAPC STATE OF ALASKA TEXACO WELL COMPLETION OR RECOMPLETION REPORT AND LOG _. ._ STATE OF ALASKA 0 I{ 16 IN ALASKA OIL AND GAS CONSERVATION COMMISSION 1. Status of Well Classification of Service Well OIL [Z GAS C~] SUSPENDED !~ ABANDONED [-] SERVICE [] 2. Name of Operator 7. Permit Number 88-123 3. Addr~; ........... ' ..... 8. APl Number 50- 029-21 875 4. Locat'io'~(~f well a~ ~'~'~'e~ ............... 9. Unit or Lease Name Prudhoe Bay Unit 2656' FNL, 1574' FEL, 5ea. 9, 'TION, RIb,E, UM At Top Producing Interval 10. Well Number 2411' FNL, 2612' FEL, 5ec.16, T10N, R14E, UM (MWD svy) At Total Depth ~ .i 1. Field and Pool 2312' FSL~ 2488' FWL~ 5ec,16, T10N, R14E~ UH (MWD svy) Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0~ ] Pool RKB 75 ' 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 10/27/88 11/19/88 01/07/89'I N/A feet MSL] 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 11835'MD/9085'TVD 11786'MD/9081 '. TVr. YES ~ NO []J 2020' feet MDJ 1900' (approx) 22. Type Electric or Other Logs Run $ I D/CNO/ERW/GR. MWD. CBT/CET/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# ~-40 $,-rf ! 03 ' 30" 2!50 sx Po! eset !3-3/8" 68.0/72.0# K-55/L-80 Surf ~,!!6' !7-!/2" 2500 sx CS !!! & 600 sx C!~ss G 9-5/8" /47.0# L-80 Surf ! 0875' ! 2-!/4" 600 sx C! .................. · -- ~-- ..... , ........... 'fl .... · - .v ........ 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) Perforated w/4 spf, 90° Phasing b,-1/2" 106b,1' 10515' 10690 '-10800 'MD/8876' -8900 'TVD 11235 ' -11580 'MD/8991 ' -9058 'TVD 26. ACl D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED 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 ~;~aska_0il & 6as Cons, C0mm~ · NOTE: Drilled RR 11/23/88. ' ~uchorage J Form 10-407 Rev. 7-1-80 WC5/080 CONTINUED ON REVERSE SIDE Submit in duplicate 29. .~.. 30. GEOLOGIC MARKERS FORMATION TESTS NAME . .. Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. , , , Top Sadl erochi t 11240 ' 8992 ' N/A HOT 11580 ' 9058 ' 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~,~, ~ Regional Drilling Engineer //~Z~/O~ Signed _ _ ~ _ Title Date ~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 [" I' T***co O,,**~ S,. ~, ~,c. TEI. E£O 6~ 16 Niet$on way A nchorage, AK 99518 (907) 562-2646 November 22, 1988 JOB #664 ARCO ALASKA INC. WELL: DS14-40 LOCATION: PRUDHOE BAY RIG: NABORS 28-E Attached please find a copy of the computer calculated MWD directional surveys for the above mentioned well. Teleco appreciates this opportunity to provide service to ARCO Alaska. Teleco is committed to providing the highest quality MWD service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Dave Reimer Field Service Supervisor DR/el Enclosures TELECO OILFIELD SERVICES JOB 664 SURVEY CALCULATIONS **************************************** Date 11/21/88 Page 1 ~mpany: ARCO ALASKA INC. ~11: DS 14-40 Ication: PRUDHOE BAY .g: NABORS 28-E :LECO Job # 664-TAK 'id Correction: ~gnetic Declination: ~tal Correction: 'oposed Direction: 0.00 degrees 30.80 degrees 30.80 degrees 190.15 degrees RADIUS OF CURVATURE CALCULATION **************************************** MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG IEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' -, ', 100.00 331.00 572.00 874.00 .649.00 :012.00 TIE IN WITH CONDUCTOR PIPE 0.0 190.1 S 10 09 W 100.00 0.00 TELECO MWD SURVEYS 0.3 219.9 S 39 54 W 0.4 210.3 S 30 18 W 0.4 113.8 S 66 12 E 0.9 111.7 S 68 18 E 0.7 191.8 S 11 48 W 0.00N 330.99 0.52 0.46S 571.99 1.85 1.665 873.98 3.50 3.43S 1648.93 5.41 6.84S 2011.89 9.07 10.95S 0.00E 0.00 N 90.000E 0.000 0.38W 0.60 S 39.900W 0.130 1.22W 2.06 S 36.503W 0.049 0.65W 3.50 S 10.766W 0.198 7.45E 10.12 S 47.479E 0.065 9.66E 14.60 S 41.439E 0.287 ~LECO Job # 664-TAK 11/21/88 Page 2 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG )EPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet . deg deg deg/min feet feet feet feet feet deg deg/100' ~330.00 7.3 189.7 S 09 42 W 2328.94 31.24 32.73S 5.53E 33.19 S 9.595E 2.076 ~744.00 12.1 190.1 S 10 06 W 2736.91 100.97 101.42S 6.45W 101.63 S 3.642W 1.160 1281.00 18.5 187.6 S 07 36 W 3254.60 242.55 241.35S 28.24W 243.00 S 6.674W 1.198 )535.00 22.3 185.8 S 05 48 W 3492.63 330.91 329.26S 38.57W 331.51 S 6.681W 1.516 ~719.00 25.6 183.4 S 03 24 W 3660.77 405~23 403.70S 44.56W 406.15 S 6.299W 1.870 1057.00 25.0 185.8 S 05 48 W 3966.34 548.99 547.67S 56.14W 550.54 S 5.853W 0.352 ~267.00 25.0 185.1 S 05 06 W 4156.67 637.44 636.01S 64.57W 639.28 S 5.797W 0.141 1681.00 25.0 185.5 S 05 30 W 4531.88 811.77 810.22S 80.73W 814.24 S 5.690W 0.042 ~116.00 28.7 184.4 S 04'24 W 4919.92 1007.40 1005.92S 97.68W 1010.66 S 5.547W 0.858 ~558.00 30.8 181.6 S 01 36 W 5303.64 1224.98 1224.92S ~650.00 30.5 183.0 S 03 00 W 5382.79 1271.44 1271.78S 109.16W 1229.77 S lll.04W 1276.62 S 5.093W 0.570 4.990W 0.842 ~937.00 31.6 181.6 S O1 36 W 5628.66 1418.08 1419.68S 116.98W 1424.49 S 4.711W 0.458 ~394.00 30.3 183.0 S 03 00 W 6020.58 1650.90 1654.51S 126.42W 1659.34 S 4.369W 0.325 5716.00 30.0 180.6 S 00 36 W 6299.02 1810.89 1816.14S 131.50W 1820.90 S 4.141W 0.386 ~029.00 29.2 178.5 S O1 30 E 6571.17 1962.85 1970.73S 130.28W 1975.04 S 3.782W 0.418 129.50W 2125.21 S 138.55W 2247.39 S ~344. O0 27.9 180.9 S O0 2110.89 2121.27S ~595.00 30 4 187.6 S 07 36 W, ~7067,~05 2232.42 2243.11S 3.493W 0.550 3.535W 1.637 ~LECO Job # 664-TAK 11/21/88 Page 3 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG )EPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100 ' ~845.00 33.7 193.6 S 13 36 W 7278.92 2365.00 2373.43S 162.94W 2379.02 S 3.927W 1.833 ~275.00 39.8 202.0 S 22 00 W 7623.30 2619.64 2618.06S 241.48W 2629.18 S 5.270W 1.835 ~473.00 44.6 200.3 S 20 18 W 7769.93 2750.16 2742.06S 289.46W 2757.30 S 6.026W 2.492 t603.00 47.1 201.0 S 21 00 W 7860.48 2841.87 2829.34S ~756.00 47.8 198.8 S 18 48 W 7963.94 2952.95 2935.32S 322.35W 2847.64 S 360.71W 2957.40 S 6.500W 1.961 7.006W 1.154 1910.00 48.2 194.6 S 14 36 W 8066.99 3066.62 3044.91S 393.59W 3070.24 S 7.365W 2.043 ~097.00 49.2 193.9 S 13 54 W 8190.40 3206.74 3181.07S 428.17W 3209.76 S 7.666W 0.604 ~279.00 51.9 194.6 S 14 36 W 8306.04 3346.90 3317.27S 462.76W 3349.39 S 7.942W 1.513 ~470.00 53.8 197.1 S 17 06 W 8421.38 3498.37 3463.70S 504.34W 3500.23 S 8.284W 1.441 563.36W 3677.56 621.12W 3840.44 668.88W 3985.91 733.87W 4194.08 ~690.00 56.4 201.1 S 21 06 W 8547.24 3676.55 3634.15S ~879.00 66.9 199.6 S 19 36 W 8636.86 3840.02 3789.88S ~036.00 73.1 198.2 S 18 12 W 8690.53 3985.76 3929.38S )256.00 72.7 197.8 S 17 48 W 8755.22 4194.07 4129.37S S 8.812W 1.902 S 9. 307W 5. 599 S 9.661W 4.037 S 10.077W 0.252 )969.00 79.1 199.5 S 19 30 W 8933.11 4876.30 4782.96S 954.39W 4877.25 S 11.285W 0.524 )826.00 78.8 198.8 S 18 48 W 8905.70 4737.68 4650.38S 908.35W 4738.26 S 11.052W 1.884 )666.00 75.8 198.5 S 18 30 W 8870.53 4583.33 4502.51S 858.44W 4583.62 S 10.794W 1.384 )477.00 73.2 198.8 S 18 48 W 8820.02 4403.22 4329.97S 800.21W 4403.29 S 10.471W 0.488 ~.LECO Job # 664.-TAK 11/21/88 Page 4 .. MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100 ' [030.00 78.7 199.5 S 19 30 W 8944.85 4935.35 4839.38S 974.39W 4936.50 S 11.384W 0.661 [149.00 77.0 197.4 S 17 24 W 8969.89 5050.46 4949.72S 1011.21W 5051.96 S 11.546W 2.240 [262.00 75.4 197.1 S 17 06 W 8996.85 5159.35 5054.52S 1043.75W 5161.16 S 11.668W 1.439 [343.00 77.0 197.8 S 17 48 W 9016.17 5237.37 5129.56S 1067.34W 5239.42 S 111754W 2.146 [440.00 79.4 197.8 S 17 48 W 9036.00 5331.46 5219.94S 1096.40W 5333.84 S 11.862W 2.475 ~536.00 81.1 197.1 S 17 06 W 9052.26 5425.30 5310.19S 1124.77W 5428.01 S 11.959W 1.911 k629.00 82.8 197.8 S 17 48 W 9065.28 5516.63 5398.03S 1152.38W 5519.67 S 12.051W 1.974 [724.00 84.9 199.2 S 19 12 W 9075.46 5610.08 5487.60S 1182.35W 5613.53 S 12.159W 2.652 PROJECTED TD ~835.00 84.9 198.1 S 18 06 W 9085.33 5719.42 5592.35S 1217.71W 5723.39 S 12.284W 0.987 ~000 3200 TELECO Oil~imld PLAN ViE~~ 400 1600 $~rv i c~s' 8OO 800 800 1600 2400 '--;--F-'--': .... '- ..... T ..... 7200 0 0 2000 6000 8000 TE~£CD 0 i 1 f i ~ i d Serv i ~ VERTICAL. PROJECTION 2000 ~000 6000 8000 10000 ' i 12000 I i I ..... 7-, ~ , 'r"-t"-~ ' ~ .t.-4---;--.~:-- ' 4000. , ,., ~ ~ ~ · ~ ; . . ..... ,., 1" ..... ."" 1"-- , -: ~_r ~ .~_?.. ,._._.,..._...,.__. _ ..... , ' , .~ . ~--'"I , . ~ i ,. ,? .._~, ......... ::. .... , ....... , , ! '--."--'----~, .... ~- . -'T-i .... i , . -i ,,.. , ,, .1,0000 ' : ~...~..~ .~- .~....~.~..?.~ ~-.~. ........ ,. ~ . : : I '. ~ , '"I- ..... 1- ~4000' ; . ' , : ::..4.. ......... '! ..... r ............ -'r" · ; , ' i , i , t t : , ; : / ~ ! . '...L....... .... : ..... ; ....... J- ....... ,. .... ,..---.- ............ .......... ~ ....... ,-""'-~. ~ ........... -- ...... 1 ...... :--r ..... :"-- ..... F ' ; ' · T : : t : , , i , I i ! ; ~ . , ' : ! ; i-. . _~ 1 ..... L_-. :~.~--~ ....................... --~ l,--~'---t--, ..... i-'- ~'--t ........ ',"" ~t" ....... ; ..... : '"'---'T"'-:' ..... ~ ~ I ; I . ' ! : i i ; t i ! I . ' t ~- ' , i ~ .... ._~. .... --' ---~-' ....... ' ....... -. .............. ' · . · ~, _ ....... , .... r__ ?_....~..__T., _..t~ .... ~. . . : ..... ' ' ~- '. z...;.-..-:.-L...~ .............. I .--~'_.4- _! ...... t..--i--,-,--.-:. ', : ; i ! :' '- 1 I:IUUU '-- ' ' " ......................... - VERTICAL SECTION". ('~t) * . W~.L LOG INVENTORY W~.r. NAME : , _ _ PAGE ! of LOG LOG COUNT DATE REC CDM (mudlog) DIL/SFL (dual induction log) CNFD (compensated neutron density) (compensated neutron formation/ Htho-density) RUN# CFD ,.. (compensated formation density) BHC/SL (borehole eompensatea sorde) . · ~ LSS (long spaced sonic) SSS (short spaced sonic) CYB (eyberlook) .- GCT (groscopic survey) DIPMETER SAMPLES: Require~t yes~:Date~_~. Received: STATE OF ALASKA -" AL/.,.:,A OIL AND GAS CONSERVATION COMMIS ..... ;N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Perforate __ Pull tubing __ Alter casing Repair well __ Pull tubing __ Other'XV Comp1 ete 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2656' FNL, 1574' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 5. Type of Well: Development Exploratory Stratigraphic Service 2411' FNL, 2612' FEL, Sec.16, TION, R14E, UM (MWD svy used for calc.) At effective depth 2358' FSt, 2504' FWL, Sec.16, TION, Ri4E, UM (MWD svy used for calc.) At total depth 2312' FSL, 2488' FWL, Sec.16, TION, R14E, UM (MWD svy used for calc.) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11835 'MD feet 9085 'TVD feet 11786 'MD feet 9081 'TVD feet Plugs (measured) None Junk (measured) 6. Datum elevation (DF or KB) RKB 75' Z UnitorPropedyname Prudhoe Bay Unit 8Wellnumber 14-40 9. Permit number/approval number 88-123/8-986 10. APl number 50-- 029 -21875 11. Field/Pool Prudhoe Bay Oil Pool None feet Casing Structural Conductor Sudace Intermediate Production Liner Perforation depth: measured Length Size Cemented Measured depth True vertical depth 80' 4083' 10843 ' 1270' 20" 13-3/8" 9-5/8" 71! 2150# Pol eset 103 'MD 103 'TVD 2500 sx CS Ill & 4116'MD 4020'TVD 600 sx Class G - Top job w/200 sx CS II 600 sx Class G 10875'MD 8915'TVD 350 sx Class G 10564'-11834'MD 8843 '-9084 'TVD Liner lap sqzd w/240 sx Class G 10690 ' -10800 'MD, 11235 ' -11580 'MD true vertical 8876' -8900 'TVD, 8991 '-9058 "TVD Tubing (size, grade, and measured depth) 4-1/2", L-80, tbg w/tail @ 10641' Packers and SSSV (type and measured depth) Baker 'DB' pkr ~ 10515' & AVA 'SC-SSV' SSSV ~ 2020' 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 14. N/A Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run ~ MWD Daily Report of Well Operations ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ned ?-'~-/ ~"'" Title Reg'.'en~-_n."'.'!] ~n; E.-.g~.nc:,-- Form 10-404 Rev 06/15/88 *Co/mplet ion Well Histe,,r,,y (Dani) 5W04/009 16. Status of well classification as: Oil %_.. Gas_ Suspended __ Service Date SUBMIT IN DUPLICATE/ ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Rel~ort" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field ARCO ALASKA INC. County. parish or borough NORTH SLOPE Lease or Unit I A DL: 28314 ]Title COMPLETE PRUDHOE BAY I State DS 14-40 IjWe~l no, I Auth. or W.O. no. AS2301 API: 50-029-21875 Operator IARCO w.I. ARCO J 21,0000 I Spudded orW.O, begunAcCEPT IDate 12/22/88 IH°ur 1130 HRS IPri°rstatusifaw'O' Date and depth Complete record for each day reported as of 8:00 a.m. AUDI RIG 4 12/23/88 (211) TD: 11835 PB:11786 SUPV: BB 12/24/88 ( 3( TD:11835 PB:11786 SUPV:BB 12/25/88 TD:11835 PB:11786 SUPV:BB 12/26/88 TD:11835 PB:11786 SUPV:BB 12/27/88 ( 3] TD:11835 PB:11786 SUPV:BB 12/28/88 ( 34 TD:11835 PB:11786 SUPV:BB CIRCULATING BOTTOMS UP 7"~11834' MW: 8.7 NaC1 MIRU AUDI RIG 4. ACCEPTED RIG AT 1130 HRS 12-22-88. ND TREE AND NU BOP'S. TESTED BOP'S. PU 3-1/2" DP AND RIH W/ MODEL "G" RBP RETRIEVING TOOL. DISPLACED 2000' METHANOL CAP W/ 9.0 PPG BRINE. CONTINUE RIH TO RBP, TAGGED AT 6978' AUDI RIG 4 RKB. RELEASED RBP AND CBU. DAILY:S53,782 CUM:$2,290,636 ETD:S2,290,636 EFC:$3,214,000 POH W/ DP 7"@11834' MW: 8.7 NaCl FINISH CBU, MONITOR WELL, LOSING +/- 36 BPH. POH W/ RBP. RIH W/ CMT RTR AND SET RETAINER AT 10479' MD. SQUEEZED LINER LAP W/ 240 SX CLASS G CEMENT. LEFT 2.5 BBLS OF CEMENT ON TOP OF RETAINER. REVERSED OUT DP AND POH. DAILY:S68,954 CUM:$2,359,590 ETD:S2,359,590 EFC:$3,214,000 POH W/ BIT 7"~11834' MW: 8.7 NaCl FINISH POH W/ CMT RTR SETTING TOOL. PU BIT AND BHA AND TAGGED FIRM CEMENT AT 10431' DRILLED CEMENT TO CMT RTR AT 10465', DRILLED CMT RTR AND CEMENT TO TeL. REVERSED HOLE CLEAN AND POOH. DAILY:S52,825 CUM:$2,412,415 ETD:S2,412,415 EFC:$3,214,000 POH W/ BIT 7"@11834' MW: 8.7 NaC1 FINISH POH W/ 8.5" BIT. PU AND RIH W/ 6" BIT. TAGGED TeL AT 10550, DRILLED CEMENT TO 10562. TESTED 9-5/8" CASING AND 7" LINER LAP TO 3000 PSI, LEAKING OFF 250 PSI IN 15 MINUTES. REVERSED BOTTOMS UP AND POH. DAILY:S41,675 CUM:$2,454,090 ETD:S2,454,090 EFC:$3,214,000 DRILLING CEMENT IN 7" LIN 7"@11834' MW: 8.7 NaCl FINISH POH W/ 6" BIT. RIH W/ 9-5/8" RTTS TO 17' ABOVE THE TeL. TESTED 9-5/8" CASING TO 3000 PSI - GOOD TEST. TESTED' 7" LINER LAP TO 3000 PSI, LEAKED OFF TO 2000 PSI IN 5 MINUTES TO 1000 PSI IN 8 MINUTES. POH W/ RTTS. RIH W/ 6" BIT, TAGGED CEMENT AT 10562', DRILLED CEMENT TO 10716' BY REPORT TIME. DAILY:S52,508 CUM:$2,506,598 ETD:S2,506,598 EFC:$3,214,000 RIH W/ CET/CBT/GR LOGS ON 7"@11834' MW: 8.5 FSW DRILLED FIRM CEMENT IN THE 7" LINER TO 10800' MD. CLEANED OUT THE 7" LINER TO THE FC AT 11786' MD. DISPLACED HOLE WITH INHIBITED SEAWATER, 8.5 PPG. POH WITH 6" BIT. MU SCHLUMBERGER CBT/CET/GR LOGS ON DP. DAILY:S41,142 CUM:$2,547,740 ETD:S2,547,740 EFC:~3,214,000 The above is ~,orrect % . AR3B-459-1-D INumber all daily well history forms consecutively as they are prepared for each well. iPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed, Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lllterlm" sheets until final completion, Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion, District Field ARCO ALASKA INC. ICounty or Parish ISfSteAK NORTH SLOPE Lease or Unit DS 14-40 PRUDHOE BAY Date and depth Complete record for each as of 8:00 a.m. 12/29/88 ( TD:11835 PB:11786 SUPV:TJ/GG 12/30/88 ( TD:11835 PB:11786 SUPV:TJ/GG 12/31/88 ( TD:11835 PB:11786 SUPV:TJ/GG 01/01/89 ( TD:11835 PB:11786 SUPV:TJ/GG 01/02/89 ( TD:11835 PB:11786 SUPV:TJ/GG 01/03/89 ( TD:11835 PB:11786 SUPV:TJ/GG 35) IWell no. day while drilling or workover in progress AUDI RIG 4 36) POH W/ TIH W/ 11677' DP CONVEYED LOGS 7"@11834' MW: 8.5 FSW DP CONVEYED CET/CBT/GR LOGGING TOOLS, LOGGED FROM - 11624'MD. POH W/ DP AND LOGGING TOOLS. The above is correct ~ For for~ prep~ration"and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 DAILY:S24,200 CUM:$2,571,940 ETD:S2,571,940 EFC:$3,214,000 TIH W/ CHAMP PKR 7"@11834' MW: 8.5 FSW FINISH POH AND LD LOGGING TOOLS. RIH W/ 7" RTTS TO 10580' MD. SET RTTS AND PRESSURE TESTED THE 9-5/8" CASING AND 7" LINER LAP TO 3000 PSI, LEAKED OFF 550 PSI IN 20 MINUTES. ATTEMPTED TO TEST THE 7" LINER DOWN THE DP AND THE RTTS FAILED. POH W/ THE RTTS AND TIH W/ 7" CHAMP PACKER. DAILY:S101,700 CUM:$2,673,640 ETD:S2,673,640 EFC:$3,214,000 CIRCULATING HOLE CLEAN 7"@11834' MW: 8.5 FSW ATTEMPTED TO SET CHAMP PACKER AT 10936' INSIDE THE 7" LINER, WOULD NOT SET. TOH TO TOL AND CBU, RECOVERED SAND, CMT AND LCM. PRESSURE TESTED THE 9-5/8" AND 7" TO 3000 PSI, BLED OFF 1500 PSI IN 60 MINUTES. TOH W/ DP AND PACKER. DAILY:S24,035 CUM:$2,697,675 ETD:S2,697,675 EFC:$3,214,000 TESTING 7" LINER 7"@11834' MW: 8.5 FSW TIH W/ 6" BIT AND SCRAPER, WASHED TO PBTD. REVERSE CIRCULATED 100 BBL AND 50 BBL HEC PILLS, RECOVERED +/- 25 BBLS OF CEMENT CUTTINGS. POH W/ BIT AND SCRAPER. MU CHAMP PACKER AND RIH TO 11470', COULD NOT GET DEEPER. ATTEMPT TO SET CHAMP PACKER AND TEST 7" LINER, HAD COMMUNICATION BETWEEN DP AND ANNULUS. ATTEMPTING TO RESET CHAMP PACKER. DAILY:S25,261 CUM:$2,722,936 ETD:S2,722,936 EFC:$3,214,000 TOH W/ MILL 7"@11834' MW: 8.5 FSW ATTEMPTED TO RESET CHAMP IN THE 7" LINER AND TEST THE LINER, HAD COMMUNICATION BETWEEN THE DP AND ANNULUS. POH W/ CHAMP PACKER, PACKER SEALING ELEMENTS BADLY TORN. MU TIW POLISH MILL AND RIH ON DP, POLISHED THE LINER TIE-BACK SLEEVE. RU HALLIBURTON AND PUMPED 150 BBL HEC SWEEP AT 8-9 BPM. RD HOWCO AND TOH W/ POLISH MILL. DAILY:S26,765 CUM:$2,749,701 ETD:S2,749,701 EFC:$3,214,000 MIXING HEC PILL 7"@11834' MW: 8.5 FSW FINISH TOH W/ POLISH MILL. MU TIW TIE-BACK PACKER ON DP AND RIH TO TOL. SET THE TIE-BACK PACKER AND TESTED THE LINER LAP AND LINER TO 3000 PSI FOR 30 MIN EACH, GOOD TESTS. POH W/ PACKER SETTING TOOL AND DP. MU AND RIH W/ 6" BIT AND JUNK BASKET ON DP. MIX 150 BBL HEC PILL. DAILY:S66,896 CUM:$2,816,597 ETD:S2,816,597 EFC:$3,214,000 AR3B-459-2-B INumber all daily well history forms as they are prepared for each well. consecutively Page no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. ARCO ALASKA. INC. IC°unty °r~(~H SLOPE I PRUDHOE BAY ILease or U~j 14-40 I Complete record ft~T T~:~hi~ ~ri~ling or workover in progress 01/04/89 ( TD:11835 PB:11786 SUPV:TJ/GG 01/05/89 ( TD:11835 PB:11786 SUPV:BB 01/06/89 ( TD:11835 PB:11786 SUPV:BB 01/07/89 ( TD:11835 PB:11786 SUPV:BB 2) ~4) IState.AK TIH W/PERF ASSY. 7"@11834' MW: 8.5 FSW MIX HEC PILL, TAG FILL/JUNK @ 11469', WASH TO 11773', PUMP 200 BBLS SW, 150 BBLS HEC, 1000 BBLS SW, POOH, MU VANN GUN & PKR ASSY, TIH W/ PERF GUNS. DAILY:S72,179 CUM:$2,888,776 ETD:S2,888,776 EFC:$3,214,000 RIH W/ PKR ASSEMBLY 7"@11834' MW: 8.5 FSW TIH W/ 4" VANN GUNS ON DP, FILLED ;iLL BUT LAST 2500' OF DP W/ 8.5 PPG SEAWATER TIED-IN WITH DRESSER ATLAS, ADJUSTED GUNS ON DEPTH. PRESSURE TESTED AND FIRED GUNS, BACKFLOWED WELL 15" AND RE'vERSED OUT DP, HAD +/- 7 BBL INFLUX. CIRC'D WELL AND MONITORED. POH W/ GUNS. PU AND RIH W/ PACKER ASSEMBLY ON DP. PERF INTERVALS: 10690-10800' (SAG) AND 11235-11580' (SADLEROCHIT). DAILY:S144,538 CUM:$3,033,314 ETD:S3,033,314 EFC:$3,214,000 LDDP 7"@11834' MW: 8.5 FSW FINISH RIH W/ PACKER ASSEMBLY ON DP. SET 9-5/8" X 4-1/2" BAKER DB PACKER AT 10500' MD (TAIL AT 10625'). TESTED PACKER TO 2500 PSI FOR 30 MINUTES - GOOD. DISPLACED WELL TO INHIBITED SEAWATER. POH LDDP. DAILY:S24,302 CUM:$3,057,616 ETD:S3,057,616 EFC:$3,214,000 NU TREE 7"@11834' MW': 8.5 FSW FINISH LD DP. PU ~%~ND RIH W/ 4-1/2" COMPLETION, SPACE OUT AND LAND TUBING. TESTED TBG AND CSG TO 3000 PSI, SSSV TO 1000 PSI DIFFERENTIAL. ND BOP'S, NU TREE. (AVA 'SC-SSV' @ 2020', BAKER 'DB' PKR @ 10515', & TT @ 10641') DAILY:S205,216 CUM:$3,262,832 ETD:S3,262,832 EFC:$3,214,000 IWell no. The above is correct , For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B Number all daily well history forms as they are prepared for each well. consecutively IPage no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ~%~'~.CO ~J..~,~% ~.~C. I County ott'~$~Z"J, ~U_P[ I Stata~K Field ~'R~D~O~, ~-~ Lease or ~'~; ;,~,~j,o~ DS ]4-40 IWell no. Auth. or W.O.~. Accounting cost center code Operator Spudded or Date and depth as of 8:00 a.m. TD:11835 PB:11786 SUPV:BB A.R.Co. '~."~ ' OOoO Date i2/22/66 Complete reCUr4& el~a~ reported otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well I JHour lt.~0 J{1{~ JPrior status if a W,O. RiG Rg~ga5sb 7"@1£834' MW: U.b FSW TEST HANGER AND TREE TO 5000 PSI. FREEZE PROTECTED WELL WITH INHIBITED DIESEL THRU ORIFICE/CHECK AT 3200'. SHEARED SHEAR-OUT SUB. SET BPV AND RELEASED RIG AT 1200 HOURS 1-7-89. DAILY:S8,295 CUM:$3,271,127 ETD:S3,271,127 EFC:$3,214,000 Old TD New TD PB Depth Released rig Date Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservo r name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected ~he above i ....... t ./~ f\ ~ For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3~C Number all daily well history forms consecutively as they are prepared for each well. jPage no. Division Of AllsntlcRIchfleldCompa~y ARCO ALASKA, INC. F'.O. BOX J00360 ANCHORAGE, ALASKA 995i~ DATE' i-t2-89 REFERENCE' ARCO CASED HOLE FINALS ~-2S ~-6-89 COLLAR/PERF RUN ~, 5' ~-26 t2-~-88 PERF RECORD RUN ~, 5' S-27 t2-75~-88 PDK-~O0 RUN ~, 5' . ** ?-~S ~-4-89 TEMF' ~'URVEY RUN ~, 5' 9-5 t 2-Z~0-88 F'FC RUN t ~ 5' t4-~9 ~-5-89 PFC RUN l, 5' t4-39 ~-7-89 PRODUCTION F'ACKER RUN ~, 5' ~4-4(~ ~2-29-88 CBT RUN ~, 5' ~4-40 ~-4-89 GAMMA RAY RUN t, 5' ~:'LEASE SIGN AND RETUJ~N TH~ ATTACHED COPY AS RECEIPT OF I)ATA. HAVE A NICE DAY AlasJ~.t~ii & Gas Cons. Commi~io~ SALLY HOFFECKER ATO-t 529 AF'F'ROVED _'~___ DISTRIBUTION A'fLA~' ~'CH ATLAS' ~'CH A'T'I_A.S' ATLA~~ ATLAS $CH ATLAS CENTRAL FILES CHEVRON D&M EXTENSION EXF'LORATION EXXON MARATHON MOBIL PHILLIF'S F'B WELL FILE~ R & D SAPC ~I'ATE OF ALASKA TEXACO ** THE CORRECTED API$ FOR THIS LOG IS 5r-J-(~29.-21809. STATE OF ALASKA ~-" AL,-,..,KA OIL AND GAS CONSERVATION COMMi~,.,,ON APPLICATION FOR SUNDRY APPROVALS ' 1. Type of Request: Abandon __ Suspend m Operation shutdown -X_ Re-enter suspended well Alter casing __ Repair well __ Plugging m Time extension __ Stimulate ~ Change approved program ~ Pull tubing ~ Variance __ Perforate ~ Other 2. Name of Operator 5. Type of Well: 6. ARCO Alaska, Inc. Development Exploratory ~ 3. Address Stratigraphic __ 7. P.0. Box 100360, Anchorage, AK 99510-0360 Service__ 4. Location of well at surface 8. 2656' FNL, 1574' FEL, Sec. 9, TION, R14E, UM At top of productive interval 9. 2550' FNL, 2500' FEL, Sec. 16, TION, R14E, UM (approx.) At effective depth 10. 2353' FSL, 2510' FWL, Sec. 16, TION, R14E, UM (approx.) At total depth 11. 2307' FSL, 2494' FWL, Sec. 16, TION, R14E, UM (approx.) 12. Present well condition summary Total depth: measured true vertical 11835 ' MD feet 9094 'TVD feet Plugs (measured) None Datum elevation (DF or KB) RKB 74 ' Unit or Property name Prudhoe Bay Unit Well number 14-40 Permit number 88-123 APl number 50-- 029-21875 Field/Pool Prudhoe Bay 0il Pool feet Effective depth: measured 11786 'MD feet true vertical 9080 'TVD feet Junk (measured) None Casing Length Size Structural 80 ' 20" Conductor 4083 ' 13-3/8" Surface Intermediate 10843 ' 9-5/8" Production Liner 1270 ' 7" Perforation depth: measured None None true vertical Tubing (size, grade, and measured de~tohn)e Packers and SSSV (type and measurefl depth) None Cemented Measured depth True vertical depth 2150# Pol eset 103 'MD 103 'TVD 2500 sx CS II! & 4116'MD 600 sx Class G-Top job w/200 sx CS I! 600 sx Class G 10875'MD 4018'TVD 8913 'TVD 350 sx Class G 10564'-11834'MD 8841'-9093'TVD 13. Attachments Description summary of proposal __ Well Hi story 14. Estimated date for commencing operation January, 1989 Detailed operations program ~ BOP sketch __ I 16. If proposal was verbally approved I Oil ~ Gas __ Name of approver Date approvedI Service ' i'7. I hereby certify that the foreg.qing is true and correct to the best of my knowledge. Signed /,~..~~~_~~' Title RegiOnal Drilling Engineer N t'f '" .,~. FOR COMMISSION USE ONLY Conditions of approval: o ~ y t.;omm~ss~on so representative may witness Plug integrity __ BOP Test ~ Location clearance ~ Mechanical Integrity Test_ Subsequent form required 10- 15. Status of well classification as: Suspended__ Date I Approval No. ,:~'.' ?OC:',~ · .~,pproved Copy ~ A Returned ~ dRIGIN, L SIGNED BY ApprovedbyorderoftheCommissioner.LoN~,I!E C. SMITH //.~'"'.,~¢ 'J~Commissioner · ~ 0~6i$A4' Form 10-403 Rev 06/15/88 Date SUBMIT IN TRIPLICATE ARCO Oil and Gas Company,,,~'~ Well History- Initial Report - Daily Instructione: Prepare and submit the "Initial Report" on the first Wednesday afte[ a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District I County, parish or borough I Field ]Lease or Unit I p RUD I..IOl~l R~¥ I ADL: 28314 Auth. or W.O. no, ITitle I ns?,~nl [Stat~l~ DR 14-40 Operator Spudded or W.O. begun .¢IPUD Date and depth as of 8:00 a.m, 10/28/88 ( TD: 500'( SUPV:JCP/KS 10/29/88 ( TD: 1700' ( 1 SUPV:JCP/KS 10/30/88 ( TD: 3070' ( 1 SUPV:JCP/KS 10/31/88 ( TD: 4028'( SUPV:JCP/KS 11/01/88 ( TD: 4137'( SUPV:JCP/KS 11/02/88 ( TD: 4137'( SUPV:JCP/KS 11/03/88 ( TD: 5600'(1 SUPV:MDD DRTT,T. API: 50-029-21875 ARCO W.I. 21.0000 10/27/f)~ 2230 fiRS Complete record for each day reporled NABORS 28E .) ;00) ~) ~00) ~) 170) ~) ~58) ,) [09) ) o) Well no. DRILLING 20"@ 103' MW: 8.8 VIS:290 FIN MOVING RIG. ACCEPT RIG AT 1130 HRS 10/27/88. N/U 20" DIVERTER, BUILD SPUD MUD. P/U 17-1/2" BIT & BHA. FUNCTION TEST DIVERTER. RIH TO 103'. SPUD AT 2230 HRS 10/27/88. DRILL TO 500'. DAILY:S66,120 CUM:$66,120 ETD:S66,120 EFC:$3,214,000 DRILLING 20"@ 103' MW: 9.5 VIS:162 DRLD TO 587'. RUN GYRO SURVEY W/ WL SURVEY. TRIP'FOR BIT CHNG. DRL TO 1286'. SURVEY. POOH FOR BIT. RIH W/ BIT % 3. DRLD TO 1700'. DAILY:S59,815 CUM:$125,935 ETD:S200,000 EFC:$3,139,935 DRLG 20"@ 103' MW: 9.6 VIS:104 DRLD TO 1978'. RUN. GYRO SURVEY W/ WL SURVEY. POOH FOR BIT. TIH AND DYNA DRLD TO 3070'. DAILY:S64,745 CUM:$190,680 ETD:S190,680 EFC:$3,214,000 DRLG 20"@ 103' MW: 9.9 VIS: 85 DYNA DRLD TO 3425'. CIRC. SURVEY. POOH TO CHNG BIT. BIT BALLED UP. RIH W/ BIT # 5 AND DYNA DRLD TO 4028'. DAILY:S64,710 CUM:$255,390 ETD:S255,390 EFC:$3,214,000 CUTTING 13-3/8" CASING 13-3/8"@ 4116' MW: 9.9 VIS: 47 DYNADRIL F/ 4028'-4137'. CIRC & COND. SHORT TRIP. CIRC & COND. POOH. RU CSG TOOLS, RUN 13-3/8", 72%, L-80, BTC 102 JTS AND I JT 13-3/8", 68~, K-55, BTC. CIRC & COND. PUMP 100 BBL WATER SPACER. MIX & PUMP 2500 SX CS III @ 12.2 PPG, TAILED IN W/ 600 SX CLASS G W/ 1% CACL @ 15.8 PPG. BUMP PLUG & TEST CSG TO 2000 PSI. PERFORM 200 SX TOP JOB W/ CS II @ 14.9 PPG. ND DIVERTER, SET SLIPS & MAKE ROUGH CUT. DAILY:S362,672 CUM:$618,062 ETD:S618,062 EFC:$3,214,000 DRILLING CEMENT 13-3/8"@ 4116' MW: 8.6 ViS: 27 ND 20" DIVERTER. MAKE FINAL CUT. WELD ON FMC WELLHEAD & TEST TO 1500 PSI. NU BOPS & TEST TO 5000 PSI. INSTALL WEAR RING. PU PDC BIT & DYNADRILL BHA. RIH. TEST CSG TO 2500 PSI. THAW OUT CUTTINGS AUGER. DRILL FLOAT COLLAR & SHOE JTS. DAILY: $75,716 CUM: $693,778 ETD: $693,778 EFC: $3,214,000 DRILLING 13-3/8"@ 4116' MW: 9.1 VIS: 31 DRLD 10' NEW HOLK. FORMATION LEAK OFF TEST TO 13.9 PPG. DRLD TO 5600'. DAILY:S43,253 CUM:$737,031 ETD:S737,031 EFC:$3,214,000 The above i~ correct ~*'*'~ For formXpreparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B~459-1-D Number all daily well history forms consecutively as they are prepared for each well. iPsge no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less Irequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. ~County or Parish ARCO ALASKA INC. I NORTH SLOPE ~Lease or Unit PRUDHOE BAY I DS 14-40 Complete record for each day while drilling or workover in progress NABORS 28W. 11/04/88 ( TD: 6105'( SUPV:MDD 11/05/88 ( TD: 7185'( SUPV:MDD 11/06/88 ( TD: 7923'( SUPV:MDD 11/07/88 ( TD: 8410'( SUPV:MDD 11/08/88 ( TD: 8650'( SUPV:MDD 11/09/88 ( TD: 9115'( SUPV:MDD 11/10/88 ( TD: 9290'( SUPV:JCP 8) 505) 380) 738) 1) 487) 2) 240) 3) 465) 4) 175) JState AK DRILLING 13-3/8"@ 4116' MW: 9.1 VIS: 33 DRILL W/ DYNADRILL. SERVICE MUD PUMP, REBUILD POP OFF VALVES. DRILL TO 5760'. POOH. L/D MOTOR & P/U NEW BHA. RIH, SLIP & CUT DRILL LINE, FIN RIH. WASH & REAM F/ 5623'-5760'. DRILL TO 6105' DAILY:S52,548 CUM:$789,579 ETD:S789,579 EFC:$3,214,000 DRILLING 13-3/8"@ 4116' MW: 9.3 VIS: 33 DRILLED TO 6454'. MIX SLUG & DROP SURVEY. TRIP FOR BIT #8. DRILLED TO 7185'. DAILY:S51,199 CUM:$840,778 ETD:S840,778 EFC:$3,214,000 DRILLING 13-3/8"@ 4116' MW: 9.4 VIS: 34 DRILLED TO 7435'. DROP SURVEY & PUMP SLUG. POOH, PU 7-3/4" STEERABLE DYNA DYNADRILL, RIH. SLIDE & DRILL TO 7923'. DAILY:S50,987 CUM:$891,765 ETD:S891,765 EFC:$3,214,000 DRILLING 13-3/8"@ 4116' MW: 9.5 VIS: 40 ROTARY & DYNA DRILL TO 8345'. SROP SURVEY & PUMP SLUG. POOH FOR BIT. RIH, SLIP & CUT, FIN RIH. WASH & REAM LAST 30' AS PRECAUTION. DRILLING AHEAD. DAILY:S57,395 CUM:$949,160 ETD:S949,160 EFC:$3,214,000 DRLG 13-3/8"@ 4116' MW: 9.5 VIS: 46 DRILL TO 8624'. DROP SURVEY, PUMP SLUG. POOH, REPLACE MOTOR & BIT, RIH. ATTEMPT TO SLIDE, DRLG VERY SLOWLY. REPAIR MUD PUMP. DRILL F/ 8624'-8650'. DAILY:S59,072 CUM:$1,008,232 ETD:S1,008,232 EFC:$3,214,000 DRILLING 13-3/8"@ 4116' MW: 9.5 VIS: 46 DRILL & SLIDE TO 8780'. REPAIR PUMP #1. DRILL & SLIDE TO 9018'. REPAIR PUMP #2. DRILL & SLIDE TO 9060'. REPAIR PUMP 91. DRILL & SLIDE TO 9090'. REPAIR PUMP #1. DRILL & SLIDE TO PD. DAILY:S48,712 CUM:$1,056,944 ETD:S1,056,944 EFC:$3,214,000 DRILLING 13-3/8"@ 4116' MW:10.1 VIS: 54 DRILL TO 9167'. DROP SURVEY & PUMP SLUG. POOH. RIH WITH NEW BIT. DRILL TO 9217', RAISE MUD WT TO 9.8 PPG. ATTEMPT TO POOH, HOLE TIGHT. RIH. DRILL TO 9228', INCREASE MUD WT TO 10.1 PPG. POOH FOR BHA. PU NEW BHA, SERVICE WEAR BUSHING. RIH, SLIP & CUT, FIN RIH. WASH & REAM 9148'-9228'. DRILL TO 9290'. DAILY:S60,748 CUM:$1,117,692 ETD:SI, II7,692 EFC:$3,214,000 JWell no. The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B INumber all daily well history forms consecutively as they are prepared for each well. IPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lnlerlm" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field ARCO ALASKA INC. ICounty or Parish IState NORTH SLOPE I AK Lease or Unit DS 14-40 PRUDHOE BAY Date and deptll as of 8:00 a.m. 11/11/88 ( TD: 9830'( SUPV:JCP 11/12/88 ( TD:10200' ( SUPV:JCP 11/13/88 ( TD:10577'( SUPV:JCP 11/14/88 ( TD:10837'( SUPV:JCP 11/15/88 ( TD:10888' ( SUPV:JCP 11/16/88 ( TD:10888' ( SUPV:JCP 11/17/88 ( TD:l1023'( SUPV:MDD 11/18/88 ( TD:l1270'( SUPV:MDD Complete record for each day while drilling or workover in progress NABORS 28E 5) DRILLING 13-3/8"@ 4116' MW: 1.2 VIS: 50 540) DRILL TO 9665'. TRIP FO BIT. DRILL TO 9830'. DAILY:S46,126 CUM:$1,163,818 ETD:S1,163,818 EFC:$3,214,000 6) DRILLING 13-3/8"@ 4116' MW:10.2 VIS: 45 370) DRILL TO 9985'. POOH FOR BIT & BHA. TIH. DRILL TO 10200' .7) 377) 8) 260) 9) 51) 0) 0) ~1) 135) 12) 247) DAILY:S56,606 CUM:$1,220,424 ETD:S1,220,424 EFC:$3,214,000 DRILLING 13-3/8"@ 4116' MW:10.2 VIS: 58 DRILL TO 10567' TRIP FOR BIT & BHA. SLIP & CUT DRILL LINE. DRILL TO 10577' DAILY:S51,572 CUM:$1,271,996 ETD:S1,271,996 EFC:$3,214,000 DRILLING 13-3/8"@ 4116' MW:10.3 VIS: 58 DRILL TO 10828' TRIP FOR BIT. DRILL TO 10837'. DAILY:S52,942 CUM:$1,324,938 ETD:S1,324,938 EFC:$3,214,000 RUNNING CASING 13-3/8"@ 4116' MW:10.3 VIS: 60 DRILL TO 10888'. CIRC. SHORT TRIP 20 STDS. CIRC & COND. POOH. PULL WEAR BUSHING, INSTALL 9-5/8" CASING RAMS. TEST BONNET SEALS TO 5000 PSI. RU CSG TOOLS. RNG 9-5/8" CSG. DAILY:S50,690 CUM:$1,375,628 ETD:S1,375,628 EFC:$3,214,000 CHANGING OUT HCR VALVE 9-5/8"@10875' MW:10.3 VIS: 60 FIN RNG 152 JTS 9-5/8"/47~/L-80/BTC. LAND & TEST PACKOFF TO 5000 PSI. CIRC & COND WHILE BATCH MIXING. PUMP 50 BBLS FRESH WATER + 1% MCS-A + 0.6% CLAYTROL. PUMP 600 SX CLASS G CMT @ 15.8 PPG. BUMP PLUG. TEST CSG TO 3000 PSI. CLEAR RIG FLOOR. CHANGE RAMS TO 5" TEST BOP, HCR VALVE FAILED. CHANGE HCR VALVE & KELLY HOSE. DAILY:S342,361 CUM:$1,717,989 ETD:S1,717,989 EFC:$3,214,000 DRILLING 9-5/8"@10875' MW: 9.2 VIS: 48 FIN CNGING OUT HCR, TEST SAME. PU BHA AND RIH. TAG FLOAT COLLAR AT 10789'. TEST CSG TO 3000 PSI. DRLD FC, CMT, FS AND 10' NEW HOLE. CIRC AND COND MUD. PERFORM LOT TO 12.5 PPG. DRLD TO 11023' DAILY:S52,966 CUM:$1,770,955 ETD:S1,770,955 EFC:$3,214,000 DRILLING 9-5/8"@10875' MW: 9.2 VIS: 46 DRILL TO 11257'. POOH, UNLOAD BAROID MWD, CHANGE BHA & RIH. DRILL TO 11270'. DAILY:S54,144 CUM:$1,825,099 ETD:S1,825,099 EFC:$3,214,000 JWell no. The above is correct Signa~~ ' ~" For form p~paration and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-,2-B INumber all daily wall history forms consecutively JPage no, as Ihey are prepared for each well. l ARCO Oil and Gas Company Daily Well History--Interim instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number alt drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Fin&l" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or {2) on Wednesday of the week in which oil string is set, Submit weekly for workovers and following setting of oil string until completion. -_ District ~County or Parish ~Stat%K ARCO ALASKA INC. I NORTH SLOPE Field JLease or Unit PRUDHOE BAY J DS 14-40 ! Complete record for each day while drilling or workover in progress NABORS 28E Date and deptl~ as of 8:00 a.m. 11/19/88 ( TD:11835' ( SUPV:MDD 11/20/88 ( TD:11835' ( SUPV:MDD 11/21/88 ( ~D:11835 SUPV:MDD 11/22/88 ( TD:11835 PB: SUPV:MDD 11/23/88 ( TD:11835 PB: SUPV:MDD 3) 565) 4) 0) CIRC & COND @ TD 9-5/8"@10875' MW: 8.7 VIS: 40 DRILL TO 11327'. PULL INTO CSG. LOST RTNS, FILL BACKSIDE W/ 160 BBLS WATER. POOH TO 5746'. TOOK 140 BBLS TO FILL HOLE. CIRC 8.6 PPG MUD AROUND. RIH TO 7631' & CIRC AROUND 8.7 PPG MUD. RIH TO CSG SHOE & CIRC. RIH TO 11327'. DRILL TO 11835' W/ 8.7 PPD MUD, HOLE STABLE. DAILY:S50,868 CUM:$1,875,967 ETD:S1,875,967 EFC:$3,214,000 RIH W/ LINER 7"@11835' MW: 8.7 VIS: 40 CBU. POOH TO 10835'. LOG W/SID/CNO/ERW/GR F/10935'-11640' REAM TO BOTTOM TO RELOG SECTION W/BAROID MWD. CIRC & COND. POOH. DUMP MWD DATA & EVALUATE SAME. SLIP & CUT DRILL LINE. LD TELECO & BAROID MWD. RU 7" CSG TOOLS. DAILY:S51,863 CUM:$1,927,830 ETD:S1,927,830 EFC:$3,214,000 RIH W/ 8-1/2" BIT 7"@11835' MW: 8.6 WBM RIH W/ 29 JTS 7", 29#, L-80, BTC LINER. CIRC @ 9-5/8" SHOE. RIH TO 11835'. CIRC @ TD . BATCH MIX 350 SX BJ GAS BLOCK CMT @ 15.8. PUMP 50 BBL MCS-A SPACER. 70-90% RETURNS DURING JOB. BUMP PLUG & SET HANGER. RELEASE FROM HANGER & POOH. PU 8-1/2" BIT & RIH. (TOL @ 10564', FC @ 11786', FS @ 11834'.) DAILY:S170,202 CUM:$2,098,032 ETD:S2,098,032 EFC:$3,214,000 DRL CMT 7"@11835' MW: 8.6 WBM RIH TO TOL AT 10564'. CBU. POOH. PU 4-3/4" DC, AND 3-1/2" DP AND RIH. TAG CMT AT 10573'. REAM HARD/RATTY CMT TO 11609'. DRL HARD CMT TO LANDING COLLAR AT 11696'. TEST LAP. DRL LANDING COLLAR AND CMT TO FLOAT COLLAR. DAILY:S55,956 CUM:$2,153,988 ETD:S2,153,988 EFC:$3,214,000 L/D DRILL PIPE 7"@11835' MW: 8.7 NaCl CIRC & COND MUD. SHORT TRIP. CIRC & COND. DISPLACE HOLE TO 8.7 PPG BRINE. POOH. RIH & SET BAKER RETRIEVABLE BRIDGE PLUG @ 6995', TEST TO 3000 PSI. L/D DRILL PIPE. DAILY:S43,387 CUM:$2,197,375 ETD:S2,197,376 EFC:$3,213,999 IWell no. The above is correct For form prep"'aration'and distribution IDate~ see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B INumber all daily well history forms consecutively as they are prepared for each well. IPage no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ~CO 3~LASK~ INC. Field PRUDHOE BAY Auth. or W.O. n~S2301 I County or ~]~}{ SLOPE Lease or C~L: 28314 T,tle DRILL API: 50-029-21875 Accounting cost center code StateAK DS 14-40 IWell no. Operator ARCO Spudded or W.~[~i:~un Date and depth as of 8:00 a.m. 11/24/88 ( TD:11835 PB: SUPV:JCP A.R.Co.V~[.0000 Date 10/27/88 Complete recc[~Ol~a~h ~l~/~'eported Iotal number of wells (active or inactive) on this, ost center prior to plugging and I bandonment of this well our 2230 }{RS IPrlor status if a W,O. I RIG RELEASE @ 2230 MRS 7"@11835' MW: 8.7 NaCl FIN L/D DRILL PIPE. FREEZE PROTECT TOP 2000' W/ 60-40 METHANOL WATER. ND BOP. NU TBG HEAD, DUMMY HGR & DRY HOLE TREE. TEST TO 5000 PSI. FIN CLEANING PITS. FREEZE PROTECT 14-38 & 14-40 ANNULI W/ DIESEL. RELEASE RIG 2230 HRS 11/23/88. DAILY:S39,479 CUM:$2,236,854 ETD:S2,236,854 EFC:$3,214,000 Old TD I New TD P8 Depth Released rig I Date K nd of r g Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Inte'rval Oil or gasTest time Production O I on test Gas per day , Pump size, SPM X length Choke size T.P, C.P. Water % GOR Gravity Allowable Effective date corrected · · The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87, AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each we I. jPage no, Olvlllon of AtlsntlcRIchfleldCompan¥ ID:Ld bJ i STATE OF ALASKA ALASR% 0IL & GAS CONSERVATION C01.E4iS$ION B.O.?.E. Inspection Report Location, General. ¢)0~0. ?ell Sig[ ...... ACCUHULAI'0R SYSI'~I General 'Housekeeping z-~"__~Rig,. Reserve Fi.t... t~' - __ . ---1 . ~ 111 .... .E u.d___S.f~vp t ems V i ~Ua 1 Trip Tank Pit Gauge T!ow Monitor Gas Detectors Audio ~--- l~xessure Annular Preventer.__~ Pipe Ram~ ........... Blind Rants Choke Line Valves R.C.R. Valve ...... Kill Line Valves Check Valve Full Charge Pressure_,~_/_~/D 0 psig Pressure After Closure__.J .A 0~ psig__ Pump incr. clos. pres, 200 psig. ~ /7~o- /faO-,/ ~ -/~'o- Controls: Haster Remote ~glinds switch cover ._K_el!j~ and Floor S~fety Valves Upper Kelly, b."' Iest Pressure Lower gell~ Bail ~'ype Test ~res,uro,_: ...~_~.o o _.0 ......... Test Pressure Inside BOP TeSt Pre,sure .. Choke Hmnifold_,.______,%e~ Pre~ure._~_~_.~.~ ~ ~o. Valves ~/ ' No, flanges___/~L- Adjustable Chokes / .H v._d r__a, u ~ c____a.l~~~_r a t e d. choke .... / .......... ~_. Test Results; ~Failures /t~'o ~.~ .... .__: Tes~ Time --___,~.~hrs, Repair or Replacement of failed equipment to be made within days and Inspector/ Commission office notified. ~ ,~, Inspector ANCHORAGE:, At...A;ii:t< A o c;, ,~',. .. ..,. ~, :'.'.~... l:~: iii: F' E: F.'. ['i: N C: E:: A F.: C. 0 H A G N E: 'i" ]: C: 'Y' A F' l!i: ,!-i: W / L.. :I: ~?? 'Y' :[ N 'i 4 ":' 4 (') '.'.' 2 .... ~i .... 8 8 CI H: F,' t... i... ," (:~. F:. / E: W I:~.'. / C N F' ::'?/' C: N 'l"/,:...' / F.'. H. (3 :(i'..'/' 3" F' i::~ ;ii: / F.: A 'i" Iii: /F.'. 0 !::' i::' i... Iii: A ;~i: iii: :~: .T. [;. N ~'.":'~ N :0 i:~:. iii: T' LJ F.: N 'i" I"i .r..i: A ~i" 'i" A C H iii: l) C: i3 i::' 'Y' A :!i! i:~: ii!: C,?.'i: :!: F:~'i'' !:3 F:' '() A'i" A ... CE[V i:k l!i: C':iii: ]: V lii:.'O :8 Y. ...................... ;ii: ih !... I.., ¥' !.-t .r.)t::' F' r:i: c: i...:: ii!: f~' .Oil & ~aS emn,s. '~ ~chorage A 'T' 0 .... ~, '~'..... ,~'. '"' q:'.. '!" F: A N ;~'.'; '"' :""" '~' ' ,'.':'~ i::' F:' F.'. 0 V Iii: :() ...................... D Z .? T F.: Z B i..j 'i" ]: 0 N ~--~;.-':.,v~: ..,..":.~ ?,~ :!:,:::/'"'~.' '¥' ~/' ...... *:4~ ~ .~A_i~_Oil & Gas Cons. Commission :!.;: ,-::.:: i... L ¥' H~::~i::'F'i~ - ', ~chorage ~'-":', '~" () .... 'i '.ii: ?. "-'.;.:' ~.-~ t... Fi,::. k A ANCHORAGE"., '" "~'' ' R ii!; F' E F;,' E N C E ' A F;: C 0 0 F' E N H 0 L.. E F' E N A L ;ii: 4 .... 4 (') i i .... ~ "? / 'i ? .... E: 8 H W D iii: W R"" [:.;- A i"i M A ( U J::' F:' iii: R ) F;..' U N 4 .... 4 6) 'i i .... -'..; '7 / i 9 "" 8 8 i"'i U D ii:.; W F;.'.'-" [;- A id i'i A ( L. 0 W E F;.: ) i:;.,, t..j ,'q 2 'i&2, i&2, i & 2, J::' I... iii; A ,fi: E *"' I (]. N A N D F;.: E"f' U R N "f' H iii: A 'T' 'T' A C H *::' D C i')F:' Y A 5' R iii; C *::' I F:' 'T' ~' j t::' D A T A · . :.:, t ..... i... ... i :. A F:' 1::' R 0 V ii!: D ..................................................................... D 15"FF;.'. ! BU'T' I ON NI... NJ... Ni... B A F;..' B A F;..' B A R BAR October 19, 1988 Telecopy No. (907) 276-7542 T P Oostermeyer Regional Drilling Engineer ARCO Alaska, P 0 Box 100360 Anchorage, AK 99510-0360 Prudhoe Bay Unit DS 14-40 ARCO Alaska, Inc Permit # 88-123 Surf Loc 2656'FNL, 1574'FEL, Sec 9, T10N, R14E, UM Btmhole Loc 2287'FSL, 2579'FEL, Sec 16, T10N, R14E, UM Dear Mr Oostermeyer: Enclosed is the approved application for permit to drill the abov~ referenced well. The permit to drill does not inden~nify you from the probable need to obtain additional permits required by law from other govern- mental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. W~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V e-fy tru% y~your s, C V ChattertOn" Chai~an A!aska~ Oil and Gas Conservation Co~ission BY O~ER OF T~ CO.fISSION 0 nclosure e: Department of Fish & Game, Habitat Section - w/o encl Department of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA G,,_ AND GAS CONSERVATION CON,.VIISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill [] Redrill ©l lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone ~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska~ Inc. RKB 74'~ PAD 42'GL feet Prudhoe Bay Field 3. Address 6. Property Designation Prudhoe Bay Oi 1 Pool P.O. Box 100360, Anchorage, AK 99510-0360 ADL 28314 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2656'FNL, 1574'FEL,Sec. 9,TION,R14E,UM Prudhoe Bay Unit Statewide At top of productive interval (~ 8987 'TVD) 8. Well nu .mber Number 2550'FNL, 2500'FEL,Sec. 16,T10N,R14E,UM DS 14-40 #8088-26-27 At total depth 9. Approximate spud date Amount 2287'FSL, 2579'FEL,Sec. 16,TlON,R14E,UM 10/21/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depthiMe and TVD) property line DS 14-22 25' 11722'MD 2287' ~ TD feet @ 2381 'MD/2380'TVDfeet 2560 9066'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth ~8{i) :~l:~t Maximum hole angle3 t~° Maximum surface 2970 psig At total depth (TVD) 3850 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' 30' 30'i 110' 110' 2000# Poleset 17-1/2" 13-3/8" 68# K-55 BTC 20' 30' 30' 50' 50' 2500 sx CS Ill & 72# L-80 BTC 4054' 50' 50' 41 04' 4000' 600 sx CS I I 12-1/4" 9-5/8" 47# L-80 3TC/Mod 10987' 30' 30' 11017' 8944' 500 sx Class G 8-1/2" 7" 29# L-80 BTC 1005' 10717' 8880' 11722' 9066' 300 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor '~ Surface '~%~ IF .... ~'" /' "'~ ½~'i Intermediate Production .... :' ,;.,' Liner :,,.. Perforation depth: measured ,~,~.~.,.~?~:., :.,.. true vertical 20. Attachments Filing fee 1~ Property plat [] BOP Sketch J~ Diverter Sketch ~ Drilling program Drilling fluid program'S' Timevs depth plot [] Refraction analysis [] Seabed report [] 20 AAC25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledg~ Signed '"'7~,~J Title Regional Dr illi nq Enqineer Date Commission Use Only (GSW) PD3/031 Permit Number I APInumber IApprovaldate ] See cover letter ~ ~' - /.2_ .,~ 50-- O ~ ¢- ~ / ~;' 7,.~' ] 0 / ]. 9~ 88 for other requirements Conditions of approval Samples required [] Yes .~No Mud Icg required Yes ~No Hydrogen sulfide measures [] Yes ~ No Directional survey required ~Yes [] No Required working,,Crf'~'S~ure for,~OP~,~'t~2!~; [] 3M; ,~ 5M; [] 10M; [] 15M by order of / Approved by Commissioner the commission Date FOrm 10-401 Rev. 12-1-85 Submit in triplicate PBU DS 14-40 OPERATIONS SUMMARY 1) MIRU drilling rig. 2) NU 20" annular diverter and function test same. 3) Spud well and drill 17-1/2" hole to 2000'. Kick off and build angle at 1.5°/100' to 30° 15' at S10°9'W. Drill to 4000'TVD/4104'MD. 4) Set 13-3/8" casing and cement same. 5) Install 13-5/8" 5000 psi RSRRA BOPE stack and test rams to 5000 psi, annular to 3500 psi. 6) Drill float equipment and 10' of new hole. Perform leak off test. 7) Drill 12-1/4" hole to 7107'TVD/7460'MD. Kick off well again and build angle at 1.5°/100' to 80° at SlO°9'W. Drill to the Sadlerochit at 8944'TVD/11017'MD. 8) Set 9-5/8" casing and cement same. 9) Test casing to 3000 psi. Drill out and perform leak off test. 10) Drill 8-1/2" hole to TD of 9066'TVD/11722'MD. Log hole with MWD formation logs. 11) Run and set 7" liner and cement same. 12) Clean out liner to PBTD. Test liner, liner lap and casing to 3000 psi for 30 minutes. 13) Run CBT/GR on drill pipe to evaluate cement bonding. 14) Circulate well to brine, freeze protect and release drilling rig. 15) MIRU completion rig. Perforate with tubing conveyed guns. RIH and set packer. Run 4-1/2" tubing with GLMs and 4-1/2" tailpipe. NU 4-1/2" tree. RD completion rig. 16) Install SSSV. Stimulate as necessary. PD3/031.2 NOTE' a) b) c) d) e) In accordance with Area Injection Order No. 4, excess non-hazardous fluids resulting from well operations and as necessary to control fluid level in reserve pit will be disposed of down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The annulus will be sealed with 300 sx of cement followed by Arctic pack upon the termina- tion of fluid disposal. Wells within 200' of the proposed well are' DS 14-17 DS 14-21 DS 14-22 168' @ 2040'TVD/2040'MD 48' @ 2640'TVD/2643'MD 25' @ 2380'TVD/2381'MD The drilling fluid program and fluid surface system will conform to the regulations set forth in 20AAC25.033. Maximum surface pressure is based upon BHP and a full column of gas to TD (0.10 psi/ft). Based upon previous logs on DS 14, no potential productive zones are anticipated above 4000'TVD. PD3/031.3 ARCO ALASKA. Ino. D.S. 14. Well Not 40 Proposed Prudhoe Bey, North Slope. Aleeke 0 . RKB ELEVAT[ON. 74' m 1000 2000 3000 4000 _ 5000 6000 _ 7000 _ 8000 _ 9000 _ 10000 .... _ KOP TVD=2000 THD=2000 DEP=O 3 6 9 12 BUILD 1.$ DEG 15 PER 100 FT 18 21 24 27 3o EOC TVD-3924 TMD-4017 DEP-520 13 3/8' CSG PT TVD-4000 TMD=4104 DEP-564 K-15 TVD-4319 TMD=4474 DEP-750 AVERAGE ANGLE 30 DEG 15 HI N K-lO TVDI6899 THD=7460 DEP-2255 2nd KOP TVD=7107 THD=7701DEP=2376 ' '~:: SAG RIVER' TOP SAD / EOC TVD=8944 TMD=11017 DEP-5012 9 5/8' CSG PT TVD-8944 TMDIIIO17 DEP-5012 TARGET TVD=8987 TMD=l1265 DEpI5256 HOT TVD-9029 TMD-IlS07 DEP-5494 O/W CONTACT TVD-9049 TMD-11622 DEP=5608 TD / 7" LINER TVD=9066 TMD-11722 DEP=5706 I I I I 0 1000 2000 3000 4000 VERTICAL SECTION I 5000 6000 HOR ~ ZONZAL PROJECT ~ ON SCALE IN. -- !000 FEET ARCO ALASKA, ! D.S. 14. Well Not 40 Propo,ed Prudhoe Bay, North Slope.Alaska 1000 O w 1000 _ z 2000 - I -,- ~000 _ 4000 _ 5000 _ 6000 _ WEST-EAST 3000 2000 1000 0 I I I TD LOCATION' 2287' FSL, 2579' FEL SEC. 16. TION. R14E 1000 I SURFACE LOCATION~ 2656' FNL, 1574' FEL SEC. 9, TlON. RI4E SURFACE S 10 DEG 9 MIN W 5256' .: (T'O TARGET) TARGET TVD-8987 THD-I1265 DEP-5256 SOUTH 5174 WEST 926 TAROET LOCAT[ON, 2550' FNL. 2500' FEL SEC, 16, TION. RI4E lO0 0 100 200 3OO 400 500 600 700 800 9O0 400 300 200 100 0 100 200 300 400 I I I I I I I I I ! 400 4000 4200 I 300 '~ooo ~200 ~2200 ! [ 2, o 3400 ~ ~00 I ~ 280 o0 ! oo 2800 ~3000 ~000 I 0 t ~ 3200 t Booo t I ~200 ~ ~400 I 3400 I I 3200 ?3600 I 3600 I I I 73800 I 3400 I 3800 I I I ~ 4000 I I I 4000 1 4200 I I I I I ~ 4400 I I 4200 ! I I I I ! 200 100 0 100 200 7400 7600 7800 300 400 100 100 200 300 400 50O 600 700 800 90O 13-518" 5000 PSI BOP STACK DIAGRAM ACCUMULATOR CAPACITY TEST l ANNULAR- PREVENTER 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. Z. 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 IADC REPORT. THE ACCEPTABLE LOWER LIMIT 15 45 SECONDS CLOSING TIME AND lZ00 PSI REMAINING PRESSURE PI PE RAMS BLI ND RAMS DRILLING SPOOL PI PE RAHS DRLG SPOOL CSG SPOOL 3-3/8" ST ART lNG HEAD ALL BOP EQUIPMENT 5000 PSI RATED 13-5/8" BOP STACK TEST 1 FILL BOP STACK AND MANIFOLD WITH A NON- FREEZING LIQUID. 2. CHECK THAT ALL HOLI~ DOWN SCREWS ARE F.ULLY RETRACTED. MARK RUNNING JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN TEST PLUG ON DRILLPlPE AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS. 3. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. 4 FUNCTIONALLY TEST CHOKES. 5 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. 6 INCREASE PRESSURE TO 3000 PSI AND HOLD FOR A MINIMUM OF SMINUTES. BLEED PRESSURE TO ZERO. 7 OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST 3MINUTES. BLEED PRESSURE TO ZERO. 8 CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES AND OPEN CHOKES. I NCREASEPRESSURETO5000PSIANDHOLDFORAT LEAST 3MINUTES. BLEED PRESSURE TO ZERO. 9 OPEN TOP SET OF PIPE PAMS 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 10. TEST REMAINING UNTESTED MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF VALVE AND ZERO PRESSURE DOWN- STREAM 1 1.BLEE~D PRESSURE TO ZERO. OPEN BOTTOM 5ET OF PIPE RAMS. 1Z. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 P51 FOR AT LEAST $ MINUTES. 13. 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. 14. TEST STANDPIPE VALVES TO 5000 PSI. 15. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI. 16. CHECK OPERATION OF DEGASSER. 17. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND 5END TO DRILLING SUPERVISOR 18. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. NABORS 28E DIVERTER SYSTEM SCHEMATIC ---- ARCO ALASKA, INC. FILL.UP LINE !, RISER I , I 2000 PSI DIVERTER FLOWLINE 10" ~BALL VALVE 10" BALL VALVE CONDUCTOR NOTE: ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS A VARIANCE FROM 20AAC25.035 RESERVE PIT 10" VENT LINE WELL 10" VENT LINE DIVERTER LINES DISCHARGE 100' FROM RIG IGNITION SOURCE. ALL TURNS ARE 90° TARGET TEES. JG 8/6/87 Depth (TVD) DS 14-40 MUD PROGRAM Plas Yield Density Visc. Point Initial 1OM FL % % pH and Cf/gal (CP) #/100 ft2 Gel Gel CC/30M Oil Solids T),pe of Mud Surf 8.8 Funnel Gel -Benex to to 100- 40-60 30+ 50+ 25 0 8 Spud Mud 13-3/8" 9.2 250 Csg Poi nt 13-3/8" 8.8 Minimum 2 2 5 25 3.5 Low solids/ Csg Shoe to Possible to to to to 0 to non-dispersed to 9.4 4 4 10 10 6.5 K-10 K-lO 9.2 10 6 4 8 8 2 4 pH 9-10 to TD to to to to to to to to Low solids/ 9-5/8" 9.8 15 10 8 12 4 5 8 non-dispersed Csg Point 9-5/8" 8.8 10 20 10 10 10 2 4 Low solids/ Csg Shoe to to to to to to to to non-di spersed to TD 9.2 15 30 16 16 4 5 8 EQUIPMENT - DRILLING FLUID SYSTEM 1. Degasser 2. Shakers 3. Pit level indicator (with both visual and audio warning devices) 4. Drilling fluid flow sensor (with readout convenient to the driller's console) 5. Trip tank 6. Agitators 7. Mud cleaner and centrifuges PD3/031 .4 TYPICAL MUD PIT SCHEMATIC BBLS BBLS TRIP TANKS SANDTRAP (30 BilLS) JSHAKER I DEGASSER (83 SeseLS) DESILTER (97 BBLS) ISHAKER I I PILL PIT (36 BBLS) DESANDER (97 BBLS) (38 BBLS) SUCTION PIT (448 BBLS) MIX PIT (122 BBLS) DRAWING IS NOT TO SCALE NOTE: SYSTEM IS EQUIPPED WITH A DRILLING FLUID PIT LEVEL INDICATOR WITH BOTH VISUAL AND AUDIO WARNING DEVICES AND A FLUID FLOW SENSOR LOCATED IN THE IMMEDIATE AREA OF THE DRILLER'S CONSOLE. JG 7/24/87 ARCO Alaska, Inc Post Office ~e× ~0036© Te~e~he~-~e 907 ~7,% ~2~5 May 3, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' ~Fa~ion Plat Dear Mr. Chatterton- Enclosed are as-built location plats for the subject wells. questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG:pk GRU13/11 Enclosure If you have any 033 ~ ~ ION. 9 I0 NO $C4L~ , -- '" ~ 160 ~ ~ 150 o~ ~ ~ o~ ~1 024200 i k 140 ~5 ~ : I~ X=674,865.286 LONG.=I48°35 i~ ~ 2363' EN.L.~ 1636' KE.L. ELEK = 42.0 ~ , 260 ~ ~ 06 ~ ~ lOc j ~ OY ~ X= 674,878.91 LONG.=I48°3~'I~.~80 ~ ~ ~ ~ ; ~4~1 'EN.L., 1623'~E.L. ELEK = 42.0 I ~ ~ 9'AO 37e ~ j~ 037-A · ~'~N.L. 1599'~E.L. ELE~ = 42.3 "' /70 ~ 280 ~ ' ~9 · I' · o ~ ~ 2ro ~.~o LEG END 0 EXIE~IN6 WELL I. 8A~IS OF LOC~ION I~ D.S. 14 CONDUCtOrS · CONDUCTOR ~S-BUILT 20~1 ~ ~UIL~S PER VECO, INC. NAD ~X DATUM. REC - IV'ED M A ARCO PROPERLY REGISTERED AND Alalka, Inc, LICENSED TO PRACTICE LAND ~*~~~~~ ....................... "" ........ fl ~IL L SI~E A~S~ AND THAT THIS ~T ~~. ~s ~~~ CONOUCrORS 37, 38,39 8 40 RE~ESENTS AN AS-BUILT SU~EY 'J~~.~.~~~~~~ AS- BUILT LOCA TI ON ARE CORRECT, AS OF: I~ ~ ~ {~ o CHEC LZST FOS WELL PmU TS ITEM APPROVE 'DATE Loc PC_ ' ' (2 chh, 8')-' . 3. 4. 5. 6. 7. > (9 thru 13) i0. <4) (i4 thru 22) (5) BOPE (23 thru 28) ! '~'29- thru' 31) rev: 08/11/88 ~.01I Company ~rc_~ /F//'m,~__, ,,, '~C,, , Lease & Well No. - YES NO the permit fee attached ' --~ ...................®..................--.- Is well to be located in a defined pool ............................. Is well located proper distance from property line .................. Is weil located proper distance from other wells .................... Is sufficient undedicated acreage available in this po°l ............ Is well to be deviated and is wellbore plat included., .............. Is operator the only affected party e.e.eeee.eeee.eee... ....e.ee.... Can permit be approved before fifteen-day.wait ....................... REMARKS Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~_ Does the well have a unique name and number ........................ ~ 14. Is conductor string provided ........................................ 15. Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... 16. Is enough cement used to circulate on conductor and surface ......... 17. Will cement tie in surface and intermediate or production strings ... 18. Will cement cover all known productive horizons ..................... 19. Will all casing give adequate safety in collapse, tension and burst.. 20. Is this well to be kicked off from an existing weilbore ............. 21. Is old wellbore abandonment.procedure included on 10-403 ............ 22. Is adequate wellbore separation proposed ............................ 23. Is a diverter system required ....................................... 24. Is the drilling fluid program schematic and list of equipment adequate,~-~ 25. Are necessary diagrams and descriptions of diverter and BOPE attached./~... 26. Does BOPE have sufficient pressure rating - Test to .~ o~ psig .. 27. Does the choke manifold comply w/AP1 RP-53 (May 84)... ' ............. 28. Is the presence of ~2S gas probable ................................. For exploratory and Stratigraphi¢ wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ............ 31. If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. INITIAL GEO. -UNIT ON/OFF /~-2~ POOL CLASS STATUS AREA _NO. SHORE ..... /&'-17 ~, ~o5'~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APpENDIX~ .. No special'effort has been made to chronologically" ~ · .. organize this category of information. ][aska Oil.& Gtts Cons. Commission AnChoraoe IED
